Kinder Morgan (KMI) 10-Q 30 Oct 13 2013 Q3 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Jun. 29, 2012	Oct. 25, 2013	Oct. 25, 2013	Oct. 25, 2013	Oct. 25, 2013
				Class A [Member]	Class B [Member]	Class C [Member]	Class P [Member]
Entity Information [Line Items]
Severance Costs		$157,000,000
Legal Fees and Reserves		96,000,000
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			$16,375,009,661
Entity Common Stock, Shares Outstanding				0	0	0	1,035,849,756
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q3
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	30-Sep-13

CONSOLIDATED_STATEMENTS_OF_INC

CONSOLIDATED STATEMENTS OF INCOME (Unaudited) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Revenues [Abstract]
Natural gas sales	$968	$670	$2,649	$1,751
Services	1,675	1,531	4,881	3,400
Product sales and other	1,113	669	2,668	1,743
Total Revenues	3,756	2,870	10,198	6,894
Operating Costs, Expenses and Other
Costs of sales	1,543	854	3,767	2,071
Operations and maintenance	517	491	1,579	1,184
Depreciation, depletion and amortization	467	403	1,327	1,010
General and administrative	158	186	481	816
Taxes, other than income taxes	95	88	295	207
Other income, net	-65	-4	-81	-22
Total Operating Costs, Expenses and Other	2,715	2,018	7,368	5,266
Operating Income (Loss) [Abstract]
Operating Income	1,041	852	2,830	1,628
Other Income (Expense)
Earnings from equity investments	100	101	294	238
Amortization of excess cost of equity investments	-11	-5	-29	-9
Interest expense, net	-418	-523	-1,247	-993
Gain on remeasurement of previously held equity interest in Eagle Ford to fair value (Note 2)	0	0	558	0
Gain on sale of investments in Express pipeline system (Note 2)	-1	0	224	0
Other, net	11	21	35	29
Total Other Income (Expense)	-319	-406	-165	-735
Income from Continuing Operations Before Income Taxes	722	446	2,665	893
Income Tax Expense	-171	-60	-675	-165
Income from Continuing Operations	551	386	1,990	728
Discontinued Operations (Notes 1 and 2)
Income from operations of KMPbs FTC Natural Gas Pipelines disposal group and other, net of tax	0	48	0	145
Loss on sale and the remeasurement of KMPbs FTC Natural Gas Pipelines disposal group to fair value, net of tax	0	-179	-2	-934
Loss from Discontinued Operations, Net of Tax	0	-131	-2	-789
Net Income (Loss)	551	255	1,988	-61
Net (Income) Loss Attributable to Noncontrolling Interests	-265	-55	-1,133	156
Net Income Attributable to Kinder Morgan, Inc.	$286	$200	$855	$95
Diluted Weighted-Average Number of Shares Outstanding
Dividends Per Common Share Declared for the Period	$0.41	$0.36	$1.19	$1.03
Class P [Member]
Earnings Per Share, Basic and Diluted [Abstract]
Basic and Diluted Earnings Per Common Share From Continuing Operations	$0.27	$0.21	$0.82	$0.33
Basic and Diluted Loss Per Common Share From Discontinued Operations	$0	($0.02)	$0	($0.22)
Total Basic and Diluted Earnings Per Common Share	$0.27	$0.19	$0.82	$0.11
Basic Weighted-Average Number of Shares Outstanding
Basic Weighted-Average Number of Shares Outstanding	1,036	605	1,036	366
Diluted Weighted-Average Number of Shares Outstanding
Diluted Weighted-Average Number of Shares Outstanding	1,036	1,039	1,036	864
Dividends Per Common Share Declared for the Period	$0.41	$0.36	$1.19	$1.03
Class A [Member]
Earnings Per Share, Basic and Diluted [Abstract]
Basic and Diluted Earnings Per Common Share From Continuing Operations		$0.19		$0.26
Basic and Diluted Loss Per Common Share From Discontinued Operations		($0.02)		($0.22)
Total Basic and Diluted Earnings Per Common Share		$0.17		$0.04
Basic Weighted-Average Number of Shares Outstanding
Basic Weighted-Average Number of Shares Outstanding		432		496
Diluted Weighted-Average Number of Shares Outstanding
Diluted Weighted-Average Number of Shares Outstanding		432		496

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Kinder Morgan, Inc.
Net income (loss) attributable to KMI	$286	$200	$855	$95
Other comprehensive income (loss), net of tax
Change in fair value of derivatives utilized for hedging purposes (net of tax benefit (expense) of $19, $19, $9, and $(15), respectively)	-42	-30	-22	25
Reclassification of change in fair value of derivatives to net income (net of tax (expense) benefit of $(5), $2, $(2), and $(1), respectively)	10	-5	5	1
Foreign currency translation adjustments (net of tax (expense) benefit of $(7), $(13), $12, and $(13), respectively)	17	22	-28	21
Adjustments to pension and other postretirement benefit plan liabilities (net of tax (expense) benefit of $(36), $1, $(37), and $(7), respectively)	66	-1	66	12
Total other comprehensive income (loss)	51	-14	21	59
Total comprehensive income	337	186	876	154
Noncontrolling Interests
Net (Income) Loss Attributable to Noncontrolling Interests	265	55	1,133	-156
Other comprehensive income (loss), net of tax (see Note 10)
Change in fair value of derivatives utilized for hedging purposes (net of tax benefit (expense) of $6, $5, $4, and $(5), respectively)	-38	-41	-27	46
Reclassification of change in fair value of derivatives to net income (net of tax (expense) benefit of $(2), $-, $(1), and $(1), respectively)	9	-5	5	4
Foreign currency translation adjustments (net of tax (expense) benefit of $(2), $(4), $4, and $(4), respectively)	16	32	-26	31
Adjustments to pension and other postretirement benefit plan liabilities (net of tax (expense) benefit of $(2), $1, $(2), and $1, respectively)	13	-2	13	-2
Total other comprehensive income (loss)	0	-16	-35	79
Total comprehensive income (loss)	265	39	1,098	-77
Total
Net income (loss)	551	255	1,988	-61
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Change in fair value of derivatives utilized for hedging purposes (net of tax benefit (expense) of $25, $24, $13, and $(20), respectively)	-80	-71	-49	71
Reclassification of change in fair value of derivatives to net income (net of tax (expense) benefit of $(7), $2, $(3) and $(2), respectively)	19	-10	10	5
Foreign currency translation adjustments (net of tax (expense) benefit of $(9), $(17), $16, and $(17), respectively)	33	54	-54	52
Adjustments to pension and other postretirement benefit plan liabilities (net of tax (expense) benefit of $(38), $2, $(39), and $(6), respectively)	79	-3	79	10
Total other comprehensive income (loss)	51	-30	-14	138
Total comprehensive income	$602	$225	$1,974	$77

CONSOLIDATED_STATEMENTS_OF_COM1

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Other comprehensive income (loss) tax (benefit) expense attributable to Kinder Morgan, Inc.
Change in fair value of derivatives utilized for hedging purposes, tax benefit attributable to KMI	$19	$19	$9	($15)
Reclassification of change in fair value of derivatives to net income, tax expense attributable to KMI	-5	2	-2	-1
Foreign currency translation adjustments, tax expense attributable to KMI	-7	-13	12	-13
Adjustments to pension and other postretirement benefit liabilities, tax benefit attributable to KMI	-36	1	-37	-7
Other comprehensive income loss tax portion attributable to noncontrolling interests
Change in fair value of derivatives utilized for hedging purposes, tax benefit attributable to noncontrolling interests	6	5	4	-5
Reclassification of change in fair value of derivatives to net income, tax expense attributable to noncontrolling interests	-2	0	-1	-1
Foreign currency translation adjustments, tax expense attributable to noncontrolling interests	-2	-4	4	-4
Adjustments to pension and other postretirement benefit liabilities, tax benefit attributable to noncontrolling interests	-2	1	-2	1
Other comprehensive income loss tax portion total
Change in fair value of derivatives utilized for hedging purposes, tax benefit total	25	24	13	-20
Reclassification of change in fair value of derivatives to net income, tax expense total	-7	2	-3	-2
Foreign currency translation adjustments, tax expense total	-9	-17	16	-17
Adjustments to pension and other postretirement benefit plan liabilities, tax benefit total	($38)	$2	($39)	($6)

CONSOLIDATED_BALANCE_SHEETS_Un

CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Assets
Cash and cash equivalents	$816	$714
Accounts receivable, net	1,420	1,333	[1]
Inventories	435	374	[1]
Assets held for sale	0	298	[1]
Deferred income taxes	428	539
Other current assets	492	416	[1]
Total current assets	3,591	3,674	[1]
Property, plant and equipment, net (Note 14)	35,275	30,996	[1]
Investments	6,044	5,804	[1]
Goodwill (Note 14)	24,494	23,632	[1]
Other intangibles, net	2,474	1,171	[1]
Deferred charges and other assets	2,697	2,968	[1]
Total Assets	74,575	68,245	[1]
Liabilities [Abstract]
Current Portion of Debt (Note 14)	2,973	2,401
Accounts payable	1,427	1,248	[1]
Accrued interest	391	513	[1]
Accrued other current liabilities	1,624	1,066	[1]
Total current liabilities	6,415	5,228	[1]
Long-term debt outstanding	30,814	29,309
Debt fair value adjustments	2,124	2,591	[1]
Total long-term debt	33,038	32,000	[1]
Deferred income taxes	4,314	4,071	[1]
Other long-term liabilities and deferred credits	2,506	2,846	[1]
Total long-term liabilities and deferred credits	39,858	38,917	[1]
Total Liabilities	46,273	44,145	[1]
Preferred stock, $0.01 par value, 10,000,000 shares authorized, none outstanding	0	0	[1]
Additional paid-in capital	14,636	14,917	[1]
Retained deficit	-1,284	-943	[1]
Accumulated other comprehensive loss	-97	-118	[1]
Total Kinder Morgan, Inc.bs stockholdersb equity	13,265	13,866	[1]
Noncontrolling interests	15,037	10,234	[1]
Total Stockholdersb Equity	28,302	24,100	[1]
Total Liabilities and Stockholdersb Equity	74,575	68,245	[1]
Regulatory Assets	540	464
KMI $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock [Member] | Mezzanine Equity, Cumulative Preferred Stock With Liquidation Approval Rights [Member]
Liabilities [Abstract]
Total long-term debt	100	100
Class P [Member]
Liabilities [Abstract]
Class P shares, $0.01 par value, 2,000,000,000 shares authorized, 1,035,846,825 and 1,035,668,596 shares, respectively, issued and outstanding	10	10	[1]
Kinder Morgan, Inc. [Member]
Assets
Cash and cash equivalents	137	71	[1]
Property, plant and equipment, net (Note 14)	2,630	2,735
Goodwill (Note 14)	17,940	18,193
Liabilities [Abstract]
Current Portion of Debt (Note 14)	2,195	1,153	[1]
Long-term debt excluding preferred interest	7,724	9,148	[1]
Total long-term debt	7,724	9,148
KMP and EPB [Member]
Assets
Cash and cash equivalents	679	643	[1]
Liabilities [Abstract]
Current Portion of Debt (Note 14)	778	1,248	[1]
Long-term debt excluding preferred interest	23,090	20,161	[1]
Kinder Morgan Energy Partners, L.P. and El Paso Pipeline Partners, L.P. [Member]
Liabilities [Abstract]
Total long-term debt	$23,090	$20,161
[1]	(a)Retrospectively adjusted as discussed in Note 2.

CONSOLIDATED_BALANCE_SHEETS_Un1

CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Preferred Stock, Shares Authorized	10,000,000	10,000,000
Stockholders' Equity
Preferred Stock, Par or Stated Value Per Share	$0.01	$0.01
Class P [Member]
Stockholders' Equity
Common stock, par value (in dollars per share)	$0.01	$0.01
Common Stock, Shares Authorized	2,000,000,000	2,000,000,000
Common Stock, Shares, Issued	1,035,846,825	1,035,668,596
Common stock, shares outstanding (in shares)	1,035,846,825	1,035,668,596

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Net income (loss)	$1,988	($61)
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depreciation, depletion and amortization	1,327	1,017
Deferred income taxes	474	20
Amortization of excess cost of equity investments	29	9
(Gain) Loss on sale and the remeasurement of KMP's FTC Natural Gas Pipelines disposal group to to fair value, net of tax	-558	856
Gain from the sale of investments in Express pipeline system (Note 2)	-224
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax	2	78
Loss on early extinguishment of debt	0	82
Non-cash compensation expense on settlement of EP stock awards	0	87
Earnings from equity investments	-294	-302
Distributions from equity investments	303	290
Proceeds from termination of interest rate swap agreements	96	53
Pension contributions in excess of expense	-59	-9
Changes in components of working capital
Accounts receivable	126	-25
Inventories	-57	-99
Other current assets	53	40
Accounts payable	-232	-47
Accrued interest	-133	-175
Accrued other current liabilities	20	79
Rate reparations, refunds and other litigation reserve adjustments	174	-23
Other, net	-258	57
Net Cash Provided by Operating Activities	2,777	1,927
Cash Flows From Investing Activities
Acquisitions of assets and investments	-292	-72
Repayments from related party	10	48
Capital expenditures	-2,270	-1,399
Contributions to investments	-171	-158
Proceeds from Sale of Property, Plant, and Equipment	74	40
Distributions from equity investments in excess of cumulative earnings	117	159
Other, net	4	-13
Net Cash Used in Investing Activities	-2,038	-6,365
Cash Flows From Financing Activities
Debt issue costs	-23	-104
Cash dividends	-1,196	-810
Warrants repurchased	-463	-136
Contributions from noncontrolling interests	1,420	1,404
Distributions to noncontrolling interests	-1,220	-853
Proceeds from (Payments for) Other Financing Activities	1	-18
Net Cash Provided by (Used in) Financing Activities	-625	4,789
Effect of Exchange Rate on Cash and Cash Equivalents	-12	13
Cash and Cash Equivalents, Period Increase (Decrease)	102	364
Cash and Cash Equivalents, beginning of period	714	411
Cash and Cash Equivalents, end of period	816	775
Noncash Investing and Financing Activities
Liabilities settled by the issuance of shares and warrents	0	12
Stock and Warrants Issued During Period, Value, Acquisitions	0	11,464
Supplemental Disclosures of Cash Flow Information
Assets acquired by the assumption or incurrance of liabilities	1,487	0
Assets acquired or liabilities settled by contributions from noncontrolling interests	3,733	306
Cash paid during the period for interest (net of capitalized interest)	1,362	1,051
Increase in accrual for capital expenditures	240	74
Net cash paid during the period for income taxes	82	175
Express Pipeline System [Member]
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Gain from the sale of investments in Express pipeline system (Note 2)		0
Cash Flows From Investing Activities
Proceeds from Sale of Investments	402	0
El Paso Corporation [Member]
Cash Flows From Investing Activities
Acquisitions of assets and investments	0	-4,970
BBPP Holdings Ltda [Member]
Cash Flows From Investing Activities
Proceeds from Sale of Investments	88	0
Kinder Morgan, Inc. [Member]
Cash Flows From Financing Activities
Issuance of debt	1,592	7,244
Payment of debt	-1,985	-4,864
KMP and EPB [Member]
Cash Flows From Financing Activities
Issuance of debt	7,915	8,483
Payment of debt	($6,666)	($5,557)

CONSOLIDATED_STATEMENTS_OF_CAS1

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) Parenthetical (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
El Paso Corporation [Member]
Cash Acquired from Acquisition	$6,581
Other Acquisitions [Member]
Cash Acquired from Acquisition	$30

CONSOLIDATED_STATEMENTS_OF_STO

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Unaudited) Statement (USD $)		Total		Common Stock [Member]	Additional Paid-in Capital [Member]	Kinder Morgan, Inc. [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	KMI [Member]	Noncontrolling Interest [Member]	KMP, EPB and KMR [Member]	KMP, EPB and KMR [Member]	KMP, EPB and KMR [Member]	KMP, EPB and KMR [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	EP Trust I Preferred [Member]	EP Trust I Preferred [Member]	EP Trust I Preferred [Member]	Class P [Member]	Class P [Member]	Class P [Member]	El Paso Corporation [Member]	El Paso Corporation [Member]	El Paso Corporation [Member]	El Paso Corporation [Member]	El Paso Corporation [Member]
In Millions												Additional Paid-in Capital [Member]	KMI [Member]	Noncontrolling Interest [Member]		Additional Paid-in Capital [Member]	KMI [Member]	Noncontrolling Interest [Member]		Additional Paid-in Capital [Member]	KMI [Member]		Retained Earnings [Member]	KMI [Member]		Common Stock [Member]	Additional Paid-in Capital [Member]	KMI [Member]	Noncontrolling Interest [Member]
Total Stockholders' Equity at Dec. 31, 2011		$8,568
Noncontrolling interests at Dec. 31, 2011										5,247
Stockholders' Equity Attributable to KMI 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
Warrants repurchased		-136			-136				-136
Conversions of EP Trust I Preferred securities																			11	11	11
Cash paid for Class P Share cancelation																						-15	-15	-15
Amortization of restricted shares		9			9				9
Impact of subidiary equity transactions															-29	47	47	-76
Tax impact on stock based compensation		101			101				101
Net income (loss) attributable to KMI		95					95		95
Net Income (Loss) Attributable to Noncontrolling Interest		156								-156
Net income (loss), including portion attributable to noncontrolling interests		-61
Distributions		853							0	-853
Contributions		1,710							0	1,710
Noncontrolling Interest, Increase from Business Combination																									3,797			0	3,797
Dividends, Common Stock, Cash		-810					-810		-810
Other		-4							0	4
Other comprehensive income (loss), net of tax, portion attributable to KMI		59						59	59
Other comprehensive income (loss), net of tax, portion attributable to noncontrolling interests		79								79
Total other comprehensive loss		138
Total Stockholders' Equity at Sep. 30, 2012		23,898
Noncontrolling interests at Sep. 30, 2012										9,752
Stockholders' Equity Attributable to KMI at Sep. 30, 2012				11	14,924		-733	-56	14,146
Total Stockholders' Equity at Dec. 31, 2012	[1]	24,100
Noncontrolling interests at Dec. 31, 2012		10,234	[1]							10,234					3,270
Stockholders' Equity Attributable to KMI at Dec. 31, 2012		13,866	[1]	10	14,917		-943	-118	13,866
Warrants repurchased		-463			-463				-463
Warrants exercised		1			1				1
Conversions of EP Trust I Preferred securities																			3	3	3
Amortization of restricted shares		24			24				24
Impact of subidiary equity transactions											-90	154	154	-244
Tax impact on stock based compensation		1			1				1
Net income (loss) attributable to KMI		855					855		855
Net Income (Loss) Attributable to Noncontrolling Interest		-1,133								1,133
Net income (loss), including portion attributable to noncontrolling interests		1,988
Distributions		1,220							0	-1,220
Contributions		5,153							0	5,153
Noncontrolling Interest, Increase from Business Combination		17							0	17
Dividends, Common Stock, Cash		-1,196					-1,196		-1,196
Other		2			1	1				1
Other comprehensive income (loss), net of tax, portion attributable to KMI		21						21	21
Other comprehensive income (loss), net of tax, portion attributable to noncontrolling interests		-35								-35
Total other comprehensive loss		-14
Total Stockholders' Equity at Sep. 30, 2013		28,302
Noncontrolling interests at Sep. 30, 2013		15,037								15,037					7,612
Stockholders' Equity Attributable to KMI at Sep. 30, 2013		$13,265		$10	$14,636		($1,284)	($97)	$13,265
[1]	(a)Retrospectively adjusted as discussed in Note 2.

General_Notes

General (Notes)	9 Months Ended
	Sep. 30, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General	General
	Organization
	Kinder Morgan, Inc. is the largest midstream and the third largest energy company in North America with a combined enterprise value of approximately $110 billion. We own an interest in or operate approximately 82,000 miles of pipelines and 180 terminals. Our pipelines transport natural gas, refined petroleum products, crude oil, CO2 and other products, and our terminals store petroleum products and chemicals, and handle such products as ethanol, coal, petroleum coke and steel. We are also the leading producer and transporter of CO2 for enhanced oil recovery projects in North America.
	Effective on May 25, 2012, we completed the acquisition of all of the outstanding shares of EP. As a result, we own a 41% limited partner interest and the 2% general partner interest in EPB, as well as certain natural gas pipeline assets.
	We also own the general partner and approximately 10% of the limited partner interests of KMP, one of the largest publicly-traded pipeline limited partnerships in America.
	Our common stock trades on the NYSE under the symbol “KMI.”
	KMR is a Delaware limited liability company.  KMGP, the general partner of KMP and a wholly-owned subsidiary of ours, owns all of KMR’s voting shares.  KMR, pursuant to a delegation of control agreement, has been delegated, to the fullest extent permitted under Delaware law, all of KMGP’s power and authority to manage and control the business and affairs of KMP, subject to KMGP’s right to approve certain transactions.
	Basis of Presentation
	General
	We have prepared our accompanying unaudited consolidated financial statements 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. Under such rules and regulations, we have condensed or omitted certain information and notes normally included in financial statements prepared in conformity with the Codification.  We believe, however, that our disclosures are adequate to make the information presented not misleading.
	Our accompanying unaudited consolidated financial statements reflect normal adjustments, and also recurring adjustments that are, in the opinion of our management, necessary for a fair statement of our financial results for the interim periods. In addition, certain amounts from prior periods have been reclassified to conform to the current presentation (including reclassifications between “Services” and “Product sales and other” within the “Revenues” section of our accompanying consolidated statements of income). Interim results are not necessarily indicative of results for a full year; accordingly, you should read these consolidated financial statements in conjunction with our consolidated financial statements and related notes included in our Annual Report on Form 10-K for the year ended December 31, 2012 (2012 Form 10-K).
	Our accounting records are maintained in United States dollars, and all references to dollars are United States dollars, except where stated otherwise.  Canadian dollars are designated as C$.  Our consolidated financial statements include our accounts and those of our majority-owned subsidiaries as well as the accounts of KMP, EPB and KMR.  Investments in jointly-owned operations in which we hold a 50% or less interest (other than KMP, EPB and KMR, because we have the ability to exercise significant control over their operating and financial policies) are accounted for under the equity method.  All significant intercompany transactions and balances have been eliminated in consolidation.
	Notwithstanding the consolidation of KMP and EPB, and their respective subsidiaries, into our financial statements, we are not liable for, and our assets are not available to satisfy, the obligations of KMP and EPB, and/or their respective subsidiaries, and vice versa, except as discussed in Note 11, “—Other Contingencies.”  Responsibility for payments of obligations reflected in our, KMP or EPB’s financial statements is a legal determination based on the entity that incurs the liability.
	KMP’s FTC Natural Gas Pipelines Disposal Group - Discontinued Operations
	Effective November 1, 2012, we sold KMP’s (i) Kinder Morgan Interstate Gas Transmission natural gas pipeline system; (ii) Trailblazer natural gas pipeline system; (iii) Casper and Douglas natural gas processing operations; and (iv) 50% equity investment in the Rockies Express natural gas pipeline system to Tallgrass Energy Partners, LP (now known as Tallgrass Development, LP) (Tallgrass) for approximately $1.8 billion in cash (before selling costs), or $3.3 billion including KMP’s share of joint venture debt. In this report, we refer to this combined group of assets as KMP’s FTC Natural Gas Pipelines disposal group. For more information about the presentation of KMP’s FTC Natural Gas Pipelines disposal group as discontinued operations, see Note 2 “Summary of Significant Accounting Policies—Basis of Presentation” to our consolidated financial statements included in our 2012 Form 10-K.
	Goodwill
	We evaluate goodwill for impairment on May 31 of each year.  For this purpose, we have seven reporting units as follows: (i) Products Pipelines—KMP (excluding associated terminals); (ii) Products Pipelines Terminals—KMP (evaluated separately from Products Pipelines—KMP for goodwill purposes); (iii) Natural Gas Pipelines Regulated; (iv) Natural Gas Pipelines Non—Regulated; (v) CO2—KMP; (vi) Terminals—KMP; and (vii) Kinder Morgan Canada—KMP.  During the quarter ended June 30, 2013, the Natural Gas Pipelines Non-Regulated reporting unit was created to include the non-regulated businesses KMP 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). Goodwill was allocated 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, 2013 impairment testing, and no event indicating an impairment has occurred subsequent to that date.
	The fair value of each reporting unit was determined 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.
	Earnings per Share
	For the three and nine months ended September 30, 2013, earnings per share was calculated using the two-class method.  Earnings were allocated to Class P shares of common stock and to 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. For the three and nine months ended September 30, 2013, the following potential Class P common shares are antidilutive and, accordingly, are excluded from the determination of diluted earnings per share; (i) 6 million and 3 million, respectively, related to unvested restricted stock awards; (ii) 400 million and 419 million, respectively, related to outstanding warrants to purchase our Class P shares; and (iii) 10 million for each period, related to convertible trust preferred securities.
	The following table sets forth the allocation of net income for Class P shares and for participating securities for the three and nine months ended September 30, 2013 (in millions):
		Three Months Ended September 30, 2013			Nine Months Ended September 30, 2013
		Net Income Available to Shareholders
	Class P	$	283		$	851
	Participating securities(a)	3			4
	Net Income Attributable to Kinder Morgan, Inc.	$	286		$	855
	_______
	(a)	Participating securities are unvested restricted stock awards issued to management employees that contain non-forfeitable rights to dividend equivalent payments.
	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.
	For the three and nine months ended September 30, 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 dilutive potential shares.  This included 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, dilutive potential shares also included the Class P shares issuable in connection with the warrants and the trust preferred securities (see Note 4).  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 three and nine months ended September 30, 2012, the following potential Class P common shares were antidilutive and, accordingly, were excluded from the determination of diluted earnings per share; (i) 450 million and 457 million, respectively, related to outstanding warrants to purchase our Class P shares; and (ii) 11 million for each period, 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 three and nine months ended September 30, 2012 (in millions, except per share amounts):
		Three Months Ended September 30, 2012
		Income from Continuing Operations Available to Shareholders
		Class P			Class A			Participating			Total
								Securities (a)
	Income from continuing operations										$	386
	Less: income from continuing operations attributable to noncontrolling interests										(171		)
	Income from continuing operations attributable to KMI										215
	Dividends paid in the period	$	212		$	142		$	10		(364		)
	Excess distributions over earnings	(87		)	(62		)	—			$	(149	)
	Income from continuing operations attributable to shareholders	$	125		$	80		$	10		$	215
	Basic earnings per share from continuing operations
	Basic weighted-average number of shares outstanding	605			432			N/A
	Basic earnings per common share from continuing operations(b)	$	0.21		$	0.19		N/A
	Diluted earnings per share from continuing operations
	Income from continuing operations attributable to shareholders and assumed conversions(c)	$	215		$	80		N/A
	Diluted weighted-average number of shares	1,039			432			N/A
	Diluted earnings per common share from continuing operations(b)	$	0.21		$	0.19		N/A
		Nine Months Ended September 30, 2012
		Income from Continuing Operations Available to Shareholders
		Class P			Class A			Participating			Total
								Securities (a)
	Income from continuing operations										$	728
	Less: income from continuing operations attributable to noncontrolling interests										(441		)
	Income from continuing operations attributable to KMI										287
	Dividends paid in the period	$	343		$	432		$	35		(810		)
	Excess distributions over earnings	(221		)	(301		)	(1		)	$	(523	)
	Income from continuing operations attributable to shareholders	$	122		$	131		$	34		$	287
	Basic earnings per share from continuing operations
	Basic weighted-average number of shares outstanding	366			496			N/A
	Basic earnings per common share from continuing operations(b)	$	0.33		$	0.26		N/A
	Diluted earnings per share from continuing operations
	Income from continuing operations attributable to shareholders and assumed conversions(c)	$	287		$	131		N/A
Diluted weighted-average number of shares	864			496			N/A
Diluted earnings per common share from continuing operations(b)	$	0.33		$	0.26		N/A
The following tables set forth the computation of total basic and diluted earnings per share for the three and nine months ended September 30, 2012 (in millions, except per share amounts):
	Three Months Ended September 30, 2012
	Net Income Available to Shareholders
	Class P			Class A			Participating			Total
							Securities (a)
Net income attributable to KMI										$	200
Dividends paid in the period	$	212		$	142		$	10		(364		)
Excess distributions over earnings	(96		)	(68		)	—			$	(164	)
Net income attributable to shareholders	$	116		$	74		$	10		$	200
Basic earnings per share
Basic weighted-average number of shares outstanding	605			432			N/A
Basic earnings per common share(b)	$	0.19		$	0.17		N/A
Diluted earnings per share
Net income attributable to shareholders and assumed conversions(c)	$	200		$	74		N/A
Diluted weighted-average number of shares	1,039			432			N/A
Diluted earnings per common share(b)	$	0.19		$	0.17		N/A
	Nine Months Ended September 30, 2012
	Net Income Available to Shareholders
	Class P			Class A			Participating			Total
							Securities (a)
Net income attributable to KMI										$	95
Dividends paid in the period	$	343		$	432		$	35		(810		)
Excess distributions over earnings	(303		)	(410		)	(2		)	$	(715	)
Net income attributable to shareholders	$	40		$	22		$	33		$	95
Basic earnings per share
Basic weighted-average number of shares outstanding	366			496			N/A
Basic earnings per common share(b)	$	0.11		$	0.04		N/A
Diluted earnings per share
Net income attributable to shareholders and assumed conversions(c)	$	95		$	22		N/A
Diluted weighted-average number of shares	864			496			N/A
Diluted earnings per common share(b)	$	0.11		$	0.04		N/A
_______
(a)	Participating securities included Class B shares, Class C shares, and unvested restricted stock awards issued to non-senior management employees that contained rights to dividend equivalents in the case of the restricted shares.  Our Class B and Class C shares were entitled to participate in our earnings, only to the extent of cash distributions made to them. As a result, no earnings in excess of dividends received were allocated to the Class B and Class C shares in our determination of basic and diluted earnings per share.
(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 dilutive potential shares.

Acquisitions_and_Divestitures_

Acquisitions and Divestitures (Notes)	9 Months Ended
	Sep. 30, 2013
Business Combinations [Abstract]
Acquisitions and Divestitures	Acquisitions and Divestitures
	Copano Energy, L.L.C. Acquisition
	Effective May 1, 2013, KMP closed its acquisition of Copano. KMP 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 KMP common unit on the NYSE on the May 1, 2013 issuance date).
	KMP accounted for its acquisition of Copano under the acquisition method of accounting, and accordingly, measured the consideration paid to Copano unitholders, the acquired identifiable tangible and intangible assets, and the assumed liabilities at their acquisition-date fair values. Also, due to the fact that KMP’s acquisition included the remaining 50% interest in Eagle Ford that it did not already own, KMP remeasured its existing 50% equity investment in Eagle Ford to its fair value as of the acquisition date, resulting in the recognition of a $558 million pre-tax non-cash gain reported separately within “Other Income (Expense)” on our accompanying consolidated statement of income for the nine months ended September 30, 2013.
	As of September 30, 2013, KMP’s preliminary purchase price allocation related to the Copano acquisition, as adjusted to date, is as follows (in millions). KMP’s evaluation of the assigned fair values is ongoing and subject to adjustment:
	Preliminary Purchase Price Allocation:
	Current assets (including cash acquired of $30)	$	218
	Property, plant and equipment	2,805
	Investments	387
	Goodwill	1,119
	Other intangibles, net	1,375
	Other assets	13
	Total assets	5,917
	Less: Fair value of previously held 50% interest in Eagle Ford	(704		)
	Total assets acquired	5,213
	Current liabilities	(207		)
	Other liabilities	(4		)
	Long-term debt	(1,252		)
	Noncontrolling interests	(17		)
	KMP’s common unit consideration	$	3,733
	The “Goodwill” intangible asset amount represents the future economic benefits expected to be derived from this acquisition that are not assignable to other individually identifiable, separately recognizable assets acquired. KMP believes the primary items that generated the goodwill are the value of the synergies created by expanding its natural gas gathering and refined product transportation operations. This goodwill is not deductible for tax purposes and is subject to an impairment test at least annually. The “Other intangibles, net” asset amount represents the fair value of acquired customer contracts and agreements, which are currently being amortized over an estimated remaining useful life of 25 years.
	Copano provides comprehensive services to natural gas producers, including natural gas gathering, processing, treating and NGL fractionation.  Copano owns an interest in or operates approximately 6,900 miles of pipelines with 2.7 Bcf/d of natural gas transportation capacity, and also owns nine natural gas processing plants with more than 1 Bcf/d of natural gas processing capacity and 315 MMcf/d of natural gas treating capacity.  Its operations are located primarily in Texas, Oklahoma and Wyoming.  Most of the acquired assets are included in the Natural Gas Pipelines business segment.
	Impact of KMP’s Acquisition of Copano on KMI’s Income Taxes
	Our accounting policy is to apply 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. As a result of the goodwill recorded by KMP for its Copano acquisition, KMI’s deferred tax liability and goodwill were adjusted by $255 million for the portion of its outside basis difference associated with KMP’s underlying goodwill.
	KMI Acquisition of EP
	Effective on May 25, 2012, we acquired all of the outstanding shares of EP for an aggregate consideration of approximately $23 billion (excluding assumed debt). In total, EP shareholders received $11.6 billion in cash, 330 million KMI Class P shares with a fair value of $10.6 billion as of May 24, 2012 and 505 million KMI warrants with a fair value of $863 million as of May 24, 2012. The warrants have an exercise price of $40 per share and a 5-year term.
	We accounted for the EP acquisition using the acquisition method of accounting which requires, among other things, that assets acquired and liabilities assumed be recognized on the balance sheet at their acquisition date fair values. During the three months ended June 30, 2013, management completed its purchase accounting valuation estimates and, as a result, retrospectively adjusted the valuations of certain liabilities with a corresponding increase to goodwill as of the acquisition date. The retrospective adjustments amounted to approximately $60 million and primarily related to revisions of estimates related to certain environmental obligations, sales and use tax liabilities, and deferred income taxes.
	Goldsmith Landreth Unit
	On June 1, 2013, KMP acquired certain oil and gas properties, rights, and related assets in the Permian Basin of West Texas from Legado Resources LLC for approximately $285 million (before working capital adjustments). KMP also assumed $18 million of liabilities. The acquisition of the Goldsmith Landreth San Andres oil field unit includes more than 6,000 acres located in Ector County, Texas, and based on KMP’s measurement of fair values for all of the identifiable tangible and intangible assets acquired and liabilities assumed, KMP assigned the $285 million amount to “Property, plant and equipment, net.” 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. The field currently produces approximately 1,250 barrels of oil per day, and as part of the transaction, KMP obtained a long-term supply contract for up to 150 MMcf/d of CO2. The acquisition complements KMP’s existing oil and gas producing assets in the Permian Basin, and the acquired assets are included as part of the CO2—KMP business segment.
	Pro Forma Information
	The following summarized unaudited pro forma consolidated income statement information for the three and nine months ended September 30, 2013 and 2012, assumes that the EP, Copano and the Goldsmith Landreth Unit acquisitions had occurred as of January 1, 2012. 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, 2012 or the results that will be attained in the future. Amounts presented below are in millions, except for the per share amounts:
		Pro Forma
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Revenues	$	3,756		$	3,341		$	10,903		$	9,384
	Income from Continuing Operations	$	551		$	379		$	1,952		$	410
	(Loss) Income from Discontinued Operations, Net of Tax	$	—		$	(131	)	$	(2	)	$	1,279
	Net Income	$	551		$	248		$	1,950		$	1,689
	Net (Income) Loss Attributable to Noncontrolling Interests	$	(265	)	$	127		$	(1,120	)	$	291
	Net Income Attributable to Kinder Morgan, Inc.	$	286		$	375		$	830		$	1,980
	Diluted Earnings per Common Share
	Class P Shares	$	0.27		$	0.36		$	0.8		$	1.91
	Class A Shares				$	0.34					$	1.84
	KMP’s FTC Natural Gas Pipelines Disposal Group – Discontinued Operations
	We began accounting for KMP’s FTC Natural Gas Pipelines disposal group as discontinued operations in the first quarter of 2012 (prior to our sale announcement, we included the disposal group in the Natural Gas Pipelines business segment).  For the nine months ended September 30, 2012, we recognized a combined $934 million non-cash loss from both the remeasurement of the disposal group to fair value and from estimated costs to sell, and we reported this loss amount separately as “Loss on sale and the remeasurement of KMP’s FTC Natural Gas Pipelines disposal group to fair value, net of tax” within the discontinued operations section of our accompanying consolidated statement of income.
	KMP and Tallgrass trued up the final consideration for the sale of our FTC Natural Gas Pipelines disposal group in the first quarter of 2013, and based on this true up, we recognized an additional $2 million loss. We reported this loss amount separately as “Loss on sale and the remeasurement of KMP’s FTC Natural Gas Pipelines disposal group to fair value, net of tax” within the discontinued operations section of our accompanying consolidated statement of income for the nine months ended September 30, 2013, and except for this loss amount, no other financial results from the operations of KMP’s FTC Natural Gas Pipelines disposal group were recorded in the first nine months of 2013.
	Summarized financial information for KMP’s FTC Natural Gas Pipelines disposal group is as follows (in millions):
		Three Months Ended September 30, 2012			Nine Months Ended September 30, 2012
	Operating revenues	$	71		$	204
	Operating expenses	(45		)	(116		)
	Depreciation and amortization	—			(7		)
	Other expense	(1		)	(1		)
	Earnings from equity investments	22			64
	Interest income and Other, net	—			1
	Income from operations of KMP’s FTC Natural Gas Pipelines disposal group, net of tax	$	47		$	145
	Express Pipeline System
	Effective March 14, 2013, KMP sold both its one-third equity ownership interest in the Express pipeline system and its subordinated debenture investment in Express to Spectra Energy Corp. KMP received net cash proceeds of $402 million (after paying both a final working capital settlement and certain transaction related selling expenses in the current quarter), and we reported the net cash proceeds received from the sale separately as “Proceeds from sale of investments in Express pipeline system” within the investing section of our accompanying consolidated statement of cash flows. For the nine months ended September 30, 2013, we recognized a combined $224 million pre-tax gain with respect to this sale, and we reported this gain amount separately as “(Loss) gain on the sale of investments in Express pipeline system” on our accompanying consolidated statement of income. We also recorded an income tax expense of $84 million related to this nine month gain, and we included this expense within “Income Tax Expense” in our accompanying consolidated statement of income.
	As of the date of sale, KMP’s equity investment in Express totaled $67 million and its note receivable due from Express totaled $110 million. Prior to KMP’s sale, we (i) accounted for KMP’s equity investment under the equity method of accounting; (ii) accounted for KMP’s debt investment under the historical amortized cost method of accounting; and (iii) included the financial results of the Express pipeline system within the Kinder Morgan Canada—KMP business segment.  As of December 31, 2012, KMP’s equity and debt investments in Express totaled $65 million and $114 million, respectively, and we included the combined $179 million amount within “Assets held for sale” on our accompanying consolidated balance sheet.
	TGP’s Sale of Production Area Facilities
	On September 1, 2013, TGP sold certain natural gas facilities located offshore in the Gulf of Mexico and onshore in the state of Louisiana for an aggregate consideration of $32 million in cash. TGP’s net assets sold in this transaction (including assets identified as “held for sale”) totaled $88 million, and as a result of the sale, TGP recognized both a $92 million increase in regulatory assets pursuant to a FERC order, and a $36 million gain from the sale of assets. We included the cash proceeds received from the sale in 2013 within “Sale or casualty of property, plant and equipment, investments and other net assets, net of removal costs” within the investing section of our accompanying consolidated statement of cash flows for the nine months ended September 30, 2013, and we included the gain amount within “Other Income (Expense)” on our accompanying consolidated statements of income for the three and nine months ended September 30, 2013.
	BBPP Holdings Ltda
	As of December 31, 2012, we owned a 2% interest in Gas Transboliviano S.A., and 33 1/3% interest in BBPP Holdings Ltda which we acquired as a part of the May 25, 2012 EP acquisition. BBPP Holdings Ltda owned a 29% interest in Transportadora Brasileira Gasoduto Bolivia-Brasil S.A. which, together with Gas Transboliviano S.A., owned the Bolivia to Brazil Pipeline. On January 18, 2013, we completed the sale of our equity interests in the Bolivia to Brazil Pipeline for $88 million. As of December 31, 2012, our $88 million equity interests in the Bolivia to Brazil Pipeline was included within “Assets held for sale” on our accompanying consolidated balance sheet.
	Drop-Down of EP Assets to KMP
	Aug-12
Effective August 1, 2012, KMP acquired a 100% ownership interest in TGP and an initial 50% ownership interest in EPNG from us for an aggregate consideration of approximately $6.2 billion (including a proportional share of assumed debt borrowings as of August 1, 2012). For additional information about this acquisition, see Note 3 “Acquisitions and Divestitures—Drop-Down of EP Assets to KMP” to our consolidated financial statements included in our 2012 Form 10-K.
Mar-13
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 for an aggregate consideration of approximately $1.7 billion (including a proportional 50% share of assumed debt borrowings as of March 1, 2013). The consideration that we received from KMP consisted of (i) $994 million in cash (including $6 million in the second quarter of 2013 to settle the final working capital adjustment); (ii) 1,249,452 common units (valued at $108 million based on the $86.72 closing market price of KMP’s common unit on the NYSE on the March 1, 2013 issuance date); and (iii) $557 million in assumed debt (consisting of 50% of the outstanding principal amount of EPNG’s debt borrowings as of March 1, 2013, excluding any debt fair value adjustments). We used the proceeds from the March 1, 2013 drop-down transaction to (i) pay down $947 million of our senior secured term loan facility; and (ii) reduce borrowings under our credit facility. See Note 3 “Debt” for further discussion. The terms of the drop-down transaction were approved on our behalf by the independent members of our board of directors and on KMP’s behalf by the audit committees and the boards of directors of both KMGP, as KMP’s general partner, and KMR, in its capacity as the delegate of KMGP, following the receipt by our independent directors and by the audit committees of KMGP and KMR of separate fairness opinions from different independent financial advisors.
The drop-down transactions were accounted for as transfers of net assets between entities under common control. Specifically, we have retrospectively adjusted our consolidated financial statements to reflect the recognition by KMP of the acquired assets and assumed liabilities at our carrying value, including our EP purchase accounting adjustments as of May 25, 2012.  In this report, we refer to these acquisitions of assets by KMP from us as the drop-down transactions; the combined group of assets acquired by KMP from us as the drop-down asset groups; the El Paso Natural Gas pipeline system or El Paso Natural Gas Company, L.L.C. as EPNG; and the EP Midstream assets or Kinder Morgan Altamont LLC (formerly, El Paso Midstream Investment Company, L.L.C.) as the midstream assets.
Income Tax Impact of the Drop-Down of EP Assets to KMP
As discussed above, we accounted for the acquisition of EP as a business combination and for the subsequent March 2013 and August 2012 drop-down transactions as transfers of net assets between entities under common control. 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.
Our accounting policy is to apply 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. 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 will be amortized to income tax expense over the remaining useful lives of the transferred assets of approximately 25 years Similar to the impact described above, KMP’s acquisition of a 50% ownership interest in the EP Midstream joint venture, also generated the recognition of a deferred charge and corresponding deferred tax liability and is included in the amount above.
The amortization of the deferred charge will result in incremental income tax expense of approximately $20 million per year. For the three and nine months ended September 30, 2013, total income tax expense related to the amortization of the deferred charges was approximately $5 million and $15 million, respectively.

Debt_Debt_Disclosure_Notes

Debt Debt Disclosure (Notes)	9 Months Ended
	Sep. 30, 2013
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 deferred costs are then amortized as interest expense in our accompanying consolidated statements of income. The following table provides detail on the principal amount of our outstanding debt balances, as of September 30, 2013 and December 31, 2012. The table amounts exclude all debt fair value adjustments, including debt discounts and premiums (in millions).
			September 30, 2013			December 31, 2012
	KMI
	Senior term loan facility, variable rate, due 2015		$	1,528		$	2,714
	Senior notes and debentures, 5.15% through 7.45%, due 2015 through 2098		315			315
	Credit facility due December 31, 2014(a)		1,514			1,035
	Subsidiary borrowings (as obligor)
	K N Capital Trust I, deferrable interest debentures issued by subsidiary trusts, 7.63% and 8.56%, due 2027 and 2028		27			27
	Kinder Morgan Finance Company, LLC, senior notes, 5.70% through 6.40%, due 2016 through 2036		1,636			1,636
	El Paso, senior notes, 6.50% through 12.00%, due 2013 through 2037		3,860			3,860
	EPC Building, LLC promissory note, 3.967%, due 2013 through 2035(b)		464			217
	Colorado Interstate Gas Services Company, 7.76% Totem note payable, due 2018		1			1
	Other credit facilities due December 20, 2013, March 20 and June 20, 2014		293			210
	EP preferred securities, 4.75%, due March 31, 2028		281			286
	KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock		100			100
	Total debt — KMI		10,019			10,401
	Less: Current portion of debt — KMI		(2,195		)	(1,153		)
	Total long-term debt — KMI(c)		$	7,824		$	9,248
	KMP and EPB
	KMP
	Senior notes, 2.65% through 9.00% due 2013 through 2043(d)		$	16,100		$	13,350
	Commercial paper borrowings(e)		174			621
	Credit facility due May 1, 2018		—			—
	KMP subsidiary borrowings (as obligor)
	TGP senior notes, 7.00% through 8.375%, due 2016 through 2037(f)		1,790			1,790
	EPNG senior notes 5.95% through 8.625%, due 2017 through 2032(g)		1,115			1,115
	Copano senior notes, 7.125%, due April 1, 2021(h)		332			—
	Other miscellaneous subsidiary debt		101			186
	Total debt — KMP		19,612			17,062
	Less: Current portion of debt — KMP(i)		(702		)	(1,155		)
	Total long-term debt — KMP(c)		18,910			15,907
	EPB
	EPPOC
	Senior notes, 4.10% through 8.00% due 2013 through 2042(j)		2,260			2,348
	Credit facility due May 27, 2016(k)		—			—
	EPB subsidiary borrowings (as obligor)
	Colorado Interstate Gas Company, L.L.C. senior notes, 5.95% through 6.85%, due 2015 through 2037		475			475
	SLNG senior notes, 9.50% through 9.75%, due 2014 through 2016		135			135
	SNG notes, 4.40% through 8.00%, due 2017 through 2032		1,211			1,211
	Other financing obligations		175			178
	Total debt — EPB		4,256			4,347
	Less: Current portion of debt — EPB		(76		)	(93		)
	Total long-term debt — EPB(c)		4,180			4,254
	Total long-term debt — KMP and EPB		$	23,090		$	20,161
	_______
	(a)	As of September 30, 2013 and December 31, 2012, the weighted average interest rates on KMI’s credit facility borrowings were 2.68% and 2.72%, respectively.
	(b)	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. EPC Building, LLC, as the landlord, leases the property to KMI as a tenant.  Proceeds from the issuance of the notes were used to reduce KMI’s credit facility borrowings.
	(c)	Excludes debt fair value adjustments. As of September 30, 2013 and December 31, 2012, our “Debt fair value adjustments” increased our debt balances by $2,124 million and $2,591 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 5 “Risk Management—Fair Value of Derivative Contracts.”
	(d)	On February 28, 2013, KMP completed a public offering of $1 billion in principal amount of senior notes in two separate series, consisting of $600 million of 3.50% notes due September 1, 2023 and $400 million of 5.00% notes due March 1, 2043. KMP received net proceeds of $991 million, and used the proceeds to pay a portion of the purchase price for the March 2013 drop-down transaction and to reduce the borrowings under its commercial paper program. On August 5, 2013, KMP completed a public offering of $1.75 billion in principal amount of senior notes in three separate series, consisting of $800 million of 2.65% notes due February 1, 2019, $650 million of 4.15% notes due February 1, 2024 and $300 million of 5.00% notes due March 1, 2043 (the 5.00% notes issued in August 2013 constitute a further issuance of the $400 million aggregate principal amount of the 5.00% notes that KMP issued in February 2013 and form a single series with these notes). KMP received net proceeds of $1,724 million, and used the proceeds to reduce the borrowings of its commercial paper program and to fund its partial redemption and retirement of Copano’s 7.125% senior notes in September 2013 (see “—KMP’s Copano Debt” below).
	(e)	In May 2013, in association with the increase of capacity negotiated for KMP’s senior unsecured revolving bank credit facility (see “—Credit Facilities - KMP” below), KMP increased its commercial paper program by $500 million to provide for the issuance of up to $2.7 billion. As of September 30, 2013 and December 31, 2012, the average interest rates on KMP’s outstanding commercial paper borrowings were 0.27% and 0.45%, respectively. The borrowings under KMP’s commercial paper program were used principally to finance the acquisitions and capital expansions made during the first nine months of 2013 and during 2012, and in the near term, KMP expects that its short-term liquidity and financing needs will be met primarily through borrowings made under its commercial paper program.
	(f)	Consists of six separate series of fixed-rate unsecured senior notes that KMP assumed as part of the August 2012 drop-down transaction.
	(g)	Consists of four separate series of fixed-rate unsecured senior notes that KMP assumed as part of the August 2012 and March 2013 drop-down transactions.
	(h)	Consists of a single series of fixed-rate unsecured senior notes that KMP guaranteed as part of its May 1, 2013 Copano acquisition. The notes mature in full on April 1, 2021, and interest on the notes is payable semiannually on April 1 and October 1 of each year. For further information about these notes, see “—KMP’s Copano Debt” below.
	(i)	As of September 30, 2013 and December 31, 2012, includes commercial paper borrowings of $174 million and $621 million.
	(j)	In September 2013, EPPOC repaid $88 million of 8% senior notes.
	(k)	LIBOR plus 1.75%.
	KMP’s Copano Debt
	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. Immediately following the acquisition, KMP repaid the outstanding $404 million of borrowings under Copano’s revolving credit facility, and terminated the credit facility at the time of such repayment. On June 1, 2013, 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. As part of its May 1, 2013 purchase price allocation, KMP valued the 7.75% senior notes equal to the $259 million redemption value and accordingly, no gain or loss was recorded from this debt retirement. KMP utilized borrowings under its commercial paper program for both of these debt retirements.
	On September 4, 2013, KMP paid $191 million to complete the partial redemption and retirement of $178 million (35%) of the total $510 million outstanding principal amount of Copano’s 7.125% senior notes, (excluding a $6 million payment for accrued and unpaid interest on the redeemed notes as of September 4, 2013). As part of its May 1, 2013 purchase price allocation, KMP valued the 7.125% senior notes equal to the $191 million redemption value and accordingly, KMP recorded no gain or loss from this debt retirement. As of September 30, 2013, an aggregate principal amount of $332 million of 7.125% senior notes remained outstanding.
	Credit Facilities
	KMI
	As of September 30, 2013, we had $1,514 million outstanding under KMI’s $1.75 billion senior secured credit facility and $80 million in letters of credit. Our availability under this facility as of September 30, 2013 was approximately $156 million.
	KMP
On May 1, 2013, KMP replaced its previous $2.2 billion, senior unsecured revolving bank credit facility that was due July 1, 2016, with a new $2.7 billion five-year senior unsecured revolving credit facility expiring May 1, 2018. Borrowings under the credit facility can be used for general partnership purposes and as a backup for KMP’s commercial paper program. KMP had no borrowings under the credit facility as of September 30, 2013. The credit facility’s financial covenants are substantially similar to those in the previous facility, and as of September 30, 2013, KMP was in compliance with all required financial covenants. The new facility provides that the margin KMP will pay with respect to borrowings and the facility fee KMP will pay on the total commitment will vary based on its senior debt credit rating. Interest on the credit facility accrues at KMP’s option at a floating rate equal to either:
▪	the administrative agent’s base rate, plus a margin, which varies depending upon the credit rating of KMP’s long-term senior unsecured debt (the administrative agent’s base rate is a rate equal to the greatest of (i) the Federal Funds Rate, plus 0.5%; (ii) the Prime Rate; or (iii) LIBOR for a one-month eurodollar loan, plus 1%); or
▪	LIBOR for a one-month eurodollar loan, plus a margin, which varies depending upon the credit rating of KMP’s long-term senior unsecured debt.
As of September 30, 2013, KMP had approximately $174 million of commercial paper borrowings outstanding under its $2.7 billion credit facility and $204 million in letters of credit. KMP’s availability under its facility as of September 30, 2013 was approximately $2,322 million.
EPB
As of September 30, 2013, EPB had no outstanding balance under its revolving credit facility. EPB’s availability under this facility as of September 30, 2013 was approximately $1 billion.
Kinder Morgan G.P., Inc. 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:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013		2012
Per share cash distribution declared for the period(a)		$	10.517		$	10.948		$	31.531	$	52.598
Per share cash distribution paid in the period		$	10.545		$	20.825		$	31.652	$	62.475
_________
(a)	Distribution declared for the three months ended September 30, 2013, was declared on October 16, 2013 and is payable on November 18, 2013 to shareholders of record as of October 31, 2013.

Stockholders_Equity_Stockholde

Stockholders Equity Stockholders' Equity (Notes)	9 Months Ended
	Sep. 30, 2013
Stockholders' Equity Attributable to Parent [Abstract]
Stockholders' Equity Note Disclosure [Text Block]	Stockholders’ Equity
	Common Equity
	As of September 30, 2013, our common equity consisted of our Class P common stock. On December 26, 2012, our remaining series of 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. Our Class P common stock is sometimes referred to herein as our “common stock,” and our Class A, Class B and Class C common stock is sometimes collectively referred to herein as our “investor retained stock.” For accounting purposes, our Class P shares are and our Class A shares, prior to the full conversion of the investor retained stock, were considered common stock, and prior to the full conversion of the investor retained stock, our Class B and Class C shares, were considered participating securities. For additional information regarding our common stock and our investor retained stock, see Note 10 “Stockholders’ Equity” to our consolidated financial statements included in our 2012 Form 10-K.
	The following tables set forth the changes in our outstanding series of shares during the nine months ended September 30, 2013 and 2012.
		Class P
	Balance at December 31, 2012	1,035,668,596
	Shares issued with conversions of EP Trust I Preferred securities	74,421
	Shares issued for exercised warrants	16,886
	Restricted shares vested	86,922
	Balance at September 30, 2013	1,035,846,825
		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 (Note 2)	330,154,610			—			—			—
	Shares issued with conversions of EP Trust I Preferred securities	454,028			—			—			—
	Shares converted	147,255,126			(147,255,126	)		(4,827,797	)		(2,761	)
	Shares canceled	(446,206	)		—			—			—
	Restricted shares vested	77,925			—			—			—
	Balance at September 30, 2012	648,416,623			388,717,261			89,304,799			2,315,497
	Dividends
	Holders of our common stock share equally in any dividend declared by our board of directors, subject to the rights of the holders of any outstanding preferred stock. The following table provides information about our per share dividends.
		Three Months Ended September 30,								Nine Months Ended September 30,
		2013				2012				2013			2012
	Per common share cash dividend declared for the period	$	0.41			$	0.36			$	1.19		$	1.03
	Per common share cash dividend paid in the period	$	0.4			$	0.35			$	1.15		$	0.98
	Dividends Subsequent to September 30, 2013
	On October 16, 2013, our board of directors declared a cash dividend of $0.41 per share for the quarterly period ended September 30, 2013, which is payable on November 15, 2013 to shareholders of record as of October 31, 2013.
	Warrants
	The table below sets forth the changes in our outstanding warrants during the nine months ended September 30, 2013 and 2012.
		Warrants
		Nine Months Ended September 30,
		2013			2012
	Beginning balance	439,809,442			—
	Warrants issued in EP acquisition(a)	—			504,598,883
	Warrants issued with conversions of EP Trust I Preferred securities(b)	113,757			693,971
	Warrants exercised	(21,208	)		—
	Warrants repurchased(c)	(91,460,387	)		(59,787,050	)
	Ending balance	348,441,604			445,505,804
	_______
	(a)	See Note 2, “Acquisitions and Divestitures—KMI Acquisition of EP.”
	(b)	See Note 8, “Debt” to our consolidated financial statements included in our 2012 Form 10-K.
	(c)	On May 23, 2012, we announced that our board of directors had approved a warrant repurchase program, authorizing us to repurchase in the aggregate up to $250 million of warrants, which repurchase was completed as of May 2013. In the second quarter of 2013, we repurchased an additional $38 million in warrants, which was approved by our board of directors separate and apart from the publicly announced repurchase program. On July 17, 2013, we announced that our board of directors had authorized an additional $350 million share and warrant repurchase program. As of September 30, 2013, $331 million of the $350 million repurchase program had been utilized. On October 16, 2013, we announced that our board of directors had approved an additional share and warrant repurchase program authorizing us to repurchase in the aggregate up to $250 million of additional shares or warrants. During the nine months ended September 30, 2013 and 2012, we paid a total of $463 million and $136 million, respectively, for the repurchase of 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. For additional information regarding our warrants, see Note 10 “Stockholders’ Equity” to our consolidated financial statements included in our 2012 Form 10-K.
	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):
		September 30,				December 31,
		2013				2012
	KMP	$	7,612			$	3,270
	EPB	4,141				4,111
	KMR	3,020				2,716
	Other	264				137
		$	15,037			$	10,234
	Contributions
	Contributions from our noncontrolling interests consist primarily of equity issuances by KMP, EPB and KMR. As of September 30, 2013, each of these subsidiaries has an equity distribution agreements in place which allows the subsidiary to sell its equity interests from time to time through a designated sales agent. The terms of each agreement are substantially similar. Sales of the subsidiary’s equity interests will be 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 may 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 provides 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 retains at all times complete control over the amount and the timing of sales under its respective equity distribution agreement, and it will designate 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 agree.
	The table below shows significant issuances of common units or shares, the net proceeds from the issuances and the use of the proceeds during the nine months ended September 30, 2013 for KMP, EPB and KMR (dollars in millions and units and shares in thousands).
		Issuances		Common units/shares			Net proceeds				Use of proceeds
				(in thousands)			(in millions)
	KMP
	Issued under equity distribution agreement(a)
		2013		8,248			$	695			Reduced borrowings under KMP's commercial paper program
	Other issuances
		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(c)
		2013		2,038			$	85		(d)	General partnership purposes
KMR(e)
	2013		1,757			$	145			Purchased additional KMP i-units; KMP then used proceeds to reduce borrowings under its commercial paper program
_______
(a)	On June 3, 2013, KMP entered into a fourth amended and restated equity distribution agreement with UBS Securities LLC (UBS) which increased the aggregate offering price of KMP’s common units to up to $2.175 billion (up from $1.9 billion), and on August 7, 2013, KMP entered into a second and separate equity distribution agreement with UBS. The terms of this second equity distribution agreement are substantially similar to those in KMP’s previous agreement, and allows it to offer and sell from time to time additional KMP common units having an aggregate offering price of up to $1.9 billion through UBS, as sales agent.
(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)	On March 7, 2013, EPB entered into an equity distribution agreement with Citigroup. Pursuant to the provisions of EPB’s equity distribution agreement, EPB may 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)	Represents proceeds received from noncontrolling interests and excludes our $2 million contribution as the owner of EPB’s general partner.
(e)	On May 4, 2012, KMR entered into an equity distribution agreement with Credit Suisse Securities (USA) LLC (Credit Suisse). Pursuant to the provisions of KMR’s equity distribution agreement, it may 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 nine months ended September 30, 2013 had the associated effects of increasing our (i) noncontrolling interests by $4,799 million; (ii) accumulated deferred income taxes by $90 million; and (iii) additional paid-in capital by $154 million.
Distributions
The following table provides information about distributions from our noncontrolling interests (in millions except per unit distribution amounts):
	Three Months Ended September 30,								Nine Months Ended September 30,
	2013				2012				2013			2012
KMP
Per unit cash distribution declared for the period	$	1.35			$	1.26			$	3.97		$	3.69
Per unit cash distribution paid in the period	$	1.32			$	1.23			$	3.91		$	3.59
Cash distributions paid in the period to the public	$	377			$	275			$	983		$	788
EPB(a)
Per unit cash distribution declared for the period	$	0.65			$	0.58			$	1.9		$	1.13
Per unit cash distribution paid in the period	$	0.63			$	0.55			$	1.86		$	0.55
Cash distributions paid in the period to the public	$	80			$	64			$	235		$	64
KMR(b)
Share distributions paid in the period	1,880,172				1,578,616				5,411,720			4,646,736
_______
(a)	Represents distribution information since the May 2012 EP acquisition.
(b)	KMR’s distributions are 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.  On October 16, 2013, KMR declared a share distribution of 0.017610 shares per outstanding share (2,153,480 total shares) payable on November 14, 2013 to shareholders of record as of October 31, 2013, based on the $1.35 per common unit distribution declared by KMP.
Subsequent Events
Noncontrolling Interests Distributions
On October 16, 2013, KMP declared a cash distribution of $1.35 per unit for the quarterly period ended September 30, 2013. The distribution will be paid on November 14, 2013 to KMP’s unitholders of record as of October 31, 2013.
On October 16, 2013, EPB declared a cash distribution of $0.65 per unit for the quarterly period ended September 30, 2013. The distribution will be paid on November 14, 2013 to EPB’s unitholders of record as of October 31, 2013.

Risk_Management_Notes

Risk Management (Notes)	9 Months Ended
	Sep. 30, 2013
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, NGLs 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 part of the May 1, 2013 Copano acquisition, KMP acquired derivative contracts related to natural gas, NGLs and crude oil. None of these derivatives are designated as accounting hedges.
	Energy Commodity Price Risk Management
	As of September 30, 2013, KMI and KMP had the following outstanding commodity forward contracts to hedge their forecasted energy commodity purchases and sales:
		Net open position long/(short)
	Derivatives designated as hedging contracts
	Crude oil fixed price	(23.1	)		million barrels
	Natural gas fixed price	(35.2	)		billion cubic feet
	Natural gas basis	(30.7	)		billion cubic feet
	Derivatives not designated as hedging contracts
	Crude oil fixed price	0.5			million barrels
	Crude oil basis	(1.2	)		million barrels
	Natural gas fixed price	0.3			billion cubic feet
	Natural gas basis	7.9			billion cubic feet
	NGLs fixed price	0.4			million barrels
	As of September 30, 2013, the maximum length of time over which we have hedged our exposure to the variability in future cash flows associated with energy commodity price risk is through December 2017.
	Interest Rate Risk Management
	As of September 30, 2013, KMI and KMP had a combined notional principal amount of $725 million and $5,050 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 KMI and KMP’s swap agreements have termination dates that correspond to the maturity dates of the related series of senior notes and, as of September 30, 2013, 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 June 2013, KMP terminated three fixed-to-variable interest rate swap agreements in separate transactions having a combined notional principal amount of $975 million, and received combined proceeds of $96 million from the early termination of these swap agreements. In August 2013, KMP entered into six separate fixed-to-variable interest rate swap agreements having a combined notional principal amount of $500 million. Four of these agreements effectively convert a portion of the interest expense associated with KMP’s 2.65% senior notes due February 1, 2019 from a fixed rate to a variable rate based on an interest rate of LIBOR plus a spread and the remaining two agreements effectively convert a portion of the interest expense associated with KMP’s 4.15% senior notes due February 1, 2024, from a fixed rate to a variable rate based on an interest rate of LIBOR plus a spread. As of December 31, 2012, KMI and KMP had a combined notional principal amount of $725 million and $5,525 million, respectively, of fixed-to-variable interest rate swap agreements.
	Fair Value of Derivative Contracts
	The following table summarizes the fair values of our derivative contracts included in our accompanying consolidated balance sheets as of September 30, 2013 and December 31, 2012 (in millions):
	Fair Value of Derivative Contracts
					Asset derivatives								Liability derivatives
					September 30,				December 31,				September 30,				December 31,
					2013				2012				2013				2012
			Balance sheet location		Fair value				Fair value				Fair value				Fair value
	Derivatives designated as hedging contracts
	Natural gas and crude derivative contracts		Other current assets/(Accrued other current liabilities)		$	19			$	42			$	(49	)		$	(18	)
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		65				40				(43		)		(11		)
	Subtotal				84				82				(92		)		(29		)
	Interest rate swap agreements		Other current assets/(Accrued other current liabilities)		114				9				—				—
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		200				656				(79		)		(1		)
	Subtotal				314				665				(79		)		(1		)
	Total				398				747				(171		)		(30		)
	Derivatives not designated as hedging contracts
	Natural gas, crude and NGL derivative contracts		Other current assets/(Accrued other current liabilities)		11				4				(2		)		(3		)
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		2				—				(1		)		(1		)
	Subtotal				13				4				(3		)		(4		)
	Power derivative contracts		Other current assets/(Accrued other current liabilities)		9				8				(55		)		(59		)
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		13				13				(85		)		(120		)
	Subtotal				22				21				(140		)		(179		)
	Total				35				25				(143		)		(183		)
	Total derivatives				$	433			$	772			$	(314	)		$	(213	)
	Certain of our derivative contracts are subject to master netting agreements. As of September 30, 2013 and December 31, 2012, we presented the fair value of our derivative contracts on a gross basis on our accompanying consolidated balance sheets. The following tables present our derivative contracts subject to such netting agreements as of the dates indicated (in millions):
			Offsetting of financial assets and derivative assets
															Gross amounts not offset in the balance sheet
			Gross amounts of recognized assets				Gross amounts offset in the balance sheet				Amounts of assets presented in the balance sheet				Financial instruments				Cash collateral held(a)			Net amount
	As of September 30, 2013:
	Natural gas, crude and NGL derivative contracts		$	97			$	—			$	97			$	(60	)		$	—		$	37
	Power derivative contracts		$	22			$	—			$	22			$	(22	)		$	—		$	—
	Interest rate swap agreements		$	314			$	—			$	314			$	(19	)		$	—		$	295
	As of December 31, 2012:
	Natural gas, crude and NGL derivative contracts		$	86			$	—			$	86			$	(17	)		$	—		$	69
	Power derivative contracts		$	21			$	—			$	21			$	(21	)		$	—		$	—
	Interest rate swap agreements		$	665			$	—			$	665			$	—			$	—		$	665
			Offsetting of financial liabilities and derivative liabilities
															Gross amounts not offset in the balance sheet
			Gross amounts of recognized liabilities				Gross amounts offset in the balance sheet				Amounts of liabilities presented in the balance sheet				Financial instruments				Cash collateral posted(b)			Net amount
	As of September 30, 2013:
	Natural gas, crude and NGL derivative contracts		$	(95	)		$	—			$	(95	)		$	60			$	—		$	(35	)
	Power derivative contracts		$	(140	)		$	—			$	(140	)		$	22			$	5		$	(113	)
	Interest rate swap agreements		$	(79	)		$	—			$	(79	)		$	19			$	—		$	(60	)
	As of December 31, 2012:
Natural gas, crude and NGL derivative contracts		$	(33	)		$	—			$	(33	)		$	17			$	5		$	(11	)
Power derivative contracts		$	(179	)		$	—			$	(179	)		$	21			$	—		$	(158	)
Interest rate swap agreements		$	(1	)		$	—			$	(1	)		$	—			$	—		$	(1	)
_______
(a)	Cash margin deposits held by KMP associated with its energy commodity contract positions and OTC swap agreements and reported within “Accrued other current liabilities” in our accompanying consolidated balance sheets.
(b)	$5 million of cash margin deposits posted by KMI at September 30, 2013 and KMP at December 31, 2012, associated with energy commodity contract positions and OTC swap agreements and reported within “Other current assets” in our accompanying consolidated balance sheets.
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 September 30, 2013 and December 31, 2012, these fair value adjustments to our debt balances included (i) $1,419 million and $1,470 million, respectively, associated with fair value adjustments to our debt previously recorded in purchase accounting; (ii) $235 million and $664 million, respectively, associated with the offsetting entry for hedged debt; (iii) $533 million and $490 million, respectively, associated with unamortized premium from the termination of interest rate swap agreements; and offset by (iv) $63 million and $33 million, respectively, associated with unamortized debt discount amounts. As of September 30, 2013, 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 two tables summarize the impact of our derivative contracts on our accompanying consolidated statements of income for each of the three and nine months ended September 30, 2013 and 2012 (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(a)
				Three Months Ended September 30,								Nine Months Ended September 30,
				2013				2012				2013				2012
Interest rate swap agreements		Interest expense		$	(26	)		$	29			$	(333	)		$	110
Total				$	(26	)		$	29			$	(333	)		$	110
Fixed rate debt		Interest expense		$	26			$	(29	)		$	333			$	(110	)
Total				$	26			$	(29	)		$	333			$	(110	)
_______
(a)	Amounts reflect the change in the fair value of interest rate swap agreements and the change in the fair value of the associated fixed rate debt which exactly offset each other as a result of no hedge ineffectiveness.
Derivatives		Amount of gain/(loss)								Location of		Amount of gain/(loss) reclassified from								Location of	Amount of gain/(loss)
in cash flow		recognized in OCI								gain/(loss)		Accumulated OCI								gain/(loss)	recognized in income
hedging		on derivative(effective portion)(a)								reclassified from		into income								recognized in	on derivative
relationships										Accumulated OCI		(effective portion)(b)								income on	(ineffective portion
										into income										derivative	and amount
										(effective										(ineffective	excluded from
										portion)										portion	effectiveness testing)
																				and amount
																				excluded from
																				effectiveness
																				testing)
		Three Months Ended September 30,										Three Months Ended September 30,									Three Months Ended September 30,
		2013				2012						2013				2012					2013			2012
Energy commodity derivative  contracts		$	(78	)		$	(69	)		Natural gas sales		$	—			$	1			Natural gas sales	$	—		$	—
										Product sales and other		(22		)		—				Product sales and other	(8		)	(5		)
										Costs of sales		3				7				Costs of sales	—			—
Interest rate swap agreements		(2		)		(2		)		Interest expense		—				2				Interest expense	—			—
Total		$	(80	)		$	(71	)		Total		$	(19	)		$	10			Total	$	(8	)	$	(5	)
Derivatives		Amount of gain/(loss)								Location of		Amount of gain/(loss)								Location of	Amount of gain/(loss)
in cash flow		recognized in OCI								gain/(loss)		reclassified from								gain/(loss)	recognized in income
hedging		on derivative(effective portion)(a)								reclassified from		Accumulated OCI								recognized in	on derivative
relationships										Accumulated OCI		into income								income on	(ineffective portion
										into income		(effective portion)(b)								derivative	and amount
										(effective										(ineffective	excluded from
										portion)										portion	effectiveness testing)
																				and amount
																				excluded from
																				effectiveness
																				testing)
		Nine Months Ended September 30,										Nine Months Ended September 30,									Nine Months Ended September 30,
		2013				2012						2013				2012					2013			2012
Energy commodity derivative  contracts		$	(55	)		$	76			Natural gas sales		$	—			$	3			Natural gas sales	$	—		$	—
										Product sales and other		(9		)		(23		)		Product sales and other	(2		)	(8		)
										Costs of sales		(2		)		13				Costs of sales	—			—
Interest rate swap agreements		6				(5		)		Interest expense		1				2				Interest expense	—			—
Total		$	(49	)		$	71			Total		$	(10	)		$	(5	)		Total	$	(2	)	$	(8	)
_______
(a)	We expect to reclassify an approximate $17 million loss associated with energy commodity price risk management activities and included in our accumulated other comprehensive loss and noncontrolling interest balances as of September 30, 2013 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).
For the three and nine months ended September 30, 2013, we recognized losses of $7 million and $10 million, respectively, in income and included these amounts within “Product sales and other” from derivative contracts not designated as accounting hedges. For the three and nine months ended September 30, 2012, such amounts were not significant.
Credit Risks
We and our subsidiary, KMP, 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 both September 30, 2013 and December 31, 2012, KMP had no outstanding letters of credit supporting its hedging of energy commodity price risks associated with the sale of natural gas, NGLs and crude oil. As of September 30, 2013 and December 31, 2012, KMI had $170 million and $300 million, respectively, of outstanding letters of credit supporting its commodity price risks associated with the sale of natural gas and power.
KMP and KMI also have agreements with certain counterparties to their derivative contracts that contain provisions requiring the posting of additional collateral upon a decrease in their credit rating.  As of September 30, 2013, we estimate that if KMP’s credit rating was downgraded one notch, KMP would be required to post no additional collateral to its counterparties.  If KMP was downgraded two notches (that is, below investment grade), KMP would be required to post $18 million of incremental collateral. As of September 30, 2013, we estimate that if KMI’s credit rating was downgraded one or two notches, KMI would be required to post no additional collateral to its counterparties.
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income
Changes in the components of our “Accumulated other comprehensive income (loss)” for the nine months ended September 30, 2013 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, 2012	$	7			$	51			$	(176	)		$	(118	)
Other comprehensive (loss) income before reclassifications	(22		)		(28		)		66				16
Amounts reclassified from accumulated other comprehensive income	5				—				—				5
Net current-period other comprehensive (loss) income	(17		)		(28		)		66				21
Balance as of September 30, 2013	$	(10	)		$	23			$	(110	)		$	(97	)

Fair_Value_Notes

Fair Value (Notes)	9 Months Ended
	Sep. 30, 2013
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 as of September 30, 2013 and December 31, 2012, based on the three levels established by the Codification. The fair value measurements in the tables below do not include cash margin deposits made by us or our counterparties, which are reported within “Other current assets” and “Accrued other current liabilities,” respectively, in our accompanying consolidated balance sheets (in millions).
		Asset fair value measurements using
		Total			Quoted prices in active markets for identical			Significant other observable inputs (Level 2)			Significant
					assets (Level 1)						unobservable
											inputs (Level 3)
	As of September 30, 2013
	Energy commodity derivative contracts(a)	$	119		$	13		$	43		$	63
	Interest rate swap agreements	$	314		$	—		$	314		$	—
	As of December 31, 2012
	Energy commodity derivative contracts(a)	$	107		$	3		$	76		$	28
	Interest rate swap agreements	$	665		$	—		$	665		$	—
		Liability fair value measurements using
		Total			Quoted prices in			Significant other  observable			Significant
					active markets			inputs (Level 2)			unobservable
					for identical						inputs (Level 3)
					liabilities
					(Level 1)
	As of September 30, 2013
	Energy commodity derivative contracts(a)	$	(235	)	$	(5	)	$	(47	)	$	(183	)
	Interest rate swap agreements	$	(79	)	$	—		$	(79	)	$	—
	As of December 31, 2012
	Energy commodity derivative contracts(a)	$	(212	)	$	(3	)	$	(26	)	$	(183	)
	Interest rate swap agreements	$	(1	)	$	—		$	(1	)	$	—
	_______
	(a)	Level 1 consists primarily of NYMEX natural gas futures. Level 2 consists primarily of OTC WTI swaps and OTC natural gas swaps that are settled on NYMEX.  Level 3 consists primarily of WTI options, WTI basis swaps, NGL options and power derivative contracts.
	The table below provides a summary of changes in the fair value of our Level 3 energy commodity derivative contracts for each of the three and nine months ended September 30, 2013 and 2012 (in millions):
	Significant unobservable inputs (Level 3)
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Derivatives-net asset (liability)
	Beginning of Period	$	(114	)	$	(220	)	$	(155	)	$	7
	Total gains or (losses)
	Included in earnings	(17		)	(7		)	(18		)	(8		)
	Included in other comprehensive loss	(2		)	(6		)	(2		)	—
	Purchases(a)	—			—			18			(243		)
	Settlements	13			14			37			25
	End of Period	$	(120	)	$	(219	)	$	(120	)	$	(219	)
	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	$	(14	)	$	(10	)	$	(13	)	$	(6	)
	_______
	(a)	2012 purchases include a net liability of $246 million of Level 3 energy commodity derivative contracts associated with the EP acquisition. 2013 purchases include a net asset of $18 million of Level 3 energy commodity derivative contracts assumed in conjunction with KMP’s May 1, 2013 Copano acquisition.
	As of September 30, 2013, our Level 3 derivative assets and liabilities consisted primarily of WTI options, WTI basis swaps, NGL options and 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.
	The significant unobservable inputs used in the fair value measurement of our power derivative contracts are illiquid pricing points. As the delivery points in our power contracts are in an illiquid market and not actively traded, we adjust the Pennsylvania-New Jersey-Maryland (PJM) forward curves by the difference between the 12-month rolling average of actual settled prices at delivery points in the PJM East region. As of September 30, 2012, the adjusted prices over the contract term ranged from $28.50 per MW/h to $60.93 per MW/h. However, we have entered into offsetting positions that eliminate the price risks associated with our PJM power contracts. Significant increases (decreases) in these inputs in isolation would result in a significantly lower (higher) fair value measurement.
	Fair Value of Financial Instruments
	The estimated fair value of our outstanding debt balance (both short-term and long-term and including debt fair value adjustments), is disclosed below (in millions):
		September 30, 2013						December 31, 2012
		Carrying			Estimated			Carrying			Estimated
		Value			Fair Value			Value			Fair Value
	Total debt	$	36,011		$	35,939		$	34,401		$	36,720
	We used Level 2 input values to measure the estimated fair value of our outstanding debt balances as of both September 30, 2013 and December 31, 2012.

Reportable_Segments_Notes

Reportable Segments (Notes)	9 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]
Reportable Segments	Reportable Segments
	We operate the following reportable business segments.  These segments and their principal sources of revenues are as follows:
	•	Natural Gas Pipelines—the sale, transport, processing, treating, fractionation, storage and gathering of natural gas and NGLs;
	•	CO2—KMP—the production, sale and transportation of crude oil from fields in the Permian Basin of West Texas and the production, transportation and marketing of CO2 used as a flooding medium for recovering crude oil from mature oil fields;
	•	Products Pipelines—KMP— the transportation and terminaling of refined petroleum products, including gasoline, diesel fuel, jet fuel, NGLs, crude and condensate, and bio-fuels;
	•	Terminals—KMP—the transloading and storing of refined petroleum products and dry and liquid bulk products, including coal, petroleum coke, cement, alumina, salt and other bulk chemicals;
	•	Kinder Morgan Canada—KMP—the transportation of crude oil and refined products from Alberta, Canada to marketing terminals and refineries in British Columbia, and the state of Washington. As further described in Note 2, Kinder Morgan Canada divested its interest in the Express pipeline system effective March 14, 2013; and
	•	Other—primarily includes several physical natural gas contracts with power plants associated with EP’s legacy trading activities. These contracts obligate EP to sell natural gas to these plants and have various expiration dates ranging from 2012 to 2028.
	We evaluate performance principally based on each segment’s earnings before depreciation, depletion and amortization expenses (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.
	Financial information by segment follows (in millions):
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Revenues
	Natural Gas Pipelines
	Revenues from external customers(a)	$	2,388		$	1,646		$	6,197		$	3,440
	Intersegment revenues	2			—			3			—
	CO2–KMP	456			420			1,345			1,250
	Products Pipelines–KMP	474			386			1,371			940
	Terminals–KMP
	Revenues from external customers	354			334			1,034			1,017
	Intersegment revenues	—			—			1			1
	Kinder Morgan Canada–KMP	74			80			221			226
	Other	1			(4		)	3			(5		)
	Total segment revenues	3,749			2,862			10,175			6,869
	Other revenues	9			8			27			26
	Less: Total intersegment revenues	(2		)	—			(4		)	(1		)
	Total consolidated revenues	$	3,756		$	2,870		$	10,198		$	6,894
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Segment earnings (loss) before depreciation, depletion, amortization and amortization of excess cost of equity investments(b)
	Natural Gas Pipelines(a)(c)	$	958		$	822		$	3,281		$	1,477
	CO2–KMP	340			327			1,040			988
	Products Pipelines–KMP(d)	202			150			399			490
	Terminals–KMP	217			183			609			564
	Kinder Morgan Canada–KMP(e)	43			56			286			158
	Other	-3			21			(4		)	18
	Total segment EBDA	1,757			1,559			5,611			3,695
	Total segment depreciation, depletion and amortization	-467			-403			(1,327		)	(1,010		)
	Total segment amortization of excess cost of investments	-11			-5			(29		)	(9		)
	Other revenues	9			8			27			26
	General and administrative expenses(f)	-158			-186			(481		)	(816		)
	Unallocable interest and other, net of unallocable interest income(g)	-420			-533			(1,257		)	(1,013		)
	Unallocable income tax expense	-159			-54			(554		)	(145		)
	Loss from discontinued operations, net of tax(h)	—			-131			(2		)	(789		)
	Total consolidated net income (loss)	$	551		$	255		$	1,988		$	(61	)
		September 30,			December 31,
		2013			2012
	Assets
	Natural Gas Pipelines	$	52,146		$	46,600
	CO2–KMP	4,611			4,148
	Products Pipelines–KMP	6,466			6,089
	Terminals–KMP	6,673			5,931
	Kinder Morgan Canada–KMP	1,662			1,724
	Other	567			601
	Total segment assets	72,125			65,093
	Corporate assets(i)	2,450			2,854
	Assets held for sale(j)	—			298
	Total consolidated assets	$	74,575		$	68,245
	_______
	(a)	Increases in the three and nine month 2013 amounts versus the three and nine month 2012 amounts reflect our May 25, 2012 acquisition of EP and KMP’s May 1, 2013 acquisition of Copano.
	(b)	Includes revenues, earnings from equity investments, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other expense (income).
	(c)	Nine month 2013 amount includes a $558 million non-cash gain from the remeasurement of net assets to fair value. See Note 2 for further discussion.
	(d)	Nine month 2013 amount includes a $177 million increase in expense associated with adjustments to certain legal liabilities related to both transportation rate cases and environmental matters.
	(e)	Three and nine month 2013 amounts include a $1 million decrease and a $140 million increase, respectively, from after-tax loss and gain amounts on the sale of KMP’s investments in the Express pipeline system.
(f)	Nine month 2012 amount includes increases in expense of (i) $157 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; and (iv) $96 million for legal fees and litigation reserves. These increases in expense were partially offset by a $17 million benefit associated with pension income.
(g)	Three and nine month 2012 amounts include increases in expense of $95 million and $104 million, respectively, of capitalized financing fees, almost all of which was associated with the EP acquisition financing, that was written-off (primarily due to debt repayment) or amortized.
(h)	Represents amounts primarily attributable to KMP’s FTC Natural Gas Pipelines disposal group and other, net of tax. Nine month 2013 amount represents an incremental loss related to the sale of KMP’s disposal group effective November 1, 2012. Three month 2012 amount includes a $179 million non-cash loss from remeasurement of net assets to fair value, and nine month 2012 amount includes a combined $934 million loss from both costs to sell and the remeasurement of net assets to fair value, net of tax, and $7 million of depreciation and amortization expense.
(i)	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.
(j)	2012 amount primarily represents amounts attributable to KMP’s Express pipelines system and our ownership interest in the Bolivia to Brazil Pipeline as of December 31, 2012.

Related_Party_Transactions_Not

Related Party Transactions (Notes)	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions
	Affiliated Balances
	The following table summarizes our balance sheet affiliate balances (in millions):
		30-Sep-13		31-Dec-12
	Balance sheet location
	Accounts receivable, net	$	20	$	25
	Assets held for sale(a)	—		114
	Other current assets	3		14
	Deferred charges and other assets	48		48
		$	71	$	201
	Current portion of debt – KMP and EPB(b)	$	5	$	5
	Accounts payable	9		11
	Long-term debt - Outstanding - KMP and EPB(b)	170		173
		$	184	$	189
	_______
	(a)2012 amount related to KMP’s equity investment in the Express pipeline system (see Note 2).
	(b)EPB has financing obligations payable to WYCO.
	Notes Receivable
	Plantation Pipe Line Company
	KMP and ExxonMobil have a term loan agreement covering a note receivable due from Plantation. KMP owns a 51.17% equity interest in Plantation and their proportionate share of the outstanding principal amount of the note receivable was $49 million as of both September 30, 2013 and December 31, 2012. 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 KMP’s portion of the note) due on July 20, 2016. We included $1 million of this note receivable balance within “Other current assets,” on our accompanying consolidated balance sheets as of both September 30, 2013 and December 31, 2012, and we included the remaining outstanding balance within “Deferred charges and other assets.”
	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. The balance of $10 million at December 31, 2012 was included in our accompanying consolidated balance sheet within “Other current assets.”

Pension_and_Other_Postretireme

Pension and Other Postretirement Benefit Planss (Notes)	9 Months Ended
	Sep. 30, 2013
Defined Benefit Plans and Other Postretirement Benefit Plans Disclosures [Abstract]
Pension and Other Postretirement Benefits Disclosure [Text Block]	Pension and Other Postretirement Benefit Plans
	Kinder Morgan, Inc.
	The components of net benefit (credit) cost for our pension and other postretirement benefit (OPEB) plans, not including KMP and EPB’s plans, are as follows (in millions):
		Pension Benefits						OPEB						Pension Benefits						OPEB
		Three Months Ended September 30,						Three Months Ended September 30,						Nine Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012			2013			2012			2013			2012
	Service cost	$	7		$	6		$	—		$	(1	)	$	19		$	13		$	—		$	—
	Interest cost	22			26			4			5			68			42			14			9
	Expected return on assets	(43		)	(43		)	(1		)	(2		)	(131		)	(69		)	(5		)	(5		)
	Amortization of prior service credits	(1		)	(1		)	—			—			—			(1		)	—			—
	Amortization of net actuarial loss	—			2			—			2			—			7			3			4
	Settlement gain(a)	—			—			—			—			(3		)	—			—			—
	Net benefit (credit) cost	$	(15	)	$	(10	)	$	3		$	4		$	(47	)	$	(8	)	$	12		$	8
	_______
	(a)	Reflects the gain recognized upon the February 2013 settlement of our obligations under the El Paso Supplemental Executive Retirement Plan.

Income_Taxes_Notes

Income Taxes ( Notes)	9 Months Ended
	Sep. 30, 2013
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes
	Income taxes from continuing operations included in our accompanying consolidated statements of income were as follows (in millions, except percentages):
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Income tax expense	$	171		$	60		$	675		$	165
	Effective tax rate	24		%	13		%	25		%	18		%
	Tax expense from income from continuing operations for the three months ended September 30, 2013 is approximately $171 million resulting in an effective tax rate of 24% as compared with $60 million tax expense, and an effective tax rate of 13%, for the same period of 2012. The effective tax rate for the three months ended September 30, 2013 is lower than the statutory federal rate of 35% primarily due to (i) the net effect of consolidating KMP and EPB’s income tax provision; (ii) dividend-received deductions from our 50% interest in Florida Gas Pipeline (through our investment in Citrus Corporation); and (iii) the tax impact of our 2013 sale of our investment in a Pakistan power plant. These decreases are partially offset by state income taxes.
	The effective tax rate for the three months ended September 30, 2012 is lower than the statutory federal rate of 35% primarily due to (i) the net effect of consolidating KMP and EPB’s income tax provisions; (ii) dividend-received deductions from our 20% investment in NGPL and 50% investment in Florida Gas Pipeline; (iii) an adjustment to non tax-deductible costs incurred to facilitate the EP acquisition; (iv) an adjustment to the deferred tax liability related to non tax-deductible goodwill recorded to our investment in KMP; and (v) adjustments to our income tax reserve for uncertain tax positions. These decreases are partially offset by state income taxes.
	Tax expense from income from continuing operations for the nine months ended September 30, 2013 is approximately $675 million resulting in an effective tax rate of 25% as compared with $165 million tax expense, and an effective tax rate of 18%, for the same period of 2012. The effective tax rate for the nine months ended September 30, 2013 is lower than the statutory federal rate of 35% primarily due to (i) the net effect of consolidating KMP’s and EPB’s income tax provision; (ii) dividend-received deductions from our 50% interest in Florida Gas Pipeline; and (iii) the tax impact of a decrease in our deferred state tax rate as a result of the drop-down of our 50% ownership interests in EPNG and EP midstream assets and KMP’s acquisition of Copano. These decreases are partially offset by state income taxes and a change in nondeductible goodwill related to our investment in KMP.
	The effective tax rate for the nine months ended September 30, 2012 is lower than the statutory federal rate of 35% primarily due to (i) the net effect of consolidating KMP and EPB’s income tax provisions; (ii) dividend-received deductions from our 20% investment in NGPL and 50% investment in Florida Gas Pipeline; (iii) adjustments to our income tax reserve for uncertain tax positions; (iv) the adjustment to the deferred tax liability related to our investment in KMR; and (v) the tax impact of recording a deferred tax asset related to our state net operating losses. These decreases are partially offset by (i) state income taxes; (ii) the impact of non tax-deductible costs incurred to facilitate the acquisition of EP; (iii) an adjustment to the deferred tax liability related to non tax-deductible goodwill recorded to our investment in KMP; and (iv) the tax impact of an increase in the deferred state tax rate as a result of the EP acquisition.

Litigation_Environmental_and_O

Litigation, Environmental and Other Contingencies (Notes)	9 Months Ended
	Sep. 30, 2013
Commitments and Contingencies Disclosure [Abstract]
Litigation, Environmental and Other Contingencies	Litigation, Environmental and Other Contingencies
	We and our subsidiaries are parties to various legal, regulatory and other matters arising from the day-to-day operations of our businesses that may result in claims against the Company. Although no assurance can be given, we believe, based on our experiences to date and taking into account established reserves, that the ultimate resolution of such items will not have a material adverse impact on our business, financial position, results of operations or dividends to our shareholders. We believe we have meritorious defenses to the matters to which we are a party and intend to vigorously defend the Company. When we determine a loss is probable of occurring and is reasonably estimable, we accrue an undiscounted liability for such contingencies based on our best estimate using information available at that time. If the estimated loss is a range of potential outcomes and there is no better estimate within the range, we accrue the amount at the low end of the range. We disclose contingencies where an adverse outcome may be material, or in the judgment of management, we conclude the matter should otherwise be disclosed.
	Federal Energy Regulatory Commission Proceedings
	The tariffs and rates charged by SFPP and EPNG are subject to a number of ongoing proceedings at the FERC. A substantial portion of our legal reserves relate to these FERC cases and the CPUC cases described below them.
	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). If the shippers are successful in proving 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 other 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 KMP’s distributions to its limited partners or 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 and EPNG implemented certain aspects of that decision. 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 is evaluating Opinion 528 and its impact. Based on our preliminary assessment, we believe our incremental exposure for refunds above our existing legal reserve is zero to $50 million.
	California Public Utilities Commission Proceedings
	KMP has 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. These matters have generally been consolidated and assigned to two administrative law judges.
	On May 26, 2011, the CPUC issued a decision in several intrastate rate cases involving SFPP and a number of its shippers (the “Long” cases). The decision includes determinations on issues, such as SFPP’s entitlement to an income tax allowance, allocation of environmental expenses, and refund liability which KMP believes are contrary both to CPUC policy and precedent and to established federal regulatory policies for pipelines. On March 8, 2012, the CPUC issued another decision related to the Long cases. This decision largely reflected the determinations made on May 26, 2011, including the denial of an income tax allowance for SFPP.  The CPUC’s order denied SFPP’s request for rehearing of the CPUC’s income tax allowance treatment, while granting requested rehearing of various, other issues relating to SFPP’s refund liability and staying the payment of refunds until resolution of the outstanding issues on rehearing. On March 23, 2012, SFPP filed a petition for writ of review in the California Court of Appeals, seeking a court order vacating the CPUC’s determination that SFPP is not entitled to recover an income tax allowance in its intrastate rates. The Court denied SFPP’s petition, and on October 16, 2013, the California Supreme Court declined SFPP’s request for further review. SFPP is currently assessing the precise impact of the now final state rulings denying SFPP an income tax allowance and is awaiting CPUC decisions that will determine the impact related to the denial of an income tax allowance.
	On April 6, 2011, in proceedings unrelated to the above-referenced CPUC dockets, a CPUC administrative law judge issued a proposed decision (Bemesderfer case) substantially reducing SFPP’s authorized cost of service and ordering SFPP to pay refunds from May 24, 2007 to the present of revenues collected in excess of the authorized cost of service. The proposed decision was subsequently withdrawn, and the presiding administrative law judge is expected to reissue a proposed decision at some indeterminate time in the future.
	On January 30, 2012, SFPP filed an application reducing its intrastate rates by approximately 7%. This matter remains pending before the CPUC, with a decision expected in the fourth quarter of 2013.
	On July 19, 2013, Calnev filed an application with the CPUC requesting a 36% increase in its intrastate rates; a decision from the CPUC is expected by the first quarter of 2014.
	Based on KMP’s review of these CPUC proceedings and the shipper comments thereon, it estimates that the shippers are requesting approximately $375 million in reparation payments and approximately $30 million in annual rate reductions.  The actual amount of reparations will be determined through further proceedings at the CPUC. As of September 30, 2013, KMP believes its legal reserve, including an adjustment of the reserve made in the second quarter of 2013 related in part to this matter, is adequate such that the resolution of pending CPUC matters will not have a material adverse impact on its business, financial position or results of operations. We do not expect any reparations that KMP would pay in this matter to impact KMP’s $5.33 per unit cash distributions it expects to pay to its limited partners for 2013.
	Copano Shareholders’ Litigation
	Three putative class action lawsuits were filed in connection with KMP’s merger with Copano: (i) Schultes v. Copano Energy, L.L.C., et al. (Case No. 06966), in the District Court of Harris County, Texas, which is referred to as the Texas State Action; (ii) Bruen v. Copano Energy, L.L.C., et al. (Case No. 4:13-CV-00540) in the United States District Court for the Southern District of Texas, which is referred to as the Texas Federal Action; and (iii) In re Copano Energy, L.L.C. Shareholder Litigation, Case No. 8284-VCN in the Court of Chancery of the State of Delaware, which is referred to as the Delaware Action, which reflects the consolidation of three actions originally filed in the Court of Chancery. The Texas State Action, the Texas Federal Action and the Delaware Action are collectively referred to as the “Actions.”
	The Actions name Copano, R. Bruce Northcutt, William L. Thacker, James G. Crump, Ernie L. Danner, T. William Porter, Scott A. Griffiths, Michael L. Johnson, Michael G. MacDougall, Kinder Morgan G.P., Inc., KMEP and Javelina Merger Sub LLC as defendants. The Actions were purportedly brought on behalf of a putative class seeking to enjoin the merger and allege, among other things, that the members of Copano’s board of directors breached their fiduciary duties by agreeing to sell Copano for inadequate and unfair consideration and pursuant to an inadequate and unfair process, and that Copano, KMEP, Kinder Morgan G.P., Inc. and Javelina Merger Sub LLC aided and abetted such alleged breaches. In addition, the plaintiffs in each of the Texas State Action and the Delaware Action alleged that the Copano directors breached their duty of candor to unitholders by failing to provide the unitholders with all material information regarding the merger and/or made misstatements in the preliminary proxy statement. The plaintiffs in the Texas Federal Action also asserted a claim under the federal securities laws alleging that the preliminary proxy statement omits and/or misrepresents material information in connection with the merger.
	On April 21, 2013, the parties in all the Actions executed a Memorandum of Understanding pursuant to which Copano agreed to make certain additional disclosures concerning the merger in a Form 8-K, which Copano filed on April 22, 2013, and the plaintiffs agreed to enter into a stipulation of settlement providing for full settlement and dismissal with prejudice of each of the Actions. The parties then prepared and filed a Stipulation of Settlement with the Delaware Chancery Court, and on June 28, 2013, Copano announced that it had reached an agreement with the plaintiffs to settle all claims asserted against all defendants. The settlement does not require the defendants to pay any monetary consideration to the proposed settlement class. Following notice to the putative class, the Delaware Chancery Court held a settlement hearing and issued a final order approving the settlement on September 9, 2013. The order, among other things, dismissed the Delaware Action with prejudice and provided for a release in favor of all of the defendants for any and all claims by any of the putative class members arising out of the merger. The order also awarded plaintiffs’ counsel in the Delaware action $450,000 for their fees and expenses, to be paid by defendants. The plaintiff in the Texas Federal Action dismissed his case on May 13, 2013 and intervened in the Texas State Action on August 12, 2013 for the sole purpose of advancing a joint motion and petition for attorneys’ fees and expenses. On October 11, 2013, the court in the Texas State Action entered an order and final judgment denying plaintiffs’ joint motion for fees and expenses.
	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 judge determined that the annual rent payable as of January 1, 2004 was $15 million, subject to annual consumer price index increases. SFPP intends to appeal the judge’s determination, but if that determination is upheld, SFPP would owe approximately $75 million in back rent. Accordingly, during 2011, KMP increased its rights-of-way liability to cover this liability amount. In addition, the judge determined that UPRR is entitled to an estimated $20 million for interest on the outstanding back rent liability.  KMP believes the award of interest is without merit and it is pursuing its appellate rights.
	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. SFPP is evaluating its post-trial and appellate options.
	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) would have an adverse effect on KMP’s financial position, its results of operations, its cash flows, and KMP’s distributions to its limited partners.  These effects would be even greater in the event SFPP is unsuccessful in one or more of these litigations.
	Severstal Sparrows Point Crane Collapse
	On June 4, 2008, a bridge crane owned by Severstal and located in Sparrows Point, Maryland collapsed while being operated by Kinder Morgan Bulk Terminals, Inc. (KMBT).  According to KMP’s investigation, the collapse was caused by unexpected, sudden and extreme winds. On June 24, 2009, Severstal filed suit against KMBT in the United States District Court for the District of Maryland, Case No. 09CV1668-WMN. Severstal and its successor in interest, RG Steel, allege that KMBT was contractually obligated to replace the collapsed crane and that its employees were negligent in failing to properly secure the crane prior to the collapse. RG Steel seeks to recover in excess of $30 million for the alleged value of the crane and lost profits. KMBT denies each of RG Steel’s allegations. Trial is scheduled to begin on November 12, 2013.
	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. We believe that we are entitled to defense and indemnity from Kinetica under the Amended and Restated Purchase and Sale Agreement with Kinetica and intend to vigorously defend the suit.
	Brinckerhoff v. El Paso Pipeline GP Company, LLC., et al.
	In December 2011 (“Brinckerhoff I”), March 2012 (“Brinckerhoff II”) and May 2013 (“Brinckerhoff III”), derivative lawsuits were filed in Delaware Chancery Court against El Paso, El Paso Pipeline GP Company, L.L.C., EPB’s general partner, and the directors of its general partner. EPB was named in these lawsuits as a “Nominal Defendant.” The lawsuits arise from the March 2010, November 2010 and May 2012 drop down transactions involving EPB’s purchase of SLNG, Elba Express, CPG and interest in SNG and CIG. The lawsuits allege various conflicts of interest and that the consideration EPB paid was excessive. Defendants’ motion to dismiss in Brinckerhoff I was denied in part. Brinckerhoff I and II have been consolidated into one proceeding. A motion to dismiss has been filed in Brinckerhoff III. Defendants continue to believe that these actions 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. Defendants’ motion to dismiss was denied. Defendants continue to believe this action is without merit and intend to defend against it vigorously.
	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 are pending in federal court in Nevada, were dismissed, however, on April 10, 2013, the 9th Circuit Court of Appeals reversed this dismissal and remanded the cases to the Nevada court. We have filed a petition for writ of certiorari with the U.S. Supreme Court, and the matter has been stayed pending the filing of such petition. 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.
	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 September 30, 2013 and December 31, 2012, our total reserve for legal matters was $619 million and $425 million, respectively.  The reserve primarily relates to various claims from regulatory proceedings arising from KMP’s products pipeline and natural gas pipeline transportation rates. The overall change in the reserve from December 31, 2012 was primarily due to increases in expense in the first nine months of 2013 associated with KMP’s adjustments to interstate and California intrastate transportation rate case liabilities.
	Environmental Matters
	We and our subsidiaries are subject to environmental cleanup and enforcement actions from time to time. In particular, the Comprehensive Environmental Response, Compensation and Liability Act, also known as 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. Specifically, we are involved in matters including incidents at terminal facilities in New Jersey and Texas involving the United States Department of Transportation PHMSA and the Texas Commission on Environmental Quality, respectively, which may result in fines and penalties for alleged violations. 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, NGLs, natural gas and CO2.
	Colorado Oil and Gas Conservation Commission Inspections
	In Fall 2012, the Colorado Oil and Gas Conservation Commission, referred to as COGCC, performed inspections at multiple well sites in Southwestern Colorado owned by KMCO2 and some of these inspections resulted in alleged violations of COGCC’s rules. KMCO2 took immediate steps to correct the alleged deficiencies and has engaged COGCC and other agencies in its efforts to maintain compliance. In June 2013, the parties settled the matter through an Administrative Order on Consent under which KMCO2 agreed to pay $220,000 of which up to $80,000 may be paid toward a public project. Other than completion of the agreed public project, this matter is resolved and no further actions are anticipated.
	Lower Passaic River Study Area of the Diamond Alkali Superfund Site, Essex, Hudson, Bergen and Passaic Counties, New Jersey
	EPEC Polymers and EPEC Oil Company Liquidating 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 remediation of the lower eight miles of the Passaic River. EPEC Polymers and EPEC Oil Company Liquidating Trust are 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 the EPEC Oil Company Liquidating Trust entered into two Administrative Orders on Consent (AOCs) which obligated them to investigate and characterize contamination at the Site. They are also part of a joint defense group of cooperating parties (CPG) which have entered into AOCs and are directing and funding the work required by EPA . Under the first AOC, a remedial investigation and feasibility study of the Site is presently estimated to be completed by 2015, at which time the EPA is expected to issue a Record of Decision directing the CPG and other parties to perform remedial measures. 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. After the completion of dredging, a cap will be installed. The removal action is ongoing and is estimated to be completed by December 2013. We have established a reserve for the anticipated cost of compliance with the AOCs.
	New Jersey Department of Environmental Protection v. Occidental Chemical Corporation, et al. (Defendants), Maxus Energy Corp. and Tierra Solutions, Inc. (Third Party Plaintiffs) v. 3M Company et al., Superior Court of New Jersey, Law Division - Essex County, Docket No. L-9868-05
	The New Jersey Department of Environmental Protection (NJDEP) sued Occidental Chemical and others under the New Jersey Spill Act for contamination in the Newark Bay Complex including numerous waterways and rivers.  Occidental et al. then brought in approximately 300 third party defendants for contribution.  NJDEP claimed damages related to forty years of discharges of TCDD (a form of dioxin), DDT and “other hazardous substances.” GATX Terminals Corporation (n/k/a Kinder Morgan Liquids Terminals LLC) (KMLT) was brought in as a third party defendant because of the noted hazardous substances language and because the Carteret, New Jersey facility (a former GATX Terminals facility) is located on the Arthur Kill River, one of the waterways included in the litigation.  This case was filed against third party defendants in 2009.  Recently, KMLT, as part of a joint defense group, entered a settlement agreement (Consent Judgment) with the NJDEP whereby the settling parties for a prescribed payment, get a contribution bar against first party defendants Occidental, Maxus and Tierra in addition to a release. This third-party Consent Judgment was published in the New Jersey Register for a 60-day comment period and no significant comments were received. Additionally, the NJDEP has reached an agreement for a settlement with Maxus and Tierra. Occidental is not part of the settlement. As part of this settlement, these defendants agreed to dismiss all direct claims against third-party defendants and to not oppose the third-party settlement. The notice and comment period for this settlement agreement has now closed and comments are being reviewed by the NJDEP. We anticipate the Maxus/Tierra settlement and the third-party settlement to be completed by year end. All discovery and trial proceedings are stayed during settlement negotiations.
	Portland Harbor Superfund Site, Willamette River, Portland, Oregon
	In December 2000, the EPA sent out 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 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.  KMP is participating in the allocation process on behalf of both KMLT and KMBT.  Each entity has two facilities located in Portland Harbor.  KMP expects the allocation to conclude in 2014 and the EPA to issue its Record of Decision in 2015. It is anticipated that the cleanup activities would 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
	This is a CERCLA case brought against a number of defendants by a water purveyor whose wells have allegedly been contaminated due to the presence of a number of contaminants.  The Roosevelt Irrigation District is seeking up to $175 million from approximately 70 defendants. Plaintiffs filed its Second Amended Complaint (SAC) on August 6,2013. In the SAC, plaintiffs added defendants but also eliminated a number of claims and defendants that were previously named in the First Amended Complaint. KMEP was added as a defendant. The claims now presented in the SAC against KMEP and SFPP are all related to alleged releases from the SFPP Phoenix Terminal and the alleged impact of these releases on water wells owned by the plaintiffs and located in the vicinity of the Terminal. On October 24, 2013, we moved to dismiss the SAC.
	The City of Los Angeles v. Kinder Morgan Liquids Terminals, LLC, Shell Oil Company, Equilon Enterprises LLC;  California Superior Court, County of Los Angeles, Case No. NC041463
	KMLT is a defendant in a lawsuit filed in 2005 alleging claims for environmental cleanup costs at the former Los Angeles Marine Terminal in the Port of Los Angeles. The lawsuit was stayed beginning in 2009 and remained stayed following the last case management conference in March 2013. On April 9, 2013, KMLT and the Port of Los Angeles entered into a Settlement and Release Agreement the terms of which provide for the dismissal of the litigation by the Port and KMLT’s agreement to pay 60% of the Port’s costs to remediate the former terminal site up to a $15 million cap. Further, according to terms of the Settlement and Release, we received a 5-year lease extension that allows KMLT to continue fuel loading and offloading operations at another KMLT Port of Los Angeles terminal property. The Court approved the parties’ Good Faith Settlement motion in the Superior Court and dismissed the case.
	The City of Los Angeles, KMLT, Chevron and Phillips 66 remain named on a Cleanup and Abatement Order from the California Regional Water Quality Control Board as parties responsible for the cleanup of the former Los Angeles Marine Terminal. The private parties have all settled with the City of Los Angeles and have agreed to pay a percentage of the City’s costs to perform the required cleanup. We anticipate that cleanup activities by the Port at the site will begin by 1st quarter 2014.
	Exxon Mobil Corporation v. GATX Corporation, Kinder Morgan Liquids Terminals, LLC and ST Services, Inc.
	On April 23, 2003, ExxonMobil filed a complaint in the Superior Court of New Jersey, Gloucester County. The lawsuit relates to environmental remediation obligations at a 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, and it too is a party to the lawsuit.
	On June 25, 2007, the NJDEP, the Commissioner of the New Jersey Department of Environmental Protection and the Administrator of the New Jersey Spill Compensation Fund, referred to collectively as the plaintiffs, filed a complaint against ExxonMobil and KMLT, formerly known as GATX Terminals Corporation, alleging natural resource damages related to historic contamination at the Paulsboro terminal.  The complaint was filed in Gloucester County, New Jersey.  Both ExxonMobil and KMLT filed third party complaints against Support Terminals/Plains and successfully brought Support Terminals/Plains into the case. The court consolidated the two cases.
	In mid 2011, KMLT and Plains Products entered into a settlement agreement with the NJDEP for settlement of the state’s alleged natural resource damages claim. The parties then entered into a Consent Judgment concerning the 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 a settlement 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.
	The settlement with the state did not resolve the original complaint brought by ExxonMobil. On or around, April 10, 2013, KMLT, Plains and ExxonMobil settled the original Exxon complaint for past remediation costs for $750,000 to be split 50/50 between KMLT and Plains. All parties have now executed the agreement and the litigation is settled and dismissed.
	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 KMP 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 number 37-2007-00073033-CU-OR-CTL.  On September 26, 2007, KMP removed the case to the United States District Court, Southern District of California, case number 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 their 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 issued its final order reaffirming in all respects its tentative rulings and 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 of this case to the United States Court of Appeals for the Ninth Circuit. The appeal is currently pending.
This site has been, and currently is, under the regulatory oversight and order of the California Regional Water Quality Control Board.  SFPP continues to conduct an extensive remediation effort at the City’s stadium property site.
On May 7, 2013, the City of San Diego filed a writ of mandamus to the California Superior Court seeking an order from the Court setting aside the California Regional Water Quality Control Board’s (RWQCB) approval of KMP’s permit request to increase the discharge of water from KMP’s groundwater treatment system to the City of San Diego’s municipal storm sewer system. KMEP is coordinating with the RWQCB to oppose the City’s writ.
Uranium Mines in Vicinity of Cameron, Arizona
In the 1950s and 1960s, Rare Metals Inc., an 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 United States 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. We are also seeking contribution from the applicable United States’ federal government agencies toward the cost of environmental activities associated with the mines, given its pervasive control over all aspects of the nuclear weapons program.
PHMSA Inspection of Carteret Terminal, Carteret, NJ
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 PHMSA, pursuant to which KMLT paid a penalty of $63,100 and is required to conduct ongoing pipeline integrity testing and other corrective measures by May, 2015.
Southeast Louisiana Flood Protection Litigation
On July 24, 2013, the Board of Commissioners of the Southeast Louisiana Flood Protection Authority - East (“Flood Protection Authority”) filed a petition for damages and injunctive relief in state district court for Orleans Parish, Louisiana (Case No. 13-6911) against TGP and SNG, and approximately one hundred 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 Flood Protection Authority 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.
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 September 30, 2013 and December 31, 2012, we have accrued a total reserve for environmental liabilities in the amount of $390 million and $421 million , respectively, of which $219 million and $253 million, respectively, are associated with KMI (excluding KMP and EPB) and primarily relate to legacy sites acquired in the May 25, 2012 EP acquisition. In addition, as of September 30, 2013 and December 31, 2012, we have recorded a receivable of $14 million and $22 million, respectively, for expected cost recoveries that have been deemed probable.
Other Contingencies
In conjunction with KMP’s acquisition of certain natural gas pipelines from us, we agreed to indemnify KMP with respect to approximately $5.9 billion of its debt. This includes $5.2 billion associated with KMP’s March 2013 and August 2012 purchases of natural gas assets from us. In conjunction with our EP acquisition, we have agreed to indemnify EPB with respect to $470 million of its debt. We would be obligated to perform under these indemnities only if KMP’s or EPB’s assets, as applicable, were unable to satisfy its obligations.
Commitments
Capital Contributions for Elba Island Liquefaction Project
In January 2013, SLC, a subsidiary of EPB, and Shell US Gas and Power, LLC (Shell G&P), a subsidiary of Royal Dutch Shell plc (Shell), formed ELC, EPB’s 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. EPB’s estimated investment at the terminal in Phase I, including both the liquefaction facilities and SLNG ancillary facilities, is approximately $800 million. Phase I of the project requires no additional Department of Energy (DOE) approval.

Accounting_for_Regulatory_Acti

Accounting for Regulatory Activities	9 Months Ended
	Sep. 30, 2013
Regulatory Assets and Liabilities Disclosure [Abstract]
Regulatory Matters	Accounting for Regulatory Activities
	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,” “Accrued other current liabilities,” and “Other long-term liabilities and deferred credits” respectively, in our accompanying consolidated balance sheets. As of September 30, 2013, the recovery period for these regulatory assets is approximately one year to forty-two years .
	The following table summarizes our regulatory asset and liability balances as of September 30, 2013 and December 31, 2012 (in millions):
		September 30, 2013		December 31, 2012
	Current regulatory assets	$	77	$	62
	Non-current regulatory assets	463		402
	Total regulatory assets(a)	$	540	$	464
	Current regulatory liabilities	$	123	$	7
	Non-current regulatory liabilities	393		113
	Total regulatory liabilities(b)	$	516	$	120
	_______
	(a)	Includes an $87 million increase since December 31, 2012 (net of related amortization of $5 million) associated with TGP’s sale of certain natural gas facilities located offshore in the Gulf of Mexico and onshore in the state of Louisiana.
	(b)	During the second quarter of 2013, we began applying regulatory accounting to another one of KMP’s pipeline systems due to a newly negotiated long-term tolling agreement approved by the system’s regulator that went into effect in April 2013. The primary impact of applying regulatory accounting was the reclassification of approximately $362 million of current and long-term deferred credits to regulatory liabilities. KMP expects this regulatory liability to be refunded to rate-payers over approximately the next four years. As of September 30, 2013, $117 million remains classified as current regulatory liability.
	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 recognized both a $92 million increase in regulatory assets and a $36 million gain from the sale of assets.
	More information about our regulatory matters can be found in Note 17 “Regulatory Matters” to our consolidated financial statements included in our 2012 Form 10-K.

Recent_Accounting_Pronouncemen

Recent Accounting Pronouncements	9 Months Ended
	Sep. 30, 2013
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recent Accounting Pronouncements	Recent Accounting Pronouncements
	Accounting Standards Updates
	None of the Accounting Standards Updates (ASU) that we adopted and that became effective January 1, 2013 (including (i) ASU No. 2011-11, “Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities;” (ii) ASU No. 2012-02, “Intangibles-Goodwill and Other (Topic 350): Testing Indefinite-Lived Intangible Assets for Impairment;” (iii) ASU No. 2013-01, “Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities;” and (iv) ASU No. 2013-02, “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income”) had a material impact on our consolidated financial statements.  More information about the four ASUs listed above can be found in Note 18 “Recent Accounting Pronouncements” to our consolidated financial statements that were included in our 2012 Form 10-K.
	On March 5, 2013 the FASB issued ASU No. 2013-05, “Parent’s Accounting for the Cumulative Translation Adjustment upon Derecognition of Certain Subsidiaries or Groups of Assets within a Foreign Entity or of an Investment in a Foreign Entity (a consensus of the FASB Emerging Issues Task Force).” This ASU amends the FASB’s Accounting Standards Codification (ASC) 830, “Foreign Currency Matters,” and ASC 810, “Consolidation,” to address diversity in practice related to the release of cumulative translation adjustments (CTA) into earnings upon the occurrence of certain derecognition events. ASU No. 2013-05 precludes the release of CTA for derecognition events that occur within a foreign entity, unless such events represent a complete or substantially complete liquidation of the foreign entity; however, derecognition events related to investments in a foreign entity result in the release of all CTA related to the derecognized foreign entity, even when a noncontrolling financial interest is retained. ASU No. 2013-05 also amends ASC 805, “Business Combinations,” for transactions that result in a company obtaining control of a business in a step acquisition by increasing an investment in a foreign entity from one accounted for under the equity method to one accounted for as a consolidated investment. ASU No. 2013-05 is effective for fiscal years beginning after December 15, 2013 (January 1, 2014 for us) and is to be applied prospectively to derecognition events occurring after the effective date. The adoption of this ASU is not expected to have a material impact on our consolidated financial statements.
	In July 2013, the FASB issued ASU No. 2013-11, “Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists (Topic 740).”  Under this ASU, an entity must present an unrecognized tax benefit in the financial statements as a reduction of a deferred tax asset for a net operating loss (NOL) carryforward, or similar tax loss or tax credit carryforward, rather than as a liability when (1) the uncertain tax position would reduce the NOL or other carryforward under the tax law of the applicable jurisdiction and (2) the entity intends to use the deferred tax asset for that purpose. This guidance is effective prospectively for fiscal years, and interim periods within those years, beginning after December 15, 2013 (early adoption and retrospective application are permitted). We are currently reviewing the effects of ASU 2013-11. However, this guidance only affects gross versus net presentation and not the recognition or measurement of uncertain tax positions under Topic 740.

Reconciliation_of_Significant_

Reconciliation of Significant Asset Balances	9 Months Ended
	Sep. 30, 2013
Reconciliation of Significant Asset Balances [Abstract]
Reconciliation of Significant Asset Balances	Reconciliation of Significant Balance Sheet Accounts
	The following is a reconciliation between KMP’s and EPB’s significant asset and liability balances as reported in KMP’s and EPB’s Quarterly Reports on Form 10-Q for the quarter ended September 30, 2013 and our consolidated asset and liability balances as shown on our accompanying consolidated balance sheets (in millions):
		September 30,		December 31,
		2013		2012 (a)
	Cash and cash equivalents - KMI(b)	$	137	$	71
	Cash and cash equivalents - KMP	534		529
	Cash and cash equivalents - EPB	145		114
	Cash and cash equivalents	$	816	$	714
	Property, plant and equipment, net–KMI(b)	$	2,630	$	2,735
	Property, plant and equipment, net–KMP	26,742		22,330
	Property, plant and equipment, net–EPB	5,903		5,931
	Property, plant and equipment, net	$	35,275	$	30,996
	Goodwill–KMI(b)	$	17,940	$	18,193
	Goodwill–KMP	6,532		5,417
	Goodwill–EPB	22		22
	Goodwill	$	24,494	$	23,632
	Current portion of debt–KMI(b)	$	2,195	$	1,153
	Current portion of debt–KMP	702		1,155
	Current portion of debt–EPB	76		93
	Current portion of debt	$	2,973	$	2,401
	Long-term debt outstanding–KMI(b)	$	7,724	$	9,148
	Long-term debt outstanding–KMP	18,910		15,907
	Long-term debt outstanding–EPB(c)	4,180		4,254
	Long-term debt outstanding	$	30,814	$	29,309
	_______
	(a)	Retrospectively adjusted as discussed in Note 2.
	(b)	Includes assets and liabilities of KMI’s consolidated subsidiaries, excluding KMP and EPB.
	(c)	Excludes debt fair value adjustments.  Decrease to long-term debt for debt fair value adjustments totaled $8 million as of both September 30, 2013 and December 31, 2012.

Guarantee_of_Securities_of_Sub

Guarantee of Securities of Subsidiaries (Notes)	9 Months Ended
	Sep. 30, 2013
Guarantees [Abstract]
Guarantees [Text Block]	Guarantee of Securities of Subsidiaries
	KMI has guaranteed the payment of the outstanding senior notes issued by El Paso LLC (formerly known as El Paso Corporation). These notes were also guaranteed by El Paso Holdco LLC (“El Paso Holdco”), El Paso LLC’s direct parent. El Paso Issuing Corporation (“Finance Corp”), a direct subsidiary of El Paso LLC, is the co-issuer of these notes. As of both September 30, 2013 and December 31, 2012, approximately $3.9 billion in aggregate principal amount of these series of El Paso LLC senior notes (referred to as the “Guaranteed Notes”) is outstanding. Finance Corp’s obligations as a co-issuer and primary obligor are the same as and joint and several with the obligations of El Paso LLC as issuer. Subject to the limitations set forth in the applicable supplemental indentures, the guarantees of KMI and El Paso Holdco are full and unconditional and joint and several, and guarantee the Guaranteed Notes through their respective maturity dates, the latest of which is in 2037. Finance Corp has no subsidiaries and no independent assets or operations. A significant amount of KMI’s and El Paso Holdco’s income and cash flow are generated by their subsidiaries. As a result, the funds necessary to meet KMI’s and El Paso Holdco’s debt service and/or guarantee obligations are provided in large part by distributions or advances from their subsidiaries. Included among the non-guarantor subsidiaries are KMP, KMR and EPB, along with Kinder Morgan G.P., Inc., the general partner of KMP and El Paso Pipeline GP Company, L.L.C., the general partner of EPB. In the unaudited condensed consolidating financial information presented below, KMI is “Parent Guarantor,” El Paso Holdco is the “Guarantor Subsidiary” and El Paso LLC and Finance Corp are the “Subsidiary Issuers.” The Guarantor Subsidiary and both of the Subsidiary Issuers are 100% owned by KMI.
	Subsequent Event
	On October 3, 2013 El Paso LLC transferred all of it’s assets to El Paso Holdco pursuant to an internal restructuring transaction. In connection with such internal restructuring, El Paso Holdco succeeded El Paso LLC as issuer with respect to the Guaranteed Notes and El Paso LLC ceased to be an obligor with respect to the Guaranteed Notes. KMI continues to guarantee the payment of the Guaranteed Notes and Finance Corp continues to be co-issuer of the Guaranteed Notes. The information below has been prepared based on the legal organization as it existed prior to the reorganization. The internal restructuring will result in a revised presentation of this unaudited condensed consolidating financial information in future periods.
	Condensed Consolidating Balance Sheets as of September 30, 2013
	(In Millions)
	(Unaudited)
		Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	ASSETS
	Cash and cash equivalents	$	106		$	—		$	—		$	710		$	—		$	816
	All other current assets	672			11			4			2,430			(342		)	2,775
	Property, plant and equipment, net	9			—			—			35,266			—			35,275
	Investments	—			—			—			6,044			—			6,044
	Investments in affiliates	20,375			10,602			6,469			—			(37,446		)	—
	Goodwill	—			—			8,062			16,432			—			24,494
	Notes receivable from affiliates	2			—			—			1,993			(1,995		)	—
	Deferred charges and all other assets	209			—			903			4,935			(876		)	5,171
	Total assets	$	21,373		$	10,613		$	15,438		$	67,810		$	(40,659	)	$	74,575
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Liabilities
	Current portion of debt	$	1,514		$	—		$	530		$	929		$	—		$	2,973
	All other current liabilities	194			5			160			3,425			(342		)	3,442
	Long-term debt	1,872			—			4,011			27,155			—			33,038
	Notes payable to affiliates	1,993			—			—			2			(1,995		)	—
	Deferred income taxes	2,021			—			—			3,169			(876		)	4,314
	All other long-term liabilities	514			—			164			1,828			—			2,506
	Total liabilities	8,108			5			4,865			36,508			(3,213		)	46,273
	Stockholders’ equity
	Total KMI equity	13,265			10,608			10,573			15,875			(37,056		)	13,265
	Noncontrolling interests	—			—			—			15,427			(390		)	15,037
	Total stockholders’ equity	13,265			10,608			10,573			31,302			(37,446		)	28,302
	Total liabilities and stockholders’ equity	$	21,373		$	10,613		$	15,438		$	67,810		$	(40,659	)	$	74,575
	Condensed Consolidating Balance Sheets as of December 31, 2012
	(In Millions)
	(Unaudited)
		Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	ASSETS
	Cash and cash equivalents	$	3		$	—		$	45		$	666		$	—		$	714
	All other current assets	813			27			123			9,322			(7,325		)	2,960
	Property, plant and equipment, net	8			—			—			30,988			—			30,996
	Investments	—			—			19			5,785			—			5,804
	Investments in affiliates	20,053			11,190			13,232			—			(44,475		)	—
	Goodwill	—			—			8,059			15,573			—			23,632
	Notes receivable from affiliates	1,555			—			—			2,095			(3,650		)	—
	Deferred charges and all other assets	202			—			1,158			3,912			(1,133		)	4,139
	Total assets	$	22,634		$	11,217		$	22,636		$	68,341		$	(56,583	)	$	68,245
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Liabilities
	Current portion of debt	$	1,035		$	—		$	115		$	1,251		$	—		$	2,401
	All other current liabilities	196			383			6,741			2,832			(7,325		)	2,827
	Long-term debt	3,068			—			4,378			24,554			—			32,000
	Notes payable to affiliates	1,764			296			35			1,555			(3,650		)	—
	Deferred income taxes	2,095			—			—			3,109			(1,133		)	4,071
	All other long term liabilities	610			—			169			2,067			—			2,846
	Total liabilities	8,768			679			11,438			35,368			(12,108		)	44,145
	Stockholders’ equity
	Total KMI equity	13,866			10,538			11,198			22,580			(44,316		)	13,866
	Noncontrolling interests	—			—			—			10,393			(159		)	10,234
	Total stockholders’ equity	13,866			10,538			11,198			32,973			(44,475		)	24,100
	Total liabilities and stockholders’ equity	$	22,634		$	11,217		$	22,636		$	68,341		$	(56,583	)	$	68,245
	Condensed Consolidating Statements of Income for the Three Months Ended September 30, 2013
	(In Millions)
	(Unaudited)
		Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Revenues	$	9		$	—		$	—		$	3,756		$	(9	)	$	3,756
Costs, expenses and other
Costs of sales	—			—			—			1,543			—			1,543
Depreciation, depletion and amortization	—			—			—			467			—			467
Other operating expenses	12			—			—			702			(9		)	705
Total costs, expenses and other	12			—			—			2,712			(9		)	2,715
Operating (loss) income	(3		)	—			—			1,044			—			1,041
Other income (expense)
Earnings from equity investments	334			50			123			100			(507		)	100
Interest, net	(58		)	—			(65		)	(295		)	—			(418		)
Amortization of excess cost of equity investments and other, net	—			—			—			(1		)	—			(1		)
Income from continuing operations before income taxes	273			50			58			848			(507		)	722
Income tax benefit (expense)	13			—			(8		)	(176		)	—			(171		)
Net income	286			50			50			672			(507		)	551
Net income attributable to noncontrolling interests	—			—			—			(280		)	15			(265		)
Net income attributable to controlling interests	$	286		$	50		$	50		$	392		$	(492	)	$	286
Condensed Consolidating Statements of Income for the Three Months Ended September 30, 2012
(In Millions)
(Unaudited)
	Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Revenues	$	9		$	—		$	—		$	2,861		$	—		$	2,870
Costs, expenses and other
Costs of sales	—			—			—			854			—			854
Depreciation, depletion and amortization	—			—			—			403			—			403
Other operating expenses	26			—			(1		)	736			—			761
Total costs, expenses and other	26			—			(1		)	1,993			—			2,018
Operating (loss) income	(17		)	—			1			868			—			852
Other income (expense)
Earnings from equity investments	350			59			138			101			(547		)	101
Interest, net	(188		)	(3		)	(129		)	(203		)	—			(523		)
Amortization of excess cost of equity investments and other, net	1			(1		)	(1		)	17			—			16
Income from continuing operations before income taxes	146			55			9			783			(547		)	446
Income tax benefit (expense)	54			1			51			(166		)	—			(60		)
Income from continuing operations	200			56			60			617			(547		)	386
Loss from discontinued operations, net of tax	—			—			—			(131		)	—			(131		)
Net income	200			56			60			486			(547		)	255
Net income attributable to noncontrolling interests	—			—			—			(53		)	(2		)	(55		)
Net income attributable to controlling interests	$	200		$	56		$	60		$	433		$	(549	)	$	200
Condensed Consolidating Statements of Income for the Nine Months Ended September 30, 2013
(In Millions)
(Unaudited)
	Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Revenues	$	27		$	—		$	—		$	10,195		$	(24	)	$	10,198
Costs, expenses and other
Costs of sales	—			—			—			3,767			—			3,767
Depreciation, depletion and amortization	1			—			—			1,326			—			1,327
Other operating expenses	21			—			(3		)	2,280			(24		)	2,274
Total costs, expenses and other	22			—			(3		)	7,373			(24		)	7,368
Operating income	5			—			3			2,822			—			2,830
Other income (expense)
Earnings from equity investments	1,007			127			378			294			(1,512		)	294
Interest, net	(194		)	—			(239		)	(814		)	—			(1,247		)
Amortization of excess cost of equity investments and other, net	(1		)	—			—			789			—			788
Income from continuing operations before income taxes	817			127			142			3,091			(1,512		)	2,665
Income tax benefit (expense)	38			—			(15		)	(698		)	—			(675		)
Income from continuing operations	855			127			127			2,393			(1,512		)	1,990
Loss from discontinued operations, net of tax	—			—			—			(2		)	—			(2		)
Net income	855			127			127			2,391			(1,512		)	1,988
Net income attributable to noncontrolling interests	—			—			—			(1,208		)	75			(1,133		)
Net income attributable to controlling interests	$	855		$	127		$	127		$	1,183		$	(1,437	)	$	855
Condensed Consolidating Statements of Income for the Nine Months Ended September 30, 2012
(In Millions)
(Unaudited)
	Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Revenues	$	26		$	—		$	—		$	6,868		$	—		$	6,894
Costs, expenses and other
Costs of sales	—			—			—			2,071			—			2,071
Depreciation, depletion and amortization	—			—			—			1,010			—			1,010
Other operating expenses	216			—			63			1,906			—			2,185
Total costs, expenses and other	216			—			63			4,987			—			5,266
Operating (loss) income	(190		)	—			(63		)	1,881			—			1,628
Other income (expense)
Earnings from equity investments	465			(17		)	106			238			(554		)	238
Interest, net	(320		)	(3		)	(143		)	(527		)	—			(993		)
Amortization of excess cost of equity investments and other, net	(1		)	(1		)	(2		)	24			—			20
(Loss) income from continuing operations before income taxes	(46		)	(21		)	(102		)	1,616			(554		)	893
Income tax benefit (expense)	142			1			86			(394		)	—			(165		)
Income (loss) from continuing operations	96			(20		)	(16		)	1,222			(554		)	728
Loss from discontinued operations, net of tax	(1		)	—			—			(788		)	—			(789		)
Net income (loss)	95			(20		)	(16		)	434			(554		)	(61		)
Net loss attributable to noncontrolling interests	—			—			—			175			(19		)	156
Net income (loss) attributable to controlling interests	$	95		$	(20	)	$	(16	)	$	609		$	(573	)	$	95
Condensed Consolidating Statements of Comprehensive Income for the Three Months Ended September 30, 2013
(In Millions)
(Unaudited)
	Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Net income	$	286		$	50		$	50		$	672		$	(507	)	$	551
Other comprehensive income, net of tax
Change in fair value of derivatives utilized for hedging purposes	(42		)	(2		)	(2		)	(78		)	44			(80		)
Reclassification of change in fair value of derivatives to net income	10			—			—			19			(10		)	19
Foreign currency translation adjustments	17			—			—			32			(16		)	33
Adjustments to pension and other postretirement benefit plan liabilities	66			52			52			78			(169		)	79
Total other comprehensive income	51			50			50			51			(151		)	51
Comprehensive income	337			100			100			723			(658		)	602
Comprehensive income attributable to noncontrolling interests	—			—			—			(265		)	—			(265		)
Comprehensive income attributable to controlling interests	$	337		$	100		$	100		$	458		$	(658	)	$	337
Condensed Consolidating Statements of Comprehensive Income for the Three Months Ended September 30, 2012
(In Millions)
(Unaudited)
	Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Net income	$	200		$	56		$	60		$	486		$	(547	)	$	255
Other comprehensive loss, net of tax
Change in fair value of derivatives utilized for hedging purposes	(30		)	(2		)	(2		)	(70		)	33			(71		)
Reclassification of change in fair value of derivatives to net income	(5		)	(2		)	(2		)	(10		)	9			(10		)
Foreign currency translation adjustments	22			—			—			52			(20		)	54
Adjustments to pension and other postretirement benefit plan liabilities	(1		)	(1		)	(1		)	(18		)	18			(3		)
Total other comprehensive loss	(14		)	(5		)	(5		)	(46		)	40			(30		)
Comprehensive income	186			51			55			440			(507		)	225
Comprehensive income attributable to noncontrolling interests	—			—			—			(39		)	—			(39		)
Comprehensive income attributable to controlling interests	$	186		$	51		$	55		$	401		$	(507	)	$	186
Condensed Consolidating Statements of Comprehensive Income for the Nine Months Ended September 30, 2013
(In Millions)
(Unaudited)
	Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Net income	$	855		$	127		$	127		$	2,391		$	(1,512	)	$	1,988
Other comprehensive income (loss), net of tax
Change in fair value of derivatives utilized for hedging purposes	(22		)	6			6			(48		)	9			(49		)
Reclassification of change in fair value of derivatives to net income	5			(1		)	(1		)	10			(3		)	10
Foreign currency translation adjustments	(28		)	—			—			(53		)	27			(54		)
Adjustments to pension and other postretirement benefit plan liabilities	66			49			49			76			(161		)	79
Total other comprehensive income (loss)	21			54			54			(15		)	(128		)	(14		)
Comprehensive income	876			181			181			2,376			(1,640		)	1,974
Comprehensive income attributable to noncontrolling interests	—			—			—			(1,098		)	—			(1,098		)
Comprehensive income attributable to controlling interests	$	876		$	181		$	181		$	1,278		$	(1,640	)	$	876
Condensed Consolidating Statements of Comprehensive Income for the Nine Months Ended September 30, 2012
(In Millions)
(Unaudited)
	Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Net income (loss)	$	95		$	(20	)	$	(16	)	$	434		$	(554	)	$	(61	)
Other comprehensive income, net of tax
Change in fair value of derivatives utilized for hedging purposes	25			(5		)	(5		)	68			(12		)	71
Reclassification of change in fair value of derivatives to net income (loss)	1			(2		)	(2		)	5			3			5
Foreign currency translation adjustments	21			—			—			50			(19		)	52
Adjustments to pension and other postretirement benefit plan liabilities, net of tax	12			12			12			(5		)	(21		)	10
Total other comprehensive income	59			5			5			118			(49		)	138
Comprehensive income (loss)	154			(15		)	(11		)	552			(603		)	77
Comprehensive loss attributable to noncontrolling interests	—			—			—			77			—			77
Comprehensive income (loss) attributable to controlling interests	$	154		$	(15	)	$	(11	)	$	629		$	(603	)	$	154
Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2013
(In Millions)
(Unaudited)
	Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Net cash provided by operating activities	$	1,129		$	—		$	113		$	3,174		$	(1,639	)	$	2,777
Cash flows from investing activities
Capital expenditures	(3		)	—			—			(2,267		)	—			(2,270		)
Proceeds from sale of investments in Express pipeline system	—			—			—			402			—			402
Proceeds from sale of investments in BBPP Holdings Ltda	—			—			—			88			—			88
Acquisitions of assets and investments	—			—			—			(292		)	—			(292		)
Repayment from related party	—			—			—			10			—			10
Funding to affiliates	(170		)	—			(581		)	(525		)	1,276			—
Drop down assets to KMP	994			—			—			(994		)	—			—
Contributions to investments	(6		)	—			—			(171		)	6			(171		)
Investments in KMP and EPB	(59		)	—			(3		)	—			62			—
Distributions from equity investments in excess of cumulative earnings	2			—			70			68			(23		)	117
Other, net	—			—			—			78			—			78
Net cash provided by (used in) investing activities	758			—			(514		)	(3,603		)	1,321			(2,038		)
Cash flows from financing activities
Issuance of debt	1,220			—			133			8,154			—			9,507
Payment of debt	(1,930		)	—			(50		)	(6,671		)	—			(8,651		)
Funding from affiliates	584			—			273			419			(1,276		)	—
Debt issuance costs	—			—			—			(23		)	—			(23		)
Cash dividends	(1,196		)	—			—			—			—			(1,196		)
Repurchase of warrants	(463		)	—			—			—			—			(463		)
Distributions to parent	—			—			—			(1,654		)	1,654			—
Contributions from noncontrolling interests	—			—			—			1,474			(54		)	1,420
Distributions to noncontrolling interests	—			—			—			(1,220		)	—			(1,220		)
Other, net	1			—			—			6			(6		)	1
Net cash (used in) provided by financing activities	(1,784		)	—			356			485			318			(625		)
Effect of exchange rate changes on cash and cash equivalents	—			—			—			(12		)	—			(12		)
Net increase (decrease) in cash and cash equivalents	103			—			(45		)	44			—			102
Cash and cash equivalents, beginning of period	3			—			45			666			—			714
Cash and cash equivalents, end of period	$	106		$	—		$	—		$	710		$	—		$	816
Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2012
(In Millions)
(Unaudited)
	Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Net cash provided by (used in)operating activities	$	725		$	—		$	(429	)	$	2,761		$	(1,130	)	$	1,927
Cash flows from investing activities
Capital expenditures	(6		)	—			—			(1,393		)	—			(1,399		)
Acquisitions of assets and investments	—			—			—			(72		)	—			(72		)
Repayment from related party	—			—			—			48			—			48
Funding to affiliates	(398		)	—			(313		)	(632		)	1,343			—
Contributions to investments	(15		)	—			—			(143		)	—			(158		)
Distributions from equity investments in excess of cumulative earnings	11			—			29			119			—			159
Investments in KMP and EPB	(69		)	—			(7		)	—			76			—
Acquisition of EP	(5,212		)	—			—			242			—			(4,970		)
Drop down assets to KMP	3,485			—			—			(3,485		)	—			—
Other, net	—			—			—			27			—			27
Net cash used in investing activities	(2,204		)	—			(291		)	(5,289		)	1,419			(6,365		)
Cash flows from financing activities
Issuance of debt	7,182			—			62			8,483			—			15,727
Payment of debt	(4,683		)	—			(176		)	(5,562		)	—			(10,421		)
Funding from affiliates	82			—			905			356			(1,343		)	—
Debt issuance costs	(88		)	—			—			(16		)	—			(104		)
Cash dividends	(810		)	—			—			—			—			(810		)
Repurchase of warrants	(136		)	—			—			—			—			(136		)
Distributions to parent	—			—			—			(1,080		)	1,080			—
Contributions from noncontrolling interests	—			—			—			1,423			(19		)	1,404
Distributions to noncontrolling interests	—			—			—			(853		)	—			(853		)
Other, net	(15		)	—			—			4			(7		)	(18		)
Net cash provided by financing activities	1,532			—			791			2,755			(289		)	4,789
Effect of exchange rate changes on cash and cash equivalents	—			—			—			13			—			13
Net increase in cash and cash equivalents	53			—			71			240			—			364
Cash and cash equivalents, beginning of period	2			—			—			409			—			411
Cash and cash equivalents, end of period	$	55		$	—		$	71		$	649		$	—		$	775
Update for Recast and Correction to Condensed Consolidating Financial Information
During the second quarter 2013, KMI determined it had incorrectly presented certain amounts in the Condensed Consolidating Financial Information included in its Form 10-K for the period ended December 31, 2012, and its Form 10-Q for the periods ended September 30, 2012 and March 31, 2013. The Company revised its Condensed Consolidating Financial Statements, for the applicable periods presented, to correct for the presentation of (i) investments, loans, capital contributions and repayments between, and (ii) incorrect inclusion of certain entities within, the Parent Guarantor, Guarantor Subsidiary, Subsidiary Issuers and Non-guarantor Subsidiaries. These errors had no impact on KMI’s consolidated results of operations, cash flows, or financial position, or any debt covenants. We concluded the errors were not material to the consolidated financial statements.
In addition, the Company has updated the Condensed Consolidating Financial Information to reflect the recast related to the March 1, 2013 drop-down transaction and the retroactive application of the EP purchase accounting adjustments discussed in Note 2 on each of the statements that were included in the Quarterly Report on Form 10-Q for the periods indicated or the Annual Report on Form 10-K for the period ended December 31, 2012. The impact of these revisions are shown in Note 15 “Guarantee of Securities of Subsidiaries” to our consolidated financial statements included in our Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2013.

General_Policies

General (Policies)	9 Months Ended
	Sep. 30, 2013
Business Acquisition [Line Items]
Income Tax, Policy [Policy Text Block]	Our accounting policy is to apply 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.
Segment Reporting, Policy [Policy Text Block]	Reportable Segments
	We operate the following reportable business segments.  These segments and their principal sources of revenues are as follows:
	•	Natural Gas Pipelines—the sale, transport, processing, treating, fractionation, storage and gathering of natural gas and NGLs;
	•	CO2—KMP—the production, sale and transportation of crude oil from fields in the Permian Basin of West Texas and the production, transportation and marketing of CO2 used as a flooding medium for recovering crude oil from mature oil fields;
	•	Products Pipelines—KMP— the transportation and terminaling of refined petroleum products, including gasoline, diesel fuel, jet fuel, NGLs, crude and condensate, and bio-fuels;
	•	Terminals—KMP—the transloading and storing of refined petroleum products and dry and liquid bulk products, including coal, petroleum coke, cement, alumina, salt and other bulk chemicals;
	•	Kinder Morgan Canada—KMP—the transportation of crude oil and refined products from Alberta, Canada to marketing terminals and refineries in British Columbia, and the state of Washington. As further described in Note 2, Kinder Morgan Canada divested its interest in the Express pipeline system effective March 14, 2013; and
	•	Other—primarily includes several physical natural gas contracts with power plants associated with EP’s legacy trading activities. These contracts obligate EP to sell natural gas to these plants and have various expiration dates ranging from 2012 to 2028.
	We evaluate performance principally based on each segment’s earnings before depreciation, depletion and amortization expenses (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.
Regulatory Assets and Liabilities [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,” “Accrued other current liabilities,” and “Other long-term liabilities and deferred credits” respectively, in our accompanying consolidated balance sheets. As of September 30, 2013, the recovery period for these regulatory assets is approximately one year to forty-two years .
Drop-Down of EP Assets to KMP [Policy Text Block]	The drop-down transactions were accounted for as transfers of net assets between entities under common control. Specifically, we have retrospectively adjusted our consolidated financial statements to reflect the recognition by KMP of the acquired assets and assumed liabilities at our carrying value, including our EP purchase accounting adjustments as of May 25, 2012.  In this report, we refer to these acquisitions of assets by KMP from us as the drop-down transactions; the combined group of assets acquired by KMP from us as the drop-down asset groups; the El Paso Natural Gas pipeline system or El Paso Natural Gas Company, L.L.C. as EPNG; and the EP Midstream assets or Kinder Morgan Altamont LLC (formerly, El Paso Midstream Investment Company, L.L.C.) as the midstream assets.
Organization	Organization
	Kinder Morgan, Inc. is the largest midstream and the third largest energy company in North America with a combined enterprise value of approximately $110 billion. We own an interest in or operate approximately 82,000 miles of pipelines and 180 terminals. Our pipelines transport natural gas, refined petroleum products, crude oil, CO2 and other products, and our terminals store petroleum products and chemicals, and handle such products as ethanol, coal, petroleum coke and steel. We are also the leading producer and transporter of CO2 for enhanced oil recovery projects in North America.
	Effective on May 25, 2012, we completed the acquisition of all of the outstanding shares of EP. As a result, we own a 41% limited partner interest and the 2% general partner interest in EPB, as well as certain natural gas pipeline assets.
	We also own the general partner and approximately 10% of the limited partner interests of KMP, one of the largest publicly-traded pipeline limited partnerships in America.
	Our common stock trades on the NYSE under the symbol “KMI.”
	KMR is a Delaware limited liability company.  KMGP, the general partner of KMP and a wholly-owned subsidiary of ours, owns all of KMR’s voting shares.  KMR, pursuant to a delegation of control agreement, has been delegated, to the fullest extent permitted under Delaware law, all of KMGP’s power and authority to manage and control the business and affairs of KMP, subject to KMGP’s right to approve certain transactions.
Earnings Per Share	Earnings per Share
	For the three and nine months ended September 30, 2013, earnings per share was calculated using the two-class method.  Earnings were allocated to Class P shares of common stock and to 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. For the three and nine months ended September 30, 2013, the following potential Class P common shares are antidilutive and, accordingly, are excluded from the determination of diluted earnings per share; (i) 6 million and 3 million, respectively, related to unvested restricted stock awards; (ii) 400 million and 419 million, respectively, related to outstanding warrants to purchase our Class P shares; and (iii) 10 million for each period, related to convertible trust preferred securities.
	The following table sets forth the allocation of net income for Class P shares and for participating securities for the three and nine months ended September 30, 2013 (in millions):
		Three Months Ended September 30, 2013		Nine Months Ended September 30, 2013
		Net Income Available to Shareholders
	Class P	$	283	$	851
	Participating securities(a)	3		4
	Net Income Attributable to Kinder Morgan, Inc.	$	286	$	855
	_______
	(a)	Participating securities are unvested restricted stock awards issued to management employees that contain non-forfeitable rights to dividend equivalent payments.
	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.
	For the three and nine months ended September 30, 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 dilutive potential shares.  This included 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, dilutive potential shares also included the Class P shares issuable in connection with the warrants and the trust preferred securities (see Note 4).  As no securities were convertible into Class A shares, the basic and diluted earnings per share computations for Class A shares were the same.
Income Tax Impact of the Drop-Down of EP Assets to KMP [Policy Text Block]	Income Tax Impact of the Drop-Down of EP Assets to KMP
	As discussed above, we accounted for the acquisition of EP as a business combination and for the subsequent March 2013 and August 2012 drop-down transactions as transfers of net assets between entities under common control. 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.
	Our accounting policy is to apply 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. 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 will be amortized to income tax expense over the remaining useful lives of the transferred assets of approximately 25 years Similar to the impact described above, KMP’s acquisition of a 50% ownership interest in the EP Midstream joint venture, also generated the recognition of a deferred charge and corresponding deferred tax liability and is included in the amount above.
	The amortization of the deferred charge will result in incremental income tax expense of approximately $20 million per year. For the three and nine months ended September 30, 2013, total income tax expense related to the amortization of the deferred charges was approximately $5 million and $15 million, respectively.
El Paso Corporation [Member]
Business Acquisition [Line Items]
Business Combinations Policy [Policy Text Block]	We accounted for the EP acquisition using the acquisition method of accounting which requires, among other things, that assets acquired and liabilities assumed be recognized on the balance sheet at their acquisition date fair values.
Kinder Morgan Energy Partners, L.P. [Member] | KMP Acquisiton of Copano Energy LLC [Member]
Business Acquisition [Line Items]
Business Combinations Policy [Policy Text Block]	KMP accounted for its acquisition of Copano under the acquisition method of accounting, and accordingly, measured the consideration paid to Copano unitholders, the acquired identifiable tangible and intangible assets, and the assumed liabilities at their acquisition-date fair values. Also, due to the fact that KMP’s acquisition included the remaining 50% interest in Eagle Ford that it did not already own, KMP remeasured its existing 50% equity investment in Eagle Ford to its fair value as of the acquisition date, resulting in the recognition of a $558 million pre-tax non-cash gain reported separately within “Other Income (Expense)
KMPbs FTC Natural Gas Pipelines [Member]
Business Acquisition [Line Items]
Basis of Accounting, Policy [Policy Text Block]	Basis of Presentation
	General
	We have prepared our accompanying unaudited consolidated financial statements under the rules and regulations of the SEC. These rules and regulations conform to the accounting principles contained in the FASB’s Accounting Standards Codification. Under such rules and regulations, we have condensed or omitted certain information and notes normally included in financial statements prepared in conformity with the Codification.  We believe, however, that our disclosures are adequate to make the information presented not misleading.
	Our accompanying unaudited consolidated financial statements reflect normal adjustments, and also recurring adjustments that are, in the opinion of our management, necessary for a fair statement of our financial results for the interim periods. In addition, certain amounts from prior periods have been reclassified to conform to the current presentation (including reclassifications between “Services” and “Product sales and other” within the “Revenues” section of our accompanying consolidated statements of income). Interim results are not necessarily indicative of results for a full year; accordingly, you should read these consolidated financial statements in conjunction with our consolidated financial statements and related notes included in our Annual Report on Form 10-K for the year ended December 31, 2012 (2012 Form 10-K).
	Our accounting records are maintained in United States dollars, and all references to dollars are United States dollars, except where stated otherwise.  Canadian dollars are designated as C$.  Our consolidated financial statements include our accounts and those of our majority-owned subsidiaries as well as the accounts of KMP, EPB and KMR.  Investments in jointly-owned operations in which we hold a 50% or less interest (other than KMP, EPB and KMR, because we have the ability to exercise significant control over their operating and financial policies) are accounted for under the equity method.  All significant intercompany transactions and balances have been eliminated in consolidation.
	Notwithstanding the consolidation of KMP and EPB, and their respective subsidiaries, into our financial statements, we are not liable for, and our assets are not available to satisfy, the obligations of KMP and EPB, and/or their respective subsidiaries, and vice versa, except as discussed in Note 11, “—Other Contingencies.”  Responsibility for payments of obligations reflected in our, KMP or EPB’s financial statements is a legal determination based on the entity that incurs the liability.
	KMP’s FTC Natural Gas Pipelines Disposal Group - Discontinued Operations
	Effective November 1, 2012, we sold KMP’s (i) Kinder Morgan Interstate Gas Transmission natural gas pipeline system; (ii) Trailblazer natural gas pipeline system; (iii) Casper and Douglas natural gas processing operations; and (iv) 50% equity investment in the Rockies Express natural gas pipeline system to Tallgrass Energy Partners, LP (now known as Tallgrass Development, LP) (Tallgrass) for approximately $1.8 billion in cash (before selling costs), or $3.3 billion including KMP’s share of joint venture debt. In this report, we refer to this combined group of assets as KMP’s FTC Natural Gas Pipelines disposal group. For more information about the presentation of KMP’s FTC Natural Gas Pipelines disposal group as discontinued operations, see Note 2 “Summary of Significant Accounting Policies—Basis of Presentation” to our consolidated financial statements included in our 2012 Form 10-K.
KMP Sale of Express Pipeline System [Member]
Business Acquisition [Line Items]
Business Combinations Policy [Policy Text Block]	Prior to KMP’s sale, we (i) accounted for KMP’s equity investment under the equity method of accounting; (ii) accounted for KMP’s debt investment under the historical amortized cost method of accounting; and (iii) included the financial results of the Express pipeline system within the Kinder Morgan Canada—KMP business segment.

General_Tables

General (Tables)	9 Months Ended
	Sep. 30, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Net Income for Shareholders and Participating Securities [Table Text Block]	The following table sets forth the allocation of net income for Class P shares and for participating securities for the three and nine months ended September 30, 2013 (in millions):
		Three Months Ended September 30, 2013			Nine Months Ended September 30, 2013
		Net Income Available to Shareholders
	Class P	$	283		$	851
	Participating securities(a)	3			4
	Net Income Attributable to Kinder Morgan, Inc.	$	286		$	855
	_______
	(a)	Participating securities are unvested restricted stock awards issued to management employees that contain non-forfeitable rights to dividend equivalent payments.
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	Income taxes from continuing operations included in our accompanying consolidated statements of income were as follows (in millions, except percentages):
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Income tax expense	$	171		$	60		$	675		$	165
	Effective tax rate	24		%	13		%	25		%	18		%
Schedule of Earnings Per Share, Basic and Diluted	The following tables set forth the computation of basic and diluted earnings per share from continuing operations for the three and nine months ended September 30, 2012 (in millions, except per share amounts):
		Three Months Ended September 30, 2012
		Income from Continuing Operations Available to Shareholders
		Class P			Class A			Participating			Total
								Securities (a)
	Income from continuing operations										$	386
	Less: income from continuing operations attributable to noncontrolling interests										(171		)
	Income from continuing operations attributable to KMI										215
	Dividends paid in the period	$	212		$	142		$	10		(364		)
	Excess distributions over earnings	(87		)	(62		)	—			$	(149	)
	Income from continuing operations attributable to shareholders	$	125		$	80		$	10		$	215
	Basic earnings per share from continuing operations
	Basic weighted-average number of shares outstanding	605			432			N/A
	Basic earnings per common share from continuing operations(b)	$	0.21		$	0.19		N/A
	Diluted earnings per share from continuing operations
	Income from continuing operations attributable to shareholders and assumed conversions(c)	$	215		$	80		N/A
	Diluted weighted-average number of shares	1,039			432			N/A
	Diluted earnings per common share from continuing operations(b)	$	0.21		$	0.19		N/A
		Nine Months Ended September 30, 2012
		Income from Continuing Operations Available to Shareholders
		Class P			Class A			Participating			Total
								Securities (a)
	Income from continuing operations										$	728
	Less: income from continuing operations attributable to noncontrolling interests										(441		)
	Income from continuing operations attributable to KMI										287
	Dividends paid in the period	$	343		$	432		$	35		(810		)
	Excess distributions over earnings	(221		)	(301		)	(1		)	$	(523	)
	Income from continuing operations attributable to shareholders	$	122		$	131		$	34		$	287
	Basic earnings per share from continuing operations
	Basic weighted-average number of shares outstanding	366			496			N/A
	Basic earnings per common share from continuing operations(b)	$	0.33		$	0.26		N/A
	Diluted earnings per share from continuing operations
	Income from continuing operations attributable to shareholders and assumed conversions(c)	$	287		$	131		N/A
	Diluted weighted-average number of shares	864			496			N/A
	Diluted earnings per common share from continuing operations(b)	$	0.33		$	0.26		N/A
	The following tables set forth the computation of total basic and diluted earnings per share for the three and nine months ended September 30, 2012 (in millions, except per share amounts):
		Three Months Ended September 30, 2012
		Net Income Available to Shareholders
		Class P			Class A			Participating			Total
								Securities (a)
	Net income attributable to KMI										$	200
	Dividends paid in the period	$	212		$	142		$	10		(364		)
	Excess distributions over earnings	(96		)	(68		)	—			$	(164	)
	Net income attributable to shareholders	$	116		$	74		$	10		$	200
	Basic earnings per share
	Basic weighted-average number of shares outstanding	605			432			N/A
	Basic earnings per common share(b)	$	0.19		$	0.17		N/A
	Diluted earnings per share
	Net income attributable to shareholders and assumed conversions(c)	$	200		$	74		N/A
	Diluted weighted-average number of shares	1,039			432			N/A
	Diluted earnings per common share(b)	$	0.19		$	0.17		N/A
		Nine Months Ended September 30, 2012
		Net Income Available to Shareholders
		Class P			Class A			Participating			Total
								Securities (a)
	Net income attributable to KMI										$	95
	Dividends paid in the period	$	343		$	432		$	35		(810		)
	Excess distributions over earnings	(303		)	(410		)	(2		)	$	(715	)
	Net income attributable to shareholders	$	40		$	22		$	33		$	95
	Basic earnings per share
	Basic weighted-average number of shares outstanding	366			496			N/A
	Basic earnings per common share(b)	$	0.11		$	0.04		N/A
	Diluted earnings per share
	Net income attributable to shareholders and assumed conversions(c)	$	95		$	22		N/A
Diluted weighted-average number of shares	864			496			N/A
Diluted earnings per common share(b)	$	0.11		$	0.04		N/A
_______
(a)	Participating securities included Class B shares, Class C shares, and unvested restricted stock awards issued to non-senior management employees that contained rights to dividend equivalents in the case of the restricted shares.  Our Class B and Class C shares were entitled to participate in our earnings, only to the extent of cash distributions made to them. As a result, no earnings in excess of dividends received were allocated to the Class B and Class C shares in our determination of basic and diluted earnings per share.
(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 dilutive potential shares

Acquisitions_and_Divestitures_1

Acquisitions and Divestitures (Tables)	9 Months Ended
	Sep. 30, 2013
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Information [Table Text Block]	The following summarized unaudited pro forma consolidated income statement information for the three and nine months ended September 30, 2013 and 2012, assumes that the EP, Copano and the Goldsmith Landreth Unit acquisitions had occurred as of January 1, 2012. 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, 2012 or the results that will be attained in the future. Amounts presented below are in millions, except for the per share amounts:
		Pro Forma
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Revenues	$	3,756		$	3,341		$	10,903		$	9,384
	Income from Continuing Operations	$	551		$	379		$	1,952		$	410
	(Loss) Income from Discontinued Operations, Net of Tax	$	—		$	(131	)	$	(2	)	$	1,279
	Net Income	$	551		$	248		$	1,950		$	1,689
	Net (Income) Loss Attributable to Noncontrolling Interests	$	(265	)	$	127		$	(1,120	)	$	291
	Net Income Attributable to Kinder Morgan, Inc.	$	286		$	375		$	830		$	1,980
	Diluted Earnings per Common Share
	Class P Shares	$	0.27		$	0.36		$	0.8		$	1.91
	Class A Shares				$	0.34					$	1.84
Copano Energy LLC [Member]
Business Acquisition [Line Items]
Schedule of Purchase Price Allocation [Table Text Block]	As of September 30, 2013, KMP’s preliminary purchase price allocation related to the Copano acquisition, as adjusted to date, is as follows (in millions). KMP’s evaluation of the assigned fair values is ongoing and subject to adjustment:
	Preliminary Purchase Price Allocation:
	Current assets (including cash acquired of $30)	$	218
	Property, plant and equipment	2,805
	Investments	387
	Goodwill	1,119
	Other intangibles, net	1,375
	Other assets	13
	Total assets	5,917
	Less: Fair value of previously held 50% interest in Eagle Ford	(704		)
	Total assets acquired	5,213
	Current liabilities	(207		)
	Other liabilities	(4		)
	Long-term debt	(1,252		)
	Noncontrolling interests	(17		)
	KMP’s common unit consideration	$	3,733
KMPbs FTC Natural Gas Pipelines [Member]
Business Acquisition [Line Items]
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	Summarized financial information for KMP’s FTC Natural Gas Pipelines disposal group is as follows (in millions):
		Three Months Ended September 30, 2012			Nine Months Ended September 30, 2012
	Operating revenues	$	71		$	204
	Operating expenses	(45		)	(116		)
	Depreciation and amortization	—			(7		)
	Other expense	(1		)	(1		)
	Earnings from equity investments	22			64
	Interest income and Other, net	—			1
	Income from operations of KMP’s FTC Natural Gas Pipelines disposal group, net of tax	$	47		$	145

Debt_Tables

Debt (Tables)	9 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]
Schedule of Debt [Table Text Block]	The following table provides detail on the principal amount of our outstanding debt balances, as of September 30, 2013 and December 31, 2012. The table amounts exclude all debt fair value adjustments, including debt discounts and premiums (in millions).
			September 30, 2013				December 31, 2012
	KMI
	Senior term loan facility, variable rate, due 2015		$	1,528			$	2,714
	Senior notes and debentures, 5.15% through 7.45%, due 2015 through 2098		315				315
	Credit facility due December 31, 2014(a)		1,514				1,035
	Subsidiary borrowings (as obligor)
	K N Capital Trust I, deferrable interest debentures issued by subsidiary trusts, 7.63% and 8.56%, due 2027 and 2028		27				27
	Kinder Morgan Finance Company, LLC, senior notes, 5.70% through 6.40%, due 2016 through 2036		1,636				1,636
	El Paso, senior notes, 6.50% through 12.00%, due 2013 through 2037		3,860				3,860
	EPC Building, LLC promissory note, 3.967%, due 2013 through 2035(b)		464				217
	Colorado Interstate Gas Services Company, 7.76% Totem note payable, due 2018		1				1
	Other credit facilities due December 20, 2013, March 20 and June 20, 2014		293				210
	EP preferred securities, 4.75%, due March 31, 2028		281				286
	KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock		100				100
	Total debt — KMI		10,019				10,401
	Less: Current portion of debt — KMI		(2,195		)		(1,153		)
	Total long-term debt — KMI(c)		$	7,824			$	9,248
	KMP and EPB
	KMP
	Senior notes, 2.65% through 9.00% due 2013 through 2043(d)		$	16,100			$	13,350
	Commercial paper borrowings(e)		174				621
	Credit facility due May 1, 2018		—				—
	KMP subsidiary borrowings (as obligor)
	TGP senior notes, 7.00% through 8.375%, due 2016 through 2037(f)		1,790				1,790
	EPNG senior notes 5.95% through 8.625%, due 2017 through 2032(g)		1,115				1,115
	Copano senior notes, 7.125%, due April 1, 2021(h)		332				—
	Other miscellaneous subsidiary debt		101				186
	Total debt — KMP		19,612				17,062
	Less: Current portion of debt — KMP(i)		(702		)		(1,155		)
	Total long-term debt — KMP(c)		18,910				15,907
	EPB
	EPPOC
	Senior notes, 4.10% through 8.00% due 2013 through 2042(j)		2,260				2,348
	Credit facility due May 27, 2016(k)		—				—
	EPB subsidiary borrowings (as obligor)
	Colorado Interstate Gas Company, L.L.C. senior notes, 5.95% through 6.85%, due 2015 through 2037		475				475
	SLNG senior notes, 9.50% through 9.75%, due 2014 through 2016		135				135
	SNG notes, 4.40% through 8.00%, due 2017 through 2032		1,211				1,211
	Other financing obligations		175				178
	Total debt — EPB		4,256				4,347
	Less: Current portion of debt — EPB		(76		)		(93		)
	Total long-term debt — EPB(c)		4,180				4,254
	Total long-term debt — KMP and EPB		$	23,090			$	20,161
	_______
	(a)	As of September 30, 2013 and December 31, 2012, the weighted average interest rates on KMI’s credit facility borrowings were 2.68% and 2.72%, respectively.
	(b)	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. EPC Building, LLC, as the landlord, leases the property to KMI as a tenant.  Proceeds from the issuance of the notes were used to reduce KMI’s credit facility borrowings.
	(c)	Excludes debt fair value adjustments. As of September 30, 2013 and December 31, 2012, our “Debt fair value adjustments” increased our debt balances by $2,124 million and $2,591 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 5 “Risk Management—Fair Value of Derivative Contracts.”
	(d)	On February 28, 2013, KMP completed a public offering of $1 billion in principal amount of senior notes in two separate series, consisting of $600 million of 3.50% notes due September 1, 2023 and $400 million of 5.00% notes due March 1, 2043. KMP received net proceeds of $991 million, and used the proceeds to pay a portion of the purchase price for the March 2013 drop-down transaction and to reduce the borrowings under its commercial paper program. On August 5, 2013, KMP completed a public offering of $1.75 billion in principal amount of senior notes in three separate series, consisting of $800 million of 2.65% notes due February 1, 2019, $650 million of 4.15% notes due February 1, 2024 and $300 million of 5.00% notes due March 1, 2043 (the 5.00% notes issued in August 2013 constitute a further issuance of the $400 million aggregate principal amount of the 5.00% notes that KMP issued in February 2013 and form a single series with these notes). KMP received net proceeds of $1,724 million, and used the proceeds to reduce the borrowings of its commercial paper program and to fund its partial redemption and retirement of Copano’s 7.125% senior notes in September 2013 (see “—KMP’s Copano Debt” below).
	(e)	In May 2013, in association with the increase of capacity negotiated for KMP’s senior unsecured revolving bank credit facility (see “—Credit Facilities - KMP” below), KMP increased its commercial paper program by $500 million to provide for the issuance of up to $2.7 billion. As of September 30, 2013 and December 31, 2012, the average interest rates on KMP’s outstanding commercial paper borrowings were 0.27% and 0.45%, respectively. The borrowings under KMP’s commercial paper program were used principally to finance the acquisitions and capital expansions made during the first nine months of 2013 and during 2012, and in the near term, KMP expects that its short-term liquidity and financing needs will be met primarily through borrowings made under its commercial paper program.
	(f)	Consists of six separate series of fixed-rate unsecured senior notes that KMP assumed as part of the August 2012 drop-down transaction.
	(g)	Consists of four separate series of fixed-rate unsecured senior notes that KMP assumed as part of the August 2012 and March 2013 drop-down transactions.
	(h)	Consists of a single series of fixed-rate unsecured senior notes that KMP guaranteed as part of its May 1, 2013 Copano acquisition. The notes mature in full on April 1, 2021, and interest on the notes is payable semiannually on April 1 and October 1 of each year. For further information about these notes, see “—KMP’s Copano Debt” below.
	(i)	As of September 30, 2013 and December 31, 2012, includes commercial paper borrowings of $174 million and $621 million.
	(j)	In September 2013, EPPOC repaid $88 million of 8% senior notes.
	(k)	LIBOR plus 1.75%.
	The estimated fair value of our outstanding debt balance (both short-term and long-term and including debt fair value adjustments), is disclosed below (in millions):
		September 30, 2013								December 31, 2012
		Carrying				Estimated				Carrying			Estimated
		Value				Fair Value				Value			Fair Value
	Total debt	$	36,011			$	35,939			$	34,401		$	36,720
Schedule of preferred share distributions [Table Text Block]	Kinder Morgan G.P., Inc. 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:
			Three Months Ended September 30,								Nine Months Ended September 30,
			2013				2012				2013			2012
	Per share cash distribution declared for the period(a)		$	10.517			$	10.948			$	31.531		$	52.598
	Per share cash distribution paid in the period		$	10.545			$	20.825			$	31.652		$	62.475
	_________
	(a)	Distribution declared for the three months ended September 30, 2013, was declared on October 16, 2013 and is payable on November 18, 2013 to shareholders of record as of October 31, 2013.

Stockholders_Equity_Tables

Stockholders Equity (Tables)	9 Months Ended
	Sep. 30, 2013
Stockholders' Equity Note [Abstract]
Schedule of Common Stock Outstanding Roll Forward	The following tables set forth the changes in our outstanding series of shares during the nine months ended September 30, 2013 and 2012.
		Class P
	Balance at December 31, 2012	1,035,668,596
	Shares issued with conversions of EP Trust I Preferred securities	74,421
	Shares issued for exercised warrants	16,886
	Restricted shares vested	86,922
	Balance at September 30, 2013	1,035,846,825
		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 (Note 2)	330,154,610			—			—			—
	Shares issued with conversions of EP Trust I Preferred securities	454,028			—			—			—
	Shares converted	147,255,126			(147,255,126	)		(4,827,797	)		(2,761	)
	Shares canceled	(446,206	)		—			—			—
	Restricted shares vested	77,925			—			—			—
	Balance at September 30, 2012	648,416,623			388,717,261			89,304,799			2,315,497
Schedule of Dividends Payable [Table Text Block]	Holders of our common stock share equally in any dividend declared by our board of directors, subject to the rights of the holders of any outstanding preferred stock. The following table provides information about our per share dividends.
		Three Months Ended September 30,								Nine Months Ended September 30,
		2013				2012				2013			2012
	Per common share cash dividend declared for the period	$	0.41			$	0.36			$	1.19		$	1.03
	Per common share cash dividend paid in the period	$	0.4			$	0.35			$	1.15		$	0.98
Schedule of Warrants Outstanding Roll Forward [Table Text Block]	The table below sets forth the changes in our outstanding warrants during the nine months ended September 30, 2013 and 2012.
		Warrants
		Nine Months Ended September 30,
		2013			2012
	Beginning balance	439,809,442			—
	Warrants issued in EP acquisition(a)	—			504,598,883
	Warrants issued with conversions of EP Trust I Preferred securities(b)	113,757			693,971
	Warrants exercised	(21,208	)		—
	Warrants repurchased(c)	(91,460,387	)		(59,787,050	)
	Ending balance	348,441,604			445,505,804
	_______
	(a)	See Note 2, “Acquisitions and Divestitures—KMI Acquisition of EP.”
	(b)	See Note 8, “Debt” to our consolidated financial statements included in our 2012 Form 10-K.
	(c)	On May 23, 2012, we announced that our board of directors had approved a warrant repurchase program, authorizing us to repurchase in the aggregate up to $250 million of warrants, which repurchase was completed as of May 2013. In the second quarter of 2013, we repurchased an additional $38 million in warrants, which was approved by our board of directors separate and apart from the publicly announced repurchase program. On July 17, 2013, we announced that our board of directors had authorized an additional $350 million share and warrant repurchase program. As of September 30, 2013, $331 million of the $350 million repurchase program had been utilized. On October 16, 2013, we announced that our board of directors had approved an additional share and warrant repurchase program authorizing us to repurchase in the aggregate up to $250 million of additional shares or warrants. During the nine months ended September 30, 2013 and 2012, we paid a total of $463 million and $136 million, respectively, for the repurchase of warrants.
Schedule of Noncontrolling Interest	caption “Noncontrolling interests” in our accompanying consolidated balance sheets consists of interests that we do not own in the following subsidiaries (in millions):
		September 30,				December 31,
		2013				2012
	KMP	$	7,612			$	3,270
	EPB	4,141				4,111
	KMR	3,020				2,716
	Other	264				137
		$	15,037			$	10,234
Schedule of noncontrolling interest contributions text block [Table Text Block]	table below shows significant issuances of common units or shares, the net proceeds from the issuances and the use of the proceeds during the nine months ended September 30, 2013 for KMP, EPB and KMR (dollars in millions and units and shares in thousands).
		Issuances		Common units/shares			Net proceeds				Use of proceeds
				(in thousands)			(in millions)
	KMP
	Issued under equity distribution agreement(a)
		2013		8,248			$	695			Reduced borrowings under KMP's commercial paper program
	Other issuances
		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(c)
		2013		2,038			$	85		(d)	General partnership purposes
	KMR(e)
		2013		1,757			$	145			Purchased additional KMP i-units; KMP then used proceeds to reduce borrowings under its commercial paper program
	_______
	(a)	On June 3, 2013, KMP entered into a fourth amended and restated equity distribution agreement with UBS Securities LLC (UBS) which increased the aggregate offering price of KMP’s common units to up to $2.175 billion (up from $1.9 billion), and on August 7, 2013, KMP entered into a second and separate equity distribution agreement with UBS. The terms of this second equity distribution agreement are substantially similar to those in KMP’s previous agreement, and allows it to offer and sell from time to time additional KMP common units having an aggregate offering price of up to $1.9 billion through UBS, as sales agent.
	(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)	On March 7, 2013, EPB entered into an equity distribution agreement with Citigroup. Pursuant to the provisions of EPB’s equity distribution agreement, EPB may 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)	Represents proceeds received from noncontrolling interests and excludes our $2 million contribution as the owner of EPB’s general partner.
	(e)	On May 4, 2012, KMR entered into an equity distribution agreement with Credit Suisse Securities (USA) LLC (Credit Suisse). Pursuant to the provisions of KMR’s equity distribution agreement, it may 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]	following table provides information about distributions from our noncontrolling interests (in millions except per unit distribution amounts):
		Three Months Ended September 30,								Nine Months Ended September 30,
		2013				2012				2013			2012
	KMP
	Per unit cash distribution declared for the period	$	1.35			$	1.26			$	3.97		$	3.69
	Per unit cash distribution paid in the period	$	1.32			$	1.23			$	3.91		$	3.59
	Cash distributions paid in the period to the public	$	377			$	275			$	983		$	788
	EPB(a)
	Per unit cash distribution declared for the period	$	0.65			$	0.58			$	1.9		$	1.13
	Per unit cash distribution paid in the period	$	0.63			$	0.55			$	1.86		$	0.55
	Cash distributions paid in the period to the public	$	80			$	64			$	235		$	64
	KMR(b)
	Share distributions paid in the period	1,880,172				1,578,616				5,411,720			4,646,736
	_______
	(a)	Represents distribution information since the May 2012 EP acquisition.
	(b)	KMR’s distributions are 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.  On October 16, 2013, KMR declared a share distribution of 0.017610 shares per outstanding share (2,153,480 total shares) payable on November 14, 2013 to shareholders of record as of October 31, 2013, based on the $1.35 per common unit distribution declared by KMP.
	S

Risk_Management_Tables

Risk Management (Tables)	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Contracts Subject to Netting Agreements [Table Text Block]	The following tables present our derivative contracts subject to such netting agreements as of the dates indicated (in millions):
			Offsetting of financial assets and derivative assets
															Gross amounts not offset in the balance sheet
			Gross amounts of recognized assets				Gross amounts offset in the balance sheet				Amounts of assets presented in the balance sheet				Financial instruments				Cash collateral held(a)			Net amount
	As of September 30, 2013:
	Natural gas, crude and NGL derivative contracts		$	97			$	—			$	97			$	(60	)		$	—		$	37
	Power derivative contracts		$	22			$	—			$	22			$	(22	)		$	—		$	—
	Interest rate swap agreements		$	314			$	—			$	314			$	(19	)		$	—		$	295
	As of December 31, 2012:
	Natural gas, crude and NGL derivative contracts		$	86			$	—			$	86			$	(17	)		$	—		$	69
	Power derivative contracts		$	21			$	—			$	21			$	(21	)		$	—		$	—
	Interest rate swap agreements		$	665			$	—			$	665			$	—			$	—		$	665
			Offsetting of financial liabilities and derivative liabilities
															Gross amounts not offset in the balance sheet
			Gross amounts of recognized liabilities				Gross amounts offset in the balance sheet				Amounts of liabilities presented in the balance sheet				Financial instruments				Cash collateral posted(b)			Net amount
	As of September 30, 2013:
	Natural gas, crude and NGL derivative contracts		$	(95	)		$	—			$	(95	)		$	60			$	—		$	(35	)
	Power derivative contracts		$	(140	)		$	—			$	(140	)		$	22			$	5		$	(113	)
	Interest rate swap agreements		$	(79	)		$	—			$	(79	)		$	19			$	—		$	(60	)
	As of December 31, 2012:
	Natural gas, crude and NGL derivative contracts		$	(33	)		$	—			$	(33	)		$	17			$	5		$	(11	)
	Power derivative contracts		$	(179	)		$	—			$	(179	)		$	21			$	—		$	(158	)
	Interest rate swap agreements		$	(1	)		$	—			$	(1	)		$	—			$	—		$	(1	)
	_______
	(a)	Cash margin deposits held by KMP associated with its energy commodity contract positions and OTC swap agreements and reported within “Accrued other current liabilities” in our accompanying consolidated balance sheets.
	(b)	$5 million of cash margin deposits posted by KMI at September 30, 2013 and KMP at December 31, 2012, associated with energy commodity contract positions and OTC swap agreements and reported within “Other current assets” in our accompanying consolidated balance sheets.
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income [Table Text Block]	Changes in the components of our “Accumulated other comprehensive income (loss)” for the nine months ended September 30, 2013 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, 2012	$	7			$	51			$	(176	)		$	(118	)
	Other comprehensive (loss) income before reclassifications	(22		)		(28		)		66				16
	Amounts reclassified from accumulated other comprehensive income	5				—				—				5
	Net current-period other comprehensive (loss) income	(17		)		(28		)		66				21
	Balance as of September 30, 2013	$	(10	)		$	23			$	(110	)		$	(97	)
Schedule of Derivative Instruments	As of September 30, 2013, KMI and KMP had the following outstanding commodity forward contracts to hedge their forecasted energy commodity purchases and sales:
		Net open position long/(short)
	Derivatives designated as hedging contracts
	Crude oil fixed price	(23.1	)		million barrels
	Natural gas fixed price	(35.2	)		billion cubic feet
	Natural gas basis	(30.7	)		billion cubic feet
	Derivatives not designated as hedging contracts
	Crude oil fixed price	0.5			million barrels
	Crude oil basis	(1.2	)		million barrels
	Natural gas fixed price	0.3			billion cubic feet
	Natural gas basis	7.9			billion cubic feet
	NGLs fixed price	0.4			million barrels
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table summarizes the fair values of our derivative contracts included in our accompanying consolidated balance sheets as of September 30, 2013 and December 31, 2012 (in millions):
	Fair Value of Derivative Contracts
					Asset derivatives								Liability derivatives
					September 30,				December 31,				September 30,				December 31,
					2013				2012				2013				2012
			Balance sheet location		Fair value				Fair value				Fair value				Fair value
	Derivatives designated as hedging contracts
	Natural gas and crude derivative contracts		Other current assets/(Accrued other current liabilities)		$	19			$	42			$	(49	)		$	(18	)
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		65				40				(43		)		(11		)
	Subtotal				84				82				(92		)		(29		)
	Interest rate swap agreements		Other current assets/(Accrued other current liabilities)		114				9				—				—
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		200				656				(79		)		(1		)
	Subtotal				314				665				(79		)		(1		)
	Total				398				747				(171		)		(30		)
	Derivatives not designated as hedging contracts
	Natural gas, crude and NGL derivative contracts		Other current assets/(Accrued other current liabilities)		11				4				(2		)		(3		)
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		2				—				(1		)		(1		)
	Subtotal				13				4				(3		)		(4		)
	Power derivative contracts		Other current assets/(Accrued other current liabilities)		9				8				(55		)		(59		)
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		13				13				(85		)		(120		)
	Subtotal				22				21				(140		)		(179		)
	Total				35				25				(143		)		(183		)
	Total derivatives				$	433			$	772			$	(314	)		$	(213	)
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance	The following two tables summarize the impact of our derivative contracts on our accompanying consolidated statements of income for each of the three and nine months ended September 30, 2013 and 2012 (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(a)
					Three Months Ended September 30,								Nine Months Ended September 30,
					2013				2012				2013				2012
	Interest rate swap agreements		Interest expense		$	(26	)		$	29			$	(333	)		$	110
	Total				$	(26	)		$	29			$	(333	)		$	110
	Fixed rate debt		Interest expense		$	26			$	(29	)		$	333			$	(110	)
	Total				$	26			$	(29	)		$	333			$	(110	)
	_______
	(a)	Amounts reflect the change in the fair value of interest rate swap agreements and the change in the fair value of the associated fixed rate debt which exactly offset each other as a result of no hedge ineffectiveness.
	Derivatives		Amount of gain/(loss)								Location of		Amount of gain/(loss) reclassified from								Location of	Amount of gain/(loss)
	in cash flow		recognized in OCI								gain/(loss)		Accumulated OCI								gain/(loss)	recognized in income
	hedging		on derivative(effective portion)(a)								reclassified from		into income								recognized in	on derivative
	relationships										Accumulated OCI		(effective portion)(b)								income on	(ineffective portion
											into income										derivative	and amount
											(effective										(ineffective	excluded from
											portion)										portion	effectiveness testing)
																					and amount
																					excluded from
																					effectiveness
																					testing)
			Three Months Ended September 30,										Three Months Ended September 30,									Three Months Ended September 30,
			2013				2012						2013				2012					2013			2012
	Energy commodity derivative  contracts		$	(78	)		$	(69	)		Natural gas sales		$	—			$	1			Natural gas sales	$	—		$	—
											Product sales and other		(22		)		—				Product sales and other	(8		)	(5		)
											Costs of sales		3				7				Costs of sales	—			—
	Interest rate swap agreements		(2		)		(2		)		Interest expense		—				2				Interest expense	—			—
	Total		$	(80	)		$	(71	)		Total		$	(19	)		$	10			Total	$	(8	)	$	(5	)
	Derivatives		Amount of gain/(loss)								Location of		Amount of gain/(loss)								Location of	Amount of gain/(loss)
	in cash flow		recognized in OCI								gain/(loss)		reclassified from								gain/(loss)	recognized in income
	hedging		on derivative(effective portion)(a)								reclassified from		Accumulated OCI								recognized in	on derivative
	relationships										Accumulated OCI		into income								income on	(ineffective portion
											into income		(effective portion)(b)								derivative	and amount
											(effective										(ineffective	excluded from
											portion)										portion	effectiveness testing)
																					and amount
																					excluded from
																					effectiveness
																					testing)
			Nine Months Ended September 30,										Nine Months Ended September 30,									Nine Months Ended September 30,
			2013				2012						2013				2012					2013			2012
	Energy commodity derivative  contracts		$	(55	)		$	76			Natural gas sales		$	—			$	3			Natural gas sales	$	—		$	—
											Product sales and other		(9		)		(23		)		Product sales and other	(2		)	(8		)
											Costs of sales		(2		)		13				Costs of sales	—			—
	Interest rate swap agreements		6				(5		)		Interest expense		1				2				Interest expense	—			—
	Total		$	(49	)		$	71			Total		$	(10	)		$	(5	)		Total	$	(2	)	$	(8	)
	_______
	(a)	We expect to reclassify an approximate $17 million loss associated with energy commodity price risk management activities and included in our accumulated other comprehensive loss and noncontrolling interest balances as of September 30, 2013 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).
	For the three and nine months ended September 30, 2013, we recognized losses of $7 million and $10 million, respectively, in income and included these amounts within “Product sales and other” from derivative contracts not designated as accounting hedges. For the three and nine months ended September 30, 2012, such amounts were not significant.

Fair_Value_Tables

Fair Value (Tables)	9 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]
Schedule of Debt [Table Text Block]	The following table provides detail on the principal amount of our outstanding debt balances, as of September 30, 2013 and December 31, 2012. The table amounts exclude all debt fair value adjustments, including debt discounts and premiums (in millions).
			September 30, 2013				December 31, 2012
	KMI
	Senior term loan facility, variable rate, due 2015		$	1,528			$	2,714
	Senior notes and debentures, 5.15% through 7.45%, due 2015 through 2098		315				315
	Credit facility due December 31, 2014(a)		1,514				1,035
	Subsidiary borrowings (as obligor)
	K N Capital Trust I, deferrable interest debentures issued by subsidiary trusts, 7.63% and 8.56%, due 2027 and 2028		27				27
	Kinder Morgan Finance Company, LLC, senior notes, 5.70% through 6.40%, due 2016 through 2036		1,636				1,636
	El Paso, senior notes, 6.50% through 12.00%, due 2013 through 2037		3,860				3,860
	EPC Building, LLC promissory note, 3.967%, due 2013 through 2035(b)		464				217
	Colorado Interstate Gas Services Company, 7.76% Totem note payable, due 2018		1				1
	Other credit facilities due December 20, 2013, March 20 and June 20, 2014		293				210
	EP preferred securities, 4.75%, due March 31, 2028		281				286
	KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock		100				100
	Total debt — KMI		10,019				10,401
	Less: Current portion of debt — KMI		(2,195		)		(1,153		)
	Total long-term debt — KMI(c)		$	7,824			$	9,248
	KMP and EPB
	KMP
	Senior notes, 2.65% through 9.00% due 2013 through 2043(d)		$	16,100			$	13,350
	Commercial paper borrowings(e)		174				621
	Credit facility due May 1, 2018		—				—
	KMP subsidiary borrowings (as obligor)
	TGP senior notes, 7.00% through 8.375%, due 2016 through 2037(f)		1,790				1,790
	EPNG senior notes 5.95% through 8.625%, due 2017 through 2032(g)		1,115				1,115
	Copano senior notes, 7.125%, due April 1, 2021(h)		332				—
	Other miscellaneous subsidiary debt		101				186
	Total debt — KMP		19,612				17,062
	Less: Current portion of debt — KMP(i)		(702		)		(1,155		)
	Total long-term debt — KMP(c)		18,910				15,907
	EPB
	EPPOC
	Senior notes, 4.10% through 8.00% due 2013 through 2042(j)		2,260				2,348
	Credit facility due May 27, 2016(k)		—				—
	EPB subsidiary borrowings (as obligor)
	Colorado Interstate Gas Company, L.L.C. senior notes, 5.95% through 6.85%, due 2015 through 2037		475				475
	SLNG senior notes, 9.50% through 9.75%, due 2014 through 2016		135				135
	SNG notes, 4.40% through 8.00%, due 2017 through 2032		1,211				1,211
	Other financing obligations		175				178
	Total debt — EPB		4,256				4,347
	Less: Current portion of debt — EPB		(76		)		(93		)
	Total long-term debt — EPB(c)		4,180				4,254
	Total long-term debt — KMP and EPB		$	23,090			$	20,161
	_______
	(a)	As of September 30, 2013 and December 31, 2012, the weighted average interest rates on KMI’s credit facility borrowings were 2.68% and 2.72%, respectively.
	(b)	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. EPC Building, LLC, as the landlord, leases the property to KMI as a tenant.  Proceeds from the issuance of the notes were used to reduce KMI’s credit facility borrowings.
	(c)	Excludes debt fair value adjustments. As of September 30, 2013 and December 31, 2012, our “Debt fair value adjustments” increased our debt balances by $2,124 million and $2,591 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 5 “Risk Management—Fair Value of Derivative Contracts.”
	(d)	On February 28, 2013, KMP completed a public offering of $1 billion in principal amount of senior notes in two separate series, consisting of $600 million of 3.50% notes due September 1, 2023 and $400 million of 5.00% notes due March 1, 2043. KMP received net proceeds of $991 million, and used the proceeds to pay a portion of the purchase price for the March 2013 drop-down transaction and to reduce the borrowings under its commercial paper program. On August 5, 2013, KMP completed a public offering of $1.75 billion in principal amount of senior notes in three separate series, consisting of $800 million of 2.65% notes due February 1, 2019, $650 million of 4.15% notes due February 1, 2024 and $300 million of 5.00% notes due March 1, 2043 (the 5.00% notes issued in August 2013 constitute a further issuance of the $400 million aggregate principal amount of the 5.00% notes that KMP issued in February 2013 and form a single series with these notes). KMP received net proceeds of $1,724 million, and used the proceeds to reduce the borrowings of its commercial paper program and to fund its partial redemption and retirement of Copano’s 7.125% senior notes in September 2013 (see “—KMP’s Copano Debt” below).
	(e)	In May 2013, in association with the increase of capacity negotiated for KMP’s senior unsecured revolving bank credit facility (see “—Credit Facilities - KMP” below), KMP increased its commercial paper program by $500 million to provide for the issuance of up to $2.7 billion. As of September 30, 2013 and December 31, 2012, the average interest rates on KMP’s outstanding commercial paper borrowings were 0.27% and 0.45%, respectively. The borrowings under KMP’s commercial paper program were used principally to finance the acquisitions and capital expansions made during the first nine months of 2013 and during 2012, and in the near term, KMP expects that its short-term liquidity and financing needs will be met primarily through borrowings made under its commercial paper program.
	(f)	Consists of six separate series of fixed-rate unsecured senior notes that KMP assumed as part of the August 2012 drop-down transaction.
	(g)	Consists of four separate series of fixed-rate unsecured senior notes that KMP assumed as part of the August 2012 and March 2013 drop-down transactions.
	(h)	Consists of a single series of fixed-rate unsecured senior notes that KMP guaranteed as part of its May 1, 2013 Copano acquisition. The notes mature in full on April 1, 2021, and interest on the notes is payable semiannually on April 1 and October 1 of each year. For further information about these notes, see “—KMP’s Copano Debt” below.
	(i)	As of September 30, 2013 and December 31, 2012, includes commercial paper borrowings of $174 million and $621 million.
	(j)	In September 2013, EPPOC repaid $88 million of 8% senior notes.
	(k)	LIBOR plus 1.75%.
	The estimated fair value of our outstanding debt balance (both short-term and long-term and including debt fair value adjustments), is disclosed below (in millions):
		September 30, 2013								December 31, 2012
		Carrying				Estimated				Carrying			Estimated
		Value				Fair Value				Value			Fair Value
	Total debt	$	36,011			$	35,939			$	34,401		$	36,720
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 as of September 30, 2013 and December 31, 2012, based on the three levels established by the Codification. The fair value measurements in the tables below do not include cash margin deposits made by us or our counterparties, which are reported within “Other current assets” and “Accrued other current liabilities,” respectively, in our accompanying consolidated balance sheets (in millions).
		Asset fair value measurements using
		Total				Quoted prices in active markets for identical				Significant other observable inputs (Level 2)			Significant
						assets (Level 1)							unobservable
													inputs (Level 3)
	As of September 30, 2013
	Energy commodity derivative contracts(a)	$	119			$	13			$	43		$	63
	Interest rate swap agreements	$	314			$	—			$	314		$	—
	As of December 31, 2012
	Energy commodity derivative contracts(a)	$	107			$	3			$	76		$	28
	Interest rate swap agreements	$	665			$	—			$	665		$	—
		Liability fair value measurements using
		Total				Quoted prices in				Significant other  observable			Significant
						active markets				inputs (Level 2)			unobservable
						for identical							inputs (Level 3)
						liabilities
						(Level 1)
	As of September 30, 2013
	Energy commodity derivative contracts(a)	$	(235	)		$	(5	)		$	(47	)	$	(183	)
	Interest rate swap agreements	$	(79	)		$	—			$	(79	)	$	—
	As of December 31, 2012
	Energy commodity derivative contracts(a)	$	(212	)		$	(3	)		$	(26	)	$	(183	)
	Interest rate swap agreements	$	(1	)		$	—			$	(1	)	$	—
	_______
	(a)	Level 1 consists primarily of NYMEX natural gas futures. Level 2 consists primarily of OTC WTI swaps and OTC natural gas swaps that are settled on NYMEX.  Level 3 consists primarily of WTI options, WTI basis swaps, NGL options and power derivative contracts.
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 for each of the three and nine months ended September 30, 2013 and 2012 (in millions):
	Significant unobservable inputs (Level 3)
		Three Months Ended September 30,								Nine Months Ended September 30,
		2013				2012				2013			2012
	Derivatives-net asset (liability)
	Beginning of Period	$	(114	)		$	(220	)		$	(155	)	$	7
	Total gains or (losses)
	Included in earnings	(17		)		(7		)		(18		)	(8		)
	Included in other comprehensive loss	(2		)		(6		)		(2		)	—
	Purchases(a)	—				—				18			(243		)
	Settlements	13				14				37			25
	End of Period	$	(120	)		$	(219	)		$	(120	)	$	(219	)
	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	$	(14	)		$	(10	)		$	(13	)	$	(6	)

Reportable_Segments_Tables

Reportable Segments (Tables)	9 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	Financial information by segment follows (in millions):
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Revenues
	Natural Gas Pipelines
	Revenues from external customers(a)	$	2,388		$	1,646		$	6,197		$	3,440
	Intersegment revenues	2			—			3			—
	CO2–KMP	456			420			1,345			1,250
	Products Pipelines–KMP	474			386			1,371			940
	Terminals–KMP
	Revenues from external customers	354			334			1,034			1,017
	Intersegment revenues	—			—			1			1
	Kinder Morgan Canada–KMP	74			80			221			226
	Other	1			(4		)	3			(5		)
	Total segment revenues	3,749			2,862			10,175			6,869
	Other revenues	9			8			27			26
	Less: Total intersegment revenues	(2		)	—			(4		)	(1		)
	Total consolidated revenues	$	3,756		$	2,870		$	10,198		$	6,894
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Segment earnings (loss) before depreciation, depletion, amortization and amortization of excess cost of equity investments(b)
	Natural Gas Pipelines(a)(c)	$	958		$	822		$	3,281		$	1,477
	CO2–KMP	340			327			1,040			988
	Products Pipelines–KMP(d)	202			150			399			490
	Terminals–KMP	217			183			609			564
	Kinder Morgan Canada–KMP(e)	43			56			286			158
	Other	-3			21			(4		)	18
	Total segment EBDA	1,757			1,559			5,611			3,695
	Total segment depreciation, depletion and amortization	-467			-403			(1,327		)	(1,010		)
	Total segment amortization of excess cost of investments	-11			-5			(29		)	(9		)
	Other revenues	9			8			27			26
	General and administrative expenses(f)	-158			-186			(481		)	(816		)
	Unallocable interest and other, net of unallocable interest income(g)	-420			-533			(1,257		)	(1,013		)
	Unallocable income tax expense	-159			-54			(554		)	(145		)
	Loss from discontinued operations, net of tax(h)	—			-131			(2		)	(789		)
	Total consolidated net income (loss)	$	551		$	255		$	1,988		$	(61	)
		September 30,			December 31,
		2013			2012
	Assets
	Natural Gas Pipelines	$	52,146		$	46,600
	CO2–KMP	4,611			4,148
	Products Pipelines–KMP	6,466			6,089
	Terminals–KMP	6,673			5,931
	Kinder Morgan Canada–KMP	1,662			1,724
	Other	567			601
	Total segment assets	72,125			65,093
	Corporate assets(i)	2,450			2,854
	Assets held for sale(j)	—			298
	Total consolidated assets	$	74,575		$	68,245
	_______
	(a)	Increases in the three and nine month 2013 amounts versus the three and nine month 2012 amounts reflect our May 25, 2012 acquisition of EP and KMP’s May 1, 2013 acquisition of Copano.
	(b)	Includes revenues, earnings from equity investments, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other expense (income).
	(c)	Nine month 2013 amount includes a $558 million non-cash gain from the remeasurement of net assets to fair value. See Note 2 for further discussion.
	(d)	Nine month 2013 amount includes a $177 million increase in expense associated with adjustments to certain legal liabilities related to both transportation rate cases and environmental matters.
	(e)	Three and nine month 2013 amounts include a $1 million decrease and a $140 million increase, respectively, from after-tax loss and gain amounts on the sale of KMP’s investments in the Express pipeline system.
	(f)	Nine month 2012 amount includes increases in expense of (i) $157 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; and (iv) $96 million for legal fees and litigation reserves. These increases in expense were partially offset by a $17 million benefit associated with pension income.
	(g)	Three and nine month 2012 amounts include increases in expense of $95 million and $104 million, respectively, of capitalized financing fees, almost all of which was associated with the EP acquisition financing, that was written-off (primarily due to debt repayment) or amortized.
	(h)	Represents amounts primarily attributable to KMP’s FTC Natural Gas Pipelines disposal group and other, net of tax. Nine month 2013 amount represents an incremental loss related to the sale of KMP’s disposal group effective November 1, 2012. Three month 2012 amount includes a $179 million non-cash loss from remeasurement of net assets to fair value, and nine month 2012 amount includes a combined $934 million loss from both costs to sell and the remeasurement of net assets to fair value, net of tax, and $7 million of depreciation and amortization expense.
	(i)	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.
	(j)	2012 amount primarily represents amounts attributable to KMP’s Express pipelines system and our ownership interest in the Bolivia to Brazil Pipeline as of December 31, 2012.

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2013
Tables [Abstract]
Related party balances [Table Text Block]	The following table summarizes our balance sheet affiliate balances (in millions):
		30-Sep-13		31-Dec-12
	Balance sheet location
	Accounts receivable, net	$	20	$	25
	Assets held for sale(a)	—		114
	Other current assets	3		14
	Deferred charges and other assets	48		48
		$	71	$	201
	Current portion of debt – KMP and EPB(b)	$	5	$	5
	Accounts payable	9		11
	Long-term debt - Outstanding - KMP and EPB(b)	170		173
		$	184	$	189
	_______
	(a)2012 amount related to KMP’s equity investment in the Express pipeline system (see Note 2).
	(b)EPB has financing obligations payable to WYCO

Pension_and_Other_Postretireme1

Pension and Other Postretirement Benefit Plans (Tables)	9 Months Ended
	Sep. 30, 2013
Defined Benefit Plans and Other Postretirement Benefit Plans Disclosures [Abstract]
Schedule of Net Benefit Costs [Table Text Block]	The components of net benefit (credit) cost for our pension and other postretirement benefit (OPEB) plans, not including KMP and EPB’s plans, are as follows (in millions):
		Pension Benefits						OPEB						Pension Benefits						OPEB
		Three Months Ended September 30,						Three Months Ended September 30,						Nine Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012			2013			2012			2013			2012
	Service cost	$	7		$	6		$	—		$	(1	)	$	19		$	13		$	—		$	—
	Interest cost	22			26			4			5			68			42			14			9
	Expected return on assets	(43		)	(43		)	(1		)	(2		)	(131		)	(69		)	(5		)	(5		)
	Amortization of prior service credits	(1		)	(1		)	—			—			—			(1		)	—			—
	Amortization of net actuarial loss	—			2			—			2			—			7			3			4
	Settlement gain(a)	—			—			—			—			(3		)	—			—			—
	Net benefit (credit) cost	$	(15	)	$	(10	)	$	3		$	4		$	(47	)	$	(8	)	$	12		$	8
	_______
	(a)	Reflects the gain recognized upon the February 2013 settlement of our obligations under the El Paso Supplemental Executive Retirement Plan.
	During the period, we made amendments to our OPEB plans which will terminate coverage for post-age 65 Medicare eligible participants effective January 1, 2014. These participants, if receiving subsidized coverage, will purchase their future coverage through a retiree Medicare exchange. For those participants who are eligible, the plan will provide a subsidy to purchase their new coverage. Based on the materiality of the change in our OPEB obligation resulting from the amendments, we remeasured the assets and liabilities of the OPEB plans as of July 31, 2013. The remeasurement had the associated effects of (i) decreasing our net liability funded balance by $84 million; (ii) decreasing our accumulated other comprehensive loss balance by $53 million; and (iii) increasing accumulated deferred income taxes by $31 million.

Income_Taxes_Tables

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2013
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	Income taxes from continuing operations included in our accompanying consolidated statements of income were as follows (in millions, except percentages):
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Income tax expense	$	171		$	60		$	675		$	165
	Effective tax rate	24		%	13		%	25		%	18		%

Accounting_for_Regulatory_Acti1

Accounting for Regulatory Activities Accounting for Regulatory Activities (Tables)	9 Months Ended
	Sep. 30, 2013
Regulatory Assets [Line Items]
Schedule of Regulatory Assets [Table Text Block]	The following table summarizes our regulatory asset and liability balances as of September 30, 2013 and December 31, 2012 (in millions):
		September 30, 2013		December 31, 2012
	Current regulatory assets	$	77	$	62
	Non-current regulatory assets	463		402
	Total regulatory assets(a)	$	540	$	464
	Current regulatory liabilities	$	123	$	7
	Non-current regulatory liabilities	393		113
	Total regulatory liabilities(b)	$	516	$	120
	_______
	(a)	Includes an $87 million increase since December 31, 2012 (net of related amortization of $5 million) associated with TGP’s sale of certain natural gas facilities located offshore in the Gulf of Mexico and onshore in the state of Louisiana.
	(b)	During the second quarter of 2013, we began applying regulatory accounting to another one of KMP’s pipeline systems due to a newly negotiated long-term tolling agreement approved by the system’s regulator that went into effect in April 2013. The primary impact of applying regulatory accounting was the reclassification of approximately $362 million of current and long-term deferred credits to regulatory liabilities. KMP expects this regulatory liability to be refunded to rate-payers over approximately the next four years. As of September 30, 2013, $117 million remains classified as current regulatory liability.

Reconciliation_of_Significant_1

Reconciliation of Significant Asset Balances (Tables)	9 Months Ended
	Sep. 30, 2013
Reconciliation of Significant Asset Balances [Abstract]
Reconciliation of Significant Assets Balances	The following is a reconciliation between KMP’s and EPB’s significant asset and liability balances as reported in KMP’s and EPB’s Quarterly Reports on Form 10-Q for the quarter ended September 30, 2013 and our consolidated asset and liability balances as shown on our accompanying consolidated balance sheets (in millions):
		September 30,		December 31,
		2013		2012 (a)
	Cash and cash equivalents - KMI(b)	$	137	$	71
	Cash and cash equivalents - KMP	534		529
	Cash and cash equivalents - EPB	145		114
	Cash and cash equivalents	$	816	$	714
	Property, plant and equipment, net–KMI(b)	$	2,630	$	2,735
	Property, plant and equipment, net–KMP	26,742		22,330
	Property, plant and equipment, net–EPB	5,903		5,931
	Property, plant and equipment, net	$	35,275	$	30,996
	Goodwill–KMI(b)	$	17,940	$	18,193
	Goodwill–KMP	6,532		5,417
	Goodwill–EPB	22		22
	Goodwill	$	24,494	$	23,632
	Current portion of debt–KMI(b)	$	2,195	$	1,153
	Current portion of debt–KMP	702		1,155
	Current portion of debt–EPB	76		93
	Current portion of debt	$	2,973	$	2,401
	Long-term debt outstanding–KMI(b)	$	7,724	$	9,148
	Long-term debt outstanding–KMP	18,910		15,907
	Long-term debt outstanding–EPB(c)	4,180		4,254
	Long-term debt outstanding	$	30,814	$	29,309
	_______
	(a)	Retrospectively adjusted as discussed in Note 2.
	(b)	Includes assets and liabilities of KMI’s consolidated subsidiaries, excluding KMP and EPB.
	(c)	Excludes debt fair value adjustments.  Decrease to long-term debt for debt fair value adjustments totaled $8 million as of both September 30, 2013 and December 31, 2012.

Guarantee_of_Securities_of_Sub1

Guarantee of Securities of Subsidiaries (Tables)	9 Months Ended
	Sep. 30, 2013
Guarantor Obligations [Line Items]
Condensed Balance Sheet [Table Text Block]	Condensed Consolidating Balance Sheets as of September 30, 2013
	(In Millions)
	(Unaudited)
		Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	ASSETS
	Cash and cash equivalents	$	106		$	—		$	—		$	710		$	—		$	816
	All other current assets	672			11			4			2,430			(342		)	2,775
	Property, plant and equipment, net	9			—			—			35,266			—			35,275
	Investments	—			—			—			6,044			—			6,044
	Investments in affiliates	20,375			10,602			6,469			—			(37,446		)	—
	Goodwill	—			—			8,062			16,432			—			24,494
	Notes receivable from affiliates	2			—			—			1,993			(1,995		)	—
	Deferred charges and all other assets	209			—			903			4,935			(876		)	5,171
	Total assets	$	21,373		$	10,613		$	15,438		$	67,810		$	(40,659	)	$	74,575
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Liabilities
	Current portion of debt	$	1,514		$	—		$	530		$	929		$	—		$	2,973
	All other current liabilities	194			5			160			3,425			(342		)	3,442
	Long-term debt	1,872			—			4,011			27,155			—			33,038
	Notes payable to affiliates	1,993			—			—			2			(1,995		)	—
	Deferred income taxes	2,021			—			—			3,169			(876		)	4,314
	All other long-term liabilities	514			—			164			1,828			—			2,506
	Total liabilities	8,108			5			4,865			36,508			(3,213		)	46,273
	Stockholders’ equity
	Total KMI equity	13,265			10,608			10,573			15,875			(37,056		)	13,265
	Noncontrolling interests	—			—			—			15,427			(390		)	15,037
	Total stockholders’ equity	13,265			10,608			10,573			31,302			(37,446		)	28,302
	Total liabilities and stockholders’ equity	$	21,373		$	10,613		$	15,438		$	67,810		$	(40,659	)	$	74,575
	Condensed Consolidating Balance Sheets as of December 31, 2012
	(In Millions)
	(Unaudited)
		Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	ASSETS
	Cash and cash equivalents	$	3		$	—		$	45		$	666		$	—		$	714
	All other current assets	813			27			123			9,322			(7,325		)	2,960
	Property, plant and equipment, net	8			—			—			30,988			—			30,996
	Investments	—			—			19			5,785			—			5,804
	Investments in affiliates	20,053			11,190			13,232			—			(44,475		)	—
	Goodwill	—			—			8,059			15,573			—			23,632
	Notes receivable from affiliates	1,555			—			—			2,095			(3,650		)	—
	Deferred charges and all other assets	202			—			1,158			3,912			(1,133		)	4,139
	Total assets	$	22,634		$	11,217		$	22,636		$	68,341		$	(56,583	)	$	68,245
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Liabilities
	Current portion of debt	$	1,035		$	—		$	115		$	1,251		$	—		$	2,401
	All other current liabilities	196			383			6,741			2,832			(7,325		)	2,827
	Long-term debt	3,068			—			4,378			24,554			—			32,000
	Notes payable to affiliates	1,764			296			35			1,555			(3,650		)	—
	Deferred income taxes	2,095			—			—			3,109			(1,133		)	4,071
	All other long term liabilities	610			—			169			2,067			—			2,846
	Total liabilities	8,768			679			11,438			35,368			(12,108		)	44,145
	Stockholders’ equity
	Total KMI equity	13,866			10,538			11,198			22,580			(44,316		)	13,866
	Noncontrolling interests	—			—			—			10,393			(159		)	10,234
	Total stockholders’ equity	13,866			10,538			11,198			32,973			(44,475		)	24,100
	Total liabilities and stockholders’ equity	$	22,634		$	11,217		$	22,636		$	68,341		$	(56,583	)	$	68,245
Condensed Cash Flow Statement [Table Text Block]	Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2013
	(In Millions)
	(Unaudited)
		Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Net cash provided by operating activities	$	1,129		$	—		$	113		$	3,174		$	(1,639	)	$	2,777
	Cash flows from investing activities
	Capital expenditures	(3		)	—			—			(2,267		)	—			(2,270		)
	Proceeds from sale of investments in Express pipeline system	—			—			—			402			—			402
	Proceeds from sale of investments in BBPP Holdings Ltda	—			—			—			88			—			88
	Acquisitions of assets and investments	—			—			—			(292		)	—			(292		)
	Repayment from related party	—			—			—			10			—			10
	Funding to affiliates	(170		)	—			(581		)	(525		)	1,276			—
	Drop down assets to KMP	994			—			—			(994		)	—			—
	Contributions to investments	(6		)	—			—			(171		)	6			(171		)
	Investments in KMP and EPB	(59		)	—			(3		)	—			62			—
	Distributions from equity investments in excess of cumulative earnings	2			—			70			68			(23		)	117
	Other, net	—			—			—			78			—			78
	Net cash provided by (used in) investing activities	758			—			(514		)	(3,603		)	1,321			(2,038		)
	Cash flows from financing activities
	Issuance of debt	1,220			—			133			8,154			—			9,507
	Payment of debt	(1,930		)	—			(50		)	(6,671		)	—			(8,651		)
	Funding from affiliates	584			—			273			419			(1,276		)	—
	Debt issuance costs	—			—			—			(23		)	—			(23		)
	Cash dividends	(1,196		)	—			—			—			—			(1,196		)
	Repurchase of warrants	(463		)	—			—			—			—			(463		)
	Distributions to parent	—			—			—			(1,654		)	1,654			—
	Contributions from noncontrolling interests	—			—			—			1,474			(54		)	1,420
	Distributions to noncontrolling interests	—			—			—			(1,220		)	—			(1,220		)
	Other, net	1			—			—			6			(6		)	1
	Net cash (used in) provided by financing activities	(1,784		)	—			356			485			318			(625		)
	Effect of exchange rate changes on cash and cash equivalents	—			—			—			(12		)	—			(12		)
	Net increase (decrease) in cash and cash equivalents	103			—			(45		)	44			—			102
	Cash and cash equivalents, beginning of period	3			—			45			666			—			714
	Cash and cash equivalents, end of period	$	106		$	—		$	—		$	710		$	—		$	816
	Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2012
	(In Millions)
	(Unaudited)
		Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Net cash provided by (used in)operating activities	$	725		$	—		$	(429	)	$	2,761		$	(1,130	)	$	1,927
	Cash flows from investing activities
	Capital expenditures	(6		)	—			—			(1,393		)	—			(1,399		)
	Acquisitions of assets and investments	—			—			—			(72		)	—			(72		)
	Repayment from related party	—			—			—			48			—			48
	Funding to affiliates	(398		)	—			(313		)	(632		)	1,343			—
	Contributions to investments	(15		)	—			—			(143		)	—			(158		)
	Distributions from equity investments in excess of cumulative earnings	11			—			29			119			—			159
	Investments in KMP and EPB	(69		)	—			(7		)	—			76			—
	Acquisition of EP	(5,212		)	—			—			242			—			(4,970		)
	Drop down assets to KMP	3,485			—			—			(3,485		)	—			—
	Other, net	—			—			—			27			—			27
	Net cash used in investing activities	(2,204		)	—			(291		)	(5,289		)	1,419			(6,365		)
	Cash flows from financing activities
	Issuance of debt	7,182			—			62			8,483			—			15,727
	Payment of debt	(4,683		)	—			(176		)	(5,562		)	—			(10,421		)
	Funding from affiliates	82			—			905			356			(1,343		)	—
	Debt issuance costs	(88		)	—			—			(16		)	—			(104		)
	Cash dividends	(810		)	—			—			—			—			(810		)
	Repurchase of warrants	(136		)	—			—			—			—			(136		)
	Distributions to parent	—			—			—			(1,080		)	1,080			—
	Contributions from noncontrolling interests	—			—			—			1,423			(19		)	1,404
	Distributions to noncontrolling interests	—			—			—			(853		)	—			(853		)
	Other, net	(15		)	—			—			4			(7		)	(18		)
	Net cash provided by financing activities	1,532			—			791			2,755			(289		)	4,789
	Effect of exchange rate changes on cash and cash equivalents	—			—			—			13			—			13
Net increase in cash and cash equivalents	53			—			71			240			—			364
Cash and cash equivalents, beginning of period	2			—			—			409			—			411
Cash and cash equivalents, end of period	$	55		$	—		$	71		$	649		$	—		$	775
Condensed Income Statement [Table Text Block]	Condensed Consolidating Statements of Income for the Three Months Ended September 30, 2013
	(In Millions)
	(Unaudited)
		Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Revenues	$	9		$	—		$	—		$	3,756		$	(9	)	$	3,756
	Costs, expenses and other
	Costs of sales	—			—			—			1,543			—			1,543
	Depreciation, depletion and amortization	—			—			—			467			—			467
	Other operating expenses	12			—			—			702			(9		)	705
	Total costs, expenses and other	12			—			—			2,712			(9		)	2,715
	Operating (loss) income	(3		)	—			—			1,044			—			1,041
	Other income (expense)
	Earnings from equity investments	334			50			123			100			(507		)	100
	Interest, net	(58		)	—			(65		)	(295		)	—			(418		)
	Amortization of excess cost of equity investments and other, net	—			—			—			(1		)	—			(1		)
	Income from continuing operations before income taxes	273			50			58			848			(507		)	722
	Income tax benefit (expense)	13			—			(8		)	(176		)	—			(171		)
	Net income	286			50			50			672			(507		)	551
	Net income attributable to noncontrolling interests	—			—			—			(280		)	15			(265		)
	Net income attributable to controlling interests	$	286		$	50		$	50		$	392		$	(492	)	$	286
	Condensed Consolidating Statements of Income for the Three Months Ended September 30, 2012
	(In Millions)
	(Unaudited)
		Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Revenues	$	9		$	—		$	—		$	2,861		$	—		$	2,870
	Costs, expenses and other
	Costs of sales	—			—			—			854			—			854
	Depreciation, depletion and amortization	—			—			—			403			—			403
	Other operating expenses	26			—			(1		)	736			—			761
	Total costs, expenses and other	26			—			(1		)	1,993			—			2,018
	Operating (loss) income	(17		)	—			1			868			—			852
	Other income (expense)
	Earnings from equity investments	350			59			138			101			(547		)	101
	Interest, net	(188		)	(3		)	(129		)	(203		)	—			(523		)
	Amortization of excess cost of equity investments and other, net	1			(1		)	(1		)	17			—			16
	Income from continuing operations before income taxes	146			55			9			783			(547		)	446
	Income tax benefit (expense)	54			1			51			(166		)	—			(60		)
	Income from continuing operations	200			56			60			617			(547		)	386
	Loss from discontinued operations, net of tax	—			—			—			(131		)	—			(131		)
	Net income	200			56			60			486			(547		)	255
	Net income attributable to noncontrolling interests	—			—			—			(53		)	(2		)	(55		)
	Net income attributable to controlling interests	$	200		$	56		$	60		$	433		$	(549	)	$	200
	Condensed Consolidating Statements of Income for the Nine Months Ended September 30, 2013
	(In Millions)
	(Unaudited)
		Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Revenues	$	27		$	—		$	—		$	10,195		$	(24	)	$	10,198
	Costs, expenses and other
	Costs of sales	—			—			—			3,767			—			3,767
	Depreciation, depletion and amortization	1			—			—			1,326			—			1,327
	Other operating expenses	21			—			(3		)	2,280			(24		)	2,274
	Total costs, expenses and other	22			—			(3		)	7,373			(24		)	7,368
	Operating income	5			—			3			2,822			—			2,830
	Other income (expense)
	Earnings from equity investments	1,007			127			378			294			(1,512		)	294
	Interest, net	(194		)	—			(239		)	(814		)	—			(1,247		)
	Amortization of excess cost of equity investments and other, net	(1		)	—			—			789			—			788
	Income from continuing operations before income taxes	817			127			142			3,091			(1,512		)	2,665
	Income tax benefit (expense)	38			—			(15		)	(698		)	—			(675		)
	Income from continuing operations	855			127			127			2,393			(1,512		)	1,990
	Loss from discontinued operations, net of tax	—			—			—			(2		)	—			(2		)
	Net income	855			127			127			2,391			(1,512		)	1,988
	Net income attributable to noncontrolling interests	—			—			—			(1,208		)	75			(1,133		)
	Net income attributable to controlling interests	$	855		$	127		$	127		$	1,183		$	(1,437	)	$	855
Condensed Consolidating Statements of Income for the Nine Months Ended September 30, 2012
(In Millions)
(Unaudited)
	Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Revenues	$	26		$	—		$	—		$	6,868		$	—		$	6,894
Costs, expenses and other
Costs of sales	—			—			—			2,071			—			2,071
Depreciation, depletion and amortization	—			—			—			1,010			—			1,010
Other operating expenses	216			—			63			1,906			—			2,185
Total costs, expenses and other	216			—			63			4,987			—			5,266
Operating (loss) income	(190		)	—			(63		)	1,881			—			1,628
Other income (expense)
Earnings from equity investments	465			(17		)	106			238			(554		)	238
Interest, net	(320		)	(3		)	(143		)	(527		)	—			(993		)
Amortization of excess cost of equity investments and other, net	(1		)	(1		)	(2		)	24			—			20
(Loss) income from continuing operations before income taxes	(46		)	(21		)	(102		)	1,616			(554		)	893
Income tax benefit (expense)	142			1			86			(394		)	—			(165		)
Income (loss) from continuing operations	96			(20		)	(16		)	1,222			(554		)	728
Loss from discontinued operations, net of tax	(1		)	—			—			(788		)	—			(789		)
Net income (loss)	95			(20		)	(16		)	434			(554		)	(61		)
Net loss attributable to noncontrolling interests	—			—			—			175			(19		)	156
Net income (loss) attributable to controlling interests	$	95		$	(20	)	$	(16	)	$	609		$	(573	)	$	95
C
Condensed consolidating statement of comprehensive income [Table Text Block]	Condensed Consolidating Statements of Comprehensive Income for the Three Months Ended September 30, 2013
	(In Millions)
	(Unaudited)
		Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Net income	$	286		$	50		$	50		$	672		$	(507	)	$	551
	Other comprehensive income, net of tax
	Change in fair value of derivatives utilized for hedging purposes	(42		)	(2		)	(2		)	(78		)	44			(80		)
	Reclassification of change in fair value of derivatives to net income	10			—			—			19			(10		)	19
	Foreign currency translation adjustments	17			—			—			32			(16		)	33
	Adjustments to pension and other postretirement benefit plan liabilities	66			52			52			78			(169		)	79
	Total other comprehensive income	51			50			50			51			(151		)	51
	Comprehensive income	337			100			100			723			(658		)	602
	Comprehensive income attributable to noncontrolling interests	—			—			—			(265		)	—			(265		)
	Comprehensive income attributable to controlling interests	$	337		$	100		$	100		$	458		$	(658	)	$	337
	Condensed Consolidating Statements of Comprehensive Income for the Three Months Ended September 30, 2012
	(In Millions)
	(Unaudited)
		Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Net income	$	200		$	56		$	60		$	486		$	(547	)	$	255
	Other comprehensive loss, net of tax
	Change in fair value of derivatives utilized for hedging purposes	(30		)	(2		)	(2		)	(70		)	33			(71		)
	Reclassification of change in fair value of derivatives to net income	(5		)	(2		)	(2		)	(10		)	9			(10		)
	Foreign currency translation adjustments	22			—			—			52			(20		)	54
	Adjustments to pension and other postretirement benefit plan liabilities	(1		)	(1		)	(1		)	(18		)	18			(3		)
	Total other comprehensive loss	(14		)	(5		)	(5		)	(46		)	40			(30		)
	Comprehensive income	186			51			55			440			(507		)	225
	Comprehensive income attributable to noncontrolling interests	—			—			—			(39		)	—			(39		)
	Comprehensive income attributable to controlling interests	$	186		$	51		$	55		$	401		$	(507	)	$	186
	Condensed Consolidating Statements of Comprehensive Income for the Nine Months Ended September 30, 2013
	(In Millions)
	(Unaudited)
		Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Net income	$	855		$	127		$	127		$	2,391		$	(1,512	)	$	1,988
	Other comprehensive income (loss), net of tax
	Change in fair value of derivatives utilized for hedging purposes	(22		)	6			6			(48		)	9			(49		)
	Reclassification of change in fair value of derivatives to net income	5			(1		)	(1		)	10			(3		)	10
	Foreign currency translation adjustments	(28		)	—			—			(53		)	27			(54		)
	Adjustments to pension and other postretirement benefit plan liabilities	66			49			49			76			(161		)	79
	Total other comprehensive income (loss)	21			54			54			(15		)	(128		)	(14		)
	Comprehensive income	876			181			181			2,376			(1,640		)	1,974
	Comprehensive income attributable to noncontrolling interests	—			—			—			(1,098		)	—			(1,098		)
	Comprehensive income attributable to controlling interests	$	876		$	181		$	181		$	1,278		$	(1,640	)	$	876
	Condensed Consolidating Statements of Comprehensive Income for the Nine Months Ended September 30, 2012
	(In Millions)
	(Unaudited)
		Parent Guarantor			Guarantor Subsidiary			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Net income (loss)	$	95		$	(20	)	$	(16	)	$	434		$	(554	)	$	(61	)
	Other comprehensive income, net of tax
	Change in fair value of derivatives utilized for hedging purposes	25			(5		)	(5		)	68			(12		)	71
	Reclassification of change in fair value of derivatives to net income (loss)	1			(2		)	(2		)	5			3			5
	Foreign currency translation adjustments	21			—			—			50			(19		)	52
	Adjustments to pension and other postretirement benefit plan liabilities, net of tax	12			12			12			(5		)	(21		)	10
	Total other comprehensive income	59			5			5			118			(49		)	138
	Comprehensive income (loss)	154			(15		)	(11		)	552			(603		)	77
	Comprehensive loss attributable to noncontrolling interests	—			—			—			77			—			77
	Comprehensive income (loss) attributable to controlling interests	$	154		$	(15	)	$	(11	)	$	629		$	(603	)	$	154

General_Organization_Details

General Organization (Details) (USD $)	9 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended
Share data in Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2012	Nov. 01, 2012
	mi	Kinder Morgan G.P., Inc. [Member]	Kinder Morgan, Inc. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Convertible Preferred Stock [Member]	Convertible Preferred Stock [Member]	Convertible Preferred Stock [Member]	Energy Transfers Partners LP [Member]
	Terminals							KMPbs FTC Natural Gas Pipelines [Member]
Entity Information [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities								$3,300,000,000
Equity Method Investment, Voting Rights Percentage		100.00%
Enterprise Market Value			$110,000,000,000
Miles Of Pipeline	82,000
Number Of Pipeline Terminals Owned Interest In And Or Operated	180
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	41.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	2.00%
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements					10	11	11
Equity Method Investment, Ownership Percentage				10.00%

General_Basis_of_Presentation_

General Basis of Presentation (Details) (USD $)	Sep. 30, 2013	Jan. 31, 2013	Nov. 01, 2012	Sep. 30, 2013	31-May-13	Sep. 30, 2013
		Rockies Express Pipeline LLC [Member]	Energy Transfers Partners LP [Member]	Goodwill [Member]	Reporting Units [Member]	Natural Gas Pipelines Non-Regulated & Natural Gas Pipelines Regulated [Member]
		KMPbs FTC Natural Gas Pipelines [Member]	KMPbs FTC Natural Gas Pipelines [Member]	segment		May 31, 2013 [Member]
Segment Reporting Information [Line Items]
Equity Method Investment, Ownership Percentage		50.00%
Goodwill, Impairment Loss					$0
Number of Reporting Units				7
Number of reportable segments for impairment testing						2
Equity Investment, Classify as Equity Method, Percentage	50.00%
Proceeds from sale of disposal group			1,800,000,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities			$3,300,000,000

General_Earnings_Per_Share_Det

General Earnings Per Share (Details) (USD $)	3 Months Ended		9 Months Ended
Share data in Millions, except Per Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Income from Continuing Operations	$551,000,000	$386,000,000	$1,990,000,000	$728,000,000
Net income (loss) attributable to KMI	286,000,000	200,000,000	855,000,000	95,000,000
Net income attributable to noncontrolling interests	265,000,000	55,000,000	1,133,000,000	-156,000,000
Less: income from continuing operations attributable to noncontrolling interests		-171,000,000		-441,000,000
Income from continuing operations attributable to KMI		215,000,000		287,000,000
Income from continuing operations attributable to shareholders		215,000,000		287,000,000
Dividends declared during the period		-364,000,000		-810,000,000
Remaining Undistributed Earnings, Continuing Operations		-149,000,000		-523,000,000
Excess distributions over earnings		-164,000,000		-715,000,000
Net (loss) income attributable to shareholders	286,000,000	200,000,000	855,000,000	95,000,000
Class C [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Excess distributions over earnings				0
Class P [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Income from continuing operations attributable to shareholders		125,000,000		122,000,000
Dividends declared during the period		-212,000,000		-343,000,000
Remaining Undistributed Earnings, Continuing Operations		-87,000,000		-221,000,000
Excess distributions over earnings		-96,000,000		-303,000,000
Net (loss) income attributable to shareholders	283,000,000	116,000,000	851,000,000	40,000,000
Basic Weighted-Average Number of Shares Outstanding	1,036	605	1,036	366
Basic earnings per common share from continuing operations (in dollars per share)	$0.27	$0.21	$0.82	$0.33
Income from continuing operations attributable to shareholders and assumed conversions		215,000,000		287,000,000
Basic earnings per common share (usd per share)	$0.27	$0.19	$0.82	$0.11
Net income attributable to shareholders and assumed conversions(c)		200,000,000		95,000,000
Diluted Weighted-Average Number of Shares Outstanding	1,036	1,039	1,036	864
Diluted loss per common share (usd per share)		$0.19		$0.11
Diluted earnings per common share from continuing operations (in dollars per share)		$0.21		$0.33
Common Class A [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Income from continuing operations attributable to shareholders		80,000,000		131,000,000
Dividends declared during the period		-142,000,000		-432,000,000
Remaining Undistributed Earnings, Continuing Operations		-62,000,000		-301,000,000
Excess distributions over earnings		-68,000,000		-410,000,000
Net (loss) income attributable to shareholders		74,000,000		22,000,000
Basic Weighted-Average Number of Shares Outstanding		432		496
Basic earnings per common share from continuing operations (in dollars per share)		$0.19		$0.26
Income from continuing operations attributable to shareholders and assumed conversions		80,000,000		131,000,000
Basic earnings per common share (usd per share)		$0.17		$0.04
Net income attributable to shareholders and assumed conversions(c)		74,000,000		22,000,000
Diluted Weighted-Average Number of Shares Outstanding		432		496
Diluted loss per common share (usd per share)		$0.17		$0.04
Diluted earnings per common share from continuing operations (in dollars per share)		$0.19		$0.26
Participating Securities [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Income from continuing operations attributable to shareholders		10,000,000		34,000,000
Dividends declared during the period		-10,000,000		-35,000,000
Remaining Undistributed Earnings, Continuing Operations		0		-1,000,000
Excess distributions over earnings		0		-2,000,000
Net (loss) income attributable to shareholders	3,000,000	10,000,000	4,000,000	33,000,000
Class B [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Excess distributions over earnings				$0
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	6		3
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	400	450	419	457
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	11		11

Acquisitions_and_Divestitures_2

Acquisitions and Divestitures Copano Energy, L.L.C. Acquisition (Details) (USD $)

3 Months Ended

9 Months Ended

0 Months Ended

9 Months Ended

0 Months Ended

0 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

1-May-13

Sep. 30, 2013

Dec. 31, 2012

3-May-13

Sep. 30, 2013

1-May-13

3-May-13

1-May-13

3-May-13

1-May-13

Sep. 30, 2013

Sep. 30, 2013

mi

mi

KMP Acquisiton of Copano Energy LLC [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Common Units [Member]

Common Units [Member]

Eagle Ford Gathering LLC [Member]

Eagle Ford Gathering LLC [Member]

Natural Gas [Member]

Natural Gas Processing Plant [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Natural Gas Pipelines [Member]

mi

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

Kinder Morgan Energy Partners, L.P. [Member]

MMcf

KMP Acquisiton of Copano Energy LLC [Member]

MMcf

Business Acquisition [Line Items]

Significant Acquisitions and Disposals, Acquisition Costs or Sale Proceeds

$5,200,000,000

Business Acquisition, Cost of Acquired Entity, percent unit for unit

100.00%

Business acquisition, share-for-share exchange rate

0.4563

Business Acquisition, Equity Interest Issued or Issuable, Number of Shares

43,371,210

Business Acquisition, Cost of Acquired Entity, Equity Interests Issued and Issuable

3,733,000,000

Business Acquisition, Share Price

$86.08

Business Acquisition, Percent Ownership Acquired

50.00%

Business Combination, Step Acquisition, Equity Interest in Acquiree, Percentage

50.00%

Gain on remeasurement of previously held equity interest in Eagle Ford to fair value (Note 2)

0

0

558,000,000

0

558,000,000

Business Acquisition, Purchase Price Allocation, Current Assets

218,000,000

Business Combination, Purchase Price Allocation, Property, Plant, and Equipment

2,805,000,000

Business Combination, Purchase Price Allocation, Investments

387,000,000

Business Acquisition, Purchase Price Allocation, Goodwill

24,494,000,000

24,494,000,000

23,632,000,000

[1]

6,532,000,000

5,417,000,000

1,119,000,000

Business Acquisition, Purchase Price Allocation, Intangible Assets Other than Goodwill

1,375,000,000

Business Acquisition, Purchase Price Allocation, Other Noncurrent Assets

13,000,000

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets, Excluding Certain Fair Value Adjustments

5,917,000,000

Less: Fair value of previously held 50% interest in Eagle Ford Gathering, LLC

-704,000,000

Business Acquisition, Purchase Price Allocation, Assets Acquired

5,213,000,000

Business Acquisition, Purchase Price Allocation, Current Liabilities

-207,000,000

Business Acquisition, Purchase Price Allocation, Other Noncurrent Liabilities

-4,000,000

Business Acquisition, Purchase Price Allocation, Notes Payable and Long-term Debt

-1,252,000,000

Consideration Attributable to Noncontrolling interest

-17,000,000

Business Acquisition, Purchase Price Allocation, Assets Acquired (Liabilities Assumed), Net

$3,733,000,000

Finite-Lived Intangible Asset, Useful Life

25 years

Miles Of Pipeline

82,000

82,000

6,900

MMcf/d Treating Capacity of Copano's Nine Processing Plants

2,700

315

Number of Processing Plants

9

Bcf/d Processing Capacity of Copano's Nine Processing Plants (more than)

1,000

[1]

(a)Retrospectively adjusted as discussed in Note 2.

Acquisitions_and_Divestitures_3

Acquisitions and Divestitures Impact of KMPbs Acquisition of Copano on KMIbs Income Taxes (Details) (Copano Energy LLC [Member], Kinder Morgan, Inc. [Member], USD $)	1-May-13
In Millions, unless otherwise specified
Copano Energy LLC [Member] | Kinder Morgan, Inc. [Member]
Business Acquisition [Line Items]
Goodwill, Allocation Adjustment	$255

Acquisitions_and_Divestitures_4

Acquisitions and Divestitures KMI Acquisition of EP Corporation (Details) (El Paso Corporation [Member], USD $)	3 Months Ended		0 Months Ended	1 Months Ended		0 Months Ended
	Sep. 30, 2013	25-May-12	25-May-12	25-May-12	Sep. 30, 2013	25-May-12
		Kinder Morgan, Inc. [Member]	Kinder Morgan, Inc. [Member]	Kinder Morgan, Inc. [Member]	Warrant [Member]	Warrant [Member]
			Class P [Member]	Class P [Member]	Kinder Morgan, Inc. [Member]	Kinder Morgan, Inc. [Member]
						Class P [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net		$23,000,000,000
Business Acquisition, Cost of Acquired Entity, Equity Interests Issued and Issuable			10,600,000,000
Business Acquisition, Cost of Acquired Entity, Cash Paid						11,600,000,000
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares				330,000,000		505,000,000
Class of Warrant or Right, Term						5 years
Retrospective Adjustments, Revisions of Estimates Related to Environmental Obligations, Sales and Use Tax Liabilities, and Deferred Income Taxes	60,000,000
Warrants and Rights Outstanding						$863,000,000
Class of Warrant or Right, Exercise Price of Warrants or Rights					40

Acquisitions_and_Divestitures_5

Acquisitions and Divestitures Goldsmith Landreth Unit (Details) (Kinder Morgan Energy Partners, L.P. [Member], Legado Resources [Member], USD $)	31-May-13
In Millions, unless otherwise specified	bbl
	MMcf
Business Acquisition [Line Items]
Approximate Production Rate (Barrels of Oil per day)	1,250
Oil and Gas Delivery Commitments and Contracts, Maximum Contractual Volume Rate (MMcf/d)	150
CO2 [Member] | Permian Basin [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transfered Before Certain Adjustments	285
Business Acquisition, Purchase Price Allocation, Liabilities Assumed	18
Gas and Oil Area, Developed, Gross (more than)	6,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	285

Acquisitions_and_Divestitures_6

Acquisitions and Divestitures Pro Forma Information (Details) (EP, Copano and the Goldsmith Landreth Unit acquisitions as if occurred as of January 1, 2012 [Member], USD $)	3 Months Ended		9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
Business Acquisition, Pro Forma Revenue	$3,756	$3,341	$10,903	$9,384
Business Acquisition, Pro Forma Income (Loss) from Continuing Operations before Changes in Accounting and Extraordinary Items, Net of Tax	551	379	1,952	410
Business Acquisition, Pro Forma Income (Loss) from Discontinued Operations before Changes in Accounting and Extraordinary Items, Net of Tax	0	-131	-2	1,279
Business Acquisition, Pro Forma Net Income (Loss)	551	248	1,950	1,689
Pro Forma Income Attributable to Noncontrolling Interests	-265	127	-1,120	291
Net Income (Loss) Attributable to Kinder Morgan, Inc.	$286	$375	$830	$1,980
Class P [Member]
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
Business Acquisition, Pro Forma Earnings Per Share, Diluted	$0.27	$0.36	$0.80	$1.91
Class A [Member]
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
Business Acquisition, Pro Forma Earnings Per Share, Diluted		$0.34		$1.84

Acquisitions_and_Divestitures_7

Acquisitions and Divestitures KMPbs FTC Natural Gas Pipelines Disposal Group b Discontinued Operations (Details) (USD $)	3 Months Ended		9 Months Ended					3 Months Ended			9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012		Dec. 31, 2012	Mar. 31, 2013	Sep. 30, 2012	Mar. 31, 2012	Sep. 30, 2012
							Express Pipeline System [Member]	KMPbs FTC Natural Gas Pipelines [Member]	KMPbs FTC Natural Gas Pipelines [Member]	KMPbs FTC Natural Gas Pipelines [Member]	KMPbs FTC Natural Gas Pipelines [Member]
							Kinder Morgan Energy Partners, L.P. [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Impairment of Long-Lived Assets to be Disposed of											$934
Loss on sale and the remeasurement of KMPbs FTC Natural Gas Pipelines disposal group to fair value, net of tax								2
Operating revenues									71		204
Operating expenses									-45		-116
Depreciation and amortization									0		-7
Disposal group, Including Discontinued Operation, Other Expenses				-1						-1
Earnings from equity investments									22		64
Interest income and Other, net									0		1
Income from operations of KMPbs FTC Natural Gas Pipelines disposal group and other, net of tax	0	48	0	145					47		145
Assets held for sale	0		0		298	[1]	179
Tax Expense On Sale of Investment	$171	$60	$675	$165
[1]	(a)Retrospectively adjusted as discussed in Note 2.

Acquisitions_and_Divestitures_8

Acquisitions and Divestitures Express Pipeline System (Details) (USD $)

3 Months Ended

9 Months Ended

9 Months Ended

9 Months Ended

0 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Mar. 14, 2013

Mar. 14, 2013

Mar. 14, 2013

Express Pipeline System [Member]

Express Pipeline System [Member]

Express Pipeline System [Member]

Express Pipeline System [Member]

Express Pipeline System [Member]

Express Pipeline System [Member]

Express Pipeline System [Member]

Kinder Morgan Energy Partners, L.P. [Member]

KMP Sale of Express Pipeline System [Member]

KMP Sale of Express Pipeline System [Member]

Spectra Energy Corp. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

KMP Sale of Express Pipeline System [Member]

Equity method investment & Suboordinated debt investment [Member]

Business Acquisition [Line Items]

Equity Method Investment, Ownership Percentage

33.33%

Proceeds from Sale of Investments

$402

$0

$402

Equity Method Investment, Realized Gain (Loss) on Disposal

224

Income Tax Expense (Benefit)

171

60

675

165

84

Equity Method Investment, Amount Sold

67

Notes Receivable, Related Parties

114

110

Equity Method Investments

65

Assets held for sale

$0

$0

$298

[1]

$179

[1]

(a)Retrospectively adjusted as discussed in Note 2.

Acquisitions_and_Divestitures_9

Acquisitions and Divestitures TGP's Sale of Production Area Facilities (Details) (USD $)	9 Months Ended		0 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 03, 2013
			TGP [Member]
			Sale of production area facilities [Domain]
Significant Acquisitions and Disposals [Line Items]
Proceeds from Sale of Property, Plant, and Equipment	$74	$40	$32
Net Assets Sold			88
Increase (Decrease) in Other Regulatory Assets			92
Gain (Loss) on Disposition of Property Plant Equipment			$36

Recovered_Sheet1

Acquisitions and Divestitures BBPP Holdings Ltda (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012		Sep. 30, 2013	Sep. 30, 2012	Mar. 31, 2013	Dec. 31, 2012	Mar. 14, 2013	Dec. 31, 2012	Mar. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified				BBPP Holdings Ltda [Member]	BBPP Holdings Ltda [Member]	Bolivia to Brazil Pipeline [Member]	Bolivia to Brazil Pipeline [Member]	Express Pipeline System [Member]	BBPP Holdings Ltda [Member]	Transportadora Brasileira Gasoduto Bolivia-Brasil S.A. [Member]	Gas Transboliviano S.A. [Member]
								Kinder Morgan Energy Partners, L.P. [Member]	El Paso Corporation [Member]	El Paso Corporation [Member]	El Paso Corporation [Member]
										BBPP Holdings Ltda [Member]
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage								33.33%	33.33%	29.00%	2.00%
Proceeds from Sale of Investments				$88	$0	$88
Assets held for sale	$0	$298	[1]				$88
[1]	(a)Retrospectively adjusted as discussed in Note 2.

Recovered_Sheet2

Acquisitions and Divestitures Drop-down of EP Assets to KMP (Details) (USD $)

0 Months Ended

3 Months Ended

0 Months Ended

0 Months Ended

Mar. 03, 2013

Jun. 30, 2013

Aug. 02, 2012

Aug. 01, 2012

Aug. 02, 2012

Aug. 01, 2012

Mar. 03, 2013

Mar. 04, 2013

Mar. 03, 2013

Mar. 04, 2013

Mar. 04, 2013

Mar. 04, 2013

EPNG Part 2 and EP Midstream Assets Part 2 Drop Downs [Member]

EPNG Part 2 and EP Midstream Assets Part 2 Drop Downs [Member]

EPNG Part 2 and EP Midstream Assets Part 2 Drop Downs [Member]

Drop-Down of EPNG and TGP Part 1 to KMP [Member]

Drop-Down of EPNG and TGP Part 1 to KMP [Member]

Drop-Down of EPNG and TGP Part 1 to KMP [Member]

EPNG Part 2 and EP Midstream Assets Part 2 Drop Downs [Member]

EPNG Part 2 and EP Midstream Assets Part 2 Drop Downs [Member]

EPNG Part 2 and EP Midstream Assets Part 2 Drop Downs [Member]

Reported Value Measurement [Member]

Drop-Down of EPNG to KMP Part 2 [Member]

Drop-Down of EP Midsteam Asets to KMP Part 2 [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

TGP [Member]

EPNG [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

NYSE [Member]

EPNG [Member]

EP Midstream Assets [Member]

EPNG and EP Midstreem Assets [Member]

EPNG and EP Midstreem Assets [Member]

EPNG and EP Midstreem Assets [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

TGP and EPNG [Member]

EPNG and EP Midstreem Assets [Member]

EPNG and EP Midstreem Assets [Member]

EPNG and EP Midstreem Assets [Member]

Common Units [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Senior secured term loan credit facility, due May 24, 2015 [Member]

EPNG Part 2 and EP Midstream Assets Part 2 Drop Downs [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Business Acquisition [Line Items]

Equity Method Investment, Ownership Percentage

50.00%

100.00%

50.00%

50.00%

50.00%

Consideration Transfered Between Entities Under Common Control, Total

$6,200,000,000

$1,700,000,000

Entities Under Common Control Transaction, Proportional Share of Debt Borrowings

50.00%

Consideration Transfered Between Entities Under Common Control, Cash

994,000,000

Consideration Transfered Between Entities Under Common Control, Working Capital Adjustment

6,000,000

Shares, Issued

1,249,452

Consideration Transfered Between Entities Under Common Control, Equity, Value

108,000,000

Sale of Stock, Price Per Share

$86.72

Business Acquisition, Purchase Price Allocation, Liabilities Assumed

557,000,000

Repayments of Long-term Debt

$947,000,000

Recovered_Sheet3

Acquisitions and Divestitures Income Tax Impact on the Drop-Down of EP Assets to KMP and KMP Investment in EP Midstream (Details) (USD $)	3 Months Ended	9 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2013	Jan. 31, 2013	Sep. 30, 2013	Sep. 30, 2013	Jun. 01, 2012
			Drop-Down of EPNG and TGP Part 1 to KMP [Member]	TGP and EPNG [Member]	EPNG Part 2 and EP Midstream Assets Part 2 Drop Downs [Member]	Kinder Morgan Energy Partners, L.P. [Member]
						Midstream Investment Company, LLC [Member]
Business Acquisition [Line Items]
Deferred Tax Assets, Deferred Income			$448		$53
Public Utilities, Property, Plant and Equipment, Equipment, Approximate Useful Life				25 years
Business Acquisition, Percent Ownership Acquired						50.00%
Estimated annual tax expense arising from drop-down transactions	20	20
Income tax expense from deferred charges that arose from drop-down transactions	$5	$15

Debt_Details

Debt (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2012

Aug. 05, 2013

Feb. 28, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Feb. 28, 2013

Feb. 28, 2013

Feb. 28, 2013

Aug. 05, 2013

Aug. 05, 2013

Aug. 05, 2013

Aug. 05, 2013

Sep. 30, 2013

1-May-13

Dec. 31, 2012

31-May-13

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

1-May-13

Dec. 31, 2012

31-May-13

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Apr. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan Finance Company, LLC [Member]

Kinder Morgan Finance Company, LLC [Member]

El Paso LLC [Member]

El Paso LLC [Member]

El Paso LLC [Member]

El Paso LLC [Member]

EPC Building LLC [Member]

EPC Building LLC [Member]

Colorado Interstate Gas Services Company [Member]

Colorado Interstate Gas Services Company [Member]

Capital Trust I [Member]

Capital Trust I [Member]

Kinder Morgan G.P., Inc. [Member]

Kinder Morgan G.P., Inc. [Member]

TGP [Member]

TGP [Member]

EPNG [Member]

EPNG [Member]

Copano Energy LLC [Member]

Copano Energy LLC [Member]

Copano Energy LLC [Member]

Copano Energy LLC [Member]

El Paso Pipeline Partners Operating Company, L.L.C. [Member]

El Paso Pipeline Partners Operating Company, L.L.C. [Member]

El Paso Pipeline Partners Operating Company, L.L.C. [Member]

El Paso Pipeline Partners Operating Company, L.L.C. [Member]

El Paso Pipeline Partners Operating Company, L.L.C. [Member]

Colorado Interstate Gas Company, L.L.C. [Member]

Colorado Interstate Gas Company, L.L.C. [Member]

Southern LNG Company, L.L.C.(SLNG) [Member]

Southern LNG Company, L.L.C.(SLNG) [Member]

SNG [Member]

SNG [Member]

El Paso Pipeline Partners, L.P. [Member]

El Paso Pipeline Partners, L.P. [Member]

El Paso Pipeline Partners, L.P. [Member]

El Paso Pipeline Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. and El Paso Pipeline Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. and El Paso Pipeline Partners, L.P. [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

High [Member]

High [Member]

High [Member]

High [Member]

High [Member]

High [Member]

High [Member]

High [Member]

High [Member]

High [Member]

High [Member]

LIBOR [Member]

LIBOR [Member]

Third parties [Member]

Third parties [Member]

Mezzanine Equity, Cumulative Preferred Stock With Liquidation Approval Rights [Member]

Mezzanine Equity, Cumulative Preferred Stock With Liquidation Approval Rights [Member]

KMP Senior notes, 2.65% through 9.00%, due 2013 through 2043 [Member]

KMP Senior notes, 2.65% through 9.00%, due 2013 through 2043 [Member]

KMP Other Miscellaneous Subsidiary Debt [Member]

KMP Other Miscellaneous Subsidiary Debt [Member]

KMP Senior Notes issued on February 28, 2013 [Member]

KMP 3.50% Senior Notes due September 1, 2023 [Member]

KMP 5% Senior Notes due March 1, 2043 [Member]

KMP Senior Notes issued on August 5, 2013 [Member]

2.65% Senior Notes due February 1, 2019 [Member]

4.15% Senior Notes due February 1, 2024 [Member] [Member]

5.00% KMP Senior notes due March 1, 2043 [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Senior secured term loan facility, variable, due May 24, 2015 [Member]

Senior secured term loan facility, variable, due May 24, 2015 [Member]

Senior notes and debentures, 5.15% through 7.45% [Member]

Senior notes and debentures, 5.15% through 7.45% [Member]

Deferrable interest debentures issued to subsidiary trusts, 7.63% and 8.56%, due 2027 and 2028 [Member]

Deferrable interest debentures issued to subsidiary trusts, 7.63% and 8.56%, due 2027 and 2028 [Member]

KMI 5.70% through 6.40% series, due 2016 through 2036 [Member]

KMI 5.70% through 6.40% series, due 2016 through 2036 [Member]

KMI Senior notes and debentures, 6.50% through 12.00%, due 2013 through 2037 [Member]

KMI Senior notes and debentures, 6.50% through 12.00%, due 2013 through 2037 [Member]

KMI Credit Facility [Member]

KMI Credit Facility [Member]

KMI Promissory note 3.967%, due 2013 through 2035 [Member]

KMI Promissory note 3.967%, due 2013 through 2035 [Member]

KMI 7.76% Totem note payable due 2018 [Member]

KMI 7.76% Totem note payable due 2018 [Member]

KMI EP Capital Trust I, due 2028 [Member]

KMI EP Capital Trust I, due 2028 [Member]

KMI $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock [Member]

KMI $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock [Member]

KMP Senior notes, 7.00% through 8.375%, due 2016 through 2037 [Member]

KMP Senior notes, 7.00% through 8.375%, due 2016 through 2037 [Member]

KMP 5.95% through 8.625%, due 2017 through 2032 [Member]

KMP 5.95% through 8.625%, due 2017 through 2032 [Member]

KMP 7.125% Senior Notes due April 1, 2021 (Copano) [Member]

KMP 7.125% Senior Notes due April 1, 2021 (Copano) [Member]

KMP 7.125% Senior Notes due April 1, 2021 (Copano) [Member]

7.75% Unsecured Senior Notes Due June 1, 2018 [Member]

EPB Notes, 4.10% through 8.00%, due 2013 through 2042 [Member]

EPB Notes, 4.10% through 8.00%, due 2013 through 2042 [Member]

Revolving Credit Facility [Member]

EPB Notes, 5.95% through 6.85%, due 2015 through 2037 [Member]

EPB Notes, 5.95% through 6.85%, due 2015 through 2037 [Member]

EPB Senior notes, 9.50% and 9.75%, due 2014 and 2016 [Member]

EPB Senior notes, 9.50% and 9.75%, due 2014 and 2016 [Member]

EPB Notes, 4.40% through 8.00%, due 2017 through 2032 [Member]

EPB Notes, 4.40% through 8.00%, due 2017 through 2032 [Member]

EPB Other Financial Obligations [Member] [Member]

EPB Other Financial Obligations [Member] [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan Finance Company, LLC [Member]

El Paso LLC [Member]

TGP [Member]

EPNG [Member]

El Paso Pipeline Partners Operating Company, L.L.C. [Member]

Colorado Interstate Gas Company, L.L.C. [Member]

Southern LNG Company, L.L.C.(SLNG) [Member]

SNG [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan Finance Company, LLC [Member]

El Paso LLC [Member]

TGP [Member]

EPNG [Member]

El Paso Pipeline Partners Operating Company, L.L.C. [Member]

Colorado Interstate Gas Company, L.L.C. [Member]

Southern LNG Company, L.L.C.(SLNG) [Member]

SNG [Member]

Kinder Morgan Energy Partners, L.P. [Member]

El Paso Pipeline Partners Operating Company, L.L.C. [Member]

EPC Building LLC [Member]

EPC Building LLC [Member]

KMI $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock [Member]

KMI $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock [Member]

KMP Senior notes, 2.65% through 9.00%, due 2013 through 2043 [Member]

Senior notes and debentures, 5.15% through 7.45% [Member]

Deferrable interest debentures issued to subsidiary trusts, 7.63% and 8.56%, due 2027 and 2028 [Member]

KMI 5.70% through 6.40% series, due 2016 through 2036 [Member]

KMI Senior notes and debentures, 6.50% through 12.00%, due 2013 through 2037 [Member]

KMP Senior notes, 7.00% through 8.375%, due 2016 through 2037 [Member]

KMP 5.95% through 8.625%, due 2017 through 2032 [Member]

EPB Notes, 4.10% through 8.00%, due 2013 through 2042 [Member]

EPB Notes, 5.95% through 6.85%, due 2015 through 2037 [Member]

EPB Senior notes, 9.50% and 9.75%, due 2014 and 2016 [Member]

EPB Notes, 4.40% through 8.00%, due 2017 through 2032 [Member]

KMP Senior notes, 2.65% through 9.00%, due 2013 through 2043 [Member]

Senior notes and debentures, 5.15% through 7.45% [Member]

Deferrable interest debentures issued to subsidiary trusts, 7.63% and 8.56%, due 2027 and 2028 [Member]

KMI 5.70% through 6.40% series, due 2016 through 2036 [Member]

KMI Senior notes and debentures, 6.50% through 12.00%, due 2013 through 2037 [Member]

KMP Senior notes, 7.00% through 8.375%, due 2016 through 2037 [Member]

KMP 5.95% through 8.625%, due 2017 through 2032 [Member]

EPB Notes, 4.10% through 8.00%, due 2013 through 2042 [Member]

EPB Notes, 5.95% through 6.85%, due 2015 through 2037 [Member]

EPB Senior notes, 9.50% and 9.75%, due 2014 and 2016 [Member]

EPB Notes, 4.40% through 8.00%, due 2017 through 2032 [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

KMI Promissory note 3.967%, due 2013 through 2035 [Member]

KMI Promissory note 3.967%, due 2013 through 2035 [Member]

Debt Instrument [Line Items]

Senior Notes

$16,100,000,000

$13,350,000,000

$400,000,000

$1,528,000,000

$2,714,000,000

$315,000,000

$315,000,000

$27,000,000

$27,000,000

$1,636,000,000

$1,636,000,000

$3,860,000,000

$3,860,000,000

$281,000,000

$286,000,000

$1,790,000,000

$1,790,000,000

$1,115,000,000

$1,115,000,000

$332,000,000

$0

$2,260,000,000

$2,348,000,000

$475,000,000

$475,000,000

$135,000,000

$135,000,000

Preferred Stock, Value, Issued

100,000,000

100,000,000

Credit Facility, Amount outstanding

0

0

174,000,000

1,514,000,000

1,035,000,000

293,000,000

210,000,000

0

0

Notes Payable

464,000,000

217,000,000

1,000,000

1,000,000

1,211,000,000

1,211,000,000

Long-term Debt

19,612,000,000

17,062,000,000

10,019,000,000

10,401,000,000

4,256,000,000

4,347,000,000

Other Long-term Debt

101,000,000

186,000,000

175,000,000

178,000,000

Long-term Debt, Current Maturities

-2,973,000,000

-2,401,000,000

-702,000,000

-1,155,000,000

-2,195,000,000

-1,153,000,000

[1]

-76,000,000

-93,000,000

Long-term-debt, Excluding Current Maturites, Includeing Preferred Interest

7,824,000,000

9,248,000,000

Total long-term debt

33,038,000,000

32,000,000,000

[1]

18,910,000,000

15,907,000,000

7,724,000,000

9,148,000,000

4,180,000,000

4,254,000,000

23,090,000,000

20,161,000,000

100,000,000

100,000,000

Debt, Weighted Average Interest Rate

0.27%

0.45%

2.68%

2.72%

Debt Instrument, Face Amount

1,000,000,000

600,000,000

1,750,000,000

800,000,000

650,000,000

300,000,000

468,000,000

251,000,000

217,000,000

Debt Instrument, Interest Rate, Stated Percentage

3.50%

5.00%

2.65%

4.15%

5.00%

3.97%

3.97%

7.76%

4.75%

7.13%

7.13%

7.75%

2.65%

5.15%

7.63%

5.70%

6.50%

7.00%

5.95%

4.10%

5.95%

9.50%

4.40%

9.00%

7.45%

8.56%

6.40%

12.00%

8.38%

8.63%

8.00%

6.85%

9.75%

8.00%

Liquidation value of note

$1,000

Debt Fair Value Adjustments

2,124,000,000

2,591,000,000

[1]

8,000,000

8,000,000

Proceeds from Issuance of Senior Long-term Debt

1,724,000,000

991,000,000

Line of Credit Facility, Maximum Borrowing Capacity Increase

500,000,000

Line of Credit Facility, Maximum Borrowing Capacity

2,700,000,000

Short-term Debt

174,000,000

621,000,000

Debt Instrument, Basis Spread on Variable Rate

1.00%

1.75%

Debt Instrument, Decrease, Repayments

88,000,000

Line of Credit Facility, Remaining Borrowing Capacity

$2,322,000,000

$156,000,000

$1,000,000,000

[1]

(a)Retrospectively adjusted as discussed in Note 2.

KMPs_Copano_Debt_Details

KMP's Copano Debt (Details) (KMP's Copano Energy LLC [Member], USD $)

0 Months Ended

0 Months Ended

0 Months Ended

In Millions, unless otherwise specified

Jun. 06, 2013

Jun. 02, 2013

31-May-13

Sep. 05, 2013

Sep. 30, 2013

Sep. 04, 2013

1-May-13

Dec. 31, 2012

1-May-13

1-May-13

3-May-13

1-May-13

7.75% Unsecured Senior Notes Due June 1, 2018 [Member]

7.75% Unsecured Senior Notes Due June 1, 2018 [Member]

7.75% Unsecured Senior Notes Due June 1, 2018 [Member]

KMP 7.125% Senior Notes due April 1, 2021 (Copano) [Member]

KMP 7.125% Senior Notes due April 1, 2021 (Copano) [Member]

KMP 7.125% Senior Notes due April 1, 2021 (Copano) [Member]

KMP 7.125% Senior Notes due April 1, 2021 (Copano) [Member]

KMP 7.125% Senior Notes due April 1, 2021 (Copano) [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

7.75% Unsecured Senior Notes Due June 1, 2018 [Member]

KMP 7.125% Senior Notes due April 1, 2021 (Copano) [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Debt Instrument [Line Items]

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt

$249

$510

$404

Debt Instrument, Interest Rate, Stated Percentage

7.75%

7.13%

7.13%

7.75%

7.13%

Interest Paid

6

Debt Instrument, Announced Expected Redemption Amount

178

259

191

Debt Instrument, Percentage of Principal Amount To Be Redeemed

35.00%

Senior Notes

332

0

510

Debt Instrument, Decrease, Repayments

404

Debt Instrument, Repurchase Amount

$259

$191

Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed

103.88%

Credit_Facilities_Details

Credit Facilities (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

1-May-13

Apr. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

3-May-13

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

El Paso Pipeline Partners Operating Company, L.L.C. [Member]

El Paso Pipeline Partners Operating Company, L.L.C. [Member]

El Paso Pipeline Partners Operating Company, L.L.C. [Member]

Federal Funds Rate [Member]

LIBOR [Member]

LIBOR [Member]

KMI Credit Facility [Member]

Letter of Credit [Member]

Commercial Paper [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Letter of Credit [Member]

Revolving Credit Facility [Member]

Kinder Morgan Energy Partners, L.P. [Member]

Kinder Morgan Energy Partners, L.P. [Member]

El Paso Pipeline Partners Operating Company, L.L.C. [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Line of Credit Facility [Line Items]

Line of Credit Facility, Current Borrowing Capacity

$1,750,000,000

$2,700,000,000

$2,200,000,000

Debt Instrument, Term

5 years

Letters of Credit Outstanding, Amount

80,000,000

204,000,000

Debt Instrument, Basis Spread on Variable Rate

0.50%

1.00%

1.75%

LIBOR Basis, Period For Eurodollar Loan

1 month

Commercial Paper

174,000,000

621,000,000

Line of Credit Facility, Amount Outstanding

1,514,000,000

1,035,000,000

1,514,000,000

0

0

174,000,000

0

0

Remaining borrowing capacity

$156,000,000

$2,322,000,000

$1,000,000,000

Kinder_Morgan_GP_Inc_Preferred

Kinder Morgan G.P., Inc. Preferred Shares (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
			Kinder Morgan G.P., Inc. [Member]	Kinder Morgan G.P., Inc. [Member]	Kinder Morgan G.P., Inc. [Member]	Kinder Morgan G.P., Inc. [Member]
Debt Instrument [Line Items]
Preferred Stock, Shares Outstanding	0	0	100,000		100,000
Preferred Stock, Dividends Per Share, Declared			$10.52	$10.95	$31.53	$52.60
Preferred Stock, Dividends, Per Share, Cash Paid			$10.54	$20.82	$31.65	$62.48

Stockholders_Equity_Common_Equ

Stockholders Equity Common Equity (Details) (USD $)	0 Months Ended		3 Months Ended		9 Months Ended					3 Months Ended	9 Months Ended			3 Months Ended		9 Months Ended				9 Months Ended		9 Months Ended		9 Months Ended		9 Months Ended					3 Months Ended		9 Months Ended
In Millions, except Share data, unless otherwise specified	Oct. 17, 2013	Jul. 18, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012		Dec. 31, 2011	Jun. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Dec. 31, 2011	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2012	Sep. 30, 2012	Sep. 30, 2012	Sep. 30, 2012	Sep. 30, 2013
										Not part of stock repurchase program [Member]	July 17, 2013 $350M Share and Warrant Repurchase program [Member]	Additional Paid-in Capital [Member]	Additional Paid-in Capital [Member]	Class P [Member]	Class P [Member]	Class P [Member]	Class P [Member]	Class P [Member]	Class P [Member]	Class A [Member]	Class A [Member]	Common Class B [Member]	Common Class B [Member]	Common Class C [Member]	Common Class C [Member]	KMI EP Capital Trust I, due 2028 [Member]	EP Trust I Preferred [Member]	Conversion of EP Trust I Preferred Securities [Member]	Conversion of EP Trust I Preferred Securities [Member]	Warrant [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	KMI's Acquisition of EP [Member]	KMI's Acquisition of EP [Member]	El Paso Corporation [Member]	El Paso Corporation [Member]	El Paso Corporation [Member]	El Paso Corporation [Member]	Warrant [Member]
																										Class P [Member]	Class P [Member]			Class P [Member]					Subsequent Event [Member]			Class P [Member]	Class A [Member]	Common Class B [Member]	Common Class C [Member]	El Paso Corporation [Member]
																																										Kinder Morgan, Inc. [Member]
Class of Stock [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit																															$1.35	$1.26	$3.97	$3.69	$1.35
Stock Issued During Period, Shares, New Issues																																						330,154,610	0	0	0
Common stock, shares outstanding (in shares)														1,035,846,825	648,416,623	1,035,846,825	648,416,623	1,035,668,596	170,921,140	388,717,261	535,972,387	89,304,799	94,132,596	2,315,497	2,318,258
Class of Warrant or Right, Outstanding			348,441,604	445,505,804	348,441,604	445,505,804	439,809,442		0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest			$28,302	$23,898	$28,302	$23,898	$24,100	[1]	$8,568
Dividends Per Common Share Declared for the Period			$0.41	$0.36	$1.19	$1.03								$0.41	$0.36	$1.19	$1.03
Warrants repurchased					463	136					331	463	136
Stock and or Warrant Repurchase Program, Authorized Amount	$250	$350			$250					$38
Shares converted (in shares)																	147,255,126			-147,255,126		-4,827,797		-2,761		74,421	454,028			16,886
Stock Canceled During Period, Shares																	-446,206			0		0		0
Restriced shares vested (in shares)																86,922	77,925			0		0		0
Common Stock, Dividends, Per Share, Cash Paid			$0.40	$0.35	$1.15	$0.98
Stock and Warrants Issued During Period Number of Warrants																												113,757	693,971							0	504,598,883
Warrants Exercised, Number of Warrants					-21,208	0
Number of Warrants Repurchased					-91,460,387	-59,787,050
Debt Instrument, Convertible, Conversion Ratio					1
Class of Warrant or Right, Exercise Price of Warrants or Rights																																										40
[1]	(a)Retrospectively adjusted as discussed in Note 2.

Stockholders_Equity_Noncontrol

Stockholders Equity Noncontrolling Interests (Details) (USD $)	9 Months Ended					3 Months Ended		9 Months Ended			3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended							9 Months Ended								9 Months Ended
	Sep. 30, 2013	Jun. 03, 2013	Jun. 02, 2013	Dec. 31, 2012		Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013
						Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	EPB [Member]	EPB [Member]	EPB [Member]	EPB [Member]	Kinder Morgan Management, LLC [Member]	Kinder Morgan Management, LLC [Member]	Kinder Morgan Management, LLC [Member]	Kinder Morgan Management, LLC [Member]	Kinder Morgan Management, LLC [Member]	Other [Member]	Other [Member]	El Paso Pipeline Partners, L.P. [Member]	El Paso Pipeline Partners, L.P. [Member]	General Partner [Member]	KMP Acquisiton of Copano Energy LLC [Member]	Subsequent Event [Member]	Dividend Declared [Member]	Noncontrolling Interest [Member]	Noncontrolling Interest [Member]	Noncontrolling Interest [Member]	Noncontrolling Interest [Member]	Equity distribution agreement [Member]	Equity distribution agreement [Member]	Equity distribution agreement [Member]
																								El Paso Pipeline Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	El Paso Pipeline Partners, L.P. [Member]					Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Management, LLC [Member]	El Paso Pipeline Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
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
Value of units available for sale under equity distribution agreement															500,000,000		500,000,000					500,000,000
Proceeds from Issuance of Common Limited Partners Units																								2,000,000
Noncontrolling interests	15,037,000,000			10,234,000,000	[1]	7,612,000,000		7,612,000,000		3,270,000,000					3,020,000,000		3,020,000,000		2,716,000,000	264,000,000	137,000,000	4,141,000,000	4,111,000,000					15,037,000,000	10,234,000,000	9,752,000,000	5,247,000,000
Distribution Made to Limited Partner, Distributions Paid, Per Unit						$1.32	$1.23	$3.91	$3.59		$0.63	$0.55	$1.86	$0.55
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders						377,000,000	275,000,000	983,000,000	788,000,000		80,000,000	64,000,000	235,000,000	64,000,000
Noncontrolling intreests, proceeds from equity issuance	4,799,000,000							385,000,000																	0							695,000,000	145,000,000	85,000,000
Noncontrolling Interest, Shares or Equity Units Issued								4,600,000																	43,371,000							8,248,000	1,757,000	2,038,000
Increase accumulated deferred income taxes	90,000,000
Increase in additional paid in capital	$154,000,000
Share distribution per share outstanding															0.01761
Declared dividend (usd per share)						$1.35	$1.26	$3.97	$3.69		$0.65	$0.58	$1.90	$1.13												$1.35	$0.65
Noncontrolling Interest, Share Distribution Declared to Noncontrolling Interest Holders															2,153,480
Noncontrolling Interest, Shares Distributed to Noncontrolling Interest Holders															1,880,172	1,578,616	5,411,720	4,646,736
[1]	(a)Retrospectively adjusted as discussed in Note 2.

Risk_Management_Energy_Commodi

Risk Management Energy Commodity Price Risk Managment (Details) (Forward Contracts [Member])	Sep. 30, 2013
Crude Oil Fixed Basis [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	-1,200,000
Natural Gas Basis [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	-30,700,000,000
Natural Gas Basis [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	7,900,000,000
Natural Gas Fixed Price [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	-35,200,000,000
Natural Gas Fixed Price [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	300,000,000
Crude Oil Fixed Price [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	-23,100,000
Crude Oil Fixed Price [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	500,000
Natural Gas Liquids Fixed Price [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	400,000

Risk_Management_Interest_Rate_

Risk Management Interest Rate Risk Managment (Details) (USD $)	Dec. 31, 2012	Jun. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Aug. 31, 2013	Dec. 31, 2012	Jun. 30, 2013	Aug. 05, 2013	Aug. 05, 2013
In Millions, unless otherwise specified	Kinder Morgan, Inc. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	fixed-to-variable interest rate swap agreement [Member]	fixed-to-variable interest rate swap agreement [Member]	fixed-to-variable interest rate swap agreement [Member]	fixed-to-variable interest rate swap agreement [Member]	fixed-to-variable interest rate swap agreement [Member]	4.15% Senior Notes due February 1, 2024 [Member] [Member]	2.65% Senior Notes due February 1, 2019 [Member]
			Kinder Morgan, Inc. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Termination of Swap Agreement [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]
							Kinder Morgan Energy Partners, L.P. [Member]
Derivative [Line Items]
Derivative, Notional Amount	$725		$725	$5,050	$500	$5,525	$975
Number of Fixed-to-Variable Interest Rate Swap Agreements Terminated		3
Interest rate, stated percentage								4.15%	2.65%
Proceeds from Settlement of Derivative Agreement		$96

Risk_Management_Fair_Value_of_

Risk Management Fair Value of Derivative Contracts (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Derivatives, Fair Value [Line Items]
Amount the adjustment to fair value of debt was increased by related to the fair value of interest rate swaps	$235	$664
Amount the fair value of debt adjustment was decreased by related to unamortized debt discounts	63	33
Unamortized premium	533	490
Amortization period of unamortized premium	16 years
Derivative Liability, Fair Value, Net	-314	-213
Derivative Asset, Fair Value, Net	433	772
Designated as Hedging Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-171	-30
Derivative Asset, Fair Value, Net	398	747
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-143	-183
Derivative Asset, Fair Value, Net	35	25
Commodity Contract [Member] | Designated as Hedging Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-92	-29
Derivative Asset, Fair Value, Net	84	82
Commodity Contract [Member] | Designated as Hedging Contracts [Member] | Current-Fair value of derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	19	42
Commodity Contract [Member] | Designated as Hedging Contracts [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-49	-18
Commodity Contract [Member] | Designated as Hedging Contracts [Member] | Non-current-Fair value of derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	65	40
Commodity Contract [Member] | Designated as Hedging Contracts [Member] | Non Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-43	-11
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-3	-4
Derivative Asset, Fair Value, Net	13	4
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Current-Fair value of derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	11	4
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-2	-3
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Non-current-Fair value of derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	2	0
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Non Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-1	-1
Power Derivative Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-140	-179
Derivative Asset, Fair Value, Net	22	21
Power Derivative Contract [Member] | Not Designated as Hedging Instrument [Member] | Current-Fair value of derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	9	8
Power Derivative Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-55	-59
Power Derivative Contract [Member] | Not Designated as Hedging Instrument [Member] | Non-current-Fair value of derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	13	13
Power Derivative Contract [Member] | Not Designated as Hedging Instrument [Member] | Non Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-85	-120
Interest Rate Swap [Member] | Designated as Hedging Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-79	-1
Derivative Asset, Fair Value, Net	314	665
Fair Value Hedging [Member] | Interest Rate Swap [Member] | Designated as Hedging Contracts [Member] | Current-Fair value of derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	114	9
Fair Value Hedging [Member] | Interest Rate Swap [Member] | Designated as Hedging Contracts [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	0	0
Fair Value Hedging [Member] | Interest Rate Swap [Member] | Designated as Hedging Contracts [Member] | Non-current-Fair value of derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	200	656
Fair Value Hedging [Member] | Interest Rate Swap [Member] | Designated as Hedging Contracts [Member] | Non Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-79	-1
Kinder Morgan, Inc. [Member]
Derivatives, Fair Value [Line Items]
Cash Margin Deposits		5
Interest Rate Swap [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	-79	-1
Balance Sheet, Derivative Liability Reduction, Gross	0	0
Derivative Liabilities Presented in Balance Sheet	-79	-1
Interest Rate Swap [Member] | Not Offset on Balance Sheet [Member]
Derivatives, Fair Value [Line Items]
Derivative Financial Instruments, Liabilities, Fair Value Disclosure	19	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative Liability, Fair Value, Net	-60	-1
Natural gas, crude and NGL derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	-95	-33
Balance Sheet, Derivative Liability Reduction, Gross	0	0
Derivative Liabilities Presented in Balance Sheet	-95	-33
Natural gas, crude and NGL derivative contracts [Member] | Not Offset on Balance Sheet [Member]
Derivatives, Fair Value [Line Items]
Derivative Financial Instruments, Liabilities, Fair Value Disclosure	60	17
Derivative, Collateral, Right to Reclaim Cash	0	5
Derivative Liability, Fair Value, Net	-35	-11
Power Derivative Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	-140	-179
Balance Sheet, Derivative Liability Reduction, Gross	0	0
Derivative Liabilities Presented in Balance Sheet	-140	-179
Power Derivative Contract [Member] | Not Offset on Balance Sheet [Member]
Derivatives, Fair Value [Line Items]
Derivative Financial Instruments, Liabilities, Fair Value Disclosure	22	21
Derivative, Collateral, Right to Reclaim Cash	5	0
Derivative Liability, Fair Value, Net	-113	-158
Interest Rate Swap [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	314	665
Balance Sheet, Derivative Asset Reduction, Gross	0	0
Derivative Assets	314	665
Derivative, Collateral, Obligation to Return Cash	0	0
Derivative Asset, Fair Value, Net	295	665
Interest Rate Swap [Member] | Not Offset on Balance Sheet [Member]
Derivatives, Fair Value [Line Items]
Financial Instruments, Asset	-19	0
Natural gas, crude and NGL derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	97	86
Balance Sheet, Derivative Asset Reduction, Gross	0	0
Derivative Assets	97	86
Derivative Asset, Fair Value, Net	37	69
Natural gas, crude and NGL derivative contracts [Member] | Not Offset on Balance Sheet [Member]
Derivatives, Fair Value [Line Items]
Financial Instruments, Asset	-60	-17
Derivative, Collateral, Obligation to Return Cash	0	0
Power Derivative Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	22	21
Balance Sheet, Derivative Asset Reduction, Gross	0	0
Derivative Assets	22	21
Derivative Asset, Fair Value, Net	0	0
Power Derivative Contract [Member] | Not Offset on Balance Sheet [Member]
Derivatives, Fair Value [Line Items]
Financial Instruments, Asset	-22	-21
Derivative, Collateral, Obligation to Return Cash	$0	$0

Risk_Management_Debt_Fair_Valu

Risk Management Debt Fair Value Adjustment (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Derivatives, Fair Value [Line Items]
Amortization Period of Deferred Gain (Loss) on Discontinuation of Interest Rate Fair Value Hedge	16 years
Amount the fair value of debt adjustment was decreased by related to unamortized debt discounts	$63	$33
Deferred Gain (Loss) on Discontinuation of Interest Rate Fair Value Hedge	533	490
Amount the adjustment to fair value of debt was increased by related to the fair value of interest rate swaps	235	664
Increase (decrease) in debt fair value adjustment related to purchase accounting	$1,419	$1,470

Risk_Management_Effect_of_Deri

Risk Management Effect of Derivative Contracts on the Income Statement (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Other Comprehensive Income (Loss) [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)recognized in OCI on derivative(effective portion)	($80)	($71)	($49)	$71
Revenues-Product sales and other [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	7		10
Interest Rate Swap [Member] | Other Comprehensive Income (Loss) [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)recognized in OCI on derivative(effective portion)	-2	-2	6	-5
Interest Rate Swap [Member] | Interest expense [Member] | Fair Value Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss) recognized in income on derivative	-26	29	-333	110
Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Loss to be reclassified within twelve months			17
Commodity Contract [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	-19	10	-10	-5
Amount of gain/(loss)recognized in incomeon derivative(ineffective portionand amountexcluded fromeffectiveness testing)	-8	-5	-2	-8
Commodity Contract [Member] | Other Comprehensive Income (Loss) [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)recognized in OCI on derivative(effective portion)	-78	-69	-55	76
Commodity Contract [Member] | Revenues Natural Gas Sales [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	0	1	0	3
Amount of gain/(loss)recognized in incomeon derivative(ineffective portionand amountexcluded fromeffectiveness testing)	0	0	0	0
Commodity Contract [Member] | Interest expense [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	0	2	1	2
Amount of gain/(loss)recognized in incomeon derivative(ineffective portionand amountexcluded fromeffectiveness testing)	0	0	0	0
Commodity Contract [Member] | Interest expense [Member] | Fair Value Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss) recognized in income on derivative	26	-29	333	-110
Commodity Contract [Member] | Revenues-Product sales and other [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	-22	0	-9	-23
Amount of gain/(loss)recognized in incomeon derivative(ineffective portionand amountexcluded fromeffectiveness testing)	-8	-5	-2	-8
Commodity Contract [Member] | Gas purchases and other costs of sales [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	3	7	-2	13
Amount of gain/(loss)recognized in incomeon derivative(ineffective portionand amountexcluded fromeffectiveness testing)	$0	$0	$0	$0

Risk_Management_Credit_Risks_D

Risk Management Credit Risks (Details) (USD $)	Sep. 30, 2013	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013
	Kinder Morgan, Inc. [Member]	Kinder Morgan, Inc. [Member]	Kinder Morgan, Inc. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]
	External Credit Rating, Non Investment Grade [Member]	Commodity [Member]	Commodity [Member]	notches	One notch credit downgrade [Member]	Two notch credit downgrade [Member]	Commodity [Member]
Credit Derivatives [Line Items]
Letters of Credit Outstanding, Amount		$170,000,000	$300,000,000				$0
Additional Collateral, Aggregate Fair Value	$0				$0	$18,000,000
Number of Credit Rating Notches				2

Risk_Management_Reporting_of_A

Risk Management Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income [Line Items]
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	($10)		($10)		$7
Accumulated Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Net of Tax	23		23		51
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	-110		-110		-176
Accumulated other comprehensive loss	-97		-97		-118	[1]
Comprehensive Income (Loss), Net of Tax, Attributable to Parent			-17
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax	25	24	13	-20
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Gain (Loss) Arising During Period, Net of Tax	17	22	-28	21
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, Net of Tax	66	-1	66	12
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	51	-14	21	59
OCI before Reclassifications [Member]
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income [Line Items]
Accumulated Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Net of Tax	-28		-28
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	66		66
Accumulated other comprehensive loss	16		16
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax			-22
Amounts reclassified from AOCI [Member]
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income [Line Items]
Accumulated Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Net of Tax	0		0
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	0		0
Accumulated other comprehensive loss	5		5
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax			$5
[1]	(a)Retrospectively adjusted as discussed in Note 2.

Fair_Value_Fair_Value_of_Deriv

Fair Value Fair Value of Derivative Contracts (Details) (USD $)	3 Months Ended		9 Months Ended																					9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	1-May-13	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012	Sep. 30, 2012	Sep. 30, 2012
						Estimate of Fair Value [Member]	Estimate of Fair Value [Member]	Estimate of Fair Value [Member]	Estimate of Fair Value [Member]	Quoted prices in active markets for identical assets (Level 1) [Member]	Quoted prices in active markets for identical assets (Level 1) [Member]	Quoted prices in active markets for identical assets (Level 1) [Member]	Quoted prices in active markets for identical assets (Level 1) [Member]	Significant other observable inputs (Level 2) [Member]	Significant other observable inputs (Level 2) [Member]	Significant other observable inputs (Level 2) [Member]	Significant other observable inputs (Level 2) [Member]	Significantunobservable inputs (Level 3) [Member]	Significantunobservable inputs (Level 3) [Member]	Significantunobservable inputs (Level 3) [Member]	Significantunobservable inputs (Level 3) [Member]	Minimum [Member]	Maximum [Member]	El Paso Corporation [Member]
						Commodity Contract [Member]	Commodity Contract [Member]	Interest Rate Swap [Member]	Interest Rate Swap [Member]	Commodity Contract [Member]	Commodity Contract [Member]	Interest Rate Swap [Member]	Interest Rate Swap [Member]	Commodity Contract [Member]	Commodity Contract [Member]	Interest Rate Swap [Member]	Interest Rate Swap [Member]	Commodity Contract [Member]	Commodity Contract [Member]	Interest Rate Swap [Member]	Interest Rate Swap [Member]	MWh	MWh
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets						$119	$107	$314	$665	$13	$3	$0	$0	$43	$76	$314	$665	$63	$28	$0	$0
Fair Value, Assets Liabilites Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning of Period	-114	-220	-155	7	18
Total gains (losses), Included in earnings	-17	-7	-18	-8
Total gains (losses), Included in other comprehensive income	-2	-6	-2	0
Purchases	0	0	18	-243																				246
Settlements	13	14	37	25
End of Period	-120	-219	-120	-219	18
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	-14	-10	-13	-6
Derivative Financial Instruments, Liabilities, Fair Value Disclosure						($235)	($212)	($79)	($1)	($5)	($3)	$0	$0	($47)	($26)	($79)	($1)	($183)	($183)	$0	$0
Price of Mega Watts Per Hour																						28.5	60.93

Fair_Value_Fair_Value_of_Finan

Fair Value Fair Value of Financial Instruments (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Fair Value Adjustments	$2,124	$2,591	[1]
Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total debt	36,011	34,401
Estimate of Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total debt	$35,939	$36,720
[1]	(a)Retrospectively adjusted as discussed in Note 2.

Reportable_Segments_Details

Reportable Segments (Details) (USD $)	3 Months Ended		9 Months Ended				3 Months Ended		9 Months Ended			3 Months Ended		9 Months Ended			3 Months Ended		9 Months Ended			3 Months Ended		9 Months Ended			3 Months Ended		9 Months Ended			3 Months Ended		9 Months Ended			3 Months Ended		9 Months Ended					3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended					3 Months Ended	9 Months Ended	3 Months Ended	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012		Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Mar. 31, 2013	Sep. 30, 2012	Sep. 30, 2012	Sep. 30, 2012
							Natural Gas Pipelines [Member]	Natural Gas Pipelines [Member]	Natural Gas Pipelines [Member]	Natural Gas Pipelines [Member]	Natural Gas Pipelines [Member]	CO2 [Member]	CO2 [Member]	CO2 [Member]	CO2 [Member]	CO2 [Member]	Products Pipelines [Member]	Products Pipelines [Member]	Products Pipelines [Member]	Products Pipelines [Member]	Products Pipelines [Member]	Terminals [Member]	Terminals [Member]	Terminals [Member]	Terminals [Member]	Terminals [Member]	Kinder Morgan Canada [Member]	Kinder Morgan Canada [Member]	Kinder Morgan Canada [Member]	Kinder Morgan Canada [Member]	Kinder Morgan Canada [Member]	All Other Segments [Member]	All Other Segments [Member]	All Other Segments [Member]	All Other Segments [Member]	All Other Segments [Member]	Operating Segments [Member]	Operating Segments [Member]	Operating Segments [Member]	Operating Segments [Member]	Operating Segments [Member]	Corporate [Member]	Corporate [Member]	Intersegment Revenues [Member]	Intersegment Revenues [Member]	Intersegment Revenues [Member]	Intersegment Revenues [Member]	Intersegment Revenues [Member]	Intersegment Revenues [Member]	Intersegment Revenues [Member]	Intersegment Revenues [Member]	Intersegment Eliminations [Member]	Intersegment Eliminations [Member]	Intersegment Eliminations [Member]	Intersegment Eliminations [Member]	Rate Case and Environmental Matters [Member]	Newly Negotiated KMP Pipeline System Tolling Aggeement , Effective as of April 2013 [Member]	Maximum [Member]	KMPbs FTC Natural Gas Pipelines [Member]	KMPbs FTC Natural Gas Pipelines [Member]	KMPbs FTC Natural Gas Pipelines [Member]	KMPbs FTC Natural Gas Pipelines [Member]
																																												Natural Gas Pipelines [Member]	Natural Gas Pipelines [Member]	Natural Gas Pipelines [Member]	Natural Gas Pipelines [Member]	Terminals [Member]	Terminals [Member]	Terminals [Member]	Terminals [Member]						KMP Pipeline System [Member]				Loss on sale and the remeasurement of FTC Natural Gas Pipelines disposal group to fair value [Member]	Loss on sale and the remeasurement of FTC Natural Gas Pipelines disposal group to fair value [Member]
																																																									Kinder Morgan Energy Partners, L.P. [Member]
Segment Reporting Information [Line Items]
Share-based Compensation				$87
Investment Advisory Fees				37
(Gain) loss from the remeasurement of of net assets to fair value									558
Regulatory Assets and Liabilities, Recovery Period																																																									4 years	42 years
Legal Fees and Reserves				96																																																				177
Pension Contributions In Excess Of Expense				17
Increase in earnings from after tax sale of investments	1		140
Payments of Financing Costs		95		104
Impairment of Long-Lived Assets to be Disposed of																																																												934	179	934
Loss on remeasurement of previously held equity interest of Kinderhawk to fair value	0	0	-558	0
Revenues	3,756	2,870	10,198	6,894			2,388	1,646	6,197	3,440		456	420	1,345	1,250		474	386	1,371	940		354	334	1,034	1,017		74	80	221	226		1	-4	3	-5		3,749	2,862	10,175	6,869				2	0	3	0	0	0	1	1	-2	0	-4	-1
Other revenues (a)	9	8	27	26
Segment earnings before DD&A							958	822	3,281	1,477		340	327	1,040	988		202	150	399	490		217	183	609	564		43	56	286	158		-3	21	-4	18		1,757	1,559	5,611	3,695
Total segment depreciation, depletion and amortization	-467	-403	-1,327	-1,010																																																										-7
Total segment amortization of excess cost of investments	-11	-5	-29	-9
General and administrative expenses(c)	-158	-186	-481	-816
Unallocable income tax expense	-159	-54	-554	-145
(Loss) income from KMPbs FTC Natural Gas Pipelines disposal group (e)	0	-131	-2	-789
Net income (loss)	551	255	1,988	-61
Assets	74,575		74,575		68,245	[1]	52,146		52,146		46,600	4,611		4,611		4,148	6,466		6,466		6,089	6,673		6,673		5,931	1,662		1,662		1,724	567		567		601	72,125		72,125		65,093	2,450	2,854
Assets held for sale	0		0		298	[1]
Loss on sale and the remeasurement of KMPbs FTC Natural Gas Pipelines disposal group to fair value, net of tax																																																											2
Unallocable Interest Expense Net Of Interest Income	-420	-533	-1,257	-1,013
Severance Costs				$157
[1]	(a)Retrospectively adjusted as discussed in Note 2.

Related_Party_Transactions_Aff

Related Party Transactions Affiliated Balances (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Related party balances [Line Items]
Assets held for sale	$0	$298	[1]
Other current assets	492	416	[1]
Deferred charges and other assets	2,697	2,968	[1]
Assets	74,575	68,245	[1]
Total Liabilities	46,273	44,145	[1]
Current Portion of Debt (Note 14)	2,973	2,401
Related Party [Member]
Related party balances [Line Items]
Accounts Receivable, Related Parties	20	25
Assets held for sale	0	114
Other current assets	3	14
Deferred charges and other assets	48	48
Assets	71	201
Total Liabilities	184	189
Accounts Payable, Related Parties, Current	9	11
KMP and EPB [Member]
Related party balances [Line Items]
Notes Payable, Related Parties, Current	5	5
Notes Payable, Related Parties, Noncurrent	$170	$173
[1]	(a)Retrospectively adjusted as discussed in Note 2.

Related_Party_Transactions_Not1

Related Party Transactions Notes Receivable (Details) (USD $)	9 Months Ended			3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2013	25-May-12	Sep. 30, 2013
			Plantation Pipe Line Company [Member]	Gulf LNG Holdings Group LLC [Member]	Gulf LNG Holdings Group LLC [Member]	Gulf LNG Holdings Group LLC [Member]	Gulf LNG Holdings Group LLC [Member]	Gulf LNG Holdings Group LLC [Member]
Related Party Transaction [Line Items]
Ownership interest			51.17%					50.00%
Notes Receivable, Related Parties			$49		$10		$85
Proceeds from Related Party Debt	10	48		10	75
Notes receivable, balloon payment, related parties			45
Notes receivable, related parties, current			$1
Debt Instrument, Interest Rate, Stated Percentage			4.25%			12.00%

Pension_and_Other_Postretireme2

Pension and Other Postretirement Benefit Plans (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Defined Benefit Plan Disclosure [Line Items]
Other Comprehensive Income (Loss), Net of Tax	$51	($30)	($14)	$138
Kinder Morgan, Inc. [Member] | Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	7	6	19	13
Defined Benefit Plan, Interest Cost	22	26	68	42
Defined Benefit Plan, Expected Return on Plan Assets	-43	-43	-131	-69
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	-1	-1	0	-1
Defined Benefit Plan, Amortization of Net Gains (Losses)	0	2	0	7
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Settlements and Curtailments	0	0	-3	0
Defined Benefit Plan, Net Periodic Benefit Cost	-15	-10	-47	-8
Kinder Morgan, Inc. [Member] | Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	0	-1	0	0
Defined Benefit Plan, Interest Cost	4	5	14	9
Defined Benefit Plan, Expected Return on Plan Assets	-1	-2	-5	-5
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	0	0	0	0
Defined Benefit Plan, Amortization of Net Gains (Losses)	0	2	3	4
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Settlements and Curtailments	0	0	0	0
Defined Benefit Plan, Net Periodic Benefit Cost	3	4	12	8
Changes Measurement [Member] | Other Pension Plan, Postretirement or Supplemental Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Increase (Decrease) in Other Accrued Liabilities			84
Other Comprehensive Income (Loss), Net of Tax			53
Increase (Decrease) in Deferred Income Taxes			$31

Income_Taxes_Details

Income Taxes (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Operating Loss Carryforwards [Line Items]
Income Tax Expense (Benefit)	$171	$60	$675	$165
Effective tax rate	24.00%	13.00%	25.00%	18.00%
Federal statutory income tax rate	35.00%	35.00%	35.00%	35.00%
Florida Gas Pipeline [Member]
Operating Loss Carryforwards [Line Items]
Ownership interest	50.00%		50.00%
NGPL [Member]
Operating Loss Carryforwards [Line Items]
Ownership interest	20.00%		20.00%

Litigation_Environmental_and_O1

Litigation, Environmental and Other Contingencies Federal Energy Regulatory Commission Proceedings (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
Loss Contingencies [Line Items]
Loss Contingentcy, Period of Time Litigation Concerns	10 years
SFPP [Member] | Repreations, Refunds, and Rate Reductions [Member] | Various Shippers [Member] | Federal Energy Regulatory Commission [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingentcy, Period of Time Litigation Concerns	2 years
EPNG [Member] | 2008 rate case and the 2010 rate case [Member] | Various Shippers [Member] | Federal Energy Regulatory Commission [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Pending Claims, Number	2
Unfavorable Regulatory Action [Member] | SFPP [Member] | Annual Revenue Reductions [Member] | Various Shippers [Member] | Federal Energy Regulatory Commission [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value	$20
Unfavorable Regulatory Action [Member] | SFPP [Member] | Revenue Subject to Refund [Member] | Various Shippers [Member] | Federal Energy Regulatory Commission [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value	100
EPNG 2010 Rate Case [Member] | Minimum [Member]
Loss Contingencies [Line Items]
Incremental Loss Contingency Above Existing Reserve Amount	0
EPNG 2010 Rate Case [Member] | Maximum [Member]
Loss Contingencies [Line Items]
Incremental Loss Contingency Above Existing Reserve Amount	$50

Litigation_Environmental_and_O2

Litigation, Environmental and Other Contingencies California Public Utilities Commission Proceedings (Details) (USD $)	9 Months Ended			9 Months Ended			12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Dec. 31, 2013
	California Public Utilities Commission [Member]	SFPP [Member]	SFPP [Member]	Reparations [Member]	Annual Revenue Reductions [Member]	Annual Revenue Reductions [Member]	Cash Distribution [Member]
		Various Shippers [Member]	Various Shippers [Member]	SFPP [Member]	SFPP [Member]	SFPP [Member]	Kinder Morgan Energy Partners, L.P. [Member]
		California Public Utilities Commission [Member]	2008 rate case and the 2010 rate case [Member]	Various Shippers [Member]	Various Shippers [Member]	Various Shippers [Member]
		Pending Litigation [Member]	California Public Utilities Commission [Member]	California Public Utilities Commission [Member]	California Public Utilities Commission [Member]	Federal Energy Regulatory Commission [Member]
			Pending Litigation [Member]	Unfavorable Regulatory Action [Member]	Unfavorable Regulatory Action [Member]	Unfavorable Regulatory Action [Member]
				Pending Litigation [Member]	Pending Litigation [Member]	Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Number of Judges			2
Reduction in rates sought by shippers in percent		7.00%
Rate increase sought, percent	36.00%
Loss Contingency, Damages Sought, Value				$375	$30	$20
Distribution Made to Limited Partner, Cash Distributions Paid							5.33

Litigation_Environmental_and_O3

Litigation, Environmental and Other Contingencies Copano Shareholders' Litigation (Details) (USD $)	9 Months Ended
	Sep. 30, 2013
Punative Class Action Lawsuits [Member] | Copano Energy LLC [Member] | Pending Litigation [Member] | Schultes v. Copano Ennergy, L.L.C., Bruen v. Copano Energy L.L.C., and In re Copano Energy, L.L.C. Shareholder Lititgation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Pending Claims, Number	3
The Texas State Action, Texas Federal Action, and Delaware Action [Member] | Punative Class Action Lawsuits [Member] | Copano Energy LLC [Member] | Consolidated Legal Proceedings [Member] | In re Copano Energy, L.L.C. Shareholder Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Pending Claims, Number	3
Copano Shareholder Litigation [Member]
Loss Contingencies [Line Items]
Litigation Settlement, Amount	$450,000

Litigation_Environmental_and_O4

Litigation, Environmental and Other Contingencies Other Commercial Matters (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
Loss Contingencies [Line Items]
Loss Contingentcy, Period of Time Litigation Concerns	10 years
Price Reporting Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value	$140
Union Pacific Railroad Company Easements [Member]
Loss Contingencies [Line Items]
Loss contingency, initial award amount	15
Loss Contingency, Damages Sought, Value	75
Loss Contingency, Interest Associated with Settlement	20
Severstal Sparrows Point Crane Collapse [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value	$30
Plains Gas Solutions, LLC v. Tennessee Gas Pipeline Company, L.L.C. et al [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought (minimum)	100
SNG [Member] | Allen vs El Paso GP [Member]
Loss Contingencies [Line Items]
Investment Owned, Percent of Net Assets	25.00%
SFPP [Member] | Federal Energy Regulatory Commission [Member] | Rent Payable and Associate Interest [Member] | Union Pacific Railroad Company [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingentcy, Period of Time Litigation Concerns	10 years

Litigation_Environmental_and_O5

Litigation, Environmental and Other Contingencies General (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Commitments and Contingencies Disclosure [Abstract]
Estimated Litigation Liability	$619	$425

Litigation_Environmental_and_O6

Litigation, Environmental and Other Contingencies Enviormental Matters (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Jun. 30, 2013

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

New Jersey Department of Environmental Protection [Member]

Portland Harbor Superfund Site [Member]

Portland Harbor Superfund Site [Member]

Roosevelt Irrigation District [Member]

Los Angeles Marine Terminal in the Port of Los Angeles [Member]

Exxon Mobil Corporation [Member]

Mission Valley Terminal Lawsuit [Member]

Southeast Louisiana Flood Protection Litigation [Member]

Colorado Oil and Gas Conservation Commission Inspections [Member]

PHMSA Inspection of Carteret Terminal [Member]

Parties

Terminals

Defendants

Defendants

Loss Contingencies [Line Items]

Payments for Environmental Liabilities

$220,000

Payment for Environmental Liabilities, Paid Toward Public Project

80,000

Loss Contingency, Damages Sought, Value

175,000,000

15,000,000

365,000,000

Penalty From Notice Of Probable Violation

63,100

Loss contingency, number of defendants (defendants)

300

70

100

Loss contingency, duration of damages sought

40 years

Number of liquid terminals (terminals)

2

Number of parties involoved in site cleanup (parties)

90

Litigation Settlement, Amount

1,000,000

Site contingency, percentage of costs applicable

60.00%

50.00%

Cost of Services, Environmental Remediation

750,000

Loss contingency, original damages sought, value

170,000,000

Accrual for environmental loss contingencies

390,000,000

421,000,000

219,000,000

253,000,000

Environmental recoveries receivable

$14,000,000

$22,000,000

Loss Contingentcy, Period of Time Litigation Concerns

10 years

Litigation_Environmental_and_O7

Litigation, Environmental and Other Contingencies Other Contingencies (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
Kinder Morgan Energy Partners, L.P. [Member]
Loss Contingencies [Line Items]
subsidiary debt indemnified by parent	$5,900
EPB [Member]
Loss Contingencies [Line Items]
subsidiary debt indemnified by parent	470
TGP and EPNG and El Paso Midstream drop down transactions [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Loss Contingencies [Line Items]
subsidiary debt indemnified by parent	5,200
Elba Liquification Company LLC [Member]
Loss Contingencies [Line Items]
Equity Method Investment, Ownership Percentage	51.00%
Estimated required contribution to equity investment	$800

Accounting_for_Regulatory_Acti2

Accounting for Regulatory Activities (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012		Sep. 30, 2013	Jun. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 03, 2013	Sep. 30, 2013
In Millions, unless otherwise specified				Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Maximum [Member]	Minimum [Member]	TGP's Sale of Production Area Facilities [Member]	TGP's Sale of Production Area Facilities [Member]
Regulatory Assets [Line Items]
Increase (Decrease) in Prepaid Expense and Other Assets									$87
Amortization of Regulatory Asset									5
Regulatory Liabilities Reclassified from Long-term Deferred Credits due to Application of Regulatory Accounting					362
Regulatory Liabilities Reclassified from Long-term Deferred Credits due to Application of Regulatory Accounting, Current				117
Regulatory Assets, Current	77	62
Assets held for sale	0	298	[1]
Regulatory Assets, Noncurrent	463	402
Regulatory Assets	540	464
Regulatory Liability, Current	123	7
Regulatory Liability, Noncurrent	393	113
Regulatory Liabilities	516	120
Regulatory Assets and Liabilities, Recovery Period						42 years	1 year
Increase (Decrease) in Other Regulatory Assets								92
Gain (Loss) on Disposition of Oil and Gas and Timber Property								$36
[1]	(a)Retrospectively adjusted as discussed in Note 2.

Reconciliation_of_Significant_2

Reconciliation of Significant Asset Balances (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Debt Fair Value Adjustments	$2,124	$2,591	[1]
Cash and Cash Equivalents, at Carrying Value	816	714
Property, plant and equipment, net (Note 14)	35,275	30,996	[1]
Investments	6,044	5,804	[1]
Goodwill (Note 14)	24,494	23,632	[1]
Current Portion of Debt (Note 14)	2,973	2,401
Long-term Debt, Excluding Current Maturities	33,038	32,000	[1]
Long-term debt outstanding	30,814	29,309
Kinder Morgan, Inc. [Member]
Cash and Cash Equivalents, at Carrying Value	137	71	[1]
Property, plant and equipment, net (Note 14)	2,630	2,735
Goodwill (Note 14)	17,940	18,193
Current Portion of Debt (Note 14)	2,195	1,153	[1]
Long-term Debt, Excluding Current Maturities	7,724	9,148
Long-term Debt	10,019	10,401
Kinder Morgan Energy Partners, L.P. [Member]
Cash and Cash Equivalents, at Carrying Value	534	529
Property, plant and equipment, net (Note 14)	26,742	22,330
Goodwill (Note 14)	6,532	5,417
Current Portion of Debt (Note 14)	702	1,155
Long-term Debt, Excluding Current Maturities	18,910	15,907
Long-term Debt	19,612	17,062
El Paso Pipeline Partners, L.P. [Member]
Debt Fair Value Adjustments	8	8
Cash and Cash Equivalents, at Carrying Value	145	114
Property, plant and equipment, net (Note 14)	5,903	5,931
Goodwill (Note 14)	22	22
Current Portion of Debt (Note 14)	76	93
Long-term Debt, Excluding Current Maturities	4,180	4,254
Long-term Debt	$4,256	$4,347
[1]	(a)Retrospectively adjusted as discussed in Note 2.

Guarantee_of_Securities_of_Sub2

Guarantee of Securities of Subsidiaries (Details) (USD $)	9 Months Ended	12 Months Ended	3 Months Ended
In Billions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013
	El Paso Corporation [Member]	El Paso Corporation [Member]	Guarantor Subsidiary: El Paso Holdco, and Subsidiary Issuers: El Passos LLC, Finance Corp [Member]
			Kinder Morgan, Inc. [Member]
Guarantor Obligations [Line Items]
Indemnified by parent subsidiary debt	$3.90	$3.90
Ownership Percentage of Subsidiary			100.00%

Guarantee_of_Securities_of_Sub3

Guarantee of Securities of Subsidiaries Balance Sheet (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012		Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012
						Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]	Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]	Parent Company [Member]	Parent Company [Member]	Guarantor Subsidiaries [Member]	Guarantor Subsidiaries [Member]	Subsidiary Issuer [Member]	Subsidiary Issuer [Member]	Non-Guarantor Subsidiaries [Member]	Non-Guarantor Subsidiaries [Member]	Consolidation, Eliminations [Member]	Consolidation, Eliminations [Member]	El Paso Corporation [Member]	El Paso Corporation [Member]	Kinder Morgan, Inc. [Member]	Kinder Morgan, Inc. [Member]
Guarantor Obligations [Line Items]
Indemnified by parent subsidiary debt																		$3,900,000,000	$3,900,000,000
Cash and cash equivalents	816,000,000	714,000,000				816,000,000	714,000,000	106,000,000	3,000,000	0	0	0	45,000,000	710,000,000	666,000,000	0	0			137,000,000	71,000,000	[1]
All other current assets	492,000,000	416,000,000	[1]			2,775,000,000	2,960,000,000	672,000,000	813,000,000	11,000,000	27,000,000	4,000,000	123,000,000	2,430,000,000	9,322,000,000	-342,000,000	-7,325,000,000
Property, plant and equipment, net (Note 14)	35,275,000,000	30,996,000,000	[1]			35,275,000,000	30,996,000,000	9,000,000	8,000,000	0	0	0	0	35,266,000,000	30,988,000,000	0	0			2,630,000,000	2,735,000,000
Goodwill (Note 14)	24,494,000,000	23,632,000,000	[1]			24,494,000,000	23,632,000,000	0	0	0	0	8,062,000,000	8,059,000,000	16,432,000,000	15,573,000,000	0	0			17,940,000,000	18,193,000,000
Due from Affiliate, Noncurrent						0	0	2,000,000	1,555,000,000	0	0	0	0	1,993,000,000	2,095,000,000	-1,995,000,000	-3,650,000,000
Deferred charges and other other assets	2,697,000,000	2,968,000,000	[1]			5,171,000,000	4,139,000,000	209,000,000	202,000,000	0	0	903,000,000	1,158,000,000	4,935,000,000	3,912,000,000	-876,000,000	-1,133,000,000
Total Assets	74,575,000,000	68,245,000,000	[1]			74,575,000,000	68,245,000,000	21,373,000,000	22,634,000,000	10,613,000,000	11,217,000,000	15,438,000,000	22,636,000,000	67,810,000,000	68,341,000,000	-40,659,000,000	-56,583,000,000
Current Portion of Debt	2,973,000,000	2,401,000,000				2,973,000,000	2,401,000,000	1,514,000,000	1,035,000,000	0	0	530,000,000	115,000,000	929,000,000	1,251,000,000	0	0			2,195,000,000	1,153,000,000	[1]
Other Liabilities, Current						3,442,000,000	2,827,000,000	194,000,000	196,000,000	5,000,000	383,000,000	160,000,000	6,741,000,000	3,425,000,000	2,832,000,000	-342,000,000	-7,325,000,000
Long-term debt	33,038,000,000	32,000,000,000	[1]			33,038,000,000	32,000,000,000	1,872,000,000	3,068,000,000	0	0	4,011,000,000	4,378,000,000	27,155,000,000	24,554,000,000	0	0			7,724,000,000	9,148,000,000
Due to Affiliate, Noncurrent						0	0	1,993,000,000	1,764,000,000	0	296,000,000	0	35,000,000	2,000,000	1,555,000,000	-1,995,000,000	-3,650,000,000
Deferred income taxes	4,314,000,000	4,071,000,000	[1]			4,314,000,000	4,071,000,000	2,021,000,000	2,095,000,000	0	0	0	0	3,169,000,000	3,109,000,000	-876,000,000	-1,133,000,000
All other long-term liabilities	2,506,000,000	2,846,000,000	[1]			2,506,000,000	2,846,000,000	514,000,000	610,000,000	0	0	164,000,000	169,000,000	1,828,000,000	2,067,000,000	0	0
Total Liabilities	46,273,000,000	44,145,000,000	[1]			46,273,000,000	44,145,000,000	8,108,000,000	8,768,000,000	5,000,000	679,000,000	4,865,000,000	11,438,000,000	36,508,000,000	35,368,000,000	-3,213,000,000	-12,108,000,000
Accumulated other comprehensive loss	-97,000,000	-118,000,000	[1]
Total KMI equity	13,265,000,000	13,866,000,000	[1]			13,265,000,000	13,866,000,000	13,265,000,000	13,866,000,000	10,608,000,000	10,538,000,000	10,573,000,000	11,198,000,000	15,875,000,000	22,580,000,000	-37,056,000,000	-44,316,000,000
Noncontrolling interests	15,037,000,000	10,234,000,000	[1]			15,037,000,000	10,234,000,000	0	0	0	0	0	0	15,427,000,000	10,393,000,000	-390,000,000	-159,000,000
Total Stockholdersb Equity	28,302,000,000	24,100,000,000	[1]	23,898,000,000	8,568,000,000	28,302,000,000	24,100,000,000	13,265,000,000	13,866,000,000	10,608,000,000	10,538,000,000	10,573,000,000	11,198,000,000	31,302,000,000	32,973,000,000	-37,446,000,000	-44,475,000,000
Total Liabilities and Stockholdersb Equity	74,575,000,000	68,245,000,000	[1]			74,575,000,000	68,245,000,000	21,373,000,000	22,634,000,000	10,613,000,000	11,217,000,000	15,438,000,000	22,636,000,000	67,810,000,000	68,341,000,000	-40,659,000,000	-56,583,000,000
Other Long-term Investments						6,044,000,000	5,804,000,000	0	0	0	0	0	19,000,000	6,044,000,000	5,785,000,000	0	0
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures						$0	$0	$20,375,000,000	$20,053,000,000	$10,602,000,000	$11,190,000,000	$6,469,000,000	$13,232,000,000	$0	$0	($37,446,000,000)	($44,475,000,000)
[1]	(a)Retrospectively adjusted as discussed in Note 2.

Guarantee_of_Securities_of_Sub4

Guarantee of Securities of Subsidiaries Income Statement (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Guarantor Obligations [Line Items]
Revenues	$3,756	$2,870	$10,198	$6,894
Costs of sales	1,543	854	3,767	2,071
Depreciation, depletion and amortization	467	403	1,327	1,010
Taxes, Miscellaneous	95	88	295	207
Total Operating Costs, Expenses and Other	2,715	2,018	7,368	5,266
Operating Income	1,041	852	2,830	1,628
Earnings from equity investments	100	101	294	238
Other Nonoperating Income (Expense)	11	21	35	29
Income from Continuing Operations Before Income Taxes	722	446	2,665	893
Income Tax Expense (Benefit)	-171	-60	-675	-165
Income from Continuing Operations	551	386	1,990	728
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	0	-131	-2	-789
Net income (loss)	551	255	1,988	-61
Net Income (Loss) Attributable to Noncontrolling Interest	-265	-55	-1,133	156
Net Income Attributable to Kinder Morgan, Inc.	286	200	855	95
Parent Company [Member]
Guarantor Obligations [Line Items]
Revenues	9	9	27	26
Costs of sales	0	0	0	0
Depreciation, depletion and amortization	0	0	1	0
Operations, maintenance, general and administrative, and other expenses	12	26	21	216
Total Operating Costs, Expenses and Other	12	26	22	216
Operating Income	-3	-17	5	-190
Earnings from equity investments	334	350	1,007	465
Income from Continuing Operations Before Income Taxes	273	146	817	-46
Income Tax Expense (Benefit)	13	54	38	142
Income from Continuing Operations		200	855	96
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest		0	0	-1
Net income (loss)	286	200	855	95
Net Income (Loss) Attributable to Noncontrolling Interest	0	0	0	0
Net Income Attributable to Kinder Morgan, Inc.	286	200	855	95
Interest Income (Expense), Net	-58	-188	-194	-320
Amortization of excess costs of equity investments and other non operating income, net	0	1	-1	-1
Guarantor Subsidiaries [Member]
Guarantor Obligations [Line Items]
Revenues	0	0	0	0
Costs of sales	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Operations, maintenance, general and administrative, and other expenses	0	0	0	0
Total Operating Costs, Expenses and Other	0	0	0	0
Operating Income	0	0	0	0
Earnings from equity investments	50	59	127	-17
Income from Continuing Operations Before Income Taxes	50	55	127	-21
Income Tax Expense (Benefit)	0	1	0	1
Income from Continuing Operations		56	127	-20
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest		0	0	0
Net income (loss)	50	56	127	-20
Net Income (Loss) Attributable to Noncontrolling Interest	0	0	0	0
Net Income Attributable to Kinder Morgan, Inc.	50	56	127	-20
Interest Income (Expense), Net	0	-3	0	-3
Amortization of excess costs of equity investments and other non operating income, net	0	-1	0	-1
Subsidiary Issuer [Member]
Guarantor Obligations [Line Items]
Revenues	0	0	0	0
Costs of sales	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Operations, maintenance, general and administrative, and other expenses	0	-1	-3	63
Total Operating Costs, Expenses and Other	0	-1	-3	63
Operating Income	0	1	3	-63
Earnings from equity investments	123	138	378	106
Income from Continuing Operations Before Income Taxes	58	9	142	-102
Income Tax Expense (Benefit)	-8	51	-15	86
Income from Continuing Operations		60	127	-16
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest		0	0	0
Net income (loss)	50	60	127	-16
Net Income (Loss) Attributable to Noncontrolling Interest	0	0	0	0
Net Income Attributable to Kinder Morgan, Inc.	50	60	127	-16
Interest Income (Expense), Net	-65	-129	-239	-143
Amortization of excess costs of equity investments and other non operating income, net	0	-1	0	-2
Non-Guarantor Subsidiaries [Member]
Guarantor Obligations [Line Items]
Revenues	3,756	2,861	10,195	6,868
Costs of sales	1,543	854	3,767	2,071
Depreciation, depletion and amortization	467	403	1,326	1,010
Operations, maintenance, general and administrative, and other expenses	702	736	2,280	1,906
Total Operating Costs, Expenses and Other	2,712	1,993	7,373	4,987
Operating Income	1,044	868	2,822	1,881
Earnings from equity investments	100	101	294	238
Income from Continuing Operations Before Income Taxes	848	783	3,091	1,616
Income Tax Expense (Benefit)	-176	-166	-698	-394
Income from Continuing Operations		617	2,393	1,222
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest		-131	-2	-788
Net income (loss)	672	486	2,391	434
Net Income (Loss) Attributable to Noncontrolling Interest	-280	-53	-1,208	175
Net Income Attributable to Kinder Morgan, Inc.	392	433	1,183	609
Interest Income (Expense), Net	-295	-203	-814	-527
Amortization of excess costs of equity investments and other non operating income, net	-1	17	789	24
Consolidation, Eliminations [Member]
Guarantor Obligations [Line Items]
Revenues	-9	0	-24	0
Costs of sales	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Operations, maintenance, general and administrative, and other expenses	-9	0	-24	0
Total Operating Costs, Expenses and Other	-9	0	-24	0
Operating Income	0	0	0	0
Earnings from equity investments	-507	-547	-1,512	-554
Income from Continuing Operations Before Income Taxes	-507	-547	-1,512	-554
Income Tax Expense (Benefit)	0	0	0	0
Income from Continuing Operations		-547	-1,512	-554
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest		0	0	0
Net income (loss)	-507	-547	-1,512	-554
Net Income (Loss) Attributable to Noncontrolling Interest	15	-2	75	-19
Net Income Attributable to Kinder Morgan, Inc.	-492	-549	-1,437	-573
Interest Income (Expense), Net	0	0	0	0
Amortization of excess costs of equity investments and other non operating income, net	0	0	0	0
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]
Guarantor Obligations [Line Items]
Revenues	3,756	2,870	10,198	6,894
Costs of sales	1,543	854	3,767	2,071
Depreciation, depletion and amortization	467	403	1,327	1,010
Operations, maintenance, general and administrative, and other expenses	705	761	2,274	2,185
Total Operating Costs, Expenses and Other	2,715	2,018	7,368	5,266
Operating Income	1,041	852	2,830	1,628
Earnings from equity investments	100	101	294	238
Income from Continuing Operations Before Income Taxes	722	446	2,665	893
Income Tax Expense (Benefit)	-171	-60	-675	-165
Income from Continuing Operations		386	1,990	728
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest		-131	-2	-789
Net income (loss)	551	255	1,988	-61
Net Income (Loss) Attributable to Noncontrolling Interest	-265	-55	-1,133	156
Net Income Attributable to Kinder Morgan, Inc.	286	200	855	95
Interest Income (Expense), Net	-418	-523	-1,247	-993
Amortization of excess costs of equity investments and other non operating income, net	($1)	$16	$788	$20

Guarantee_of_Securities_of_Sub5

Guarantee of Securities of Subsidiaries Comprehensive income (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Guarantor Obligations [Line Items]
Net Income (Loss)	$551	$255	$1,988	($61)
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	-80	-71	-49	71
Reclassification of change in fair value of derivatives to net income	19	-10	10	5
Foreign currency translation adjustments	33	54	-54	52
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	79	-3	79	10
Total other comprehensive income (loss)	51	-30	-14	138
Total comprehensive income	602	225	1,974	77
Comprehensive (Income) Loss, Net of Tax, Attributable to Noncontrolling Interest	-265	-39	-1,098	77
Total comprehensive income	337	186	876	154
Parent Company [Member]
Guarantor Obligations [Line Items]
Net Income (Loss)	286	200	855	95
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	-42	-30	-22	25
Reclassification of change in fair value of derivatives to net income	10	-5	5	1
Foreign currency translation adjustments	17	22	-28	21
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	66	-1	66	12
Total other comprehensive income (loss)	51	-14	21	59
Total comprehensive income	337	186	876	154
Comprehensive (Income) Loss, Net of Tax, Attributable to Noncontrolling Interest	0	0	0	0
Total comprehensive income	337	186	876	154
Guarantor Subsidiaries [Member]
Guarantor Obligations [Line Items]
Net Income (Loss)	50	56	127	-20
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	-2	-2	6	-5
Reclassification of change in fair value of derivatives to net income	0	-2	-1	-2
Foreign currency translation adjustments	0	0	0	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	52	-1	49	12
Total other comprehensive income (loss)	50	-5	54	5
Total comprehensive income	100	51	181	-15
Comprehensive (Income) Loss, Net of Tax, Attributable to Noncontrolling Interest	0	0	0	0
Total comprehensive income	100	51	181	-15
Subsidiary Issuer [Member]
Guarantor Obligations [Line Items]
Net Income (Loss)	50	60	127	-16
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	-2	-2	6	-5
Reclassification of change in fair value of derivatives to net income	0	-2	-1	-2
Foreign currency translation adjustments	0	0	0	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	52	-1	49	12
Total other comprehensive income (loss)	50	-5	54	5
Total comprehensive income	100	55	181	-11
Comprehensive (Income) Loss, Net of Tax, Attributable to Noncontrolling Interest	0	0	0	0
Total comprehensive income	100	55	181	-11
Non-Guarantor Subsidiaries [Member]
Guarantor Obligations [Line Items]
Net Income (Loss)	672	486	2,391	434
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	-78	-70	-48	68
Reclassification of change in fair value of derivatives to net income	19	-10	10	5
Foreign currency translation adjustments	32	52	-53	50
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	78	-18	76	-5
Total other comprehensive income (loss)	51	-46	-15	118
Total comprehensive income	723	440	2,376	552
Comprehensive (Income) Loss, Net of Tax, Attributable to Noncontrolling Interest	-265	-39	-1,098	77
Total comprehensive income	458	401	1,278	629
Consolidation, Eliminations [Member]
Guarantor Obligations [Line Items]
Net Income (Loss)	-507	-547	-1,512	-554
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	44	33	9	-12
Reclassification of change in fair value of derivatives to net income	-10	9	-3	3
Foreign currency translation adjustments	-16	-20	27	-19
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	-169	18	-161	-21
Total other comprehensive income (loss)	-151	40	-128	-49
Total comprehensive income	-658	-507	-1,640	-603
Comprehensive (Income) Loss, Net of Tax, Attributable to Noncontrolling Interest	0	0	0	0
Total comprehensive income	-658	-507	-1,640	-603
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]
Guarantor Obligations [Line Items]
Net Income (Loss)	551	255	1,988	-61
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	-80	-71	-49	71
Reclassification of change in fair value of derivatives to net income	19	-10	10	5
Foreign currency translation adjustments	33	54	-54	52
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	79	-3	79	10
Total other comprehensive income (loss)	51	-30	-14	138
Total comprehensive income	602	225	1,974	77
Comprehensive (Income) Loss, Net of Tax, Attributable to Noncontrolling Interest	-265	-39	-1,098	77
Total comprehensive income	$337	$186	$876	$154

Guarantee_of_Securities_of_Sub6

Guarantee of Securities of Subsidiaries Cash Flows (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Dec. 31, 2011
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	$2,777	$1,927
Cash Flows From Investing Activities
Payments to Acquire Property, Plant, and Equipment	-2,270	-1,399
Acquisition Of Investments	-292	-72
Repayments from related party	10	48
Payments to Acquire Other Investments	-171	-158
Capital Distributions From Equity Investments	117	159
Payments for (Proceeds from) Other Investing Activities	4	-13
Net Cash Provided by (Used in) Investing Activities	-2,038	-6,365
Cash Flows From Operating Activities
Proceeds from Contributions from Affiliates		0
Payments of Debt Issuance Costs	-23	-104
Payments Of Dividends To Owners	-1,196	-810
Warrants repurchased	-463	-136
Contributions from noncontrolling interests	1,420	1,404
Payments of Ordinary Dividends, Noncontrolling Interest	-1,220	-853
Proceeds from (Payments for) Other Financing Activities	1	-18
Net Cash Provided by (Used in) Financing Activities	-625	4,789
Effect of Exchange Rate on Cash and Cash Equivalents	-12	13
Cash and Cash Equivalents, Period Increase (Decrease)	102	364
Total Cash and Cash Equivalents	816	775	714	411
KMP and EPB [Member]
Cash Flows From Operating Activities
Issuance of debt	7,915	8,483
Payment of debt	-6,666	-5,557
Express Pipeline System [Member]
Cash Flows From Investing Activities
Proceeds from Sale of Investments	402	0
BBPP Holdings Ltda [Member]
Cash Flows From Investing Activities
Proceeds from Sale of Investments	88	0
Parent Company [Member]
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	1,129	725
Cash Flows From Investing Activities
Payments to Acquire Property, Plant, and Equipment	-3	-6
Acquisition Of Investments	0	0
Repayments from related party	0	0
Payments for Advance to Affiliate	-170	-398
Payments to Acquire Other Investments	-6	-15
Capital Distributions From Equity Investments	2	11
Payments for (Proceeds from) Other Investing Activities	0	0
Net Cash Provided by (Used in) Investing Activities	758	-2,204
Cash Flows From Operating Activities
Issuance of debt	1,220	7,182
Payment of debt	-1,930	-4,683
Proceeds from Contributions from Affiliates	584	82
Payments of Debt Issuance Costs	0	-88
Payments Of Dividends To Owners	-1,196	-810
Warrants repurchased	-463	-136
Cash Dividends Paid to Parent Company	0	0
Contributions from noncontrolling interests	0	0
Payments of Ordinary Dividends, Noncontrolling Interest	0	0
Proceeds from (Payments for) Other Financing Activities	1	-15
Net Cash Provided by (Used in) Financing Activities	-1,784	1,532
Effect of Exchange Rate on Cash and Cash Equivalents	0	0
Cash and Cash Equivalents, Period Increase (Decrease)	103	53
Total Cash and Cash Equivalents	106	55	3	2
Parent Company [Member] | KMP and EPB [Member]
Cash Flows From Investing Activities
Payments for (Proceeds from) Businesses and Interest in Affiliates	-59	-69
Parent Company [Member] | Express Pipeline System [Member]
Cash Flows From Investing Activities
Proceeds from Sale of Investments	0
Parent Company [Member] | BBPP Holdings Ltda [Member]
Cash Flows From Investing Activities
Proceeds from Sale of Investments	0
Parent Company [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Cash Flows From Investing Activities
Acquisition Of Investments	994	3,485
Parent Company [Member] | El Paso Corporation [Member]
Cash Flows From Investing Activities
Acquisition Of Investments		-5,212
Guarantor Subsidiaries [Member]
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	0	0
Cash Flows From Investing Activities
Payments to Acquire Property, Plant, and Equipment	0	0
Acquisition Of Investments	0	0
Repayments from related party	0	0
Payments for Advance to Affiliate	0	0
Payments to Acquire Other Investments	0	0
Capital Distributions From Equity Investments	0	0
Payments for (Proceeds from) Other Investing Activities	0	0
Net Cash Provided by (Used in) Investing Activities	0	0
Cash Flows From Operating Activities
Issuance of debt	0	0
Payment of debt	0	0
Proceeds from Contributions from Affiliates	0
Payments of Debt Issuance Costs	0	0
Payments Of Dividends To Owners	0	0
Warrants repurchased	0	0
Cash Dividends Paid to Parent Company	0	0
Contributions from noncontrolling interests	0	0
Payments of Ordinary Dividends, Noncontrolling Interest	0	0
Proceeds from (Payments for) Other Financing Activities	0	0
Net Cash Provided by (Used in) Financing Activities	0	0
Effect of Exchange Rate on Cash and Cash Equivalents	0
Cash and Cash Equivalents, Period Increase (Decrease)	0	0
Total Cash and Cash Equivalents	0	0	0	0
Guarantor Subsidiaries [Member] | KMP and EPB [Member]
Cash Flows From Investing Activities
Payments for (Proceeds from) Businesses and Interest in Affiliates	0	0
Guarantor Subsidiaries [Member] | Express Pipeline System [Member]
Cash Flows From Investing Activities
Proceeds from Sale of Investments	0
Guarantor Subsidiaries [Member] | BBPP Holdings Ltda [Member]
Cash Flows From Investing Activities
Proceeds from Sale of Investments	0
Guarantor Subsidiaries [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Cash Flows From Investing Activities
Acquisition Of Investments	0	0
Guarantor Subsidiaries [Member] | El Paso Corporation [Member]
Cash Flows From Investing Activities
Acquisition Of Investments		0
Subsidiary Issuer [Member]
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	113	-429
Cash Flows From Investing Activities
Payments to Acquire Property, Plant, and Equipment	0	0
Acquisition Of Investments	0	0
Repayments from related party	0	0
Payments for Advance to Affiliate	-581	-313
Payments to Acquire Other Investments	0	0
Capital Distributions From Equity Investments	70	29
Payments for (Proceeds from) Other Investing Activities	0	0
Net Cash Provided by (Used in) Investing Activities	-514	-291
Cash Flows From Operating Activities
Issuance of debt	133	62
Payment of debt	-50	-176
Proceeds from Contributions from Affiliates	273	905
Payments of Debt Issuance Costs	0	0
Payments Of Dividends To Owners	0	0
Warrants repurchased	0	0
Cash Dividends Paid to Parent Company	0	0
Contributions from noncontrolling interests	0	0
Payments of Ordinary Dividends, Noncontrolling Interest	0	0
Proceeds from (Payments for) Other Financing Activities	0	0
Net Cash Provided by (Used in) Financing Activities	356	791
Effect of Exchange Rate on Cash and Cash Equivalents	0	0
Cash and Cash Equivalents, Period Increase (Decrease)	-45	71
Total Cash and Cash Equivalents	0	71	45	0
Subsidiary Issuer [Member] | KMP and EPB [Member]
Cash Flows From Investing Activities
Payments for (Proceeds from) Businesses and Interest in Affiliates	-3	-7
Subsidiary Issuer [Member] | Express Pipeline System [Member]
Cash Flows From Investing Activities
Proceeds from Sale of Investments	0
Subsidiary Issuer [Member] | BBPP Holdings Ltda [Member]
Cash Flows From Investing Activities
Proceeds from Sale of Investments	0
Subsidiary Issuer [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Cash Flows From Investing Activities
Acquisition Of Investments	0	0
Subsidiary Issuer [Member] | El Paso Corporation [Member]
Cash Flows From Investing Activities
Acquisition Of Investments		0
Non-Guarantor Subsidiaries [Member]
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	3,174	2,761
Cash Flows From Investing Activities
Payments to Acquire Property, Plant, and Equipment	-2,267	-1,393
Acquisition Of Investments	-292	-72
Repayments from related party	10	48
Payments for Advance to Affiliate	-525	-632
Payments to Acquire Other Investments	-171	-143
Capital Distributions From Equity Investments	68	119
Payments for (Proceeds from) Other Investing Activities	78	27
Net Cash Provided by (Used in) Investing Activities	-3,603	-5,289
Cash Flows From Operating Activities
Issuance of debt	8,154	8,483
Payment of debt	-6,671	-5,562
Proceeds from Contributions from Affiliates	419	356
Payments of Debt Issuance Costs	-23	-16
Payments Of Dividends To Owners	0	0
Warrants repurchased	0	0
Cash Dividends Paid to Parent Company	-1,654	-1,080
Contributions from noncontrolling interests	1,474	1,423
Payments of Ordinary Dividends, Noncontrolling Interest	-1,220	-853
Proceeds from (Payments for) Other Financing Activities	6	4
Net Cash Provided by (Used in) Financing Activities	485	2,755
Effect of Exchange Rate on Cash and Cash Equivalents	-12	13
Cash and Cash Equivalents, Period Increase (Decrease)	44	240
Total Cash and Cash Equivalents	710	649	666	409
Non-Guarantor Subsidiaries [Member] | KMP and EPB [Member]
Cash Flows From Investing Activities
Payments for (Proceeds from) Businesses and Interest in Affiliates	0	0
Non-Guarantor Subsidiaries [Member] | Express Pipeline System [Member]
Cash Flows From Investing Activities
Proceeds from Sale of Investments	402
Non-Guarantor Subsidiaries [Member] | BBPP Holdings Ltda [Member]
Cash Flows From Investing Activities
Proceeds from Sale of Investments	88
Non-Guarantor Subsidiaries [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Cash Flows From Investing Activities
Acquisition Of Investments	-994	-3,485
Non-Guarantor Subsidiaries [Member] | El Paso Corporation [Member]
Cash Flows From Investing Activities
Acquisition Of Investments		242
Consolidation, Eliminations [Member]
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	-1,639	-1,130
Cash Flows From Investing Activities
Payments to Acquire Property, Plant, and Equipment	0	0
Acquisition Of Investments	0	0
Repayments from related party	0	0
Payments for Advance to Affiliate	1,276	1,343
Payments to Acquire Other Investments	6	0
Capital Distributions From Equity Investments	-23	0
Payments for (Proceeds from) Other Investing Activities	0	0
Net Cash Provided by (Used in) Investing Activities	1,321	1,419
Cash Flows From Operating Activities
Issuance of debt	0	0
Payment of debt	0	0
Proceeds from Contributions from Affiliates	-1,276	-1,343
Payments of Debt Issuance Costs	0	0
Payments Of Dividends To Owners	0	0
Warrants repurchased	0	0
Cash Dividends Paid to Parent Company	1,654	1,080
Contributions from noncontrolling interests	-54	-19
Payments of Ordinary Dividends, Noncontrolling Interest	0	0
Proceeds from (Payments for) Other Financing Activities	-6	-7
Net Cash Provided by (Used in) Financing Activities	318	-289
Effect of Exchange Rate on Cash and Cash Equivalents	0	0
Cash and Cash Equivalents, Period Increase (Decrease)	0	0
Total Cash and Cash Equivalents	0	0	0	0
Consolidation, Eliminations [Member] | KMP and EPB [Member]
Cash Flows From Investing Activities
Payments for (Proceeds from) Businesses and Interest in Affiliates	62	76
Consolidation, Eliminations [Member] | Express Pipeline System [Member]
Cash Flows From Investing Activities
Proceeds from Sale of Investments	0
Consolidation, Eliminations [Member] | BBPP Holdings Ltda [Member]
Cash Flows From Investing Activities
Proceeds from Sale of Investments	0
Consolidation, Eliminations [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Cash Flows From Investing Activities
Acquisition Of Investments	0	0
Consolidation, Eliminations [Member] | El Paso Corporation [Member]
Cash Flows From Investing Activities
Acquisition Of Investments		0
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	2,777	1,927
Cash Flows From Investing Activities
Payments to Acquire Property, Plant, and Equipment	-2,270	-1,399
Acquisition Of Investments	-292	-72
Repayments from related party	10	48
Payments for Advance to Affiliate	0	0
Payments to Acquire Other Investments	-171	-158
Capital Distributions From Equity Investments	117	159
Payments for (Proceeds from) Other Investing Activities	78	27
Net Cash Provided by (Used in) Investing Activities	-2,038	-6,365
Cash Flows From Operating Activities
Issuance of debt	9,507	15,727
Payment of debt	-8,651	-10,421
Proceeds from Contributions from Affiliates	0	0
Payments of Debt Issuance Costs	-23	-104
Payments Of Dividends To Owners	-1,196	-810
Warrants repurchased	-463	-136
Cash Dividends Paid to Parent Company	0	0
Contributions from noncontrolling interests	1,420	1,404
Payments of Ordinary Dividends, Noncontrolling Interest	-1,220	-853
Proceeds from (Payments for) Other Financing Activities	1	-18
Net Cash Provided by (Used in) Financing Activities	-625	4,789
Effect of Exchange Rate on Cash and Cash Equivalents	-12	13
Cash and Cash Equivalents, Period Increase (Decrease)	102	364
Total Cash and Cash Equivalents	816	775	714	411
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member] | KMP and EPB [Member]
Cash Flows From Investing Activities
Payments for (Proceeds from) Businesses and Interest in Affiliates	0	0
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member] | Express Pipeline System [Member]
Cash Flows From Investing Activities
Proceeds from Sale of Investments	402
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member] | BBPP Holdings Ltda [Member]
Cash Flows From Investing Activities
Proceeds from Sale of Investments	88
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Cash Flows From Investing Activities
Acquisition Of Investments	0	0
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member] | El Paso Corporation [Member]
Cash Flows From Investing Activities
Acquisition Of Investments		($4,970)