Kinder Morgan Energy Partners L P 10-Q 28 Jul 14 2014 Q2 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	6 Months Ended
	Jun. 30, 2014	Jul. 25, 2014	Jun. 28, 2013
Entity Information [Line Items]	'	'	'
Entity Registrant Name	'KINDER MORGAN ENERGY PARTNERS L P	'	'
Entity Central Index Key	'0000888228	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Filer Category	'Large Accelerated Filer	'	'
Entity Public Float	'	'	$18,553,816,889
Entity Common Stock, Shares Outstanding	'	325,113,505	'
Document Fiscal Year Focus	'2014	'	'
Document Fiscal Period Focus	'Q2	'	'
Document Type	'10-Q	'	'
Amendment Flag	'false	'	'
Document Period End Date	30-Jun-14	'	'

CONSOLIDATED_STATEMENTS_OF_INC

CONSOLIDATED STATEMENTS OF INCOME (Unaudited) (USD $)	3 Months Ended		6 Months Ended
In Millions, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues	'	'	'	'
Natural gas sales	$1,012	$942	$2,108	$1,677
Services	1,467	1,252	2,925	2,483
Product sales and other	1,098	823	2,196	1,518
Total Revenues	3,577	3,017	7,229	5,678
Operating Costs, Expenses and Other	'	'	'	'
Cost of Sales	1,602	1,248	3,240	2,205
Operations and maintenance	492	597	942	981
Depreciation, depletion and amortization	406	357	807	685
General and administrative	132	163	285	297
Taxes, other than income taxes	87	75	170	149
Other expenses (income), net	3	-24	-3	-24
Total Operating Costs, Expenses and Other	2,722	2,416	5,441	4,293
Operating Income	855	601	1,788	1,385
Other Income (Expense)	'	'	'	'
Earnings from equity investments	65	74	137	157
Amortization of excess cost of equity investments	-5	-2	-8	-4
Interest, net	-231	-214	-469	-413
Gain on remeasurement of previously held equity interest in Eagle Ford Gathering to fair value (Note 2)	0	558	0	558
Gain on sale of investments in Express pipeline system (Note 2)	0	0	0	225
Other, net	9	19	15	23
Total Other Income (Expense)	-162	435	-325	546
Income from Continuing Operations Before Income Taxes	693	1,036	1,463	1,931
Income Tax Expense	-24	-26	-40	-127
Income from Continuing Operations	669	1,010	1,423	1,804
Loss from Discontinued Operations	0	0	0	-2
Net Income	669	1,010	1,423	1,802
Net Income Attributable to Noncontrolling Interests	-8	-10	-16	-19
Net Income Attributable to KMEP	661	1,000	1,407	1,783
Calculation of Limited Partners’ Interest in Net Income Attributable to KMEP:	'	'	'	'
Income from Continuing Operations attributable to KMEP	661	1,000	1,407	1,785
Less: Pre-acquisition income from operations of March 2013 drop-down asset group allocated to General Partner (Note 1)	0	0	0	-19
Add: Drop-down asset group's severance expense allocated to General Partner (Note 1)	1	4	6	6
Less: General Partner’s remaining interest	-465	-422	-917	-824
Limited Partners’ Interest	197	582	496	948
Add: Limited Partners’ Interest in Discontinued Operations	0	0	0	-2
Limited Partners’ Interest in Net Income	$197	$582	$496	$946
Limited Partners’ Net Income per Unit:	'	'	'	'
Income from Continuing Operations	$0.43	$1.41	$1.09	$2.40
Loss from Discontinued Operations	$0	$0	$0	($0.01)
Net Income	$0.43	$1.41	$1.09	$2.39
Weighted Average Number of Units Used in Computation of Limited Partners' Net Income per Unit	457	413	453	395
Per Unit Cash Distribution Declared for the Period	$1.39	$1.32	$2.77	$2.62

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Net Income	$669	$1,010	$1,423	$1,802
Change in fair value of derivatives utilized for hedging purposes	-113	70	-169	29
Reclassification of change in fair value of derivatives to net income	18	-3	36	-10
Foreign currency translation adjustments	71	-71	-8	-114
Adjustments to pension and other postretirement benefit plan liabilities	-1	0	-3	1
Total Other Comprehensive (Loss)	-25	-4	-144	-94
Comprehensive Income	644	1,006	1,279	1,708
Comprehensive Income Attributable to Noncontrolling Interests	-8	-10	-15	-18
Comprehensive Income Attributable to KMEP	$636	$996	$1,264	$1,690

CONSOLIDATED_BALANCE_SHEETS_Un

CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Current assets	'	'
Cash and cash equivalents	$263	$404
Accounts receivable, net	1,445	1,511
Inventories	424	393
Other current assets	388	360
Total current assets	2,520	2,668
Property, plant and equipment, net	29,285	27,405
Investments	2,193	2,233
Goodwill	6,721	6,547
Other intangibles, net	2,345	2,414
Deferred charges and other assets	1,487	1,497
Total Assets	44,551	42,764
Current liabilities	'	'
Current portion of debt	1,337	1,504
Accounts payable	1,397	1,537
Accrued interest	396	371
Accrued contingencies	600	529
Other current liabilities	808	636
Total current liabilities	4,538	4,577
Long-term debt	'	'
Outstanding	19,610	18,410
Debt fair value adjustments	1,267	1,214
Total long-term debt	20,877	19,624
Deferred income taxes	297	285
Other long-term liabilities and deferred credits	1,054	1,057
Total long-term liabilities and deferred credits	22,228	20,966
Total Liabilities	26,766	25,543
Partners’ Capital	'	'
General partner	3,092	3,081
Accumulated other comprehensive (loss) income	-110	33
Total KMEP Partners’ Capital	17,317	16,801
Noncontrolling interests	468	420
Total Partners’ Capital	17,785	17,221
Total Liabilities and Partners’ Capital	44,551	42,764
Common units	'	'
Partners’ Capital	'	'
Limited Partners' units	9,878	9,459
Class B units	'	'
Partners’ Capital	'	'
Limited Partners' units	-2	6
i-units	'	'
Partners’ Capital	'	'
Limited Partners' units	$4,459	$4,222

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Cash Flows From Operating Activities	'	'
Net Income	$1,423	$1,802
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	807	685
Amortization of excess cost of equity investments	8	4
Gain on remeasurement of previously held equity interest in Eagle Ford Gathering to fair value (Note 2)	0	-558
Gain on sale of investments in Express pipeline system (Note 2)	0	-225
Earnings from equity investments	137	157
Distributions from equity investment earnings	124	152
Proceeds from termination of interest swap agreements	0	96
Changes in components of working capital, net of the effects of acquisitions:	'	'
Accounts receivable	36	-26
Inventories	-25	-50
Other current assets	-35	-35
Accounts payable	-53	-151
Accrued interest	25	12
Accrued contingencies and other current liabilities	116	-7
Rate reparations, refunds and other litigation reserve adjustments, net	36	177
Other, net	-76	23
Net Cash Provided by Operating Activities	2,249	1,742
Cash Flows From Investing Activities	'	'
Payment to KMI for March 2013 drop-down asset group (Note 1)	0	-994
Acquisitions of assets and investments, net of cash acquired	-993	-286
Capital expenditures	-1,658	-1,268
Proceeds from sale of investments in Express pipeline system	0	403
Contributions to investments	-89	-93
Distributions from equity investments in excess of cumulative earnings	37	36
Natural gas storage and natural gas and liquids line-fill	22	0
Sale or casualty of property, plant and equipment, investments and other net assets, net of removal costs	11	23
Other, net	-5	5
Net Cash Used in Investing Activities	-2,675	-2,174
Cash Flows From Financing Activities	'	'
Issuance of debt	6,083	4,858
Payment of debt	-5,060	-3,860
Debt issue costs	-11	-11
Proceeds from issuance of common units	938	834
Proceeds from issuance of i-units	97	73
Contributions from noncontrolling interests	57	99
Contributions from General Partner	0	38
Pre-acquisition contributions from KMI to March 2013 drop-down asset group	0	35
Distributions to partners and noncontrolling interests	-1,813	-1,487
Other, net	-2	0
Net Cash Provided by Financing Activities	289	579
Effect of Exchange Rate Changes on Cash and Cash Equivalents	-4	-20
Net (decrease) increase in Cash and Cash Equivalents	-141	127
Cash and Cash Equivalents, beginning of period	404	529
Cash and Cash Equivalents, end of period	263	656
Noncash Investing and Financing Activities	'	'
Assets acquired or liabilities settled by the issuance of common units (Note 1)	0	3,841
Assets acquired by the assumption or incurrence of liabilities	73	1,490
Supplemental Disclosures of Cash Flow Information	'	'
Cash paid during the period for interest (net of capitalized interest)	451	411
Cash paid during the period for income taxes	$17	$14

CONSOLIDATED_STATEMENTS_OF_PAR

CONSOLIDATED STATEMENTS OF PARTNERS' CAPITAL Statement (USD $)	Total	Accumulated other comprehensive income (loss)	Noncontrolling interests	Common units	Class B units	i-units	General partner
In Millions, except Share data, unless otherwise specified
Beginning Balance at Dec. 31, 2012	$168	$168	'	'	'	'	'
Beginning Balance, Amount at Dec. 31, 2012	'	'	267	4,723	14	3,564	4,026
Beginning Balance, Units at Dec. 31, 2012	'	'	'	252,756,425	5,313,400	115,118,338	'
Net income, Amount	1,783	'	'	659	13	274	837
Net Income, Noncontrolling interests	19	'	19	'	'	'	'
Units issued as consideration in the acquisition of assets, Units	'	'	'	44,620,662	'	'	'
Units issued as consideration in the acquisition of assets, Amount	'	'	'	3,841	'	'	'
Units issued for cash, Units	'	'	'	9,863,329	'	860,600	'
Units issued for cash, Amount	'	'	'	834	'	73	'
Contributions, Noncontrolling interests	99	'	99	'	'	'	'
Distribution, Units	'	'	'	'	'	3,531,548	'
Distributions, Amount	-1,487	'	'	-662	-14	0	-792
Distributions, Noncontrolling interests	'	'	-19	'	'	'	'
Drop-Down acquisition (Note 1)	'	'	'	'	'	'	-1,057
Drop-Down acquisition (Note 1), Noncontrolling interests	'	'	-10	'	'	'	'
Reimbursed severance expense allocated from KMI	'	'	'	'	'	'	5
Contributions from general partner	'	'	'	'	'	'	38
Accumulated other comprehensive income (loss):	'	'	'	'	'	'	'
Other comprehensive Ioss	'	-93	-1	'	'	'	'
Other adjustments	'	'	'	'	'	'	2
Total Partners' Capital, Amount at Jun. 30, 2013	16,808	'	'	'	'	'	'
Ending Balance, Amount at Jun. 30, 2013	16,453	'	355	9,395	13	3,911	3,059
Ending Balance at Jun. 30, 2013	75	75	'	'	'	'	'
Ending Balance, Units at Jun. 30, 2013	432,064,302	'	'	307,240,416	5,313,400	119,510,486	'
Total Partners' Capital, Units at Jun. 30, 2013	432,064,302	'	'	'	'	'	'
Beginning Balance at Dec. 31, 2013	33	33	'	'	'	'	'
Beginning Balance, Amount at Dec. 31, 2013	16,801	'	420	9,459	6	4,222	3,081
Beginning Balance, Units at Dec. 31, 2013	'	'	'	312,791,561	5,313,400	125,323,734	'
Net income, Amount	1,407	'	'	350	6	140	911
Net Income, Noncontrolling interests	16	'	16	'	'	'	'
Units issued as consideration in the acquisition of assets, Units	'	'	'	0	'	'	'
Units issued as consideration in the acquisition of assets, Amount	'	'	'	0	'	'	'
Units issued for cash, Units	'	'	'	12,321,944	'	1,333,960	'
Units issued for cash, Amount	'	'	'	938	'	97	'
Contributions, Noncontrolling interests	57	'	57	'	'	'	'
Distribution, Units	'	'	'	'	'	4,624,072	'
Distributions, Amount	-1,813	'	'	-869	-14	0	-906
Distributions, Noncontrolling interests	'	'	-24	'	'	'	'
Drop-Down acquisition (Note 1)	'	'	'	'	'	'	0
Drop-Down acquisition (Note 1), Noncontrolling interests	'	'	0	'	'	'	'
Reimbursed severance expense allocated from KMI	'	'	'	'	'	'	6
Contributions from general partner	'	'	'	'	'	'	0
Accumulated other comprehensive income (loss):	'	'	'	'	'	'	'
Other comprehensive Ioss	'	-143	-1	'	'	'	'
Other adjustments	'	'	'	'	'	'	0
Total Partners' Capital, Amount at Jun. 30, 2014	17,785	'	'	'	'	'	'
Ending Balance, Amount at Jun. 30, 2014	17,317	'	468	9,878	-2	4,459	3,092
Ending Balance at Jun. 30, 2014	($110)	($110)	'	'	'	'	'
Ending Balance, Units at Jun. 30, 2014	461,708,671	'	'	325,113,505	5,313,400	131,281,766	'
Total Partners' Capital, Units at Jun. 30, 2014	461,708,671	'	'	'	'	'	'

General

General	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
General	'
	General
	Organization
	KMEP is a Delaware limited partnership formed in August 1992.  We are a leading pipeline transportation and energy storage company in North America, with a diversified portfolio of energy transportation and storage assets. We own an interest in or operate approximately 52,000 miles of pipelines and 180 terminals, and we conduct our business through five reportable business segments (described further in Note 7). Our common units trade on the NYSE under the symbol “KMP.”
	Our pipelines transport natural gas, refined petroleum products, crude oil, condensate, CO2 and other products, and our terminals transport, transload and store petroleum products, ethanol and chemicals, and handle such products as coal, petroleum coke and steel. We are also the leading producer and transporter of CO2, for enhanced oil recovery projects in North America.
	KMI and Kinder Morgan G.P., Inc.
	KMI, a Delaware corporation, indirectly owns all the common stock of our general partner, Kinder Morgan G.P., Inc., a Delaware corporation. In July 2007, our general partner issued and sold to a third party 100,000 shares of Series A fixed-to-floating rate term cumulative preferred stock due 2057. The consent of holders of a majority of these preferred shares is required with respect to a commencement of or a filing of a voluntary bankruptcy proceeding with respect to us or two of our subsidiaries, SFPP and Calnev. KMI’s common stock trades on the NYSE under the symbol “KMI.”
	As of June 30, 2014, KMI and its consolidated subsidiaries owned, through KMI’s general and limited partner interests in us and its ownership of shares issued by its subsidiary KMR (discussed below), an approximate 11.4% interest in us. In addition, as of June 30, 2014, KMI owns a 39.6% limited partner interest and the 2% general partner interest in EPB.
	KMR
	KMR is a Delaware LLC. Our general partner owns all of KMR’s voting securities and, pursuant to a delegation of control agreement, has delegated to KMR, to the fullest extent permitted under Delaware law and our partnership agreement, all of its power and authority to manage and control our business and affairs, except that KMR cannot take certain specified actions without the approval of our general partner. Generally, KMR makes all decisions relating to the management and control of our business, and in general, KMR has a duty to manage us in a manner beneficial to KMEP. KMR’s shares representing LLC interests trade on the NYSE under the symbol “KMR.” As of June 30, 2014, KMR, through its sole ownership of our i-units, owned approximately 28.4% of all of our outstanding limited partner units (which are in the form of i-units that are issued only to KMR).
	More information about the entities referred to above and the delegation of control agreement is contained in our 2013 Form 10-K. For a more complete discussion of our related party transactions with the entities referred to above, including (i) the accounting for our general and administrative expenses; (ii) KMI’s operation and maintenance of the assets comprising our Natural Gas Pipelines business segment; and (iii) our partnership interests and distributions, see Note 11 “Related Party Transactions” to our consolidated financial statements included in our 2013 Form 10-K.
	Basis of Presentation
	General
	Our reporting currency is in U.S. dollars, and all references to dollars are U.S. dollars, except where stated otherwise.  Our accompanying unaudited consolidated financial statements include our accounts, majority-owned and controlled subsidiaries, and have been prepared under the rules and regulations of the SEC. These rules and regulations conform to the accounting principles contained in the FASB’s Accounting Standards Codification, the single source of GAAP. Under such rules and regulations, all significant intercompany items have been eliminated in consolidation. Additionally, 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 2013 Form 10-K.
	Our financial statements are consolidated into the consolidated financial statements of KMI; however, except for the related party transactions described in Note 8 “Related Party Transactions—Asset Acquisitions and Sales,” KMI is not liable for, and its assets are not available to satisfy, our obligations and/or our subsidiaries’ obligations, and vice versa.  Responsibility for payments of obligations reflected in our or KMI’s financial statements is a legal determination based on the entity that incurs the liability. Furthermore, the determination of responsibility for payment among entities in our consolidated group of subsidiaries is not impacted by the consolidation of our financial statements into the consolidated financial statements of KMI.
	March 2013 KMI Asset Drop-Down
	Effective March 1, 2013, we acquired from KMI the remaining 50% ownership interest we did not already own in both EPNG and the EP midstream assets for an aggregate consideration of approximately $1.7 billion (including our proportional share of assumed debt borrowings as of March 1, 2013). In this report, we refer to this acquisition of assets from KMI as the March 2013 drop-down transaction; the combined group of assets acquired from KMI effective March 1, 2013 as the March 2013 drop-down asset group; and the EP midstream assets of Kinder Morgan Altamont LLC (formerly, El Paso Midstream Investment Company, L.L.C.) as the EP midstream assets. Prior to the March 2013 drop-down transaction, we accounted for our initial 50% ownership interests in both EPNG and the EP midstream assets under the equity method of accounting.
	KMI acquired all of the assets included in the March 2013 drop-down asset group as part of its May 25, 2012 acquisition of EP, and KMI accounted for its EP acquisition under the acquisition method of accounting. We, however, accounted for the March 2013 drop-down transaction as combinations of entities under common control. Accordingly, we prepared our consolidated financial statements to reflect the transfer of the March 2013 drop-down asset group from KMI to us as if such transfer had taken place on the date when the March 2013 drop-down asset group met the accounting requirements for entities under common control—May 25, 2012 for EPNG, and June 1, 2012 for the EP midstream assets.
	Additionally, because KMI both controls us and consolidates our financial statements into its consolidated financial statements as a result of its ownership of our general partner, we fully allocated to our general partner:
	▪	the earnings of the March 2013 drop-down asset group for the periods beginning on the effective dates of common control (described above) and ending March 1, 2013 (we refer to these earnings as “pre-acquisition” earnings and we reported these earnings separately as “Pre-acquisition income from operations of March 2013 drop-down asset group allocated to General Partner” within the “Calculation of Limited Partners’ Interest in Net Income Attributable to KMEP” section of our accompanying consolidated statement of income for the six months ended June 30, 2013); and
	▪	incremental severance expense related to KMI’s acquisition of EP and allocated to us from KMI. This severance expense allocated to us was associated with both the March 2013 drop-down asset group and assets we acquired pursuant to an earlier drop-down from KMI effective August 1, 2012; however, we do not have any obligation, nor did we pay any amounts related to this expense. Furthermore, we reported this expense separately as “Drop-down asset group’s severance expense allocated to General Partner” within the “Calculation of Limited Partners’ Interest in Net Income Attributable to KMEP” section of our accompanying consolidated statements of income for each of the three and six months ended June 30, 2014 and 2013.
	For all periods beginning after our acquisition date of March 1, 2013, we allocated our earnings (including the earnings from the March 2013 drop-down asset group) to all of our partners according to our partnership agreement.
	Goodwill
	We evaluate goodwill for impairment on May 31 of each year.  There were no impairment charges resulting from our May 31, 2014 impairment testing, and no event indicating an impairment has occurred subsequent to that date.
	Limited Partners’ Net Income per Unit
	We compute Limited Partners’ Net Income per Unit by dividing our limited partners’ interest in net income by the weighted average number of units outstanding during the period.

Acquisitions_and_Divestitures

Acquisitions and Divestitures	6 Months Ended
	Jun. 30, 2014
Business Acquisition [Line Items]	'
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	'
	Acquisitions and Divestitures
	Acquisitions
	American Petroleum Tankers and State Class Tankers
	Effective January 17, 2014, we acquired APT and State Class Tankers (SCT) for aggregate consideration of $961 million in cash (the APT acquisition). APT is engaged in the marine transportation of crude oil, condensate and refined products in the U.S. domestic trade, commonly referred to as the Jones Act trade. APT’s primary assets consist of a fleet of five medium range Jones Act qualified product tankers, each with 330 MBbl of cargo capacity, and each operating pursuant to long-term time charters with high quality counterparties, including major integrated oil companies, major refiners and the U.S. Military Sealift Command. As of the closing date, the vessels’ time charters had an average remaining term of approximately four years, with renewal options to extend the terms by an average of two years. APT’s vessels are operated by Crowley Maritime Corporation.
	SCT has commissioned the construction of four medium range Jones Act qualified product tankers, each with 330 MBbl of cargo capacity. The SCT vessels are scheduled to be delivered in 2015 and 2016 and are being constructed by General Dynamics’ NASSCO shipyard. We expect to invest approximately $214 million to complete the construction of these four SCT vessels, and upon delivery, the vessels will be operated pursuant to long-term time charters with a major integrated oil company. Each of the time charters has an initial term of five years, with renewal options to extend the term by up to three years. Our APT acquisition complements and extends our existing crude oil and refined products transportation business, and all of the acquired assets are included in our Terminals business segment.
	As of June 30, 2014, our preliminary purchase price allocation related to our APT acquisition, as adjusted to date, is as follows (in millions). Our evaluation of the assigned fair values is ongoing and subject to adjustment.
	Purchase Price Allocation:
	Current assets	$	6
	Property, plant and equipment	951
	Goodwill	67
	Other assets	3
	Total assets acquired	1,027
	Current liabilities	(5		)
	Unfavorable customer contracts	(61		)
	Cash consideration	$	961
	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. We believe the goodwill was primarily generated by the value of the synergies created by expanding our non-pipeline liquids handling operations. Furthermore, we expect to fully deduct for tax purposes the entire amount of goodwill we recognized. The “Unfavorable customer contracts” figure represents the amount, on a present value basis, by which the customer contracts were below market day rates at the time of acquisition. This amount is amortized as a noncash adjustment to revenue over the remaining contract period.
	Other
	Effective May 1, 2013, we acquired all of Copano’s outstanding units for a total purchase price of approximately $5.2 billion (including assumed debt and all other assumed liabilities). The transaction was a 100% unit for unit transaction with an exchange ratio of 0.4563 of our common units for each Copano common unit. We issued 43,371,210 of our common units valued at $3,733 million as consideration for the Copano acquisition (based on the $86.08 closing market price of a common unit on the NYSE on the May 1, 2013 issuance date). Also, due to the fact that our Copano acquisition included the remaining 50% interest in Eagle Ford Gathering LLC that we did not already own, we remeasured our existing 50% equity investment in Eagle Ford to its fair value as of the acquisition date. As a result of our remeasurement, we recognized a $558 million non-cash gain, which represented the excess of the investment’s fair value ($704 million) over our carrying value as of May 1, 2013 ($146 million), and we reported this gain separately as “Gain on remeasurement of previously held equity interest in Eagle Ford Gathering to fair value” on our accompanying consolidated statements of income for the three and six months ended June 30, 2013.
	As of June 30, 2014, our purchase price allocation related to the Copano acquisition, is as follows (in millions):
	Purchase Price Allocation:
	Current assets (including cash acquired of $30)	$	218
	Property, plant and equipment	2,788
	Investments	300
	Goodwill	1,248
	Other intangibles	1,375
	Other assets	13
	Total assets	5,942
	Less: Fair value of previously held 50% interest in Eagle Ford Gathering LLC	(704		)
	Total assets acquired	5,238
	Current liabilities	(208		)
	Other liabilities	(28		)
	Long-term debt	(1,252		)
	Noncontrolling interests	(17		)
	Common unit consideration	$	3,733
	The table above reflects changes we made in the first six months of 2014 to our preliminary purchase price allocation as of December 31, 2013. Based on our final measurement of fair values for all of the identifiable tangible and intangible assets acquired and liabilities assumed on the acquisition date, we reduced the preliminary value assigned to (i) “Investments” by $87 million; (ii) “Property, plant and equipment” by $17 million; and (ii) combined working capital items by $3 million.
	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. We believe the primary items that generated the goodwill are the value of the synergies created by expanding our natural gas gathering and refined product transportation operations. This goodwill is not deductible for tax purposes, but 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. We are currently amortizing these intangible assets over an estimated remaining useful life of 25 years.
	Effective June 1, 2013, we acquired certain oil and gas properties, rights, and related assets located in the Goldsmith Landreth San Andres oil field unit in the Permian Basin of West Texas from Legado Resources LLC for an aggregate consideration of $298 million, consisting of $280 million in cash and assumed liabilities of $18 million (including $12 million of long-term asset retirement obligations).
	For additional information about our Copano and Goldsmith Landreth acquisitions (including our preliminary purchase price allocations as of December 31, 2013), see Note 3 “Acquisitions and Divestitures—Business Combinations and Acquisitions of Investments” to our consolidated financial statements included in our 2013 Form 10-K.
	Pro Forma Information
	The following summarized unaudited pro forma consolidated income statement information for the six months ended June 30, 2013 assumes that our acquisitions of (i) APT, (ii) Copano and (iii) the Goldsmith Landreth oil field unit had occurred as of January 1, 2013. We prepared the following summarized unaudited pro forma financial results for comparative purposes only. The summarized unaudited pro forma financial results may not be indicative of the results that would have occurred if we had completed these acquisitions as of January 1, 2013, or the results that will be attained in the future. Amounts presented below are in millions, except for the per unit amounts:
		Pro Forma
		Six Months Ended
		30-Jun-13
		(Unaudited)
	Revenues	$	6,432
	Income from Continuing Operations	1,766
	Loss from Discontinued Operations	(2		)
	Net Income	1,764
	Net Income Attributable to Noncontrolling Interests	(19		)
	Net Income Attributable to KMEP	$	1,745
	Limited Partners’ Net Income per Unit:
	Income from Continuing Operations	$	2.12
	Net Income	$	2.12
	Divestitures
	Express Pipeline System
	Effective March 14, 2013, we sold both our one-third equity ownership interest in the Express pipeline system and our subordinated debenture investment in Express to Spectra Energy Corp. We received net cash proceeds of $402 million (after paying $1 million in the third quarter of 2013 for both a final working capital settlement and certain
	transaction-related selling expenses), and we reported the $403 million proceeds received in the first half of 2013 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 six months ended June 30, 2013. Additionally, we recognized a combined $225 million pre-tax gain with respect to this sale in the first half of 2013, and we reported this gain amount separately as “Gain on sale of investments in Express pipeline system” on our accompanying consolidated statement of income for the six months ended June 30, 2013. We also recorded an income tax expense of $84 million related to this gain on sale for the six months ended June 30, 2013, and we included this expense within “Income Tax Expense.” As of the date of sale, our equity investment in Express totaled $67 million and our note receivable due from Express totaled $110 million.

Debt

Debt	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Debt	'
	Debt
	We classify our debt based on the contractual maturity dates of the underlying debt instruments. We defer costs associated with debt issuance over the applicable term. These costs are then amortized as interest expense in our accompanying consolidated statements of income using the effective interest rate method. The following table provides detail on the principal amount of our outstanding debt as of June 30, 2014 and December 31, 2013. The table amounts exclude all debt fair value adjustments, including debt discounts and premiums (in millions).
		June 30,			December 31,
		2014			2013
	KMEP borrowings:
	Senior notes, 2.65% through 9.00%, due 2014 through 2044(a)	$	17,100		$	15,600
	Commercial paper borrowings(b)	513			979
	Credit facility due May 1, 2018(c)	—			—
	Subsidiary borrowings (as obligor):
	TGP - Senior Notes, 7.00% through 8.375%, due 2016 through 2037	1,790			1,790
	EPNG - Senior Notes, 5.95% through 8.625%, due 2017 through 2032	1,115			1,115
	Copano - Senior Notes, 7.125%, due April 1, 2021	332			332
	Other miscellaneous subsidiary debt	97			98
	Total debt	20,947			19,914
	Less: Current portion of debt(d)	(1,337		)	(1,504		)
	Total long-term debt(e)	$	19,610		$	18,410
	__________
	(a)	All of our fixed rate senior notes provide that we may redeem the notes at any time at a price equal to 100% of the principal amount of the notes plus accrued interest to the redemption date plus a make-whole premium.
	(b)	As of both June 30, 2014 and December 31, 2013, the average interest rate on our outstanding commercial paper borrowings was 0.28%. The borrowings under our commercial paper program were used principally to finance the acquisitions and capital expansions, and in the near term, we expect that our short-term liquidity and financing needs will be met primarily through borrowings made under our commercial paper program.
	(c)	See “—Credit Facilities” below.
	(d)	Amounts include outstanding commercial paper borrowings, discussed above in footnote (b).
	(e)	As of June 30, 2014 and December 31, 2013, our “Debt fair value adjustments” increased our debt balances by $1,267 million and $1,214 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—Debt Fair Value Adjustments.”
	Credit Facilities
	As of both June 30, 2014 and December 31, 2013, we had no borrowings under our $2.7 billion five-year senior unsecured revolving credit facility maturing May 1, 2018. Borrowings under our revolving credit facility can be used for general partnership purposes and as a backup for our commercial paper program. Similarly, borrowings under our commercial paper program reduce the borrowings allowed under our credit facility.
	We had, as of June 30, 2014, $1,807 million of borrowing capacity available under our credit facility. The amount available for borrowing under our credit facility was reduced by a combined amount of $893 million, consisting of (i) $513 million of commercial paper borrowings; (ii) $205 million of letters of credit; and (iii) $175 million related to a capital contribution commitment to one of our unconsolidated subsidiaries. For more information, see Note 8 “Related Party Transactions.”
	Changes in Debt
	On January 15, 2014, in anticipation of our APT acquisition, we entered into a short-term unsecured liquidity facility with us as borrower, and UBS as administrative agent. This liquidity facility provided for borrowings of up to $1.0 billion from a syndicate of financial institutions and was scheduled to mature on July 15, 2014. Additionally, in conjunction with the establishment of this liquidity facility, we increased our commercial paper program to provide for the issuance of up to $3.7 billion (up from $2.7 billion). We made no borrowings under this liquidity facility, and after receiving the cash proceeds from both our February 2014 public offering of senior notes (described following) and our February 2014 public offering of common units (described in Note 4 “Partners’ Capital—Equity Issuances”), we terminated the liquidity facility and decreased our commercial paper program to again provide for the issuance of up to $2.7 billion.
	On February 24, 2014, we completed a public offering of a total $1.5 billion in principal amount of senior notes in two separate series. We received net proceeds of $743 million from the offering of $750 million in principal amount of 3.50% senior notes due March 1, 2021, and $739 million from the offering of $750 million in principal amount of 5.50% senior notes due March 1, 2044. We used the proceeds from our February 2014 debt offering to reduce the borrowings under our commercial paper program (reducing the incremental commercial paper borrowings we made in January 2014 to fund our APT acquisition).

Partners_Capital

Partners Capital	6 Months Ended
	Jun. 30, 2014
Partners' Capital [Abstract]	'
Partners’ Capital	'
	Partners’ Capital
	Equity Issuances
	For the six month period ended June 30, 2014, our equity issuances, which were used to reduce borrowings under our commercial paper program, consisted of the following:
	•	on February 24, 2014, we issued, in a public offering, 7,935,000 of our common units at a price of $78.32 per unit, resulting in net proceeds of $603 million;
	•	during the six months ended June 30, 2014, we issued 4,386,944 of our common units pursuant to our equity distribution agreements with UBS (including 198,110 common units to settle sales made on or before December 31, 2013), resulting in net proceeds of $335 million; and
	•	during the six months ended June 30, 2014, we issued 1,333,960 i-units to KMR (including 76,100
	i-units to settle sales made on or before December 31, 2013), resulting in net proceeds of $97 million.
	Income Allocations
	For the purposes of maintaining partner capital accounts, our partnership agreement specifies that items of income and loss shall be allocated among the partners, other than owners of i-units, in accordance with their percentage interests.  Normal allocations according to percentage interests are made, however, only after giving effect to any priority income allocations in an amount equal to the incentive distributions that are allocated 100% to our general partner. Incentive distributions are generally defined as all cash distributions paid to our general partner that are in excess of 2% of the aggregate value of cash and i-units being distributed, and we determine the allocation of incentive distributions to our general partner by the amount quarterly distributions to unitholders exceed certain specified target levels, according to the provisions of our partnership agreement.
	Partnership Distributions
	The following table provides information about our distributions for the three and six month periods ended June 30, 2014 and 2013 (in millions except per unit and i-unit distributions amounts):
		Three Months Ended June 30,				Six Months Ended June 30,
		2014		2013		2014		2013
	Per unit cash distribution declared for the period	$	1.39	$	1.32	$	2.77	$	2.62
	Per unit cash distribution paid in the period	$	1.38	$	1.3	$	2.74	$	2.59
	Cash distributions paid in the period to all partners(a)(b)	$	918	$	757	$	1,813	$	1,487
	i-unit distributions made in the period to KMR(c)	2,386,814		1,726,952		4,624,072		3,531,548
	General Partner’s incentive distribution(d):
	Declared for the period(e)	$	463	$	416	$	912	$	814
	Paid in the period(b)(c)(f)	$	449	$	398	$	894	$	782
	______________
	(a)	Consisting of our common and Class B unitholders, our general partner and noncontrolling interests.
	(b)	The period-to-period increases in distributions paid primarily reflect the increases in amounts distributed per unit as well as the issuance of additional units.
	(c)	Under the terms of our partnership agreement, we agreed that we will not, except in liquidation, make a distribution on an i-unit other than in additional i-units or a security that has in all material respects the same rights and privileges as our i-units.  The number of i-units we distribute to KMR is based upon the amount of cash we distribute to the owners of our common units. When cash is paid to the holders of our common units, we will issue additional i-units to KMR.  The fraction of an i-unit paid per i-unit owned by KMR will have a value based on the cash payment on the common units.  If additional units are distributed to the holders of our common units, we will issue an equivalent amount of i-units to KMR based on the number of i-units it owns. Based on the preceding, the i-units we distributed were based on the $1.38 and $1.30 per unit paid to our common unitholders during the second quarters of 2014 and 2013, respectively, and the $2.74 and $2.59 per unit paid to our common unitholders during the first six months of 2014 and 2013, respectively.
	(d)	Incentive distribution does not include the general partner’s initial 2% distribution of available cash.
	(e)	Amounts are net of waived incentive distributions of $33 million and $25 million for the three months ended June 30, 2014 and 2013, respectively, and $66 million and $29 million for the six months ended June 30, 2014 and 2013, respectively, related to certain acquisitions. In addition, our general partner agreed to waive a portion of our future incentive distributions amounts equal to $33 million and $34 million for our third and fourth quarters in 2014, respectively, $139 million for 2015, $116 million for 2016, $105 million for 2017, and annual amounts thereafter decreasing by $5 million per year from the 2017 level related to certain acquisitions.
	(f)	Amounts are net of waived incentive distributions of $33 million and $4 million for the three months ended June 30, 2014 and 2013, respectively, and $58 million and $11 million for the six months ended June 30, 2014 and 2013, respectively, related to certain acquisitions.
	For additional information about our partnership distributions, see Note 11 “Related Party Transactions—Partnership Interests and Distributions” to our consolidated financial statements included in our 2013 Form 10-K.
	Subsequent Events
	On July 16, 2014, we declared a cash distribution of $1.39 per unit for the quarterly period ended June 30, 2014.  The distribution will be paid on August 14, 2014 to unitholders of record as of July 31, 2014. KMR will receive a distribution of additional i-units based on the $1.39 distribution per common unit. For each outstanding i-unit that KMR holds, a fraction of an i-unit will be issued. This fraction will be determined by dividing:
	•	$1.39, the cash amount distributed per common unit
	by
	•	the average of KMR’s shares’ closing market prices from July 15-28, 2014, the ten consecutive trading days preceding the date on which the shares began to trade ex-dividend under the rules of the NYSE.

Risk_Management

Risk Management	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Risk Management	'
	Risk Management
	Certain of our business activities expose us to risks associated with unfavorable changes in the market price of natural gas, NGL and crude oil. We also have exposure to interest rate risk as a result of the issuance of our debt obligations. Pursuant to our management’s approved risk management policy, we use derivative contracts to hedge or reduce our exposure to certain of these risks.
	Energy Commodity Price Risk Management
	As of June 30, 2014, we had the following outstanding commodity forward contracts to hedge our forecasted energy commodity purchases and sales:
		Net open position long/(short)
	Derivatives designated as hedging contracts
	Crude oil fixed price	-24.2		MMBbl
	Natural gas fixed price	-26.1		Bcf
	Natural gas basis	-26.7		Bcf
	Derivatives not designated as hedging contracts
	Crude oil fixed price	-0.4		MMBbl
	Crude oil basis	-0.6		MMBbl
	Natural gas fixed price	-7.7		Bcf
	Natural gas basis	-0.1		Bcf
	NGL fixed price	-0.8		MMBbl
	As of June 30, 2014, 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 2018.
	Interest Rate Risk Management
	As of June 30, 2014, we had a combined notional principal amount of $5,175 million of fixed-to-variable interest rate swap agreements, effectively converting the interest expense associated with certain series of our senior notes from fixed rates to variable rates based on an interest rate of LIBOR plus a spread. All of our swap agreements have termination dates that correspond to the maturity dates of the related series of senior notes and, as of June 30, 2014, the maximum length of time over which we have hedged a portion of our exposure to the variability in the value of this debt due to interest rate risk is through March 15, 2035.
	As of December 31, 2013, we had a combined notional principal amount of $4,675 million of fixed-to-variable interest rate swap agreements. In February 2014, we entered into four separate fixed-to-variable interest rate swap agreements having a combined notional principal amount of $500 million. These agreements effectively convert a portion of the interest expense associated with our 3.50% senior notes due March 1, 2021, from a fixed rate to a variable rate based on an interest rate of LIBOR plus a spread.
	Fair Value of Derivative Contracts
	The following table summarizes the fair values of our derivative contracts included on our accompanying consolidated balance sheets as of June 30, 2014 and December 31, 2013 (in millions):
	Fair Value of Derivative Contracts
				Asset derivatives								Liability derivatives
				June 30,				December 31,				June 30,				December 31,
				2014				2013				2014				2013
		Balance sheet location		Fair value				Fair value				Fair value				Fair value
	Derivatives designated as hedging contracts
	Energy commodity derivative contracts	Other current assets/(Other current liabilities)		$	6			$	18			$	(97	)		$	(33	)
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		4				58				(72		)		(30		)
	Subtotal			10				76				(169		)		(63		)
	Interest rate swap agreements	Other current assets/(Other current liabilities)		79				76				—				—
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		192				141				(46		)		(116		)
	Subtotal			271				217				(46		)		(116		)
	Total			281				293				(215		)		(179		)
	Derivatives not designated as hedging contracts
	Energy commodity derivative contracts	Other current assets/(Other current liabilities)		4				4				(10		)		(5		)
	Total			4				4				(10		)		(5		)
	Total derivatives			$	285			$	297			$	(225	)		$	(184	)
	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 June 30, 2014 and December 31, 2013, these fair value adjustments to our debt balances included (i) $613 million and $645 million, respectively, associated with fair value adjustments to our debt previously recorded in purchase accounting; (ii) $225 million and $101 million, respectively, associated with the offsetting entry for hedged debt; (iii) $486 million and $517 million, respectively, associated with unamortized premium from the termination of interest rate swap agreements; and offset by (iv) $57 million and $49 million, respectively, associated with unamortized debt discount amounts. As of June 30, 2014, the weighted-average amortization period of the unamortized premium from the termination of the interest rate swaps was approximately 16 years.
	Effect of Derivative Contracts on the Income Statement
	The following three tables summarize the impact of our derivative contracts on our accompanying consolidated statements of income for each of the three and six months ended June 30, 2014 and 2013 (in millions):
	Derivatives in fair value hedging		Location of gain/(loss) recognized		Amount of gain/(loss) recognized in income
	relationships		in income on derivatives		on derivatives and related hedged item(a)
					Three Months Ended June 30,								Six Months Ended June 30,
					2014				2013				2014				2013
	Interest rate swap agreements		Interest expense		$	63			$	(211	)		$	124			$	(294	)
	Total				$	63			$	(211	)		$	124			$	(294	)
	Fixed rate debt		Interest expense		$	(63	)		$	211			$	(124	)		$	294
	Total				$	(63	)		$	211			$	(124	)		$	294
	______________
	(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 in		Amount of gain/(loss)								Location of		Amount of gain/(loss)							Location of	Amount of gain/(loss)
	cash flow hedging		recognized in other								gain/(loss)		reclassified from							gain/(loss)	recognized in income
	relationships		comprehensive income on								reclassified from		Accumulated other							recognized in	on derivative
			derivative (effective								Accumulated		comprehensive income							income on	(ineffective portion
			portion)(a)								other		into income							derivative	and amount
											comprehensive income		(effective portion)(b)							(ineffective portion	excluded from
											into income									and amount	effectiveness testing)
											(effective portion)									excluded from
																				effectiveness
																				testing)
			Three Months Ended June 30,										Three Months Ended June 30,								Three Months Ended June 30,
		2014				2013						2014				2013				2014			2013
Energy commodity derivative contracts		$	(113	)		$	70			Revenues-Natural gas sales		$	(2	)		$	—		Revenues-Natural gas sales	$	—		$	—
										Revenues-Product sales and other		(23		)		8			Revenues-Product sales and other	(27		)	9
										Costs of sales		7				(5		)	Costs of sales	—			—
Total		$	(113	)		$	70			Total		$	(18	)		$	3		Total	$	(27	)	$	9
		Six Months Ended June 30,										Six Months Ended June 30,								Six Months Ended June 30,
		2014				2013						2014				2013				2014			2013
Energy commodity derivative contracts		$	(169	)		$	29			Revenues-Natural gas sales		$	(12	)		$	—		Revenues-Natural gas sales	$	—		$	—
										Revenues-Product sales and other		(32		)		15			Revenues-Product sales and other	(32		)	6
										Costs of sales		8				(5		)	Costs of sales	—			—
Total		$	(169	)		$	29			Total		$	(36	)		$	10		Total	$	(32	)	$	6
______________
(a)	We expect to reclassify an approximate $71 million loss associated with energy commodity price risk management activities included in our Partners’ Capital as of June 30, 2014 into earnings during the next twelve months (when the associated forecasted sales and purchases are also expected to occur); however, actual amounts reclassified into earnings could vary materially as a result of changes in market prices.
(b)	Amounts reclassified were the result of the hedged forecasted transactions actually affecting earnings (i.e., when the forecasted sales and purchases actually occurred).
Derivatives not designated		Location of gain/(loss) recognized		Amount of gain/(loss) recognized in income on derivatives
as accounting hedges		in income on derivatives		Three Months Ended June 30,								Six Months Ended June 30,
				2014				2013				2014				2013
Energy commodity derivative contracts		Revenues-Natural gas sales		$	(9	)		$	—			$	(16	)		$	—
		Revenues-Product sales and other		6				(1		)		(1		)		3
		Costs of sales		(3		)		(1		)		7				(1		)
		Other expense (income)		—				—				(2		)		—
Total				$	(6	)		$	(2	)		$	(12	)		$	2
Credit Risks
We have counterparty credit risk as a result of our use of financial derivative contracts. Our counterparties consist primarily of financial institutions, major energy companies 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; (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 June 30, 2014 and December 31, 2013, we had no outstanding letters of credit supporting our hedging of energy commodity price risks associated with the sale of natural gas, NGL and crude oil.
We also have agreements with certain counterparties to our derivative contracts that contain provisions requiring us to post additional collateral upon a decrease in our credit rating. As of June 30, 2014, we estimate that if our credit rating was downgraded one notch, we would be required to post no additional collateral to our counterparties. If we were downgraded two notches (that is, below investment grade), we would be required to post $122 million of additional collateral.
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income
Cumulative revenues, expenses, gains and losses that under GAAP are included within our comprehensive income but excluded from our earnings are reported as “Accumulated other comprehensive (loss) income” within “Partners’ Capital” in our consolidated balance sheets. Changes in the components of our “Accumulated other comprehensive (loss) income” for each of the six months ended June 30, 2014 and 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 adjs.				income/(loss)
Balance as of December 31, 2013	$	24			$	(4	)		$	13			$	33
Other comprehensive (loss) income before reclassifications	(169		)		(7		)		(3		)		(179		)
Amounts reclassified from accumulated other comprehensive income	36				—				—				36
Net current-period other comprehensive (loss) income	(133		)		(7		)		(3		)		(143		)
Balance as of June 30, 2014	$	(109	)		$	(11	)		$	10			$	(110	)
	Net unrealized				Foreign				Pension and				Total
	gains/(losses)				currency				other				Accumulated other
	on cash flow				translation				postretirement				comprehensive
	hedge derivatives				adjustments				liability adjs.				income/(loss)
Balance as of December 31, 2012	$	66			$	132			$	(30	)		$	168
Other comprehensive (loss) income before reclassifications	30				(114		)		1				(83		)
Amounts reclassified from accumulated other comprehensive income	(10		)		—				—				(10		)
Net current-period other comprehensive (loss) income	20				(114		)		1				(93		)
Balance as of June 30, 2013	$	86			$	18			$	(29	)		$	75

Fair_Value

Fair Value	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value	'
	Fair Value
	The fair values of our financial instruments are separated into three broad levels (Levels 1, 2 and 3) based on our assessment of the availability of observable market data and the significance of non-observable data used to determine fair value. Each fair value measurement must be assigned to a level corresponding to the lowest level input that is significant to the fair value measurement in its entirety.
	The three broad levels of inputs defined by the fair value hierarchy are as follows:
	▪	Level 1 Inputs—quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity has the ability to access at the measurement date;
	▪	Level 2 Inputs—inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. If the asset or liability has a specified (contractual) term, a Level 2 input must be observable for substantially the full term of the asset or liability; and
	▪	Level 3 Inputs—unobservable inputs for the asset or liability. These unobservable inputs reflect the entity’s own assumptions about the assumptions that market participants would use in pricing the asset or liability, and are developed based on the best information available in the circumstances (which might include the reporting entity’s own data).
	Fair Value of Derivative Contracts
	The following two tables summarize the fair value measurements of our (i) energy commodity derivative contracts; and (ii) interest rate swap agreements as of June 30, 2014 and December 31, 2013, based on the three levels established by the Codification. Also, certain of our derivative contracts are subject to master netting agreements. The following tables present our derivative contracts subject to such netting agreements as of June 30, 2014 and December 31, 2013 (in millions):
		Balance Sheet asset												Amounts not offset in the Balance Sheet					Net Amount
		fair value measurements using
		Level 1			Level 2			Level 3			Gross Amount			Financial Instruments			Cash Collateral Held(b)
	As of June 30, 2014
	Energy commodity derivative contracts(a)	$	3		$	7		$	4		$	14		$	(12	)	$	—	$	2
	Interest rate swap agreements	$	—		$	271		$	—		$	271		$	(22	)	$	—	$	249
	As of December 31, 2013
	Energy commodity derivative contracts(a)	$	4		$	46		$	30		$	80		$	(44	)	$	—	$	36
	Interest rate swap agreements	$	—		$	217		$	—		$	217		$	(28	)	$	—	$	189
		Balance Sheet liability												Amounts not offset in the Balance Sheet					Net Amount
		fair value measurements using
		Level 1			Level 2			Level 3			Gross Amount			Financial Instruments			Cash Collateral Posted(c)
	As of June 30, 2014
	Energy commodity derivative contracts(a)	$	(10	)	$	(134	)	$	(35	)	$	(179	)	$	12		$	17	$	(150	)
	Interest rate swap agreements	$	—		$	(46	)	$	—		$	(46	)	$	22		$	—	$	(24	)
	As of December 31, 2013
	Energy commodity derivative contracts(a)	$	(6	)	$	(31	)	$	(31	)	$	(68	)	$	44		$	17	$	(7	)
	Interest rate swap agreements	$	—		$	(116	)	$	—		$	(116	)	$	28		$	—	$	(88	)
	______________
	(a)	Level 1 consists primarily of New York Mercantile Exchange natural gas futures. Level 2 consists primarily of OTC WTI swaps. Level 3 consists primarily of WTI options and NGL options.
	(b)	Cash margin deposits held by us associated with our energy commodity contract positions and OTC swap agreements and reported within “Other current liabilities” on our accompanying consolidated balance sheets.
	(c)	Cash margin deposits posted by us associated with our energy commodity contract positions and OTC swap agreements and reported within “Other current assets” on our accompanying consolidated balance sheets.
	The table below provides a summary of changes in the fair value of our Level 3 energy commodity derivative contracts for each of the three and six months ended June 30, 2014 and 2013 (in millions):
	Significant unobservable inputs (Level 3)
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
	Derivatives-net asset (liability)
	Beginning of Period	$	(3	)	$	3		$	(1	)	$	3
	Total gains or (losses):
	Included in earnings	(19		)	—			(18		)	6
	Included in other comprehensive income (loss)	(9		)	1			(10		)	—
	Purchases(a)	—			18			—			18
	Settlements	—			(4		)	(2		)	(9		)
	End of Period	$	(31	)	$	18		$	(31	)	$	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	)	$	1		$	(16	)	$	5
	______________
	(a)	Three and six month 2013 amounts represent the purchase of Level 3 energy commodity derivative contracts associated with our May 1, 2013 Copano acquisition.
	As of June 30, 2014, our Level 3 derivative assets and liabilities consisted primarily of WTI options and NGL options, 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 is our management’s best estimate of fair value.
	Fair Value of Financial Instruments
	The estimated fair value of our outstanding debt balance as of June 30, 2014 and December 31, 2013 (both short-term and long-term and including debt fair value adjustments), is disclosed below (in millions):
		June 30, 2014						December 31, 2013
		Carrying			Estimated			Carrying			Estimated
		Value			Fair value			Value			Fair value
	Total debt	$	22,214		$	23,450		$	21,128		$	21,550
	We used Level 2 input values to measure the estimated fair value of our outstanding debt balance as of both June 30, 2014 and December 31, 2013.

Reportable_Segments

Reportable Segments	6 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
Reportable Segments	'
	Reportable Segments
	We operate in five 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 NGL;
	▪	CO2—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—the transportation and terminaling of refined petroleum products (including gasoline, diesel fuel and jet fuel), NGL, crude oil and condensate, and bio-fuels;
	▪	Terminals—the transportation, transloading and storing of refined petroleum products, crude oil, condensate, and bulk products, including coal, petroleum coke, cement, alumina, salt and other bulk chemicals; and
	▪	Kinder Morgan Canada—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.
	We evaluate performance principally based on each segment’s EBDA (including amortization of excess cost of equity investments), which excludes general and administrative expenses, third party debt costs and interest expense, unallocable interest income, and unallocable income tax expense. Our reportable segments are strategic business units that offer different products and services, and they are structured based on how our chief operating decision makers organize their operations for optimal performance and resource allocation. Each segment is managed separately because each segment involves different products and marketing strategies. Financial information by segment follows (in millions):
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
	Revenues
	Natural Gas Pipelines
	Revenues from external customers	$	2,111		$	1,696		$	4,286		$	3,065
	Intersegment revenues	1			—			2			—
	CO2	454			460			937			889
	Products Pipelines	524			443			1,058			897
	Terminals
	Revenues from external customers	420			343			$	811		$	680
	Intersegment revenues	1			1			1			1
	Kinder Morgan Canada	68			75			137			147
	Total segment revenues	3,579			3,018			7,232			5,679
	Less: Total intersegment revenues	(2		)	(1		)	(3		)	(1		)
	Total consolidated revenues	$	3,577		$	3,017		$	7,229		$	5,678
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
	Segment EBDA(a)
	Natural Gas Pipelines(b)	$	639		$	1,123		$	1,358		$	1,680
	CO2	332			358			695			700
	Products Pipelines(c)	203			12			411			197
	Terminals	233			207			447			393
	Kinder Morgan Canada(d)	40			50			88			243
	Segment EBDA	1,447			1,750			2,999			3,213
	Total segment DD&A expense	(406		)	(357		)	(807		)	(685		)
	Total segment amortization of excess cost of investments	(5		)	(2		)	(8		)	(4		)
	General and administrative expense	(132		)	(163		)	(285		)	(297		)
	Interest expense, net of unallocable interest income	(231		)	(215		)	(470		)	(417		)
	Unallocable income tax expense	(4		)	(3		)	(6		)	(6		)
	Loss from discontinued operations	—			—			—			(2		)
	Total consolidated net income	$	669		$	1,010		$	1,423		$	1,802
		June 30,			December 31,
		2014			2013
	Assets
	Natural Gas Pipelines	$	25,704		$	25,721
	CO2	3,039			2,954
	Products Pipelines	5,782			5,488
	Terminals	7,592			6,124
	Kinder Morgan Canada	1,690			1,678
	Total segment assets	43,807			41,965
	Corporate assets(e)	744			799
	Total consolidated assets	$	44,551		$	42,764
	______________
	(a)	Includes revenues, earnings from equity investments, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other income, net. Operating expenses include natural gas purchases and other costs of sales, operations and maintenance expenses, and taxes, other than income taxes.
	(b)	Three and six month 2013 amounts include a $558 million non-cash gain from the remeasurement of our previously held equity interest in Eagle Ford Gathering to fair value (discussed further in Note 2 “Acquisitions and Divestitures—Acquisitions—Other”).
	(c)	Three and six month 2013 amounts include increases in operating expense of $162 million and $177 million, respectively, associated with adjustments to legal liabilities related to both transportation rate case and environmental matters.
	(d)	Six month 2013 amount includes a $141 million increase in earnings from the after-tax gain on the sale of our investments in the Express pipeline system.
	(e)	Includes cash and cash equivalents; margin and restricted deposits; unallocable interest receivable, prepaid assets and deferred charges; and risk management assets related to debt fair value adjustments.

Related_Party_Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	Asset Acquisitions and Sales
	From time to time in the ordinary course of business, we buy and sell assets and related services from KMI and its subsidiaries.  Such transactions are conducted in accordance with all applicable laws and regulations and on an arms’-length basis consistent with our policies governing such transactions.  In conjunction with our acquisition of (i) certain Natural Gas Pipelines assets and partnership interests from KMI in December 1999 and December 2000; (ii) TransColorado Gas Transmission Company LLC from KMI in November 2004; (iii) TGP and 50% of EPNG from KMI in August 2012; and (iv) the March 2013 drop-down asset group, KMI has agreed to indemnify us and our general partner with respect to approximately $5.9 billion of our debt as of June 30, 2014. KMI would be obligated to perform under this indemnity only if we are unable, and/or our assets were insufficient, to satisfy our obligations.
	Contingent Debt
	Our contingent debt disclosures pertain to certain types of guarantees or indemnifications we have made and cover certain types of guarantees included within debt agreements, even if the likelihood of requiring our performance under such guarantees or indemnifications are remote.  As of June 30, 2014 and December 31, 2013, our contingent debt obligations, as well as our obligations with respect to related letters of credit, totaled $79 million and $74 million, respectively.
	Other Commitments
	One of our wholly owned subsidiaries is committed to contribute $175 million to one of our unconsolidated subsidiaries during 2014.

Litigation_Environmental_and_O

Litigation, Environmental and Other Contingencies	6 Months Ended
	Jun. 30, 2014
Litigation, Environmental and Other Contingencies [Abstract]	'
Legal Matters and Contingencies [Text Block]	'
	Litigation, Environmental and Other Contingencies
	We are party to various legal, regulatory and other matters arising from the day-to-day operations of our businesses that may result in claims against the Partnership. 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 distributions to limited partners. We believe we have meritorious defenses to the matters to which we are a party and intend to vigorously defend the Partnership. 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).  In late June of 2014, certain shippers filed complaints with the FERC (docketed at OR14-35 and OR14-36) challenging SFPP’s adjustments to its rates in 2012 and 2013 for inflation under the FERC’s indexing regulations. If the shippers are successful in proving these claims or other of their claims, they are entitled to seek reparations (which may reach back up to two years prior to the filing of their complaints) or refunds of any excess rates paid, and SFPP may be required to reduce its rates going forward.  These proceedings tend to be protracted, with decisions of the FERC often appealed to the federal courts.  The issues involved in these proceedings include, among others, whether indexed rate increases are justified, and the appropriate level of return and income tax allowance we may include in our rates.  With respect to all of the SFPP proceedings at the FERC, we estimate that the shippers are seeking approximately $20 million in annual rate reductions and approximately $100 million in refunds.  However, applying the principles of several recent FERC decisions in SFPP cases, as applicable, to pending cases would result in substantially lower rate reductions and refunds than those sought by the shippers.  We do not expect refunds in these cases to have an impact on our distributions to our limited partners.
	EPNG
	The tariffs and rates charged by EPNG are subject to two ongoing FERC proceedings (the “2008 rate case” and the “2010 rate case”). With respect to the 2008 rate case, the FERC issued its decision (Opinion 517) in May 2012. EPNG implemented certain aspects of that decision and believes it has an appropriate reserve related to the findings in Opinion 517. EPNG has sought rehearing on Opinion 517. With respect to the 2010 rate case, the FERC issued its decision (Opinion 528) on October 17, 2013. EPNG sought rehearing on certain issues in Opinion 528. As required by Opinion 528, EPNG filed revised pro forma recalculated rates consistent with the terms of Opinion 528. The FERC also required an Administrative Law Judge to conduct an additional hearing concerning one of the issues in Opinion 528 and a decision is expected in September 2014.
	California Public Utilities Commission Proceedings
	We have previously reported ratemaking and complaint proceedings against SFPP pending with the CPUC.  The ratemaking and complaint cases generally involve challenges to rates charged by SFPP for intrastate transportation of refined petroleum products through its pipeline system in the state of California and request prospective rate adjustments and refunds with respect to tariffed and previously untariffed charges for certain pipeline transportation and related services.  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 included determinations on issues, such as SFPP’s entitlement to an income tax allowance, allocation of environmental expenses, and refund liability which we asserted 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. 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. The precise impact of the now final state rulings denying SFPP an income tax allowance, together with other pending ratemaking issues, are subject to further consideration and determination by the CPUC.
	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.
	On July 19, 2013, Calnev filed an application with the CPUC requesting a 36% increase in its intrastate rates. A decision from the CPUC approving the requested rate increase was issued on November 14, 2013.
	On November 27, 2013, the CPUC issued its Order to Show Cause directing SFPP to demonstrate whether or not the CPUC should require immediate refund payments associated with various pending SFPP rate matters. Subsequently, the CPUC issued an order directing SFPP and its shippers to engage in mandatory settlement discussions. On April 3, 2014, the CPUC issued its ruling suspending proceedings in all pending SFPP matters until October 1, 2014 or the date upon which SFPP and its shippers inform the CPUC that SFPP and its shippers have reached settlement of all pending matters or have failed to do so. If the matter is not settled, a decision addressing, if not resolving, all pending SFPP rate matters at the CPUC is anticipated in the first quarter of 2015.
	Based on our review of these CPUC proceedings and the shipper comments thereon, we estimate that the shippers are requesting approximately $400 million in reparation payments and approximately $30 million in annual rate reductions.  The actual amount of reparations will be determined through settlement negotiations or further proceedings at the CPUC. As of June 30, 2014, we believe our legal reserve is adequate such that the resolution of pending CPUC matters will not have a material adverse impact on our business, financial position or results of operations. Furthermore, we do not expect any reparations that we would pay in this matter to impact the per unit cash distributions we expect to pay to our limited partners for 2014.
	Other Commercial Matters
	Union Pacific Railroad Company Easements
	SFPP and Union Pacific Railroad Company (UPRR) are engaged in a proceeding to determine the extent, if any, to which the rent payable by SFPP for the use of pipeline easements on rights-of-way held by UPRR should be adjusted pursuant to existing contractual arrangements for the ten-year period beginning January 1, 2004 (Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al., Superior Court of the State of California for the County of Los Angeles, filed July 28, 2004). In September 2011, the trial judge determined that the annual rent payable as of January 1, 2004 was $14 million, subject to annual consumer price index increases. Judgment was entered by the Superior Court on May 29, 2012 and SFPP appealed the judgment. If the judgment is upheld on appeal, SFPP would owe approximately $95 million in back rent. Accordingly, we have increased our rights-of-way liability to cover this potential liability for back rent. In addition, the trial judge determined that UPRR is entitled to approximately $20 million for interest through the date of the judgment on the outstanding back rent liability. We believe the award of interest is without merit and are pursuing our appellate rights. On June 27, 2014, the California Court of Appeals heard oral argument and requested that the parties submit supplemental briefing on the following issues: whether the UPRR ever had sufficient ownership interests to allow it to grant subsurface easements in land granted to it by Congress; whether there is sufficient evidence in the record on this question; and assuming that the UPRR did not have sufficient ownership interests to grant subsurface easements and that its rental agreements with SFPP were invalid, whether the parties can limit the scope of the Court’s inquiry on appeal by not disputing the underlying rights of the railroad. The parties are in the process of filing supplemental briefs on the foregoing issues and a decision is anticipated by the Court of Appeals in 2014.
	By notice dated October 25, 2013, UPRR demanded the payment of $22.25 million in rent for the first year of the next ten-year period beginning January 1, 2014. SFPP rejected the demand and the parties are pursuing the dispute resolution procedure in their contract to determine the rental adjustment, if any, for such period.
	SFPP and UPRR are also engaged in multiple disputes over the circumstances under which SFPP must pay for a relocation of its pipeline within the UPRR right-of-way and the safety standards that govern relocations. In July 2006, a trial before a judge regarding the circumstances under which SFPP must pay for relocations concluded, and the judge determined that SFPP must pay for any relocations resulting from any legitimate business purpose of the UPRR. SFPP appealed this decision, and in December 2008, the appellate court affirmed the decision. In addition, UPRR contends that SFPP must comply with the more expensive American Railway Engineering and Maintenance-of-Way Association (AREMA) standards in determining when relocations are necessary and in completing relocations. Each party is seeking declaratory relief with respect to its positions regarding the application of these standards with respect to relocations. A trial occurred in the fourth quarter of 2011, with a verdict having been reached that SFPP was obligated to comply with AREMA standards in connection with a railroad project in Beaumont Hills, California. On March 10, 2014, the trial court issued a tentative statement of decision addressing all of the causes of action and defenses and resolved those matters against SFPP, consistent with the jury’s verdict. If the tentative statement of decision and jury verdict become final and are affirmed on appeal, SFPP will be required to pay a judgment of $42.65 million. SFPP is continuing to evaluate 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 our financial position, our results of operations, our cash flows, and our distributions to our 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 our subsidiary Kinder Morgan Bulk Terminals, Inc. (KMBT). According to our investigation, the collapse was caused by unexpected, sudden and extreme winds. On June 24, 2009, Severstal filed suit against KMBT in the U.S. 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. A bench trial occurred in November 2013. On March 6, 2014, the Court issued findings of fact and conclusions of law and entered judgment against KMBT in the amount of $13.79 million, which was later amended to $15.55 million by order dated May 6, 2014. KMBT has filed a notice of appeal of the judgment.
	Plains Gas Solutions, LLC v. Tennessee Gas Pipeline Company, L.L.C. et al
	On October 16, 2013, Plains Gas Solutions, LLC (Plains) filed a petition in the 151st Judicial District Court for Harris County, Texas (Case No. 62528) against TGP, Kinetica Partners, LLC and two other Kinetica entities. The suit arises from the sale by TGP of the Cameron System in Louisiana to Kinetica Partners, LLC on September 1, 2013. Plains alleges that defendants breached a straddle agreement requiring that gas on the Cameron System be committed to Plains’ Grand Chenier gas-processing facility, that requisite daily volume reports were not provided, that TGP improperly assigned its obligations under the straddle agreement to Kinetica, and that defendants interfered with Plains’ contracts with producers. The petition alleges damages of at least $100 million. Under the Amended and Restated Purchase and Sale Agreement with Kinetica, Kinetica has agreed to indemnify TGP in connection with the gas commitment and reporting claims. The suit was removed to federal court and Plains has filed a motion to remand. We intend to vigorously defend the suit.
	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 June 30, 2014 and December 31, 2013, our total reserve for legal matters was $678 million and $611 million, respectively. The reserve primarily relates to various claims from regulatory proceedings arising from our products pipeline and natural gas pipeline transportation rates.
	Other
	Slotoroff v. Kinder Morgan, Inc., Kinder Morgan G.P., Inc., et al
	On February 5, 2014, a putative class action and derivative complaint was filed in the Court of Chancery in the State of Delaware (Case No. 9318) against defendants KMI, KMGP and nominal defendant KMEP. The suit was filed by Jon Slotoroff, a purported unitholder of KMEP, and seeks to assert claims both individually and on behalf of a putative class consisting of all public holders of KMEP units during the period of February 5, 2011 through the date of the filing of the suit. The suit alleges direct and derivative causes of action for breach of the partnership agreement, breach of the duty of good faith and fair dealing, aiding and abetting, and tortious interference. Among other things, the suit alleges that defendants made a bad faith allocation of capital expenditures to expansion capital expenditures rather than maintenance capital expenditures for the alleged purpose of “artificially” inflating KMEP’s distributions and growth rate. The suit seeks disgorgement of any distributions to KMGP, KMI and any related entities, beyond amounts that would have been distributed in accordance with a “good faith” allocation of maintenance capital expenses, together with other unspecified monetary damages including punitive damages and attorney fees. Defendants believe this suit is without merit and intend to defend it vigorously.
	Burns et al v. Kinder Morgan, Inc. Kinder Morgan G.P., Inc. et al
	On March 27, 2014, a putative class action and derivative complaint was filed in the Court of Chancery in the State of Delaware (Case No. 9479) against defendants KMI, KMGP and nominal defendant KMEP. The suit was filed by Darrell Burns and Terrence Zehrer, purported unitholders of KMEP, and seeks to assert claims both individually and on behalf of a putative class consisting of all public holders of KMEP units during the period of February 5, 2011 through the date of the filing of the suit. The suit asserts claims and allegations substantially similar to the suit filed by Jon Slotoroff described above. On April 8, 2014, the Court ordered that this suit be consolidated for all purposes with the suit filed by Jon Slotoroff described above and that the caption of the consolidated action shall be In Re Kinder Morgan Energy Partners, L.P. Derivative Litigation, Consolidated Case No. 9318.
	Walker v. Kinder Morgan, Inc., Kinder Morgan G.P., Inc. et al
	On March 6, 2014, a putative class action and derivative complaint was filed in the District Court of Harris County, Texas (Case No. 2014-11872 in the 215th Judicial District) against KMI, KMGP, KMR, Richard D. Kinder, Steven J. Kean, Ted A. Gardner, Gary L. Hultquist, Perry M. Waughtal and nominal defendant KMEP. The suit was filed by Kenneth Walker, a purported unit holder of KMEP, and alleges direct and derivative causes of action for alleged violation of duties owed under the partnership agreement, breach of the implied covenant of good faith and fair dealing, “abuse of control” and “gross mismanagement” in connection with the calculation of distributions and allocation of capital expenditures to expansion capital expenditures and maintenance capital expenditures. The suit seeks unspecified money damages, interest, punitive damages, attorney and expert fees, costs and expenses, unspecified equitable relief, and demands a trial by jury. Defendants believe this suit is without merit and intend to defend it vigorously. By agreement of the parties, the case is stayed pending further resolution of the suit filed by Jon Slotoroff described above.
	Environmental Matters
	We are subject to environmental cleanup and enforcement actions from time to time. In particular, CERCLA generally imposes joint and several liability for cleanup and enforcement costs on current and predecessor owners and operators of a site, among others, without regard to fault or the legality of the original conduct, subject to the right of a liable party to establish a “reasonable basis” for apportionment of costs. Our operations are also subject to federal, state and local laws and regulations relating to protection of the environment. Although we believe our operations are in substantial compliance with applicable environmental law and regulations, risks of additional costs and liabilities are inherent in pipeline, terminal and CO2 field and oil field operations, and there can be no assurance that we will not incur significant costs and liabilities. Moreover, it is possible that other developments, such as increasingly stringent environmental laws, regulations and enforcement policies under the terms of authority of those laws, and claims for damages to property or persons resulting from our operations, could result in substantial costs and liabilities to us.
	We are currently involved in several governmental proceedings involving alleged violations of environmental and safety regulations. As we receive notices of non-compliance, we attempt to negotiate and settle such matters where appropriate. We do not believe that these alleged violations will have a material adverse effect on our business, financial position, results of operations or distributions to limited partners.
	We are also currently involved in several governmental proceedings involving groundwater and soil remediation efforts under administrative orders or related state remediation programs. We have established a reserve to address the costs associated with the cleanup.
	In addition, we are involved with and have been identified as a potentially responsible party in several federal and state superfund sites. Environmental reserves have been established for those sites where our contribution is probable and reasonably estimable. In addition, we are from time to time involved in civil proceedings relating to damages alleged to have occurred as a result of accidental leaks or spills of refined petroleum products, NGL, natural gas and CO2.
	Portland Harbor Superfund Site, Willamette River, Portland, Oregon
	In December 2000, the EPA issued General Notice letters to potentially responsible parties including GATX Terminals Corporation (n/k/a KMLT). At that time, GATX owned two liquids terminals along the lower reach of the Willamette River, an industrialized area known as Portland Harbor. Portland Harbor is listed on the National Priorities List and is designated as a Superfund Site under CERCLA. A group of potentially responsible parties formed what is known as the Lower Willamette Group (LWG), of which KMLT is a non-voting member and pays a minimal fee to be part of the group. The LWG agreed to conduct the remedial investigation and feasibility study (RI/FS) leading to the proposed remedy for cleanup of the Portland Harbor site. Once the EPA determines the cleanup remedy from the remedial investigations and feasibility studies conducted during the last decade at the site, it will issue a Record of Decision. Currently, KMLT and 90 other parties are involved in an allocation process to determine each party’s respective share of the cleanup costs. This is a non-judicial allocation process. We are participating in the allocation process on behalf of both KMLT and KMBT. Each entity has two facilities located in Portland Harbor. We expect the allocation process to conclude in 2015. We also expect the LWG to complete the RI/FS process in 2015, after which the EPA is expected to develop a proposed plan leading to a Record of Decision targeted for 2017. It is anticipated that the cleanup activities will begin within one year of the issuance of the Record of Decision.
	Roosevelt Irrigation District v. Kinder Morgan G.P., Inc., Kinder Morgan Energy Partners, L.P. , U.S. District Court, Arizona
	The Roosevelt Irrigation District sued KMGP, KMEP and others under CERCLA for contamination of the water purveyor’s wells.  The First Amended Complaint sought $175 million in damages against approximately 70 defendants.  On August 6, 2013, plaintiffs filed their Second Amended Complaint seeking monetary damages in unspecified amounts and reducing the number of defendants to 26 including KMEP and SFPP. The claims now presented against KMEP and SFPP are related to alleged releases from a specific parcel within the SFPP Phoenix Terminal and the alleged impact of such releases on water wells owned by the plaintiffs and located in the vicinity of the Terminal. On October 24, 2013, we moved to dismiss this suit and the motion remains pending.
	Paulsboro, New Jersey Liquids Terminal Consent Judgment
	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 in Gloucester County, New Jersey against ExxonMobil and KMLT, formerly known as GATX Terminals Corporation, alleging natural resource damages related to historic contamination at the Paulsboro, New Jersey liquids terminal owned by ExxonMobil from the mid-1950s through November 1989, by GATX Terminals Corporation from 1989 through September 2000, and later owned by Support Terminals and Pacific Atlantic Terminals, LLC. The terminal is now owned by Plains Products, which was also joined as a party to the lawsuit.
	In mid-2011, KMLT and Plains Products entered into a settlement agreement and subsequent Consent Judgment with the NJDEP which resolved the state’s alleged natural resource damages claim. The natural resource damage settlement includes a monetary award of $1 million and a series of remediation and restoration activities at the terminal site. KMLT and Plains Products have joint responsibility for this settlement. Simultaneously, KMLT and Plains Products entered into an agreement that settled each party’s relative share of responsibility (50/50) to the NJDEP under the Consent Judgment noted above. The Consent Judgment is now entered with the Court and the settlement is final. According to the agreement, Plains will conduct remediation activities at the site and KMLT will provide oversight and 50% of the costs. We are awaiting approval from the NJDEP in order to begin remediation activities.
	Mission Valley Terminal Lawsuit
	In August 2007, the City of San Diego, on its own behalf and purporting to act on behalf of the People of the State of California, filed a lawsuit against us and several affiliates seeking injunctive relief and unspecified damages allegedly resulting from hydrocarbon and methyl tertiary butyl ether (MTBE) impacted soils and groundwater beneath the City’s stadium property in San Diego arising from historic operations at the Mission Valley terminal facility. The case was filed in the Superior Court of California, San Diego County, case number 37-2007-00073033-CU-OR-CTL. On September 26, 2007, we removed the case to the U.S. 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 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 U.S. 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 (RWQCB).  SFPP has completed the soil and groundwater remediation at the City of San Diego’s stadium property site and will continue quarterly sampling and monitoring through 2014 as part of the compliance evaluation required by the RWQCB. SFPP's remediation effort is now focused on its adjacent Mission Valley Terminal site.
	On May 7, 2013, the City of San Diego filed a writ of mandamus to the California Superior Court seeking an order from the Court setting aside the RWQCB’s approval of our permit request to increase the discharge of water from our groundwater treatment system to the City of San Diego’s municipal storm sewer system. SFPP and KMEP are 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 20 uranium mines in the vicinity of Cameron, Arizona, many of which are located on the Navajo Indian Reservation.  The mining activities were in response to numerous incentives provided to industry by the U.S. to locate and produce domestic sources of uranium to support the Cold War-era nuclear weapons program.  In May 2012, EPNG received a general notice letter from the EPA notifying EPNG of the EPA’s investigation of certain sites and its determination that the EPA considers EPNG to be a potentially responsible party within the meaning of CERCLA.  In August 2013, EPNG and the EPA entered into an Administrative Order on Consent and Scope of Work, pursuant to which EPNG will conduct a radiological assessment of the surface of the mines.  We are also seeking contribution from the applicable federal government agencies toward the cost of environmental activities associated with the mines, given their pervasive control over all aspects of the nuclear weapons program.
	PHMSA Inspection of Carteret Terminal, Carteret, New Jersey
	On April 4, 2013, the PHMSA, Office of Pipeline Safety issued a Notice of Probable Violation, Proposed Civil Penalty and Proposed Compliance Order (NOPV) arising from an inspection at the KMLT, Carteret, New Jersey location on March 15, 2011, following a release and fire that occurred during maintenance activity on March 14, 2011. On July 17, 2013, KMLT entered into a Consent Agreement and Order with the PHMSA, pursuant to which KMLT paid a penalty of $63,100 and is required to complete ongoing pipeline integrity testing and other corrective measures by May 2015.
	Southeast Louisiana Flood Protection Litigation
	On July 24, 2013, the Board of Commissioners of the Southeast Louisiana Flood Protection Authority - East (SLFPA) filed a petition for damages and injunctive relief in state district court for Orleans Parish, Louisiana (Case No. 13-6911) against TGP and approximately 100 energy companies, alleging that defendants’ drilling, dredging, pipeline and industrial operations since the 1930’s have caused direct land loss and increased erosion and submergence resulting in alleged increased storm surge risk, increased flood protection costs and unspecified damages to the plaintiff. The SLFPA asserts claims for negligence, strict liability, public nuisance, private nuisance, and breach of contract. Among other relief, the petition seeks unspecified monetary damages, attorney fees, interest, and injunctive relief in the form of abatement and restoration of the alleged coastal land loss including but not limited to backfilling and re-vegetation of canals, wetlands and reef creation, land bridge construction, hydrologic restoration, shoreline protection, structural protection, and bank stabilization. On August 13, 2013, the suit was removed to the U.S. District Court for the Eastern District of Louisiana. On September 10, 2013, the SLFPA filed a motion to remand the case to the state district court for Orleans Parish. The Court denied the remand motion on June 27, 2014. Louisiana Act 544 went into effect on June 6, 2014 and specified the political entities authorized to institute litigation for environmental damage in the coastal zone. Under the Act, which was specifically made retroactive, the SLFPA is not a valid plaintiff. Defendants intend to move to dismiss the suit under the Act among other grounds.
	Plaquemines Parish Louisiana Coastal Zone Litigation
	On November 8, 2013, the Parish of Plaquemines, Louisiana filed a petition for damages in the state district court for Plaquemines Parish, Louisiana (Docket No. 60-999) against TGP and 17 other energy companies, alleging that defendants’ oil and gas exploration, production and transportation operations in the Bastian Bay, Buras, Empire and Fort Jackson oil and gas fields of Plaquemines Parish caused substantial damage to the coastal waters and nearby lands (Coastal Zone) within the Parish, including the erosion of marshes and the discharge of oil waste and other pollutants which detrimentally affected the quality of state waters and plant and animal life, in violation of the State and Local Coastal Resources Management Act of 1978 (Coastal Zone Management Act). As a result of such alleged violations of the Coastal Zone Management Act, Plaquemines Parish seeks, among other relief, unspecified monetary relief, attorney fees, interest, and payment of costs necessary to restore the allegedly affected Coastal Zone to its original condition, including costs to clear, vegetate and detoxify the Coastal Zone. On December 18, 2013, defendants removed the case to the U.S. District Court for the Eastern District of Louisiana. On January 14, 2014, the plaintiff filed a motion to remand the case to state court and such motion remains pending.
Pennsylvania Department of Environmental Protection Notice of Alleged Violations
The Pennsylvania Department of Environmental Protection (PADEP) has notified TGP of alleged violations of certain conditions to the construction permits issued to TGP for the construction of TGP’s 300 Line Project in 2011. The alleged violations arise from field inspections performed during construction by county conservation districts, as delegates of the PADEP, and generally involve the alleged failure by TGP to implement and maintain best practices to achieve sufficient erosion and sediment controls, stabilization of the right of way, and prevention of potential discharge of sediment into the waters of the commonwealth during construction and before placing the line into service. To resolve such alleged violations, the PADEP initially proposed a collective penalty of approximately $1.5 million. TGP and the PADEP are seeking to reach a mutually agreeable resolution of the alleged notices of violations, including an agreed penalty amount.
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 are a party, will not have a material adverse effect on our business, financial position, results of operations or cash flows. As of June 30, 2014 and December 31, 2013, our total reserve for environmental liabilities was $161 million and $168 million, respectively.

Recent_Accounting_Pronouncemen

Recent Accounting Pronouncements	6 Months Ended
	Jun. 30, 2014
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]	'
Recent Accounting Pronouncements	'
	Recent Accounting Pronouncements
	Accounting Standards Updates-Adopted
	None of the Accounting Standards Updates (ASU) that we adopted and that became effective January 1, 2014 (including 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)) had a material impact on our consolidated financial statements. More information about this ASU can be found in Note 17 “Recent Accounting Pronouncements” to our consolidated financial statements that were included in our 2013 Form 10-K.
	ASU No. 2014-09
	On May 28, 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” This ASU is designed to create greater comparability for financial statement users across industries and jurisdictions. The provisions of ASU No. 2014-09 include a five-step process by which entities will recognize revenue to depict the transfer of goods or services to customers in amounts that reflect the payment to which an entity expects to be entitled in exchange for those goods or services. The standard also will require enhanced disclosures, provide more comprehensive guidance for transactions such as service revenue and contract modifications, and enhance guidance for multiple-element arrangements. ASU No. 2014-09 will be effective for U.S. public companies for annual reporting periods beginning after December 15, 2016, including interim reporting periods (January 1, 2017 for us). Early adoption is not permitted. We are currently reviewing the effect of ASU No. 2014-09 on our revenue recognition.

Guarantee_of_Securities_of_Sub

Guarantee of Securities of Subsidiaries (Notes)	6 Months Ended
	Jun. 30, 2014
Guarantees [Abstract]	'
Guarantees [Text Block]	'
	11. Guarantee of Securities of Subsidiaries
	KMEP has guaranteed the payment of Copano’s outstanding 7.125% senior notes due April 1, 2021 (referred to in this report as the “Guaranteed Notes”). Copano Energy Finance Corporation (Copano Finance Corp.), a direct subsidiary of Copano, is the co-issuer of the Guaranteed Notes. Excluding fair value adjustments, as of June 30, 2014, Copano had $332 million of Guaranteed Notes outstanding. Copano Finance Corp’s obligations as a co-issuer and primary obligor are the same as and joint and several with the obligations of Copano as issuer, however, it has no subsidiaries and no independent assets or operations. Subject to the limitations set forth in the applicable supplemental indentures, KMEP’s guarantee is full and unconditional and guarantees the Guaranteed Notes through their maturity date. The prior periods presented herein have been retrospectively adjusted for a Copano reorganization that occurred on December 31, 2013.
	A significant amount of KMEP’s income and cash flow is generated by its respective subsidiaries. As a result, the funds necessary to meet its debt service and/or guarantee obligations are provided in large part by distributions or advances it receives from its respective subsidiaries. For purposes of the condensed consolidating financial information, distributions from our wholly-owned subsidiaries have been presented as operating cash flows whether or not distributions exceeded cumulative earnings. In addition, we utilize a centralized cash pooling program among our majority-owned and consolidated subsidiaries, including the subsidiary issuers and non-guarantor subsidiaries. The following Condensed Consolidating Statements of Cash Flows present the intercompany loan and distribution activity, as well as cash collection and payments made on behalf of our subsidiaries, as cash activities.
	Included among the non-guarantor subsidiaries are KMEP’s five operating limited partnerships and their majority-owned and controlled subsidiaries, along with Copano’s remaining majority-owned and controlled subsidiaries. In the following unaudited condensed consolidating financial information, KMEP is “Parent Guarantor,” and Copano and Copano Finance Corp. are the “Subsidiary Issuers.” The Subsidiary Issuers are 100% owned by KMEP.
	Condensed Consolidating Statements of Income and Comprehensive Income
	for the Three Months ended June 30, 2014
	(In Millions)
	(Unaudited)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
	Total Revenues	$	—		$	—		$	3,577		$	—		$	3,577
	Operating Costs, Expenses and Other
	Costs of sales	—			—			1,602			—			1,602
	Depreciation, depletion and amortization	—			—			406			—			406
	Other operating expenses	—			8			706			—			714
	Total Operating Costs, Expenses and Other	—			8			2,714			—			2,722
	Operating (Loss) Income	—			(8		)	863			—			855
	Other Income (Expense), Net	663			45			(160		)	(710		)	(162		)
	Income Before Income Taxes	663			37			703			(710		)	693
	Income Tax Expense	(2		)	—			(22		)	—			(24		)
	Net Income	661			37			681			(710		)	669
	Net Income Attributable to Noncontrolling Interests	—			—			(8		)	—			(8		)
	Net Income Attributable to KMEP	$	661		$	37		$	673		$	(710	)	$	661
	Net Income	$	661		$	37		$	681		$	(710	)	$	669
	Total Other Comprehensive (Loss)	(25		)	—			(25		)	25			(25		)
	Comprehensive Income	636			37			656			(685		)	644
	Comprehensive Income Attributable to Noncontrolling Interests	—			—			(8		)	—			(8		)
	Comprehensive Income Attributable to KMEP	$	636		$	37		$	648		$	(685	)	$	636
	Condensed Consolidating Statements of Income and Comprehensive Income
	for the Three Months ended June 30, 2013
	(In Millions)
	(Unaudited)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
	Total Revenues	$	—		$	—		$	3,017		$	—		$	3,017
	Operating Costs, Expenses and Other
	Costs of sales	—			—			1,248			—			1,248
	Depreciation, depletion and amortization	—			2			355			—			357
	Other operating expenses	—			26			785			—			811
	Total Operating Costs, Expenses and Other	—			28			2,388			—			2,416
	Operating (Loss) Income	—			(28		)	629			—			601
	Other Income, Net	1,004			35			435			(1,039		)	435
	Income Before Income Taxes	1,004			7			1,064			(1,039		)	1,036
	Income Tax Expense	(4		)	—			(22		)	—			(26		)
	Net Income	1,000			7			1,042			(1,039		)	1,010
	Net Income Attributable to Noncontrolling Interests	—			—			(10		)	—			(10		)
	Net Income Attributable to KMEP	$	1,000		$	7		$	1,032		$	(1,039	)	$	1,000
	Net Income	$	1,000		$	7		$	1,042		$	(1,039	)	$	1,010
	Total Other Comprehensive (Loss)	(4		)	—			(4		)	4			(4		)
	Comprehensive Income	996			7			1,038			(1,035		)	1,006
	Comprehensive Income Attributable to Noncontrolling Interests	—			—			(10		)	—			(10		)
	Comprehensive Income Attributable to KMEP	$	996		$	7		$	1,028		$	(1,035	)	$	996
	Condensed Consolidating Statements of Income and Comprehensive Income
	for the Six Months ended June 30, 2014
	(In Millions)
	(Unaudited)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
	Total Revenues	$	—		$	—		$	7,229		$	—		$	7,229
	Operating Costs, Expenses and Other
	Costs of sales	—			—			3,240			—			3,240
	Depreciation, depletion and amortization	—			—			807			—			807
	Other operating expenses	—			15			1,379			—			1,394
	Total Operating Costs, Expenses and Other	—			15			5,426			—			5,441
	Operating (Loss) Income	—			(15		)	1,803			—			1,788
	Other Income (Expense), Net	1,412			78			(323		)	(1,492		)	(325		)
Income Before Income Taxes	1,412			63			1,480			(1,492		)	1,463
Income Tax Expense	(5		)	—			(35		)	—			(40		)
Net Income	1,407			63			1,445			(1,492		)	1,423
Net Income Attributable to Noncontrolling Interests	—			—			(16		)	—			(16		)
Net Income Attributable to KMEP	$	1,407		$	63		$	1,429		$	(1,492	)	$	1,407
Net Income	$	1,407		$	63		$	1,445		$	(1,492	)	$	1,423
Total Other Comprehensive (Loss)	(143		)	—			(144		)	143			(144		)
Comprehensive Income	1,264			63			1,301			(1,349		)	1,279
Comprehensive Income Attributable to Noncontrolling Interests	—			—			(15		)	—			(15		)
Comprehensive Income Attributable to KMEP	$	1,264		$	63		$	1,286		$	(1,349	)	$	1,264
Condensed Consolidating Statements of Income and Comprehensive Income
for the Six Months ended June 30, 2013
(In Millions)
(Unaudited)
	Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
Total Revenues	$	—		$	—		$	5,678		$	—		$	5,678
Operating Costs, Expenses and Other
Costs of sales	—			—			2,205			—			2,205
Depreciation, depletion and amortization	—			2			683			—			685
Other operating expenses	—			26			1,377			—			1,403
Total Operating Costs, Expenses and Other	—			28			4,265			—			4,293
Operating (Loss) Income	—			(28		)	1,413			—			1,385
Other Income, Net	1,789			35			537			(1,815		)	546
Income from Continuing Operations Before Income Taxes	1,789			7			1,950			(1,815		)	1,931
Income Tax Expense	(6		)	—			(121		)	—			(127		)
Income from Continuing Operations	1,783			7			1,829			(1,815		)	1,804
Loss from Discontinued Operations	—			—			(2		)	—			(2		)
Net Income	1,783			7			1,827			(1,815		)	1,802
Net Income Attributable to Noncontrolling Interests	—			—			(19		)	—			(19		)
Net Income Attributable to KMEP	$	1,783		$	7		$	1,808		$	(1,815	)	$	1,783
Net Income	$	1,783		$	7		$	1,827		$	(1,815	)	$	1,802
Total Other Comprehensive (Loss)	(93		)	—			(94		)	93			(94		)
Comprehensive Income	1,690			7			1,733			(1,722		)	1,708
Comprehensive Income Attributable to Noncontrolling Interests	—			—			(18		)	—			(18		)
Comprehensive Income Attributable to KMEP	$	1,690		$	7		$	1,715		$	(1,722	)	$	1,690
Condensed Consolidating Balance Sheets as of June 30, 2014
(In Millions)
(Unaudited)
	Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
ASSETS
Cash and cash equivalents	$	28		$	—		$	235		$	—		$	263
All other current assets	3,433			7			2,165			(3,348		)	2,257
Property, plant and equipment, net	—			15			29,270			—			29,285
Investments	—			—			2,193			—			2,193
Investments in subsidiaries	14,017			4,434			—			(18,451		)	—
Goodwill	—			920			5,801			—			6,721
Notes receivable from affiliates	18,279			—			—			(18,279		)	—
Other non-current assets	290			—			3,542			—			3,832
Total Assets	$	36,047		$	5,376		$	43,206		$	(40,078	)	$	44,551
LIABILITIES AND PARTNERS’ CAPITAL
Liabilities
Current portion of debt	$	1,337		$	—		$	—		$	—		$	1,337
All other current liabilities	355			137			6,057			(3,348		)	3,201
Total long-term debt	16,931			389			3,557			—			20,877
Notes payable to affiliates	—			765			17,514			(18,279		)	—
Deferred income taxes	—			2			295			—			297
Other long-term liabilities and deferred credits	107			2			945			—			1,054
Total Liabilities	18,730			1,295			28,368			(21,627		)	26,766
Partners’ Capital
Total KMEP Partners’ Capital	17,317			4,081			14,370			(18,451		)	17,317
Noncontrolling interests	—			—			468			—			468
Total Partners’ Capital	17,317			4,081			14,838			(18,451		)	17,785
Total Liabilities and Partners’ Capital	$	36,047		$	5,376		$	43,206		$	(40,078	)	$	44,551
Condensed Consolidating Balance Sheets as of December 31, 2013
(In Millions)
	Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
ASSETS
Cash and cash equivalents	$	10		$	1		$	393		$	—		$	404
All other current assets	3,071			13			2,151			(2,971		)	2,264
Property, plant and equipment, net	—			170			27,235			—			27,405
Investments	—			—			2,233			—			2,233
Investments in subsidiaries	13,931			4,430			—			(18,361		)	—
Goodwill	—			813			5,734			—			6,547
Notes receivable from affiliates	17,284			—			—			(17,284		)	—
Other non-current assets	233			—			3,678			—			3,911
Total Assets	$	34,529		$	5,427		$	41,424		$	(38,616	)	$	42,764
LIABILITIES AND PARTNERS’ CAPITAL
Liabilities
Current portion of debt	$	1,504		$	—		$	—		$	—		$	1,504
All other current liabilities	407			107			5,530			(2,971		)	3,073
Total long-term debt	15,644			393			3,587			—			19,624
Notes payable to affiliates	—			907			16,377			(17,284		)	—
Deferred income taxes	—			2			283			—			285
Other long-term liabilities and deferred credits	173			—			884			—			1,057
Total Liabilities	17,728			1,409			26,661			(20,255		)	25,543
Partners’ Capital
Total KMEP Partners’ Capital	16,801			4,018			14,343			(18,361		)	16,801
Noncontrolling interests	—			—			420			—			420
Total Partners’ Capital	16,801			4,018			14,763			(18,361		)	17,221
Total Liabilities and Partners’ Capital	$	34,529		$	5,427		$	41,424		$	(38,616	)	$	42,764
Condensed Consolidating Statements of Cash Flow for the Six Months ended June 30, 2014
(In Millions)
(Unaudited)
	Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
Net Cash Provided by (Used in) Operating Activities	$	1,723		$	(29	)	$	2,691		$	(2,136	)	$	2,249
Cash Flows From Investing Activities
Acquisitions of assets and investments, net of cash acquired	—			—			(993		)	—			(993		)
Capital expenditures	—			(47		)	(1,803		)	192			(1,658		)
Contributions to investments	—			—			(89		)	—			(89		)
Distributions from equity investments in excess of cumulative earnings	—			—			37			—			37
Funding (to) from affiliates	(1,571		)	72			420			1,079			—
Natural gas storage and natural gas and liquids line-fill	—			—			22			—			22
Sale, casualty and transfer of property, plant and equipment, investments and other net assets, net of removal costs	—			192			11			(192		)	11
Other, net	—			—			(5		)	—			(5		)
Net Cash (Used in) Provided by Investing Activities	(1,571		)	217			(2,400		)	1,079			(2,675		)
Cash Flows From Financing Activities
Issuance of debt	6,083			—			—			—			6,083
Payment of debt	(5,059		)	—			(1		)	—			(5,060		)
Debt issue costs	(11		)	—			—			—			(11		)
Funding (to) from affiliates	(392		)	(189		)	1,660			(1,079		)	—
Proceeds from issuance of common units	938			—			—			—			938
Proceeds from issuance of i-units	97			—			—			—			97
Contributions from noncontrolling interests	—			—			57			—			57
Distributions to partners and noncontrolling interests	(1,789		)	—			(2,160		)	2,136			(1,813		)
Other, net	(1		)	—			(1		)	—			(2		)
Net Cash (Used in) Provided by Financing Activities	(134		)	(189		)	(445		)	1,057			289
Effect of Exchange Rate Changes on Cash and Cash Equivalents	—			—			(4		)	—			(4		)
Net increase (decrease) in Cash and Cash Equivalents	18			(1		)	(158		)	—			(141		)
Cash and Cash Equivalents, beginning of period	10			1			393			—			404
Cash and Cash Equivalents, end of period	$	28		$	—		$	235		$	—		$	263
Condensed Consolidating Statements of Cash Flow for the Six Months ended June 30, 2013
(In Millions)
(Unaudited)
	Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
Net Cash Provided by Operating Activities	$	1,548		$	6		$	1,956		$	(1,768	)	$	1,742
Cash Flows From Investing Activities
Payment to KMI for March 2013 drop-down asset group	—			—			(994		)	—			(994		)
Acquisitions of assets and investments, net of cash acquired	—			5			(291		)	—			(286		)
Capital expenditures	—			(60		)	(1,208		)	—			(1,268		)
Proceeds from sale of investments in Express pipeline system	—			—			403			—			403
Contributions to investments	—			—			(93		)	—			(93		)
Distributions from equity investments in excess of cumulative earnings	—			—			36			—			36
Funding to affiliates	(3,690		)	(501		)	(1,234		)	5,425			—
Sale or casualty of property, plant and equipment, investments and other net assets, net of removal costs	—			—			23			—			23
Other, net	5			—			—			—			5
Net Cash Used in Investing Activities	(3,685		)	(556		)	(3,358		)	5,425			(2,174		)
Cash Flows From Financing Activities
Issuance of debt	4,844			—			14			—			4,858
Payment of debt	(3,100		)	(663		)	(97		)	—			(3,860		)
Debt issue costs	(11		)	—			—			—			(11		)
Funding from affiliates	832			1,214			3,379			(5,425		)	—
Proceeds from issuance of common units	834			—			—			—			834
Proceeds from issuance of i-units	73			—			—			—			73
Contributions from noncontrolling interests	—			—			99			—			99
Contributions from General Partner	38			—			—			—			38
Pre-acquisition contributions from KMI to March 2013 drop-down asset group	—			—			35			—			35
Distributions to partners and noncontrolling interests	(1,468		)	—			(1,787		)	1,768			(1,487		)
Net Cash Provided by Financing Activities	2,042			551			1,643			(3,657		)	579
Effect of Exchange Rate Changes on Cash and Cash Equivalents	—			—			(20		)	—			(20		)
Net (decrease) increase in Cash and Cash Equivalents	(95		)	1			221			—			127
Cash and Cash Equivalents, beginning of period	95			—			434			—			529
Cash and Cash Equivalents, end of period	$	—		$	1		$	655		$	—		$	656

General_Policies

General (Policies)	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Organization	'
	Organization
	KMEP is a Delaware limited partnership formed in August 1992.  We are a leading pipeline transportation and energy storage company in North America, with a diversified portfolio of energy transportation and storage assets. We own an interest in or operate approximately 52,000 miles of pipelines and 180 terminals, and we conduct our business through five reportable business segments (described further in Note 7). Our common units trade on the NYSE under the symbol “KMP.”
	Our pipelines transport natural gas, refined petroleum products, crude oil, condensate, CO2 and other products, and our terminals transport, transload and store petroleum products, ethanol and chemicals, and handle such products as coal, petroleum coke and steel. We are also the leading producer and transporter of CO2, for enhanced oil recovery projects in North America.
	KMI and Kinder Morgan G.P., Inc.
	KMI, a Delaware corporation, indirectly owns all the common stock of our general partner, Kinder Morgan G.P., Inc., a Delaware corporation. In July 2007, our general partner issued and sold to a third party 100,000 shares of Series A fixed-to-floating rate term cumulative preferred stock due 2057. The consent of holders of a majority of these preferred shares is required with respect to a commencement of or a filing of a voluntary bankruptcy proceeding with respect to us or two of our subsidiaries, SFPP and Calnev. KMI’s common stock trades on the NYSE under the symbol “KMI.”
	As of June 30, 2014, KMI and its consolidated subsidiaries owned, through KMI’s general and limited partner interests in us and its ownership of shares issued by its subsidiary KMR (discussed below), an approximate 11.4% interest in us. In addition, as of June 30, 2014, KMI owns a 39.6% limited partner interest and the 2% general partner interest in EPB.
	KMR
	KMR is a Delaware LLC. Our general partner owns all of KMR’s voting securities and, pursuant to a delegation of control agreement, has delegated to KMR, to the fullest extent permitted under Delaware law and our partnership agreement, all of its power and authority to manage and control our business and affairs, except that KMR cannot take certain specified actions without the approval of our general partner. Generally, KMR makes all decisions relating to the management and control of our business, and in general, KMR has a duty to manage us in a manner beneficial to KMEP. KMR’s shares representing LLC interests trade on the NYSE under the symbol “KMR.” As of June 30, 2014, KMR, through its sole ownership of our i-units, owned approximately 28.4% of all of our outstanding limited partner units (which are in the form of i-units that are issued only to KMR).
	More information about the entities referred to above and the delegation of control agreement is contained in our 2013 Form 10-K. For a more complete discussion of our related party transactions with the entities referred to above, including (i) the accounting for our general and administrative expenses; (ii) KMI’s operation and maintenance of the assets comprising our Natural Gas Pipelines business segment; and (iii) our partnership interests and distributions, see Note 11 “Related Party Transactions” to our consolidated financial statements included in our 2013 Form 10-K.
Basis of Presentation	'
	Basis of Presentation
	General
	Our reporting currency is in U.S. dollars, and all references to dollars are U.S. dollars, except where stated otherwise.  Our accompanying unaudited consolidated financial statements include our accounts, majority-owned and controlled subsidiaries, and have been prepared under the rules and regulations of the SEC. These rules and regulations conform to the accounting principles contained in the FASB’s Accounting Standards Codification, the single source of GAAP. Under such rules and regulations, all significant intercompany items have been eliminated in consolidation. Additionally, 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 2013 Form 10-K.
	Our financial statements are consolidated into the consolidated financial statements of KMI; however, except for the related party transactions described in Note 8 “Related Party Transactions—Asset Acquisitions and Sales,” KMI is not liable for, and its assets are not available to satisfy, our obligations and/or our subsidiaries’ obligations, and vice versa.  Responsibility for payments of obligations reflected in our or KMI’s financial statements is a legal determination based on the entity that incurs the liability. Furthermore, the determination of responsibility for payment among entities in our consolidated group of subsidiaries is not impacted by the consolidation of our financial statements into the consolidated financial statements of KMI.
	March 2013 KMI Asset Drop-Down
	Effective March 1, 2013, we acquired from KMI the remaining 50% ownership interest we did not already own in both EPNG and the EP midstream assets for an aggregate consideration of approximately $1.7 billion (including our proportional share of assumed debt borrowings as of March 1, 2013). In this report, we refer to this acquisition of assets from KMI as the March 2013 drop-down transaction; the combined group of assets acquired from KMI effective March 1, 2013 as the March 2013 drop-down asset group; and the EP midstream assets of Kinder Morgan Altamont LLC (formerly, El Paso Midstream Investment Company, L.L.C.) as the EP midstream assets. Prior to the March 2013 drop-down transaction, we accounted for our initial 50% ownership interests in both EPNG and the EP midstream assets under the equity method of accounting.
	KMI acquired all of the assets included in the March 2013 drop-down asset group as part of its May 25, 2012 acquisition of EP, and KMI accounted for its EP acquisition under the acquisition method of accounting. We, however, accounted for the March 2013 drop-down transaction as combinations of entities under common control. Accordingly, we prepared our consolidated financial statements to reflect the transfer of the March 2013 drop-down asset group from KMI to us as if such transfer had taken place on the date when the March 2013 drop-down asset group met the accounting requirements for entities under common control—May 25, 2012 for EPNG, and June 1, 2012 for the EP midstream assets.
	Additionally, because KMI both controls us and consolidates our financial statements into its consolidated financial statements as a result of its ownership of our general partner, we fully allocated to our general partner:
	▪	the earnings of the March 2013 drop-down asset group for the periods beginning on the effective dates of common control (described above) and ending March 1, 2013 (we refer to these earnings as “pre-acquisition” earnings and we reported these earnings separately as “Pre-acquisition income from operations of March 2013 drop-down asset group allocated to General Partner” within the “Calculation of Limited Partners’ Interest in Net Income Attributable to KMEP” section of our accompanying consolidated statement of income for the six months ended June 30, 2013); and
	▪	incremental severance expense related to KMI’s acquisition of EP and allocated to us from KMI. This severance expense allocated to us was associated with both the March 2013 drop-down asset group and assets we acquired pursuant to an earlier drop-down from KMI effective August 1, 2012; however, we do not have any obligation, nor did we pay any amounts related to this expense. Furthermore, we reported this expense separately as “Drop-down asset group’s severance expense allocated to General Partner” within the “Calculation of Limited Partners’ Interest in Net Income Attributable to KMEP” section of our accompanying consolidated statements of income for each of the three and six months ended June 30, 2014 and 2013.
	For all periods beginning after our acquisition date of March 1, 2013, we allocated our earnings (including the earnings from the March 2013 drop-down asset group) to all of our partners according to our partnership agreement.
	Goodwill
	We evaluate goodwill for impairment on May 31 of each year.  There were no impairment charges resulting from our May 31, 2014 impairment testing, and no event indicating an impairment has occurred subsequent to that date.
	Limited Partners’ Net Income per Unit
	We compute Limited Partners’ Net Income per Unit by dividing our limited partners’ interest in net income by the weighted average number of units outstanding during the period.
Earnings Per Share	'
	Limited Partners’ Net Income per Unit
	We compute Limited Partners’ Net Income per Unit by dividing our limited partners’ interest in net income by the weighted average number of units outstanding during the period.

Acquisitions_and_Discontinued_

Acquisitions and Discontinued Operations (Tables)	6 Months Ended
	Jun. 30, 2014
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]	'
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	'
	Acquisitions and Divestitures
	Acquisitions
	American Petroleum Tankers and State Class Tankers
	Effective January 17, 2014, we acquired APT and State Class Tankers (SCT) for aggregate consideration of $961 million in cash (the APT acquisition). APT is engaged in the marine transportation of crude oil, condensate and refined products in the U.S. domestic trade, commonly referred to as the Jones Act trade. APT’s primary assets consist of a fleet of five medium range Jones Act qualified product tankers, each with 330 MBbl of cargo capacity, and each operating pursuant to long-term time charters with high quality counterparties, including major integrated oil companies, major refiners and the U.S. Military Sealift Command. As of the closing date, the vessels’ time charters had an average remaining term of approximately four years, with renewal options to extend the terms by an average of two years. APT’s vessels are operated by Crowley Maritime Corporation.
	SCT has commissioned the construction of four medium range Jones Act qualified product tankers, each with 330 MBbl of cargo capacity. The SCT vessels are scheduled to be delivered in 2015 and 2016 and are being constructed by General Dynamics’ NASSCO shipyard. We expect to invest approximately $214 million to complete the construction of these four SCT vessels, and upon delivery, the vessels will be operated pursuant to long-term time charters with a major integrated oil company. Each of the time charters has an initial term of five years, with renewal options to extend the term by up to three years. Our APT acquisition complements and extends our existing crude oil and refined products transportation business, and all of the acquired assets are included in our Terminals business segment.
	As of June 30, 2014, our preliminary purchase price allocation related to our APT acquisition, as adjusted to date, is as follows (in millions). Our evaluation of the assigned fair values is ongoing and subject to adjustment.
	Purchase Price Allocation:
	Current assets	$	6
	Property, plant and equipment	951
	Goodwill	67
	Other assets	3
	Total assets acquired	1,027
	Current liabilities	(5		)
	Unfavorable customer contracts	(61		)
	Cash consideration	$	961
	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. We believe the goodwill was primarily generated by the value of the synergies created by expanding our non-pipeline liquids handling operations. Furthermore, we expect to fully deduct for tax purposes the entire amount of goodwill we recognized. The “Unfavorable customer contracts” figure represents the amount, on a present value basis, by which the customer contracts were below market day rates at the time of acquisition. This amount is amortized as a noncash adjustment to revenue over the remaining contract period.
	Other
	Effective May 1, 2013, we acquired all of Copano’s outstanding units for a total purchase price of approximately $5.2 billion (including assumed debt and all other assumed liabilities). The transaction was a 100% unit for unit transaction with an exchange ratio of 0.4563 of our common units for each Copano common unit. We issued 43,371,210 of our common units valued at $3,733 million as consideration for the Copano acquisition (based on the $86.08 closing market price of a common unit on the NYSE on the May 1, 2013 issuance date). Also, due to the fact that our Copano acquisition included the remaining 50% interest in Eagle Ford Gathering LLC that we did not already own, we remeasured our existing 50% equity investment in Eagle Ford to its fair value as of the acquisition date. As a result of our remeasurement, we recognized a $558 million non-cash gain, which represented the excess of the investment’s fair value ($704 million) over our carrying value as of May 1, 2013 ($146 million), and we reported this gain separately as “Gain on remeasurement of previously held equity interest in Eagle Ford Gathering to fair value” on our accompanying consolidated statements of income for the three and six months ended June 30, 2013.
	As of June 30, 2014, our purchase price allocation related to the Copano acquisition, is as follows (in millions):
	Purchase Price Allocation:
	Current assets (including cash acquired of $30)	$	218
	Property, plant and equipment	2,788
	Investments	300
	Goodwill	1,248
	Other intangibles	1,375
	Other assets	13
	Total assets	5,942
	Less: Fair value of previously held 50% interest in Eagle Ford Gathering LLC	(704		)
	Total assets acquired	5,238
	Current liabilities	(208		)
	Other liabilities	(28		)
	Long-term debt	(1,252		)
	Noncontrolling interests	(17		)
	Common unit consideration	$	3,733
	The table above reflects changes we made in the first six months of 2014 to our preliminary purchase price allocation as of December 31, 2013. Based on our final measurement of fair values for all of the identifiable tangible and intangible assets acquired and liabilities assumed on the acquisition date, we reduced the preliminary value assigned to (i) “Investments” by $87 million; (ii) “Property, plant and equipment” by $17 million; and (ii) combined working capital items by $3 million.
	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. We believe the primary items that generated the goodwill are the value of the synergies created by expanding our natural gas gathering and refined product transportation operations. This goodwill is not deductible for tax purposes, but 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. We are currently amortizing these intangible assets over an estimated remaining useful life of 25 years.
	Effective June 1, 2013, we acquired certain oil and gas properties, rights, and related assets located in the Goldsmith Landreth San Andres oil field unit in the Permian Basin of West Texas from Legado Resources LLC for an aggregate consideration of $298 million, consisting of $280 million in cash and assumed liabilities of $18 million (including $12 million of long-term asset retirement obligations).
	For additional information about our Copano and Goldsmith Landreth acquisitions (including our preliminary purchase price allocations as of December 31, 2013), see Note 3 “Acquisitions and Divestitures—Business Combinations and Acquisitions of Investments” to our consolidated financial statements included in our 2013 Form 10-K.
	Pro Forma Information
	The following summarized unaudited pro forma consolidated income statement information for the six months ended June 30, 2013 assumes that our acquisitions of (i) APT, (ii) Copano and (iii) the Goldsmith Landreth oil field unit had occurred as of January 1, 2013. We prepared the following summarized unaudited pro forma financial results for comparative purposes only. The summarized unaudited pro forma financial results may not be indicative of the results that would have occurred if we had completed these acquisitions as of January 1, 2013, or the results that will be attained in the future. Amounts presented below are in millions, except for the per unit amounts:
		Pro Forma
		Six Months Ended
		30-Jun-13
		(Unaudited)
	Revenues	$	6,432
	Income from Continuing Operations	1,766
	Loss from Discontinued Operations	(2		)
	Net Income	1,764
	Net Income Attributable to Noncontrolling Interests	(19		)
	Net Income Attributable to KMEP	$	1,745
	Limited Partners’ Net Income per Unit:
	Income from Continuing Operations	$	2.12
	Net Income	$	2.12
	Divestitures
	Express Pipeline System
	Effective March 14, 2013, we sold both our one-third equity ownership interest in the Express pipeline system and our subordinated debenture investment in Express to Spectra Energy Corp. We received net cash proceeds of $402 million (after paying $1 million in the third quarter of 2013 for both a final working capital settlement and certain
	transaction-related selling expenses), and we reported the $403 million proceeds received in the first half of 2013 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 six months ended June 30, 2013. Additionally, we recognized a combined $225 million pre-tax gain with respect to this sale in the first half of 2013, and we reported this gain amount separately as “Gain on sale of investments in Express pipeline system” on our accompanying consolidated statement of income for the six months ended June 30, 2013. We also recorded an income tax expense of $84 million related to this gain on sale for the six months ended June 30, 2013, and we included this expense within “Income Tax Expense.” As of the date of sale, our equity investment in Express totaled $67 million and our note receivable due from Express totaled $110 million.
Business Acquisition, Pro Forma Information [Table Text Block]	'
	Acquisitions
	American Petroleum Tankers and State Class Tankers
	Effective January 17, 2014, we acquired APT and State Class Tankers (SCT) for aggregate consideration of $961 million in cash (the APT acquisition). APT is engaged in the marine transportation of crude oil, condensate and refined products in the U.S. domestic trade, commonly referred to as the Jones Act trade. APT’s primary assets consist of a fleet of five medium range Jones Act qualified product tankers, each with 330 MBbl of cargo capacity, and each operating pursuant to long-term time charters with high quality counterparties, including major integrated oil companies, major refiners and the U.S. Military Sealift Command. As of the closing date, the vessels’ time charters had an average remaining term of approximately four years, with renewal options to extend the terms by an average of two years. APT’s vessels are operated by Crowley Maritime Corporation.
	SCT has commissioned the construction of four medium range Jones Act qualified product tankers, each with 330 MBbl of cargo capacity. The SCT vessels are scheduled to be delivered in 2015 and 2016 and are being constructed by General Dynamics’ NASSCO shipyard. We expect to invest approximately $214 million to complete the construction of these four SCT vessels, and upon delivery, the vessels will be operated pursuant to long-term time charters with a major integrated oil company. Each of the time charters has an initial term of five years, with renewal options to extend the term by up to three years. Our APT acquisition complements and extends our existing crude oil and refined products transportation business, and all of the acquired assets are included in our Terminals business segment.
	As of June 30, 2014, our preliminary purchase price allocation related to our APT acquisition, as adjusted to date, is as follows (in millions). Our evaluation of the assigned fair values is ongoing and subject to adjustment.
	Purchase Price Allocation:
	Current assets	$	6
	Property, plant and equipment	951
	Goodwill	67
	Other assets	3
	Total assets acquired	1,027
	Current liabilities	(5		)
	Unfavorable customer contracts	(61		)
	Cash consideration	$	961
	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. We believe the goodwill was primarily generated by the value of the synergies created by expanding our non-pipeline liquids handling operations. Furthermore, we expect to fully deduct for tax purposes the entire amount of goodwill we recognized. The “Unfavorable customer contracts” figure represents the amount, on a present value basis, by which the customer contracts were below market day rates at the time of acquisition. This amount is amortized as a noncash adjustment to revenue over the remaining contract period.
	Other
	Effective May 1, 2013, we acquired all of Copano’s outstanding units for a total purchase price of approximately $5.2 billion (including assumed debt and all other assumed liabilities). The transaction was a 100% unit for unit transaction with an exchange ratio of 0.4563 of our common units for each Copano common unit. We issued 43,371,210 of our common units valued at $3,733 million as consideration for the Copano acquisition (based on the $86.08 closing market price of a common unit on the NYSE on the May 1, 2013 issuance date). Also, due to the fact that our Copano acquisition included the remaining 50% interest in Eagle Ford Gathering LLC that we did not already own, we remeasured our existing 50% equity investment in Eagle Ford to its fair value as of the acquisition date. As a result of our remeasurement, we recognized a $558 million non-cash gain, which represented the excess of the investment’s fair value ($704 million) over our carrying value as of May 1, 2013 ($146 million), and we reported this gain separately as “Gain on remeasurement of previously held equity interest in Eagle Ford Gathering to fair value” on our accompanying consolidated statements of income for the three and six months ended June 30, 2013.
	As of June 30, 2014, our purchase price allocation related to the Copano acquisition, is as follows (in millions):
	Purchase Price Allocation:
	Current assets (including cash acquired of $30)	$	218
	Property, plant and equipment	2,788
	Investments	300
	Goodwill	1,248
	Other intangibles	1,375
	Other assets	13
	Total assets	5,942
	Less: Fair value of previously held 50% interest in Eagle Ford Gathering LLC	(704		)
	Total assets acquired	5,238
	Current liabilities	(208		)
	Other liabilities	(28		)
	Long-term debt	(1,252		)
	Noncontrolling interests	(17		)
	Common unit consideration	$	3,733
	The table above reflects changes we made in the first six months of 2014 to our preliminary purchase price allocation as of December 31, 2013. Based on our final measurement of fair values for all of the identifiable tangible and intangible assets acquired and liabilities assumed on the acquisition date, we reduced the preliminary value assigned to (i) “Investments” by $87 million; (ii) “Property, plant and equipment” by $17 million; and (ii) combined working capital items by $3 million.
	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. We believe the primary items that generated the goodwill are the value of the synergies created by expanding our natural gas gathering and refined product transportation operations. This goodwill is not deductible for tax purposes, but 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. We are currently amortizing these intangible assets over an estimated remaining useful life of 25 years.
	Effective June 1, 2013, we acquired certain oil and gas properties, rights, and related assets located in the Goldsmith Landreth San Andres oil field unit in the Permian Basin of West Texas from Legado Resources LLC for an aggregate consideration of $298 million, consisting of $280 million in cash and assumed liabilities of $18 million (including $12 million of long-term asset retirement obligations).
	For additional information about our Copano and Goldsmith Landreth acquisitions (including our preliminary purchase price allocations as of December 31, 2013), see Note 3 “Acquisitions and Divestitures—Business Combinations and Acquisitions of Investments” to our consolidated financial statements included in our 2013 Form 10-K.
	Pro Forma Information
	The following summarized unaudited pro forma consolidated income statement information for the six months ended June 30, 2013 assumes that our acquisitions of (i) APT, (ii) Copano and (iii) the Goldsmith Landreth oil field unit had occurred as of January 1, 2013. We prepared the following summarized unaudited pro forma financial results for comparative purposes only. The summarized unaudited pro forma financial results may not be indicative of the results that would have occurred if we had completed these acquisitions as of January 1, 2013, or the results that will be attained in the future. Amounts presented below are in millions, except for the per unit amounts:
		Pro Forma
		Six Months Ended
		30-Jun-13
		(Unaudited)
	Revenues	$	6,432
	Income from Continuing Operations	1,766
	Loss from Discontinued Operations	(2		)
	Net Income	1,764
	Net Income Attributable to Noncontrolling Interests	(19		)
	Net Income Attributable to KMEP	$	1,745
	Limited Partners’ Net Income per Unit:
	Income from Continuing Operations	$	2.12
	Net Income	$	2.12
Kinder Morgan Energy Partners, L.P. [Member] | American Petroleum Tankers and State Class Tankers [Member]	'
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed - APT [Table Text Block]	'
	Purchase Price Allocation:
	Current assets	$	6
	Property, plant and equipment	951
	Goodwill	67
	Other assets	3
	Total assets acquired	1,027
	Current liabilities	(5		)
	Unfavorable customer contracts	(61		)
	Cash consideration	$	961

Debt_Schedule_of_Debt_Tables

Debt Schedule of Debt (Tables)	6 Months Ended
	Jun. 30, 2014
Debt Instrument [Line Items]	'
Schedule of Long-term Debt Instruments [Table Text Block]	'
	We classify our debt based on the contractual maturity dates of the underlying debt instruments. We defer costs associated with debt issuance over the applicable term. These costs are then amortized as interest expense in our accompanying consolidated statements of income using the effective interest rate method. The following table provides detail on the principal amount of our outstanding debt as of June 30, 2014 and December 31, 2013. The table amounts exclude all debt fair value adjustments, including debt discounts and premiums (in millions).
		June 30,			December 31,
		2014			2013
	KMEP borrowings:
	Senior notes, 2.65% through 9.00%, due 2014 through 2044(a)	$	17,100		$	15,600
	Commercial paper borrowings(b)	513			979
	Credit facility due May 1, 2018(c)	—			—
	Subsidiary borrowings (as obligor):
	TGP - Senior Notes, 7.00% through 8.375%, due 2016 through 2037	1,790			1,790
	EPNG - Senior Notes, 5.95% through 8.625%, due 2017 through 2032	1,115			1,115
	Copano - Senior Notes, 7.125%, due April 1, 2021	332			332
	Other miscellaneous subsidiary debt	97			98
	Total debt	20,947			19,914
	Less: Current portion of debt(d)	(1,337		)	(1,504		)
	Total long-term debt(e)	$	19,610		$	18,410
	__________
	(a)	All of our fixed rate senior notes provide that we may redeem the notes at any time at a price equal to 100% of the principal amount of the notes plus accrued interest to the redemption date plus a make-whole premium.
	(b)	As of both June 30, 2014 and December 31, 2013, the average interest rate on our outstanding commercial paper borrowings was 0.28%. The borrowings under our commercial paper program were used principally to finance the acquisitions and capital expansions, and in the near term, we expect that our short-term liquidity and financing needs will be met primarily through borrowings made under our commercial paper program.
	(c)	See “—Credit Facilities” below.
	(d)	Amounts include outstanding commercial paper borrowings, discussed above in footnote (b).
	(e)	As of June 30, 2014 and December 31, 2013, our “Debt fair value adjustments” increased our debt balances by $1,267 million and $1,214 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—Debt Fair Value Adjustments.”
	The estimated fair value of our outstanding debt balance as of June 30, 2014 and December 31, 2013 (both short-term and long-term and including debt fair value adjustments), is disclosed below (in millions):
		June 30, 2014						December 31, 2013
		Carrying			Estimated			Carrying		Estimated
		Value			Fair value			Value		Fair value
	Total debt	$	22,214		$	23,450		$	21,128	$	21,550

Partners_Capital_Tables

Partners Capital (Tables)	6 Months Ended
	Jun. 30, 2014
Partners' Capital [Abstract]	'
Schedule of Distributions Made to Members or Limited Partners, by Distribution [Table Text Block]	'
	The following table provides information about our distributions for the three and six month periods ended June 30, 2014 and 2013 (in millions except per unit and i-unit distributions amounts):
		Three Months Ended June 30,				Six Months Ended June 30,
		2014		2013		2014		2013
	Per unit cash distribution declared for the period	$	1.39	$	1.32	$	2.77	$	2.62
	Per unit cash distribution paid in the period	$	1.38	$	1.3	$	2.74	$	2.59
	Cash distributions paid in the period to all partners(a)(b)	$	918	$	757	$	1,813	$	1,487
	i-unit distributions made in the period to KMR(c)	2,386,814		1,726,952		4,624,072		3,531,548
	General Partner’s incentive distribution(d):
	Declared for the period(e)	$	463	$	416	$	912	$	814
	Paid in the period(b)(c)(f)	$	449	$	398	$	894	$	782
	______________
	(a)	Consisting of our common and Class B unitholders, our general partner and noncontrolling interests.
	(b)	The period-to-period increases in distributions paid primarily reflect the increases in amounts distributed per unit as well as the issuance of additional units.
	(c)	Under the terms of our partnership agreement, we agreed that we will not, except in liquidation, make a distribution on an i-unit other than in additional i-units or a security that has in all material respects the same rights and privileges as our i-units.  The number of i-units we distribute to KMR is based upon the amount of cash we distribute to the owners of our common units. When cash is paid to the holders of our common units, we will issue additional i-units to KMR.  The fraction of an i-unit paid per i-unit owned by KMR will have a value based on the cash payment on the common units.  If additional units are distributed to the holders of our common units, we will issue an equivalent amount of i-units to KMR based on the number of i-units it owns. Based on the preceding, the i-units we distributed were based on the $1.38 and $1.30 per unit paid to our common unitholders during the second quarters of 2014 and 2013, respectively, and the $2.74 and $2.59 per unit paid to our common unitholders during the first six months of 2014 and 2013, respectively.
	(d)	Incentive distribution does not include the general partner’s initial 2% distribution of available cash.
	(e)	Amounts are net of waived incentive distributions of $33 million and $25 million for the three months ended June 30, 2014 and 2013, respectively, and $66 million and $29 million for the six months ended June 30, 2014 and 2013, respectively, related to certain acquisitions. In addition, our general partner agreed to waive a portion of our future incentive distributions amounts equal to $33 million and $34 million for our third and fourth quarters in 2014, respectively, $139 million for 2015, $116 million for 2016, $105 million for 2017, and annual amounts thereafter decreasing by $5 million per year from the 2017 level related to certain acquisitions.
	(f)	Amounts are net of waived incentive distributions of $33 million and $4 million for the three months ended June 30, 2014 and 2013, respectively, and $58 million and $11 million for the six months ended June 30, 2014 and 2013, respectively, related to certain acquisitions.

Risk_Management_Tables

Risk Management (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule of Derivative Instruments	'
	As of June 30, 2014, we had the following outstanding commodity forward contracts to hedge our forecasted energy commodity purchases and sales:
		Net open position long/(short)
	Derivatives designated as hedging contracts
	Crude oil fixed price	-24.2		MMBbl
	Natural gas fixed price	-26.1		Bcf
	Natural gas basis	-26.7		Bcf
	Derivatives not designated as hedging contracts
	Crude oil fixed price	-0.4		MMBbl
	Crude oil basis	-0.6		MMBbl
	Natural gas fixed price	-7.7		Bcf
	Natural gas basis	-0.1		Bcf
	NGL fixed price	-0.8		MMBbl
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	'
	The following table summarizes the fair values of our derivative contracts included on our accompanying consolidated balance sheets as of June 30, 2014 and December 31, 2013 (in millions):
	Fair Value of Derivative Contracts
				Asset derivatives								Liability derivatives
				June 30,				December 31,				June 30,				December 31,
				2014				2013				2014				2013
		Balance sheet location		Fair value				Fair value				Fair value				Fair value
	Derivatives designated as hedging contracts
	Energy commodity derivative contracts	Other current assets/(Other current liabilities)		$	6			$	18			$	(97	)		$	(33	)
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		4				58				(72		)		(30		)
	Subtotal			10				76				(169		)		(63		)
	Interest rate swap agreements	Other current assets/(Other current liabilities)		79				76				—				—
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		192				141				(46		)		(116		)
	Subtotal			271				217				(46		)		(116		)
	Total			281				293				(215		)		(179		)
	Derivatives not designated as hedging contracts
	Energy commodity derivative contracts	Other current assets/(Other current liabilities)		4				4				(10		)		(5		)
	Total			4				4				(10		)		(5		)
	Total derivatives			$	285			$	297			$	(225	)		$	(184	)
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance	'
	The following three tables summarize the impact of our derivative contracts on our accompanying consolidated statements of income for each of the three and six months ended June 30, 2014 and 2013 (in millions):
	Derivatives in fair value hedging		Location of gain/(loss) recognized		Amount of gain/(loss) recognized in income
	relationships		in income on derivatives		on derivatives and related hedged item(a)
					Three Months Ended June 30,								Six Months Ended June 30,
					2014				2013				2014				2013
	Interest rate swap agreements		Interest expense		$	63			$	(211	)		$	124			$	(294	)
	Total				$	63			$	(211	)		$	124			$	(294	)
	Fixed rate debt		Interest expense		$	(63	)		$	211			$	(124	)		$	294
	Total				$	(63	)		$	211			$	(124	)		$	294
	______________
	(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 in		Amount of gain/(loss)								Location of		Amount of gain/(loss)							Location of	Amount of gain/(loss)
	cash flow hedging		recognized in other								gain/(loss)		reclassified from							gain/(loss)	recognized in income
	relationships		comprehensive income on								reclassified from		Accumulated other							recognized in	on derivative
			derivative (effective								Accumulated		comprehensive income							income on	(ineffective portion
			portion)(a)								other		into income							derivative	and amount
											comprehensive income		(effective portion)(b)							(ineffective portion	excluded from
											into income									and amount	effectiveness testing)
											(effective portion)									excluded from
																				effectiveness
																				testing)
			Three Months Ended June 30,										Three Months Ended June 30,								Three Months Ended June 30,
			2014				2013						2014				2013				2014			2013
	Energy commodity derivative contracts		$	(113	)		$	70			Revenues-Natural gas sales		$	(2	)		$	—		Revenues-Natural gas sales	$	—		$	—
											Revenues-Product sales and other		(23		)		8			Revenues-Product sales and other	(27		)	9
											Costs of sales		7				(5		)	Costs of sales	—			—
	Total		$	(113	)		$	70			Total		$	(18	)		$	3		Total	$	(27	)	$	9
			Six Months Ended June 30,										Six Months Ended June 30,								Six Months Ended June 30,
			2014				2013						2014				2013				2014			2013
	Energy commodity derivative contracts		$	(169	)		$	29			Revenues-Natural gas sales		$	(12	)		$	—		Revenues-Natural gas sales	$	—		$	—
											Revenues-Product sales and other		(32		)		15			Revenues-Product sales and other	(32		)	6
											Costs of sales		8				(5		)	Costs of sales	—			—
	Total		$	(169	)		$	29			Total		$	(36	)		$	10		Total	$	(32	)	$	6
	______________
	(a)	We expect to reclassify an approximate $71 million loss associated with energy commodity price risk management activities included in our Partners’ Capital as of June 30, 2014 into earnings during the next twelve months (when the associated forecasted sales and purchases are also expected to occur); however, actual amounts reclassified into earnings could vary materially as a result of changes in market prices.
	(b)	Amounts reclassified were the result of the hedged forecasted transactions actually affecting earnings (i.e., when the forecasted sales and purchases actually occurred).
	Derivatives not designated		Location of gain/(loss) recognized		Amount of gain/(loss) recognized in income on derivatives
	as accounting hedges		in income on derivatives		Three Months Ended June 30,								Six Months Ended June 30,
					2014				2013				2014				2013
	Energy commodity derivative contracts		Revenues-Natural gas sales		$	(9	)		$	—			$	(16	)		$	—
			Revenues-Product sales and other		6				(1		)		(1		)		3
			Costs of sales		(3		)		(1		)		7				(1		)
			Other expense (income)		—				—				(2		)		—
	Total				$	(6	)		$	(2	)		$	(12	)		$	2
Amounts reclassified out of comprehensive income [Table Text Block]	'
	Changes in the components of our “Accumulated other comprehensive (loss) income” for each of the six months ended June 30, 2014 and 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 adjs.				income/(loss)
	Balance as of December 31, 2013	$	24			$	(4	)		$	13			$	33
	Other comprehensive (loss) income before reclassifications	(169		)		(7		)		(3		)		(179		)
	Amounts reclassified from accumulated other comprehensive income	36				—				—				36
	Net current-period other comprehensive (loss) income	(133		)		(7		)		(3		)		(143		)
	Balance as of June 30, 2014	$	(109	)		$	(11	)		$	10			$	(110	)
		Net unrealized				Foreign				Pension and				Total
		gains/(losses)				currency				other				Accumulated other
		on cash flow				translation				postretirement				comprehensive
		hedge derivatives				adjustments				liability adjs.				income/(loss)
	Balance as of December 31, 2012	$	66			$	132			$	(30	)		$	168
	Other comprehensive (loss) income before reclassifications	30				(114		)		1				(83		)
	Amounts reclassified from accumulated other comprehensive income	(10		)		—				—				(10		)
	Net current-period other comprehensive (loss) income	20				(114		)		1				(93		)
	Balance as of June 30, 2013	$	86			$	18			$	(29	)		$	75

Fair_Value_Tables

Fair Value (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	'
	The following two tables summarize the fair value measurements of our (i) energy commodity derivative contracts; and (ii) interest rate swap agreements as of June 30, 2014 and December 31, 2013, based on the three levels established by the Codification. Also, certain of our derivative contracts are subject to master netting agreements. The following tables present our derivative contracts subject to such netting agreements as of June 30, 2014 and December 31, 2013 (in millions):
		Balance Sheet asset												Amounts not offset in the Balance Sheet					Net Amount
		fair value measurements using
		Level 1			Level 2			Level 3			Gross Amount			Financial Instruments			Cash Collateral Held(b)
	As of June 30, 2014
	Energy commodity derivative contracts(a)	$	3		$	7		$	4		$	14		$	(12	)	$	—	$	2
	Interest rate swap agreements	$	—		$	271		$	—		$	271		$	(22	)	$	—	$	249
	As of December 31, 2013
	Energy commodity derivative contracts(a)	$	4		$	46		$	30		$	80		$	(44	)	$	—	$	36
	Interest rate swap agreements	$	—		$	217		$	—		$	217		$	(28	)	$	—	$	189
		Balance Sheet liability												Amounts not offset in the Balance Sheet					Net Amount
		fair value measurements using
		Level 1			Level 2			Level 3			Gross Amount			Financial Instruments			Cash Collateral Posted(c)
	As of June 30, 2014
	Energy commodity derivative contracts(a)	$	(10	)	$	(134	)	$	(35	)	$	(179	)	$	12		$	17	$	(150	)
	Interest rate swap agreements	$	—		$	(46	)	$	—		$	(46	)	$	22		$	—	$	(24	)
	As of December 31, 2013
	Energy commodity derivative contracts(a)	$	(6	)	$	(31	)	$	(31	)	$	(68	)	$	44		$	17	$	(7	)
	Interest rate swap agreements	$	—		$	(116	)	$	—		$	(116	)	$	28		$	—	$	(88	)
	______________
	(a)	Level 1 consists primarily of New York Mercantile Exchange natural gas futures. Level 2 consists primarily of OTC WTI swaps. Level 3 consists primarily of WTI options and NGL options.
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 six months ended June 30, 2014 and 2013 (in millions):
	Significant unobservable inputs (Level 3)
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
	Derivatives-net asset (liability)
	Beginning of Period	$	(3	)	$	3		$	(1	)	$	3
	Total gains or (losses):
	Included in earnings	(19		)	—			(18		)	6
	Included in other comprehensive income (loss)	(9		)	1			(10		)	—
	Purchases(a)	—			18			—			18
	Settlements	—			(4		)	(2		)	(9		)
	End of Period	$	(31	)	$	18		$	(31	)	$	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	)	$	1		$	(16	)	$	5
	______________
	(a)	Three and six month 2013 amounts represent the purchase of Level 3 energy commodity derivative contracts associated with our May 1, 2013 Copano acquisition
Fair Value, by Balance Sheet Grouping	'
	We classify our debt based on the contractual maturity dates of the underlying debt instruments. We defer costs associated with debt issuance over the applicable term. These costs are then amortized as interest expense in our accompanying consolidated statements of income using the effective interest rate method. The following table provides detail on the principal amount of our outstanding debt as of June 30, 2014 and December 31, 2013. The table amounts exclude all debt fair value adjustments, including debt discounts and premiums (in millions).
		June 30,			December 31,
		2014			2013
	KMEP borrowings:
	Senior notes, 2.65% through 9.00%, due 2014 through 2044(a)	$	17,100		$	15,600
	Commercial paper borrowings(b)	513			979
	Credit facility due May 1, 2018(c)	—			—
	Subsidiary borrowings (as obligor):
	TGP - Senior Notes, 7.00% through 8.375%, due 2016 through 2037	1,790			1,790
	EPNG - Senior Notes, 5.95% through 8.625%, due 2017 through 2032	1,115			1,115
	Copano - Senior Notes, 7.125%, due April 1, 2021	332			332
	Other miscellaneous subsidiary debt	97			98
	Total debt	20,947			19,914
	Less: Current portion of debt(d)	(1,337		)	(1,504		)
	Total long-term debt(e)	$	19,610		$	18,410
	__________
	(a)	All of our fixed rate senior notes provide that we may redeem the notes at any time at a price equal to 100% of the principal amount of the notes plus accrued interest to the redemption date plus a make-whole premium.
	(b)	As of both June 30, 2014 and December 31, 2013, the average interest rate on our outstanding commercial paper borrowings was 0.28%. The borrowings under our commercial paper program were used principally to finance the acquisitions and capital expansions, and in the near term, we expect that our short-term liquidity and financing needs will be met primarily through borrowings made under our commercial paper program.
	(c)	See “—Credit Facilities” below.
	(d)	Amounts include outstanding commercial paper borrowings, discussed above in footnote (b).
	(e)	As of June 30, 2014 and December 31, 2013, our “Debt fair value adjustments” increased our debt balances by $1,267 million and $1,214 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—Debt Fair Value Adjustments.”
	The estimated fair value of our outstanding debt balance as of June 30, 2014 and December 31, 2013 (both short-term and long-term and including debt fair value adjustments), is disclosed below (in millions):
		June 30, 2014						December 31, 2013
		Carrying			Estimated			Carrying			Estimated
		Value			Fair value			Value			Fair value
	Total debt	$	22,214		$	23,450		$	21,128		$	21,550

Reportable_Segments_Tables

Reportable Segments (Tables)	6 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
Schedule of Segment Reporting Information, by Segment	'
	Financial information by segment follows (in millions):
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
	Revenues
	Natural Gas Pipelines
	Revenues from external customers	$	2,111		$	1,696		$	4,286		$	3,065
	Intersegment revenues	1			—			2			—
	CO2	454			460			937			889
	Products Pipelines	524			443			1,058			897
	Terminals
	Revenues from external customers	420			343			$	811		$	680
	Intersegment revenues	1			1			1			1
	Kinder Morgan Canada	68			75			137			147
	Total segment revenues	3,579			3,018			7,232			5,679
	Less: Total intersegment revenues	(2		)	(1		)	(3		)	(1		)
	Total consolidated revenues	$	3,577		$	3,017		$	7,229		$	5,678
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
	Segment EBDA(a)
	Natural Gas Pipelines(b)	$	639		$	1,123		$	1,358		$	1,680
	CO2	332			358			695			700
	Products Pipelines(c)	203			12			411			197
	Terminals	233			207			447			393
	Kinder Morgan Canada(d)	40			50			88			243
	Segment EBDA	1,447			1,750			2,999			3,213
	Total segment DD&A expense	(406		)	(357		)	(807		)	(685		)
	Total segment amortization of excess cost of investments	(5		)	(2		)	(8		)	(4		)
	General and administrative expense	(132		)	(163		)	(285		)	(297		)
	Interest expense, net of unallocable interest income	(231		)	(215		)	(470		)	(417		)
	Unallocable income tax expense	(4		)	(3		)	(6		)	(6		)
	Loss from discontinued operations	—			—			—			(2		)
	Total consolidated net income	$	669		$	1,010		$	1,423		$	1,802
		June 30,			December 31,
		2014			2013
	Assets
	Natural Gas Pipelines	$	25,704		$	25,721
	CO2	3,039			2,954
	Products Pipelines	5,782			5,488
	Terminals	7,592			6,124
	Kinder Morgan Canada	1,690			1,678
	Total segment assets	43,807			41,965
	Corporate assets(e)	744			799
	Total consolidated assets	$	44,551		$	42,764
	______________
	(a)	Includes revenues, earnings from equity investments, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other income, net. Operating expenses include natural gas purchases and other costs of sales, operations and maintenance expenses, and taxes, other than income taxes.
	(b)	Three and six month 2013 amounts include a $558 million non-cash gain from the remeasurement of our previously held equity interest in Eagle Ford Gathering to fair value (discussed further in Note 2 “Acquisitions and Divestitures—Acquisitions—Other”).
	(c)	Three and six month 2013 amounts include increases in operating expense of $162 million and $177 million, respectively, associated with adjustments to legal liabilities related to both transportation rate case and environmental matters.
	(d)	Six month 2013 amount includes a $141 million increase in earnings from the after-tax gain on the sale of our investments in the Express pipeline system.
	(e)	Includes cash and cash equivalents; margin and restricted deposits; unallocable interest receivable, prepaid assets and deferred charges; and risk management assets related to debt fair value adjustments.

Guarantee_of_Securities_of_Sub1

Guarantee of Securities of Subsidiaries (Tables)	6 Months Ended
	Jun. 30, 2014
Guarantees [Abstract]	'
Condensed Balance Sheet [Table Text Block]	'
	Condensed Consolidating Balance Sheets as of June 30, 2014
	(In Millions)
	(Unaudited)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
	ASSETS
	Cash and cash equivalents	$	28		$	—		$	235		$	—		$	263
	All other current assets	3,433			7			2,165			(3,348		)	2,257
	Property, plant and equipment, net	—			15			29,270			—			29,285
	Investments	—			—			2,193			—			2,193
	Investments in subsidiaries	14,017			4,434			—			(18,451		)	—
	Goodwill	—			920			5,801			—			6,721
	Notes receivable from affiliates	18,279			—			—			(18,279		)	—
	Other non-current assets	290			—			3,542			—			3,832
	Total Assets	$	36,047		$	5,376		$	43,206		$	(40,078	)	$	44,551
	LIABILITIES AND PARTNERS’ CAPITAL
	Liabilities
	Current portion of debt	$	1,337		$	—		$	—		$	—		$	1,337
	All other current liabilities	355			137			6,057			(3,348		)	3,201
	Total long-term debt	16,931			389			3,557			—			20,877
	Notes payable to affiliates	—			765			17,514			(18,279		)	—
	Deferred income taxes	—			2			295			—			297
	Other long-term liabilities and deferred credits	107			2			945			—			1,054
	Total Liabilities	18,730			1,295			28,368			(21,627		)	26,766
	Partners’ Capital
	Total KMEP Partners’ Capital	17,317			4,081			14,370			(18,451		)	17,317
	Noncontrolling interests	—			—			468			—			468
	Total Partners’ Capital	17,317			4,081			14,838			(18,451		)	17,785
	Total Liabilities and Partners’ Capital	$	36,047		$	5,376		$	43,206		$	(40,078	)	$	44,551
	Condensed Consolidating Balance Sheets as of December 31, 2013
	(In Millions)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
	ASSETS
	Cash and cash equivalents	$	10		$	1		$	393		$	—		$	404
	All other current assets	3,071			13			2,151			(2,971		)	2,264
	Property, plant and equipment, net	—			170			27,235			—			27,405
	Investments	—			—			2,233			—			2,233
	Investments in subsidiaries	13,931			4,430			—			(18,361		)	—
	Goodwill	—			813			5,734			—			6,547
	Notes receivable from affiliates	17,284			—			—			(17,284		)	—
	Other non-current assets	233			—			3,678			—			3,911
	Total Assets	$	34,529		$	5,427		$	41,424		$	(38,616	)	$	42,764
	LIABILITIES AND PARTNERS’ CAPITAL
	Liabilities
	Current portion of debt	$	1,504		$	—		$	—		$	—		$	1,504
	All other current liabilities	407			107			5,530			(2,971		)	3,073
	Total long-term debt	15,644			393			3,587			—			19,624
	Notes payable to affiliates	—			907			16,377			(17,284		)	—
	Deferred income taxes	—			2			283			—			285
	Other long-term liabilities and deferred credits	173			—			884			—			1,057
	Total Liabilities	17,728			1,409			26,661			(20,255		)	25,543
	Partners’ Capital
	Total KMEP Partners’ Capital	16,801			4,018			14,343			(18,361		)	16,801
	Noncontrolling interests	—			—			420			—			420
	Total Partners’ Capital	16,801			4,018			14,763			(18,361		)	17,221
	Total Liabilities and Partners’ Capital	$	34,529		$	5,427		$	41,424		$	(38,616	)	$	42,764
Condensed Income Statement [Table Text Block]	'
	Condensed Consolidating Statements of Income and Comprehensive Income
	for the Three Months ended June 30, 2014
	(In Millions)
	(Unaudited)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
	Total Revenues	$	—		$	—		$	3,577		$	—		$	3,577
	Operating Costs, Expenses and Other
	Costs of sales	—			—			1,602			—			1,602
	Depreciation, depletion and amortization	—			—			406			—			406
	Other operating expenses	—			8			706			—			714
	Total Operating Costs, Expenses and Other	—			8			2,714			—			2,722
	Operating (Loss) Income	—			(8		)	863			—			855
	Other Income (Expense), Net	663			45			(160		)	(710		)	(162		)
	Income Before Income Taxes	663			37			703			(710		)	693
	Income Tax Expense	(2		)	—			(22		)	—			(24		)
	Net Income	661			37			681			(710		)	669
	Net Income Attributable to Noncontrolling Interests	—			—			(8		)	—			(8		)
	Net Income Attributable to KMEP	$	661		$	37		$	673		$	(710	)	$	661
	Net Income	$	661		$	37		$	681		$	(710	)	$	669
	Total Other Comprehensive (Loss)	(25		)	—			(25		)	25			(25		)
	Comprehensive Income	636			37			656			(685		)	644
	Comprehensive Income Attributable to Noncontrolling Interests	—			—			(8		)	—			(8		)
	Comprehensive Income Attributable to KMEP	$	636		$	37		$	648		$	(685	)	$	636
	Condensed Consolidating Statements of Income and Comprehensive Income
	for the Three Months ended June 30, 2013
	(In Millions)
	(Unaudited)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
	Total Revenues	$	—		$	—		$	3,017		$	—		$	3,017
	Operating Costs, Expenses and Other
	Costs of sales	—			—			1,248			—			1,248
	Depreciation, depletion and amortization	—			2			355			—			357
	Other operating expenses	—			26			785			—			811
	Total Operating Costs, Expenses and Other	—			28			2,388			—			2,416
	Operating (Loss) Income	—			(28		)	629			—			601
	Other Income, Net	1,004			35			435			(1,039		)	435
	Income Before Income Taxes	1,004			7			1,064			(1,039		)	1,036
	Income Tax Expense	(4		)	—			(22		)	—			(26		)
	Net Income	1,000			7			1,042			(1,039		)	1,010
	Net Income Attributable to Noncontrolling Interests	—			—			(10		)	—			(10		)
	Net Income Attributable to KMEP	$	1,000		$	7		$	1,032		$	(1,039	)	$	1,000
	Net Income	$	1,000		$	7		$	1,042		$	(1,039	)	$	1,010
	Total Other Comprehensive (Loss)	(4		)	—			(4		)	4			(4		)
	Comprehensive Income	996			7			1,038			(1,035		)	1,006
	Comprehensive Income Attributable to Noncontrolling Interests	—			—			(10		)	—			(10		)
	Comprehensive Income Attributable to KMEP	$	996		$	7		$	1,028		$	(1,035	)	$	996
	Condensed Consolidating Statements of Income and Comprehensive Income
	for the Six Months ended June 30, 2014
	(In Millions)
	(Unaudited)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
	Total Revenues	$	—		$	—		$	7,229		$	—		$	7,229
	Operating Costs, Expenses and Other
	Costs of sales	—			—			3,240			—			3,240
	Depreciation, depletion and amortization	—			—			807			—			807
	Other operating expenses	—			15			1,379			—			1,394
	Total Operating Costs, Expenses and Other	—			15			5,426			—			5,441
	Operating (Loss) Income	—			(15		)	1,803			—			1,788
	Other Income (Expense), Net	1,412			78			(323		)	(1,492		)	(325		)
	Income Before Income Taxes	1,412			63			1,480			(1,492		)	1,463
	Income Tax Expense	(5		)	—			(35		)	—			(40		)
	Net Income	1,407			63			1,445			(1,492		)	1,423
	Net Income Attributable to Noncontrolling Interests	—			—			(16		)	—			(16		)
Net Income Attributable to KMEP	$	1,407		$	63		$	1,429		$	(1,492	)	$	1,407
Net Income	$	1,407		$	63		$	1,445		$	(1,492	)	$	1,423
Total Other Comprehensive (Loss)	(143		)	—			(144		)	143			(144		)
Comprehensive Income	1,264			63			1,301			(1,349		)	1,279
Comprehensive Income Attributable to Noncontrolling Interests	—			—			(15		)	—			(15		)
Comprehensive Income Attributable to KMEP	$	1,264		$	63		$	1,286		$	(1,349	)	$	1,264
Condensed Consolidating Statements of Income and Comprehensive Income
for the Six Months ended June 30, 2013
(In Millions)
(Unaudited)
	Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
Total Revenues	$	—		$	—		$	5,678		$	—		$	5,678
Operating Costs, Expenses and Other
Costs of sales	—			—			2,205			—			2,205
Depreciation, depletion and amortization	—			2			683			—			685
Other operating expenses	—			26			1,377			—			1,403
Total Operating Costs, Expenses and Other	—			28			4,265			—			4,293
Operating (Loss) Income	—			(28		)	1,413			—			1,385
Other Income, Net	1,789			35			537			(1,815		)	546
Income from Continuing Operations Before Income Taxes	1,789			7			1,950			(1,815		)	1,931
Income Tax Expense	(6		)	—			(121		)	—			(127		)
Income from Continuing Operations	1,783			7			1,829			(1,815		)	1,804
Loss from Discontinued Operations	—			—			(2		)	—			(2		)
Net Income	1,783			7			1,827			(1,815		)	1,802
Net Income Attributable to Noncontrolling Interests	—			—			(19		)	—			(19		)
Net Income Attributable to KMEP	$	1,783		$	7		$	1,808		$	(1,815	)	$	1,783
Net Income	$	1,783		$	7		$	1,827		$	(1,815	)	$	1,802
Total Other Comprehensive (Loss)	(93		)	—			(94		)	93			(94		)
Comprehensive Income	1,690			7			1,733			(1,722		)	1,708
Comprehensive Income Attributable to Noncontrolling Interests	—			—			(18		)	—			(18		)
Comprehensive Income Attributable to KMEP	$	1,690		$	7		$	1,715		$	(1,722	)	$	1,690
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]	'
	Condensed Consolidating Statements of Cash Flow for the Six Months ended June 30, 2014
	(In Millions)
	(Unaudited)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
	Net Cash Provided by (Used in) Operating Activities	$	1,723		$	(29	)	$	2,691		$	(2,136	)	$	2,249
	Cash Flows From Investing Activities
	Acquisitions of assets and investments, net of cash acquired	—			—			(993		)	—			(993		)
	Capital expenditures	—			(47		)	(1,803		)	192			(1,658		)
	Contributions to investments	—			—			(89		)	—			(89		)
	Distributions from equity investments in excess of cumulative earnings	—			—			37			—			37
	Funding (to) from affiliates	(1,571		)	72			420			1,079			—
	Natural gas storage and natural gas and liquids line-fill	—			—			22			—			22
	Sale, casualty and transfer of property, plant and equipment, investments and other net assets, net of removal costs	—			192			11			(192		)	11
	Other, net	—			—			(5		)	—			(5		)
	Net Cash (Used in) Provided by Investing Activities	(1,571		)	217			(2,400		)	1,079			(2,675		)
	Cash Flows From Financing Activities
	Issuance of debt	6,083			—			—			—			6,083
	Payment of debt	(5,059		)	—			(1		)	—			(5,060		)
	Debt issue costs	(11		)	—			—			—			(11		)
	Funding (to) from affiliates	(392		)	(189		)	1,660			(1,079		)	—
	Proceeds from issuance of common units	938			—			—			—			938
	Proceeds from issuance of i-units	97			—			—			—			97
	Contributions from noncontrolling interests	—			—			57			—			57
	Distributions to partners and noncontrolling interests	(1,789		)	—			(2,160		)	2,136			(1,813		)
	Other, net	(1		)	—			(1		)	—			(2		)
	Net Cash (Used in) Provided by Financing Activities	(134		)	(189		)	(445		)	1,057			289
	Effect of Exchange Rate Changes on Cash and Cash Equivalents	—			—			(4		)	—			(4		)
	Net increase (decrease) in Cash and Cash Equivalents	18			(1		)	(158		)	—			(141		)
	Cash and Cash Equivalents, beginning of period	10			1			393			—			404
	Cash and Cash Equivalents, end of period	$	28		$	—		$	235		$	—		$	263
	Condensed Consolidating Statements of Cash Flow for the Six Months ended June 30, 2013
	(In Millions)
	(Unaudited)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMP
	Net Cash Provided by Operating Activities	$	1,548		$	6		$	1,956		$	(1,768	)	$	1,742
	Cash Flows From Investing Activities
	Payment to KMI for March 2013 drop-down asset group	—			—			(994		)	—			(994		)
	Acquisitions of assets and investments, net of cash acquired	—			5			(291		)	—			(286		)
	Capital expenditures	—			(60		)	(1,208		)	—			(1,268		)
	Proceeds from sale of investments in Express pipeline system	—			—			403			—			403
	Contributions to investments	—			—			(93		)	—			(93		)
	Distributions from equity investments in excess of cumulative earnings	—			—			36			—			36
	Funding to affiliates	(3,690		)	(501		)	(1,234		)	5,425			—
	Sale or casualty of property, plant and equipment, investments and other net assets, net of removal costs	—			—			23			—			23
	Other, net	5			—			—			—			5
	Net Cash Used in Investing Activities	(3,685		)	(556		)	(3,358		)	5,425			(2,174		)
	Cash Flows From Financing Activities
	Issuance of debt	4,844			—			14			—			4,858
	Payment of debt	(3,100		)	(663		)	(97		)	—			(3,860		)
	Debt issue costs	(11		)	—			—			—			(11		)
	Funding from affiliates	832			1,214			3,379			(5,425		)	—
	Proceeds from issuance of common units	834			—			—			—			834
	Proceeds from issuance of i-units	73			—			—			—			73
	Contributions from noncontrolling interests	—			—			99			—			99
	Contributions from General Partner	38			—			—			—			38
	Pre-acquisition contributions from KMI to March 2013 drop-down asset group	—			—			35			—			35
	Distributions to partners and noncontrolling interests	(1,468		)	—			(1,787		)	1,768			(1,487		)
	Net Cash Provided by Financing Activities	2,042			551			1,643			(3,657		)	579
	Effect of Exchange Rate Changes on Cash and Cash Equivalents	—			—			(20		)	—			(20		)
	Net (decrease) increase in Cash and Cash Equivalents	(95		)	1			221			—			127
	Cash and Cash Equivalents, beginning of period	95			—			434			—			529
	Cash and Cash Equivalents, end of period	$	—		$	1		$	655		$	—		$	656

General_Details

General (Details) (USD $)	6 Months Ended				6 Months Ended
In Billions, unless otherwise specified	Jun. 30, 2014	Mar. 01, 2013	Mar. 01, 2013	Aug. 01, 2012	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014
	segment	EPNG and EP Midstream [Member]	EPNG [Member]	El Paso Natural Gas Company and El Paso Midstream Investment Company LLC [Member]	El Paso LLC [Member]	Kinder Morgan Management, LLC [Member]	Kinder Morgan Energy Partners, L.P. [Member]
	mi						Kinder Morgan, Inc. [Member]
Schedule of Equity Method Investments [Line Items]	'	'	'	'	'	'	'
Miles of pipe	52,000	'	'	'	'	'	'
Number of pipeline terminals owned interest in and or operated	180	'	'	'	'	'	'
Number of Reportable Segments	5	'	'	'	'	'	'
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	'	'	'	'	'	28.40%	11.40%
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	'	'	'	'	39.60%	'	'
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	'	'	'	'	2.00%	'	'
Business Acquisition, Percent Acquired	'	50.00%	'	'	'	'	'
Business Acquisition, Transaction Costs	'	'	$1.70	'	'	'	'
Ownership interest	'	'	'	50.00%	'	'	'

Acquisitions_and_Discontinued_1

Acquisitions and Discontinued Operations Acquisitions (Details) (USD $)

6 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

6 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Jan. 17, 2014

Jun. 30, 2014

Jan. 17, 2014

Jun. 30, 2014

3-May-13

Jun. 30, 2014

1-May-13

Jan. 17, 2014

Jun. 30, 2014

Jun. 02, 2013

31-May-13

3-May-13

1-May-13

1-May-13

3-May-13

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]

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]

Common Units [Member]

Common Units [Member]

Eagle Ford Gathering LLC [Member]

Other Income (Expense) [Member]

American Petroleum Tankers and State Class Tankers [Member]

American Petroleum Tankers and State Class Tankers [Member]

American Petroleum Tankers [Member]

American Petroleum Tankers [Member]

Copano Energy, LLC [Member]

Copano Energy, LLC [Member]

Copano Energy, LLC [Member]

Dynamics NASSCO shipyard [Member]

Dynamics NASSCO shipyard [Member]

Legado Resources [Member]

Legado Resources [Member]

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

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

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

Eagle Ford Gathering LLC [Member]

MMBbls

State Class Tankers [Member]

State Class Tankers [Member]

Goldsmith-Landreth Field Unit [Member]

Goldsmith-Landreth Field Unit [Member]

Copano Energy, LLC [Member]

Copano Energy, LLC [Member]

Copano Energy, LLC [Member]

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

MMBbls

Copano Energy, LLC [Member]

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payments to Acquire Businesses, Gross

'

'

'

'

$961,000,000

'

'

'

'

'

'

'

'

$280,000,000

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

Number of Vessels

'

'

'

'

'

'

'

5

'

'

'

'

4

'

'

'

'

'

'

Tanker Capacity

'

'

'

'

'

'

330,000,000

'

'

'

'

330,000,000

'

'

'

'

'

'

'

Capital expenditures

-1,658,000,000

-1,268,000,000

'

'

'

'

'

'

'

'

'

-214,000,000

'

'

'

'

'

'

'

Business Combination, Consideration Transferred

'

'

'

'

'

'

'

'

5,200,000,000

'

'

'

'

'

'

'

'

'

'

Business acquisition, unit exchange ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.4563

'

'

Common Units Issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

43,371,210

'

'

'

Business Acquisition, Equity Interest Issued or Issuable, Value Assigned

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,733,000,000

'

'

'

Business Acquisition, Share Price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$86.08

'

'

Business Acquisition, Percentage of Voting Interests Acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

Business Combination, Step Acquisition, Equity Interest in Acquiree, Remeasurement Gain (Loss), Net

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

558,000,000

(Gain) loss from the remeasurement of of net assets to fair value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

704,000,000

'

Equity Method Investments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

146,000,000

'

Current assets

'

'

'

'

'

6,000,000

'

'

'

218,000,000

'

'

'

'

'

'

'

'

'

Property, plant and equipment

'

'

'

'

'

951,000,000

'

'

'

2,788,000,000

'

'

'

'

298,000,000

'

'

'

'

Investments

'

'

'

'

'

'

'

'

'

300,000,000

'

'

'

'

'

'

'

'

'

Goodwill

6,721,000,000

'

6,547,000,000

'

'

67,000,000

'

'

'

1,248,000,000

'

'

'

'

'

'

'

'

'

Other intangibles

'

'

'

'

'

'

'

'

'

1,375,000,000

'

'

'

'

'

'

'

'

'

Other assets

'

'

'

'

'

3,000,000

'

'

'

13,000,000

'

'

'

'

'

'

'

'

'

Total assets

'

'

'

'

'

1,027,000,000

'

'

'

5,942,000,000

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

-704,000,000

'

'

'

'

'

'

'

'

'

'

Total assets acquired

'

'

'

'

'

'

'

'

'

5,238,000,000

'

'

'

'

'

'

'

'

'

Current liabilities

'

'

'

-208,000,000

'

-5,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other

'

'

'

'

'

-61,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Other liabilities

'

'

'

'

'

'

'

'

'

28,000,000

'

'

'

'

'

'

'

'

'

Long-term debt

'

'

'

'

'

'

'

'

'

-1,252,000,000

'

'

'

'

'

'

'

'

'

Noncontrolling interests

'

'

'

'

'

'

'

'

'

-17,000,000

'

'

'

'

'

'

'

'

'

Asset at Fair Value, Changes in Fair Value Resulting from Changes in Assumptions

'

'

'

'

'

'

'

'

'

87,000,000

'

'

'

'

'

'

'

'

'

Property, Plant and Equipment, Transfers and Changes

'

'

'

'

'

'

'

'

'

17,000,000

'

'

'

'

'

'

'

'

'

Increase (Decrease) in Other Current Assets

'

'

'

'

'

'

'

'

'

3,000,000

'

'

'

'

'

'

'

'

'

Finite-Lived Intangible Asset, Useful Life

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'25 years

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

18,000,000

'

'

'

'

Asset Retirement Obligations, Noncurrent

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$12,000,000

'

'

'

'

Acquisitions_and_Discontinued_2

Acquisitions and Discontinued Operations Acquisitions Pro Forma (Details) (USD $)	6 Months Ended
In Millions, except Per Share data, unless otherwise specified	Jun. 30, 2013	Jun. 30, 2014
		APT and SCT, Copano and the Goldsmith Landreth Unit acquisitions occurred as of beginning of reporting period [Member]
Business Acquisition [Line Items]	'	'
Revenues	'	$6,432
Income from Continuing Operations	'	1,766
Income from Continuing Operations	'	-2
Net Income	'	1,764
Net Income Attributable to Noncontrolling Interests	'	-19
Net Income Attributable to KMEP	'	$1,745
Income from Continuing Operations	$2.12	'
Net Income	$2.12	'

Acquisitions_and_Discontinued_3

Acquisitions and Discontinued Operations Divestitures and Discontinued Operations (Details) (USD $)	3 Months Ended		6 Months Ended		0 Months Ended	3 Months Ended	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Mar. 14, 2013	Sep. 30, 2013	Jun. 30, 2013
					Express Pipeline System [Member]	Express Pipeline System [Member]	Express Pipeline System [Member]
					Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]
					Equity method investment & Suboordinated debt investment [Member]	Equity method investment & Suboordinated debt investment [Member]	Equity method investment & Suboordinated debt investment [Member]
					Spectra Energy Corp. [Member]	Spectra Energy Corp. [Member]	Spectra Energy Corp. [Member]
					KMP Sale of Express Pipeline System [Member]	KMP Sale of Express Pipeline System [Member]	KMP Sale of Express Pipeline System [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'
Proceeds from Sale of Equity Method Investments	'	'	'	'	$402	'	'
Working Capital Settlement and Selling Expenses	'	'	'	'	'	1	'
Proceeds from sale of investments in Express pipeline system	'	'	0	-403	'	'	-403
Gain on Sale of Investments	'	'	'	'	'	'	225
Tax expense on sale of investments	24	26	40	127	'	'	84
Equity Method Investments	'	'	'	'	67	'	'
Notes Receivable, Related Parties	'	'	'	'	$110	'	'

Debt_Debt_Details

Debt Debt (Details) (USD $)

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

TGP - Notes, 7.00% through 8.375%, due 2016 through 2037 [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]

Kinder Morgan Liquids Terminals LLC NJ Development Revenue Bonds [Member]

Kinder Morgan Liquids Terminals LLC NJ Development Revenue Bonds [Member]

Senior Notes [Member]

EPNG - Notes, 5.95% through 8.625%, due 2017 through 2032 [Member]

Copano Energy, LLC [Member]

TGP [Member]

TGP [Member]

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

Copano Energy, LLC [Member]

Copano Energy, LLC [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Revolving Credit Facility [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]

Kinder Morgan Operating L.P. B IL Revenue Bonds [Member]

Kinder Morgan Operating L.P. B IL Revenue Bonds [Member]

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

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

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

KMP five-year senior unsecured revolving credit facility maturing May 1, 2018. [Member]

KMP five-year senior unsecured revolving credit facility maturing May 1, 2018. [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior Notes

'

'

'

$17,100,000,000

$15,600,000,000

$1,115,000,000

$1,115,000,000

'

'

'

$1,790,000,000

$1,790,000,000

'

$332,000,000

$332,000,000

'

'

'

Commercial Paper

'

979,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

513,000,000

'

Line of Credit Facility, Amount Outstanding

0

0

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

0

Other Long-term Debt

97,000,000

98,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net carrying value of debt

20,947,000,000

19,914,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Debt, Current Maturities

1,337,000,000

1,504,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unsecured Long-term Debt, Noncurrent

19,610,000,000

18,410,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Redemption price of debt as a percentage of face amount

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt, Weighted Average Interest Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.28%

'

'

Debt fair value adjustments

$1,267,000,000

$1,214,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum

'

'

7.00%

'

'

'

'

2.65%

5.95%

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum

'

'

8.38%

'

'

'

'

9.00%

8.63%

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

'

'

'

'

'

7.13%

'

'

'

'

'

'

'

'

Debt_Changes_in_Debt_Details

Debt Changes in Debt (Details) (USD $)

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Feb. 17, 2014

Feb. 24, 2014

Feb. 17, 2014

Feb. 24, 2014

Feb. 17, 2014

Jun. 30, 2014

Jan. 15, 2014

Jun. 30, 2014

Jan. 15, 2014

Dec. 31, 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]

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

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

KMP Senior Notes issued on February 24, 2014 [Member]

KMP 3.50% Senior Notes due March 1, 2021 [Member]

KMP 3.50% Senior Notes due March 1, 2021 [Member]

KMP 5.50% Senior Notes due March 1, 2044 [Member]

KMP 5.50% Senior Notes due March 1, 2044 [Member]

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

UBS [Member]

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

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

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

KMP five-year senior unsecured revolving credit facility maturing May 1, 2018. [Member]

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

KMP five-year senior unsecured revolving credit facility maturing May 1, 2018. [Member]

KMP five-year senior unsecured revolving credit facility maturing May 1, 2018. [Member]

KMP five-year senior unsecured revolving credit facility maturing May 1, 2018. [Member]

Syndicate of of financial institutions [Member]

Liquidity Facility [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

'

'

'

'

'

'

'

'

'

$1,000,000,000

$2,700,000,000

$3,700,000,000

$2,700,000,000

Line of Credit Facility, Amount Outstanding

0

0

0

'

'

'

'

'

0

'

'

'

'

Debt Instrument, Face Amount

'

'

'

1,500,000,000

'

750,000,000

'

750,000,000

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

'

3.50%

'

5.50%

'

'

'

'

'

Proceeds from Issuance of Senior Long-term Debt

'

'

'

'

$743,000,000

'

$739,000,000

'

'

'

'

'

'

Debt_Credit_Facilities_Details

Debt Credit Facilities (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jan. 15, 2014	Dec. 31, 2013
			Line of Credit [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Revolving Credit Facility [Member]	Commercial Paper [Member]	Commercial Paper [Member]	Commercial Paper [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]
					KMP five-year senior unsecured revolving credit facility maturing May 1, 2018. [Member]	KMP five-year senior unsecured revolving credit facility maturing May 1, 2018. [Member]	KMP five-year senior unsecured revolving credit facility maturing May 1, 2018. [Member]	KMP five-year senior unsecured revolving credit facility maturing May 1, 2018. [Member]
Debt Instrument [Line Items]	'	'	'	'	'	'	'	'
Line of Credit Facility, Amount Outstanding	$0	$0	'	$0	$0	'	'	'
Line of Credit Facility, Maximum Borrowing Capacity	'	'	'	'	'	2,700,000,000	3,700,000,000	2,700,000,000
Debt Instrument, Term	'	'	'	'	'5 years	'	'	'
Line of Credit Facility, Remaining Borrowing Capacity	'	'	'	'	1,807,000,000	'	'	'
Line of Credit Facility, Amount Current Borrowing Capacity is Reduced	'	'	893,000,000	'	'	'	'	'
Commercial Paper	'	979,000,000	'	'	'	513,000,000	'	'
Letters of Credit Outstanding, Amount	'	'	'	'	205,000,000	'	'	'
Indemnified by parent of subsidiary debt	'	'	'	$175,000,000	'	'	'	'

Partners_Capital_Equity_Issuan

Partners Capital Equity Issuances (Details) (USD $)	6 Months Ended		2 Months Ended	3 Months Ended		3 Months Ended		6 Months Ended	3 Months Ended	6 Months Ended
In Millions, except Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Feb. 24, 2014	Jun. 30, 2014	Feb. 17, 2014	Jun. 30, 2014	Mar. 31, 2014	Jun. 30, 2014	Mar. 31, 2014	Jun. 30, 2014
			Common units	Common units	Common units	i-units [Member]	UBS [Member]	UBS [Member]	Kinder Morgan Management, LLC [Member]	Kinder Morgan Management, LLC [Member]
							Common units	Common units	UBS [Member]	UBS [Member]
									i-units [Member]	i-units [Member]
Limited Partners' Capital Account [Line Items]	'	'	'	'	'	'	'	'	'	'
Units issued for cash, Units	'	'	7,935,000	'	'	'	'	'	'	'
Proceeds from issuance of i-units	$97	$73	$603	$335	'	$97	'	'	'	'
Stock Issued During Period, Shares, Issued for Cash	'	'	'	'	'	'	198,110	4,386,944	76,100	1,333,960
Sale of Stock, Price Per Share	'	'	'	'	$78.32	'	'	'	'	'

Partners_Capital_Income_Alloca

Partners Capital Income Allocation and Declared Distributions (Details) (USD $)

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

12 Months Ended

In Millions, except Share data, unless otherwise specified

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2014

Sep. 30, 2014

Dec. 31, 2017

Dec. 31, 2016

Dec. 31, 2015

Common units

Common units

General Partner [Member]

General Partner [Member]

Noncontrolling interests

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

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

Scenario, Forecast [Member]

Scenario, Forecast [Member]

Scenario, Forecast [Member]

Scenario, Forecast [Member]

Scenario, Forecast [Member]

KMI and Consolidated Affiliates [Member]

KMI and Consolidated Affiliates [Member]

General Partner [Member]

Distribution Made to Member or Limited Partner [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent incentive distribution allocated to general partners income

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest

'

'

'

'

'

'

'

'

2.00%

'

'

'

'

'

'

'

Per Unit Cash Distribution Declared for the Period

$1.39

$1.32

$2.77

$2.62

'

'

'

'

'

$2.77

$2.62

'

'

'

'

'

Amount of cash distribution (usd per share)

'

'

'

'

$1.38

$1.30

'

'

'

$2.74

$2.59

'

'

'

'

'

Cash distributions paid in the period to all partners

$918

$757

$1,813

$1,487

'

'

$906

$792

'

'

'

'

'

'

'

'

Stock Dividends, Shares

2,386,814

1,726,952

4,624,072

3,531,548

'

'

'

'

'

'

'

'

'

'

'

'

Partners' Capital Account, Units, Sale of Units

463

416

912

814

'

'

'

'

'

'

'

'

'

'

'

'

Partners' Capital Account, Sale of Units

449

398

894

782

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of General Partner Initial Interest Excluding Incentive Distribution Rights

'

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive Distribution Amounts Waived - Declared

33

25

66

29

'

'

'

'

'

'

'

34

33

105

116

139

Incentive Distribution Amounts Waived Reduction - Declared

'

'

'

'

'

'

'

'

'

'

'

'

'

5

'

'

Incentive Distribution Amounts Waived

$33

$4

$58

$11

'

'

'

'

'

'

'

'

'

'

'

'

Partners_Capital_Subsequent_Ev

Partners Capital Subsequent Events (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Subsequent Event [Line Items]	'	'	'	'
Per Unit Cash Distribution Declared for the Period	$1.39	$1.32	$2.77	$2.62
Stock Dividends, Shares	2,386,814	1,726,952	4,624,072	3,531,548
Kinder Morgan Energy Partners, L.P. [Member]	'	'	'	'
Subsequent Event [Line Items]	'	'	'	'
Per Unit Cash Distribution Declared for the Period	'	'	$2.77	$2.62

Risk_Management_Energy_Commodi

Risk Management Energy Commodity Price Risk Managment (Details) (Hedge Funds, Equity Long (Short) [Member], Forward Contracts [Member])	Jun. 30, 2014
	Bcf
Natural Gas Basis [Member] | Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-26,700,000,000
Natural Gas Basis [Member] | Not Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-100,000,000
Crude Oil Basis [Member] | Not Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-600,000
Crude Oil Fixed Price [Member] | Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-24,200,000
Crude Oil Fixed Price [Member] | Not Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-400,000
Natural Gas Fixed Price [Member] | Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-26,100,000,000
Natural Gas Fixed Price [Member] | Not Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-7,700,000,000
Natural Gas Liquids Fixed Price [Member] | Not Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-800,000

Risk_Management_Interest_Rate_

Risk Management Interest Rate Risk Managment (Details) (Kinder Morgan Energy Partners, L.P. [Member], USD $)	1 Months Ended
In Millions, unless otherwise specified	Feb. 28, 2014	Jun. 30, 2014	Jun. 30, 2014	Feb. 28, 2014	Dec. 31, 2013
		2.65% Senior Notes due February 1, 2019 [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]
Derivative [Line Items]	'	'	'	'	'
Derivative, Notional Amount	'	'	$5,175	$500	$4,675
Number of Fixed-to-Variable Interest Rate Swap Agreements Entered Into	4	'	'	'	'
Debt Instrument, Interest Rate, Stated Percentage	'	3.50%	'	'	'

Risk_Management_Fair_Value_of_

Risk Management Fair Value of Derivative Contracts (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	$285	$297
Liability derivatives	-225	-184
Designated as Hedging Contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	281	293
Liability derivatives	-215	-179
Commodity Contract [Member] | Designated as Hedging Contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	10	76
Liability derivatives	-169	-63
Commodity Contract [Member] | Designated as Hedging Contracts [Member] | Current-Fair value of derivative contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	6	18
Commodity Contract [Member] | Designated as Hedging Contracts [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Liability derivatives	-97	-33
Commodity Contract [Member] | Designated as Hedging Contracts [Member] | Non-current-Fair value of derivative contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	4	58
Commodity Contract [Member] | Designated as Hedging Contracts [Member] | Non Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Liability derivatives	-72	-30
Commodity Contract [Member] | Not Designated as Hedging Contracts [Member] | Non-current-Fair value of derivative contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	4	4
Commodity Contract [Member] | Not Designated as Hedging Contracts [Member] | Non Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Liability derivatives	-10	-5
Interest Rate Swap [Member] | Designated as Hedging Contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	271	217
Liability derivatives	-46	-116
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]	'	'
Asset derivatives	79	76
Fair Value Hedging [Member] | Interest Rate Swap [Member] | Designated as Hedging Contracts [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Liability derivatives	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]	'	'
Asset derivatives	192	141
Fair Value Hedging [Member] | Interest Rate Swap [Member] | Designated as Hedging Contracts [Member] | Non Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Liability derivatives	($46)	($116)

Risk_Management_Effect_of_Deri

Risk Management Effect of Derivative Contracts on the Income Statement (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
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)	($113,000,000)	$70,000,000	($169,000,000)	$29,000,000
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	63,000,000	-211,000,000	124,000,000	-294,000,000
Commodity Contract [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-6,000,000	-2,000,000	-12,000,000	2,000,000
Gain to be reclassified within twelve months	'	'	71,000,000	'
Commodity Contract [Member] | Cash Flow Hedging [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of gain/(loss) reclassified from Accumulated OCI into income (effective portion)	-18,000,000	3,000,000	-36,000,000	10,000,000
Amount of gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	-27,000,000	9,000,000	-32,000,000	6,000,000
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)	-113,000,000	70,000,000	-169,000,000	29,000,000
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	-63,000,000	211,000,000	-124,000,000	294,000,000
Commodity Contract [Member] | Revenues-Natural Gas Sales [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-9,000,000	0	-16,000,000	0
Commodity Contract [Member] | Revenues-Natural Gas Sales [Member] | Cash Flow Hedging [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of gain/(loss) reclassified from Accumulated OCI into income (effective portion)	-2,000,000	0	-12,000,000	0
Amount of gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	0	0	0	0
Commodity Contract [Member] | Revenues-Product sales and other [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	6,000,000	-1,000,000	-1,000,000	3,000,000
Commodity Contract [Member] | Revenues-Product sales and other [Member] | Cash Flow Hedging [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of gain/(loss) reclassified from Accumulated OCI into income (effective portion)	-23,000,000	8,000,000	-32,000,000	15,000,000
Amount of gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	-27,000,000	9,000,000	-32,000,000	6,000,000
Commodity Contract [Member] | Gas purchases and other costs of sales [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-3,000,000	-1,000,000	7,000,000	-1,000,000
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 from Accumulated OCI into income (effective portion)	7,000,000	-5,000,000	8,000,000	-5,000,000
Amount of gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	0	0	0	0
Commodity Contract [Member] | Other Income (Expense) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	0	0	-2,000,000	0
Kinder Morgan Energy Partners, L.P. [Member] | 3.50% Senior Notes due March 1, 2021 [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Debt Instrument, Interest Rate, Stated Percentage	3.50%	'	3.50%	'
Two notch credit downgrade [Member] | Kinder Morgan Energy Partners, L.P. [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Additional Collateral, Aggregate Fair Value	$122,000,000	'	$122,000,000	'

Risk_Management_Credit_Risks_D

Risk Management Credit Risks (Details Textrual) (USD $)	3 Months Ended	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014
	Kinder Morgan Energy Partners, L.P. [Member]	One notch credit downgrade [Member]	Two notch credit downgrade [Member]	One notch credit downgrade [Member]
	notches	notches	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]
Credit Derivatives [Line Items]	'	'	'	'
Number of credit rating notches	2	1	'	'
Additional Collateral, Aggregate Fair Value	'	'	$122,000,000	$0

Risk_Management_Amounts_reclas

Risk Management Amounts reclassified out of other comprehensive income (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013	Dec. 31, 2012
Derivatives, Fair Value [Line Items]	'	'	'	'	'	'
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	($109)	$86	($109)	$86	$24	$66
Accumulated Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Net of Tax	-11	18	-11	18	-4	132
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	10	-29	10	-29	13	-30
Accumulated Other Comprehensive Income (Loss), Net of Tax	-110	75	-110	75	33	168
Other Comprehensive Income Unrealized Gain Loss On Derivatives Arising During Period Net Of Tax Portion Attributable To Parent	-113	70	-169	29	'	'
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Adjustment, Net of Tax, Portion Attributable to Parent	71	-71	-8	-114	'	'
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Tax	-1	0	-3	1	'	'
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax	18	-3	36	-10	'	'
Total Other Comprehensive (Loss)	-25	-4	-144	-94	'	'
Kinder Morgan Energy Partners, L.P. [Member]	'	'	'	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'	'	'	'
Other Comprehensive Income Unrealized Gain Loss On Derivatives Arising During Period Net Of Tax Portion Attributable To Parent	'	'	-169	'	'	'
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax, Portion Attributable to Parent	'	'	-133	20	'	'
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Adjustment, Net of Tax, Portion Attributable to Parent	'	'	-7	-114	'	'
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Tax	'	'	-3	1	'	'
Total Other Comprehensive (Loss)	'	'	-143	-93	'	'
Kinder Morgan Energy Partners, L.P. [Member] | Amounts reclassified from AOCI [Member]	'	'	'	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'	'	'	'
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax	'	'	36	-10	'	'
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Reclassification Adjustment from AOCI, Realized upon Sale or Liquidation, Net of Tax	'	'	0	0	'	'
Other Comprehensive Income Loss Reclassification Adjustment From AOCI Pension And Other Postretiremen tBenefit Plans Net Of Tax Portion Attributable To Parent	'	'	0	0	'	'
Other comprehensive income reclassified from accumulated other comprehensive income, net of tax, portion attributable to parent	'	'	36	-10	'	'
Kinder Morgan Energy Partners, L.P. [Member] | OCI before Reclassifications [Member]	'	'	'	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'	'	'	'
Other Comprehensive Income Unrealized Gain Loss On Derivatives Arising During Period Net Of Tax Portion Attributable To Parent	'	'	'	30	'	'
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Adjustment, Net of Tax, Portion Attributable to Parent	'	'	-7	-114	'	'
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, before Reclassification Adjustments, Net of Tax	'	'	-3	1	'	'
Other comprehensive income (loss) before reclassifications, net of tax, portion attributable to parent	'	'	($179)	($83)	'	'

Risk_Management_Debt_Fair_Valu

Risk Management Debt Fair Value Adjustments (Details Textrual) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Debt Fair Value Adjustments (Details Textrual) [Abstract]	'	'
Increase (decrease) in debt fair value adjustment related to purchase accounting	$613	$645
Amount the adjustment to fair value of debt was increased by related to the fair value of interest rate swaps	225	101
Deferred Gain (Loss) on Discontinuation of Interest Rate Fair Value Hedge	486	517
Amount the fair value of debt adjustment was decreased by related to unamortized debt discounts	$57	$49
Amortization Period of Deferred Gain (Loss) on Discontinuation of Interest Rate Fair Value Hedge	'16 years	'

Fair_Value_Fair_Value_of_Deriv

Fair Value Fair Value of Derivative Contracts (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Liability Net, Purchases	$0	$18	$0	$18	'
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	225	'	225	'	184
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	285	'	285	'	297
Estimate of Fair Value [Member] | Commodity Contract [Member]	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'
Derivative Liability	179	'	179	'	68
Asset fair value, derivative	14	'	14	'	80
Estimate of Fair Value [Member] | Interest Rate Swap [Member]	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'
Derivative Liability	46	'	46	'	116
Asset fair value, derivative	271	'	271	'	217
Quoted prices in active markets for identical assets (Level 1) [Member] | Commodity Contract [Member]	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'
Derivative Liability	10	'	10	'	6
Asset fair value, derivative	3	'	3	'	4
Quoted prices in active markets for identical assets (Level 1) [Member] | Interest Rate Swap [Member]	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'
Derivative Liability	0	'	0	'	0
Asset fair value, derivative	0	'	0	'	0
Significant other observable inputs (Level 2) [Member] | Commodity Contract [Member]	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'
Derivative Liability	134	'	134	'	31
Asset fair value, derivative	7	'	7	'	46
Significant other observable inputs (Level 2) [Member] | Interest Rate Swap [Member]	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'
Derivative Liability	46	'	46	'	116
Asset fair value, derivative	271	'	271	'	217
Significantunobservable inputs (Level 3) [Member] | Commodity Contract [Member]	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'
Derivative Liability	35	'	35	'	31
Asset fair value, derivative	4	'	4	'	30
Significantunobservable inputs (Level 3) [Member] | Interest Rate Swap [Member]	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'
Derivative Liability	0	'	0	'	0
Asset fair value, derivative	0	'	0	'	0
Energy Related Derivative [Member]	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	150	'	150	'	7
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	2	'	2	'	36
Interest Rate Swap [Member]	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	24	'	24	'	88
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	249	'	249	'	189
Not Offset on Balance Sheet [Member] | Energy Related Derivative [Member]	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'
Net Liability Adjustment for Financial Instruments Subject to Master Netting Agreement but Presented Gross	12	'	12	'	44
Derivative, Collateral, Right to Reclaim Cash	17	'	17	'	17
Net Asset Adjustment for Financial Instruments subject to Master Netting Agreement but Presented Gross	-12	'	-12	'	-44
Derivative, Collateral, Obligation to Return Cash	0	'	0	'	0
Not Offset on Balance Sheet [Member] | Interest Rate Swap [Member]	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'
Net Liability Adjustment for Financial Instruments Subject to Master Netting Agreement but Presented Gross	22	'	22	'	28
Derivative, Collateral, Right to Reclaim Cash	0	'	0	'	0
Net Asset Adjustment for Financial Instruments subject to Master Netting Agreement but Presented Gross	-22	'	-22	'	-28
Derivative, Collateral, Obligation to Return Cash	$0	'	$0	'	$0

Fair_Value_Significant_unobser

Fair Value Significant unobservable inputs (Level 3) (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2012
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'	'	'	'	'	'	'	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Liability Net, Value	($31)	$18	($31)	$18	($3)	($1)	$3	$3
Fair Value, Assets Liabilites Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'	'	'	'	'	'	'	'
Total gains (losses), Included in earnings	-19	0	-18	6	'	'	'	'
Total gains (losses), Included in other comprehensive income	-9	1	-10	0	'	'	'	'
Settlements	0	-4	-2	-9	'	'	'	'
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss)	($14)	$1	($16)	$5	'	'	'	'

Fair_Value_Fair_Value_of_Finan

Fair Value Fair Value of Financial Instruments (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Reported Value Measurement [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total debt	$22,214	$21,128
Estimate of Fair Value Measurement [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total debt	$23,450	$21,550

Reportable_Segments_Reportable

Reportable Segments Reportable Segments (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'	'
Total Revenues	$3,577	$3,017	$7,229	$5,678
Depreciation, depletion and amortization	-406	-357	-807	-685
Natural Gas Pipelines [Member]	'	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	639	1,123	1,358	1,680
Total Revenues	2,111	1,696	4,286	3,065
CO2 [Member]	'	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	332	358	695	700
Total Revenues	454	460	937	889
Products Pipelines [Member]	'	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	203	12	411	197
Total Revenues	524	443	1,058	897
Terminals [Member]	'	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	233	207	447	393
Total Revenues	420	343	811	680
Kinder Morgan Canada [Member]	'	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	40	50	88	243
Total Revenues	68	75	137	147
Operating Segments [Member]	'	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	1,447	1,750	2,999	3,213
Total Revenues	3,579	3,018	7,232	5,679
Intersegment Eliminations [Member]	'	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'	'
Total Revenues	-2	-1	-3	-1
Intersegment Revenues [Member] | Natural Gas Pipelines [Member]	'	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'	'
Total Revenues	1	0	2	0
Intersegment Revenues [Member] | Terminals [Member]	'	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'	'
Total Revenues	$1	$1	$1	$1

Reportable_Segments_Reportable1

Reportable Segments Reportable Segment (Details 1) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]	'	'	'	'
Depreciation, Depletion and Amortization	($406)	($357)	($807)	($685)
Amortization of excess cost of equity investments	-5	-2	-8	-4
General and Administrative Expense	-132	-163	-285	-297
Unallocable Interest Expense Net Of Interest Income	-231	-215	-470	-417
Unallocable Income Tax Expense	-4	-3	-6	-6
Loss from Discontinued Operations	0	0	0	-2
Net Income (Loss)	669	1,010	1,423	1,802
Natural Gas Pipelines [Member]	'	'	'	'
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]	'	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	639	1,123	1,358	1,680
CO2 [Member]	'	'	'	'
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]	'	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	332	358	695	700
Products Pipelines [Member]	'	'	'	'
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]	'	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	203	12	411	197
Terminals [Member]	'	'	'	'
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]	'	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	233	207	447	393
Kinder Morgan Canada [Member]	'	'	'	'
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]	'	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	40	50	88	243
Operating Segments [Member]	'	'	'	'
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]	'	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	1,447	1,750	2,999	3,213
Operating Expense [Member]	'	'	'	'
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]	'	'	'	'
Increase in earnings from after tax sale of investments	'	'	'	$141

Reportable_Segments_Reportable2

Reportable Segments Reportable Segments (Details 2) (USD $)	3 Months Ended	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Segment Reporting, Asset Reconciling Item [Line Items]	'	'	'	'
(Gain) loss from the remeasurement of of net assets to fair value	'	$0	$558	'
Rate Reparations Refunds And Other Litigation and Environmental Reserve Adjustment, Expense Portion	162	'	177	'
Assets	'	44,551	'	42,764
Natural Gas Pipelines [Member]	'	'	'	'
Segment Reporting, Asset Reconciling Item [Line Items]	'	'	'	'
Assets	'	25,704	'	25,721
CO2 [Member]	'	'	'	'
Segment Reporting, Asset Reconciling Item [Line Items]	'	'	'	'
Assets	'	3,039	'	2,954
Products Pipelines [Member]	'	'	'	'
Segment Reporting, Asset Reconciling Item [Line Items]	'	'	'	'
Assets	'	5,782	'	5,488
Terminals [Member]	'	'	'	'
Segment Reporting, Asset Reconciling Item [Line Items]	'	'	'	'
Assets	'	7,592	'	6,124
Kinder Morgan Canada [Member]	'	'	'	'
Segment Reporting, Asset Reconciling Item [Line Items]	'	'	'	'
Assets	'	1,690	'	1,678
Operating Segments [Member]	'	'	'	'
Segment Reporting, Asset Reconciling Item [Line Items]	'	'	'	'
Assets	'	43,807	'	41,965
Corporate Segment [Member]	'	'	'	'
Segment Reporting, Asset Reconciling Item [Line Items]	'	'	'	'
Assets	'	$744	'	$799

Reportable_Segments_Details_Te

Reportable Segments (Details Textrual)	6 Months Ended
	Jun. 30, 2014
	segment
Segment Reporting [Abstract]	'
Number of Reportable Segments	5

Related_Party_Details

Related Party (Details) (USD $)	6 Months Ended
	Jun. 30, 2014	Dec. 31, 2013	Aug. 01, 2012	Aug. 01, 2012	Jun. 30, 2014
			El Paso Natural Gas Company [Member]	El Paso Natural Gas Company and El Paso Midstream Investment Company LLC [Member]	Kinder Morgan Energy Partners, L.P. [Member]
Related Party Transaction [Line Items]	'	'	'	'	'
Equity Method Investment, Ownership Percentage	'	'	50.00%	50.00%	'
Subsidiary debt indemnified by KMI	$5,900,000,000	'	'	'	'
Contingent Debt Obligations	79,000,000	74,000,000	'	'	'
Long-term Debt	20,947,000,000	19,914,000,000	'	'	'
Indemnified by parent of subsidiary debt	'	'	'	'	$175,000,000

Litigation_Environmental_and_O1

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

Jun. 30, 2014

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 1969

Oct. 25, 2013

Mar. 31, 2014

Jun. 30, 2014

Jan. 01, 2004

Jun. 30, 2014

Mar. 31, 2014

Jun. 30, 2014

Jun. 30, 2014

Sep. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2011

Aug. 31, 2007

Dec. 31, 2010

Dec. 31, 2000

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jan. 30, 2012

Jul. 20, 2013

Oct. 25, 2013

In Millions, unless otherwise specified

Plains Gas Solutions, LLC v. Tennessee Gas Pipeline Company, L.L.C. et al [Member]

Rare Metals Inc. [Member]

Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al. [Member]

Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al. [Member]

Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al. [Member]

Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al. [Member]

SFPP, L.P. vs. UPRR on relocation costs [Member]

Severstal Sparrows Point Crane Collapse [Member]

Severstal Sparrows Point Crane Collapse [Member]

TGP's 300 Line Project [Member]

SFPP Phoenix Terminal [Member]

SFPP Phoenix Terminal [Member]

SFPP Phoenix Terminal [Member]

SFPP Phoenix Terminal [Member]

Mission Valley Terminal Facility [Member]

Mission Valley Terminal Facility [Member]

Allocation Process Negotiations and Awaiting Record of Decision [Member]

Allocation Process Negotiations and Awaiting Record of Decision [Member]

Regulated Operation [Member]

Regulated Operation [Member]

Regulated Operation [Member]

Regulated Operation [Member]

Regulated Operation [Member]

Regulated Operation [Member]

Regulated Operation [Member]

Regulated Operation [Member]

Regulated Operation [Member]

2014 - 2023 [Member]

SFPP L.P. [Member]

SFPP L.P. [Member]

SFPP L.P. [Member]

SFPP L.P. [Member]

SFPP L.P. [Member]

Kinder Morgan Bulk Terminals, Inc. [Member]

Kinder Morgan Bulk Terminals, Inc. [Member]

Environmental Issue [Member]

Roosevelt Irrigation District v. Kinder Morgan G.P., Inc., Kinder Morgan Energy Partners, L.P. , U.S. District Court, Arizona [Member]

Roosevelt Irrigation District v. Kinder Morgan G.P., Inc., Kinder Morgan Energy Partners, L.P. , U.S. District Court, Arizona [Member]

Roosevelt Irrigation District v. Kinder Morgan G.P., Inc., Kinder Morgan Energy Partners, L.P. , U.S. District Court, Arizona [Member]

Paulsboro, New Jersey Liquids Terminal [Member]

Environmental Issue [Member]

Environmental Issue [Member]

Portland Harbor Superfund Site, Willamette River, Portland, Oregon [Member]

Portland Harbor Superfund Site, Willamette River, Portland, Oregon [Member]

California Public Utilities Commission [Member]

Repreations, Refunds, and Rate Reductions [Member]

Annual Rate Reductions [Member]

Revenue Subject to Refund [Member]

Reparations [Member]

Annual Revenue Reductions [Member]

2008 rate case and the 2010 rate case [Member]

Intrastate [Member]

Intrastate [Member]

Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al. [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Loss on Long-term Purchase Commitment [Member]

Loss on Long-term Purchase Commitment [Member]

Pending Litigation [Member]

Negligence Claim [Member]

Negligence Claim [Member]

Pennsylvania Department of Environmental Protection [Member]

KMEP and SFPP [Member]

KMEP and SFPP [Member]

KMEP and SFPP [Member]

GATX Terminals Corporation (n/k/a KMLT) [Member]

United States District Court, Southern District of California, case number 07CV1883WCAB [Member]

United States District Court, Southern District of California, case number 07CV1883WCAB [Member]

Environmental Protection Agency [Member]

Environmental Protection Agency [Member]

Various Shippers [Member]

Federal Energy Regulatory Commission [Member]

Federal Energy Regulatory Commission [Member]

Federal Energy Regulatory Commission [Member]

California Public Utilities Commission [Member]

California Public Utilities Commission [Member]

Federal Energy Regulatory Commission [Member]

California Public Utilities Commission [Member]

California Public Utilities Commission [Member]

SFPP L.P. [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Tennessee Gas Pipeline Company LLC [Member]

Unfavorable Regulatory Action [Member]

Unfavorable Regulatory Action [Member]

Unfavorable Regulatory Action [Member]

Pending Litigation [Member]

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

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

GATX Terminals Corporation (n/k/a KMLT) [Member]

GATX Terminals Corporation (n/k/a KMLT) [Member]

SFPP [Member]

Various Shippers [Member]

Various Shippers [Member]

Various Shippers [Member]

Various Shippers [Member]

Various Shippers [Member]

Various Shippers [Member]

Various Shippers [Member]

Various Shippers [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Terminals

Terminals

Pending Litigation [Member]

SFPP [Member]

SFPP [Member]

SFPP [Member]

SFPP [Member]

SFPP [Member]

EPNG [Member]

SFPP [Member]

Calnev Pipe Line LLC [Member]

Defendants

Defendants

Parties

Unfavorable Regulatory Action [Member]

Unfavorable Regulatory Action [Member]

Unfavorable Regulatory Action [Member]

Unfavorable Regulatory Action [Member]

Unfavorable Regulatory Action [Member]

Unfavorable Regulatory Action [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Opinion 517 issued and implemented (rehearing pending); and Opinion 528 issued and is awaiting filing of court document) [Member]

Loss Contingencies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss Contingentcy, Period of Time Litigation Concerns

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'2 years

'

'

'

'

'

'

'

'

Number of Parties Involved In Site Cleanup Allocation Negotiations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

90

'

'

'

'

'

'

'

'

'

'

Loss Contingency, Damages Sought, Value

'

'

$100

'

$22.25

'

'

'

'

'

$30

$1.50

'

$175

'

$1

$170

$365

'

'

'

'

$20

$100

$400

$30

'

'

'

'

Loss Contingency, Pending Claims, Number

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

Estimated Litigation Liability

678

611

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Lessee Leasing Arrangements, Operating Leases, Term of Contract

'

'

'

'

'

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'10 years

Loss contingency, settlement tentative by court, value

'

'

'

'

'

'

'

'

42.65

13.79

15.55

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Litigation, Environmental Settlement Amount, Percentage of Cost

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss Contingency, Number of Judges

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

Public Utilities, Requested Rate Increase (Decrease), Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-7.00%

36.00%

'

Annual rent payable

'

'

'

'

'

'

'

14

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss Contingency, Estimate of Possible Loss

'

'

'

'

'

'

95

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss contingency, interest associated with settlement

'

'

'

'

'

'

$20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of Liquid Terminals

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

2

'

'

'

'

'

'

'

'

'

'

Loss Contingency, Number of Defendants

'

'

'

'

'

'

'

'

'

'

'

'

26

'

70

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of Uranium Mines

'

'

'

20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Litigation_Environmental_and_O2

Litigation, Environmental and Other Contingencies Enviormental Matters (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jul. 24, 2013	Nov. 08, 2013	Jun. 30, 2011	Dec. 31, 2013
			TGP [Member]	Tennessee Gas Pipeline Company LLC [Member]	Pending Litigation [Member]	Settled [Member]
			Southeast Louisiana Flood Protection Litigation [Member]	Bastian Bay, Buras, Empire and Fort Jackson oil and gas fields of Plaquemines Parish [Member]	Paulsboro, New Jersey Liquids Terminal [Member]	PHMSA Inspection of Carteret Terminal [Member]
			Environmental Issue [Member]	Plaquemines Parish, Louisiana (Docket No. 60-999) [Member]	GATX Terminals Corporation (n/k/a KMLT) [Member]	GATX Terminals Corporation (n/k/a KMLT) [Member]
			Board of Commissioners of the Southeast Louisiana Flood Protection Authority - East [Member]	Environmental Issue [Member]	SFPP Phoenix Terminal [Member]
				Parish of Plaquemines, Louisiana [Member]
Loss Contingencies [Line Items]	'	'	'	'	'	'
Litigation, Environmental Settlement Amount, Percentage of Cost	'	'	'	'	50.00%	'
Litigation Settlement, Expense	'	'	'	'	'	$63,100
Loss Contingency, Number of Defendants	'	'	100	17	'	'
Loss Contingency, Damages Sought, Value	'	'	'	'	1,000,000	'
Accrual for environmental loss contingencies	$161,000,000	$168,000,000	'	'	'	'

Guarantee_of_Securities_of_Sub2

Guarantee of Securities of Subsidiaries Income Statement (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Total Revenues	$3,577	$3,017	$7,229	$5,678
Cost of Sales	1,602	1,248	3,240	2,205
Depreciation, depletion and amortization	406	357	807	685
Other operating expenses	3	-24	-3	-24
Total Operating Costs, Expenses and Other	2,722	2,416	5,441	4,293
Operating (Loss) Income	855	601	1,788	1,385
Other Income (Expense), Net	-162	435	-325	546
Income from Continuing Operations Before Income Taxes	693	1,036	1,463	1,931
Income Tax Expense	-24	-26	-40	-127
Income from Continuing Operations	669	1,010	1,423	1,804
Loss from Discontinued Operations	0	0	0	-2
Net Income	669	1,010	1,423	1,802
Net Income Attributable to Noncontrolling Interests	-8	-10	-16	-19
Net Income (Loss) Attributable to KMEP	661	1,000	1,407	1,783
Total Other Comprehensive (Loss)	-25	-4	-144	-94
Comprehensive Income	644	1,006	1,279	1,708
Comprehensive Income Attributable to Noncontrolling Interests	-8	-10	-15	-18
Comprehensive Income Attributable to KMEP	636	996	1,264	1,690
Parent Company [Member]	'	'	'	'
Total Revenues	0	0	0	0
Cost of Sales	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Other operating expenses	0	0	0	0
Total Operating Costs, Expenses and Other	0	0	0	0
Operating (Loss) Income	0	0	0	0
Other Income (Expense), Net	663	1,004	1,412	1,789
Income from Continuing Operations Before Income Taxes	663	1,004	1,412	1,789
Income Tax Expense	-2	-4	-5	-6
Income from Continuing Operations	'	'	'	1,783
Loss from Discontinued Operations	'	'	'	0
Net Income	661	1,000	1,407	1,783
Net Income Attributable to Noncontrolling Interests	0	0	0	0
Net Income (Loss) Attributable to KMEP	661	1,000	1,407	1,783
Total Other Comprehensive (Loss)	-25	-4	-143	-93
Comprehensive Income	636	996	1,264	1,690
Comprehensive Income Attributable to Noncontrolling Interests	0	0	0	0
Comprehensive Income Attributable to KMEP	636	996	1,264	1,690
Subsidiary Issuer [Member]	'	'	'	'
Total Revenues	0	0	0	0
Cost of Sales	0	0	0	0
Depreciation, depletion and amortization	0	2	0	2
Other operating expenses	8	26	15	26
Total Operating Costs, Expenses and Other	8	28	15	28
Operating (Loss) Income	-8	-28	-15	-28
Other Income (Expense), Net	45	35	78	35
Income from Continuing Operations Before Income Taxes	37	7	63	7
Income Tax Expense	0	0	0	0
Income from Continuing Operations	'	'	'	7
Loss from Discontinued Operations	'	'	'	0
Net Income	37	7	63	7
Net Income Attributable to Noncontrolling Interests	0	0	0	0
Net Income (Loss) Attributable to KMEP	37	7	63	7
Total Other Comprehensive (Loss)	0	0	0	0
Comprehensive Income	37	7	63	7
Comprehensive Income Attributable to Noncontrolling Interests	0	0	0	0
Comprehensive Income Attributable to KMEP	37	7	63	7
Non-Guarantor Subsidiaries [Member]	'	'	'	'
Total Revenues	3,577	3,017	7,229	5,678
Cost of Sales	1,602	1,248	3,240	2,205
Depreciation, depletion and amortization	406	355	807	683
Other operating expenses	706	785	1,379	1,377
Total Operating Costs, Expenses and Other	2,714	2,388	5,426	4,265
Operating (Loss) Income	863	629	1,803	1,413
Other Income (Expense), Net	-160	435	-323	537
Income from Continuing Operations Before Income Taxes	703	1,064	1,480	1,950
Income Tax Expense	-22	-22	-35	-121
Income from Continuing Operations	'	'	'	1,829
Loss from Discontinued Operations	'	'	'	-2
Net Income	681	1,042	1,445	1,827
Net Income Attributable to Noncontrolling Interests	-8	-10	-16	-19
Net Income (Loss) Attributable to KMEP	673	1,032	1,429	1,808
Total Other Comprehensive (Loss)	-25	-4	-144	-94
Comprehensive Income	656	1,038	1,301	1,733
Comprehensive Income Attributable to Noncontrolling Interests	8	-10	-15	18
Comprehensive Income Attributable to KMEP	648	1,028	1,286	1,715
Consolidation, Eliminations [Member]	'	'	'	'
Total Revenues	0	0	0	0
Cost of Sales	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Other operating expenses	0	0	0	0
Total Operating Costs, Expenses and Other	0	0	0	0
Operating (Loss) Income	0	0	0	0
Other Income (Expense), Net	-710	-1,039	-1,492	-1,815
Income from Continuing Operations Before Income Taxes	-710	-1,039	-1,492	-1,815
Income Tax Expense	0	0	0	0
Income from Continuing Operations	'	'	'	-1,815
Loss from Discontinued Operations	'	'	'	0
Net Income	-710	-1,039	-1,492	-1,815
Net Income Attributable to Noncontrolling Interests	0	0	0	0
Net Income (Loss) Attributable to KMEP	-710	-1,039	-1,492	-1,815
Total Other Comprehensive (Loss)	25	4	143	93
Comprehensive Income	-685	-1,035	-1,349	-1,722
Comprehensive Income Attributable to Noncontrolling Interests	0	0	0	0
Comprehensive Income Attributable to KMEP	-685	-1,035	-1,349	-1,722
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]	'	'	'	'
Total Revenues	3,577	3,017	7,229	5,678
Cost of Sales	1,602	1,248	3,240	2,205
Depreciation, depletion and amortization	406	357	807	685
Other operating expenses	714	811	1,394	1,403
Total Operating Costs, Expenses and Other	2,722	2,416	5,441	4,293
Operating (Loss) Income	855	601	1,788	1,385
Other Income (Expense), Net	-162	435	-325	546
Income from Continuing Operations Before Income Taxes	693	1,036	1,463	1,931
Income Tax Expense	-24	-26	-40	-127
Income from Continuing Operations	'	'	'	1,804
Loss from Discontinued Operations	'	'	'	-2
Net Income	669	1,010	1,423	1,802
Net Income Attributable to Noncontrolling Interests	-8	-10	-16	-19
Net Income (Loss) Attributable to KMEP	661	1,000	1,407	1,783
Total Other Comprehensive (Loss)	-25	-4	-144	-94
Comprehensive Income	644	1,006	1,279	1,708
Comprehensive Income Attributable to Noncontrolling Interests	8	-10	-15	18
Comprehensive Income Attributable to KMEP	$636	$996	$1,264	$1,690

Guarantee_of_Securities_of_Sub3

Guarantee of Securities of Subsidiaries Comprehensive Income (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Net Income	$669	$1,010	$1,423	$1,802
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	1	0	3	-1
Comprehensive Income	644	1,006	1,279	1,708
Comprehensive Income Attributable to Noncontrolling Interests	-8	-10	-15	-18
Comprehensive Income Attributable to KMEP	636	996	1,264	1,690
Parent Company [Member]	'	'	'	'
Net Income	661	1,000	1,407	1,783
Comprehensive Income	636	996	1,264	1,690
Comprehensive Income Attributable to Noncontrolling Interests	0	0	0	0
Comprehensive Income Attributable to KMEP	636	996	1,264	1,690
Subsidiary Issuer [Member]	'	'	'	'
Net Income	37	7	63	7
Comprehensive Income	37	7	63	7
Comprehensive Income Attributable to Noncontrolling Interests	0	0	0	0
Comprehensive Income Attributable to KMEP	37	7	63	7
Non-Guarantor Subsidiaries [Member]	'	'	'	'
Net Income	681	1,042	1,445	1,827
Comprehensive Income	656	1,038	1,301	1,733
Comprehensive Income Attributable to Noncontrolling Interests	8	-10	-15	18
Comprehensive Income Attributable to KMEP	648	1,028	1,286	1,715
Consolidation, Eliminations [Member]	'	'	'	'
Net Income	-710	-1,039	-1,492	-1,815
Comprehensive Income	-685	-1,035	-1,349	-1,722
Comprehensive Income Attributable to Noncontrolling Interests	0	0	0	0
Comprehensive Income Attributable to KMEP	-685	-1,035	-1,349	-1,722
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]	'	'	'	'
Net Income	669	1,010	1,423	1,802
Comprehensive Income	644	1,006	1,279	1,708
Comprehensive Income Attributable to Noncontrolling Interests	8	-10	-15	18
Comprehensive Income Attributable to KMEP	$636	$996	$1,264	$1,690

Guarantee_of_Securities_of_Sub4

Guarantee of Securities of Subsidiaries Balance Sheet (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013	Dec. 31, 2012	Jun. 30, 2014	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2012	Jun. 30, 2014	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2012	Jun. 30, 2014	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2012	Jun. 30, 2014	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2012	Jun. 30, 2014	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified					Parent Company [Member]	Parent Company [Member]	Parent Company [Member]	Parent Company [Member]	Subsidiary Issuer [Member]	Subsidiary Issuer [Member]	Subsidiary Issuer [Member]	Subsidiary Issuer [Member]	Non-Guarantor Subsidiaries [Member]	Non-Guarantor Subsidiaries [Member]	Non-Guarantor Subsidiaries [Member]	Non-Guarantor Subsidiaries [Member]	Consolidation, Eliminations [Member]	Consolidation, Eliminations [Member]	Consolidation, Eliminations [Member]	Consolidation, Eliminations [Member]	Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]	Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]	Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]	Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]
Cash and cash equivalents	$263	$404	$656	$529	$28	$10	$0	$95	$0	$1	$1	$0	$235	$393	$655	$434	$0	$0	$0	$0	$263	$404	$656	$529
All other current assets	388	360	'	'	3,433	3,071	'	'	7	13	'	'	2,165	2,151	'	'	-3,348	-2,971	'	'	2,257	2,264	'	'
Property, plant and equipment, net	29,285	27,405	'	'	0	0	'	'	15	170	'	'	29,270	27,235	'	'	0	0	'	'	29,285	27,405	'	'
Investments	2,193	2,233	'	'	0	0	'	'	0	0	'	'	2,193	2,233	'	'	0	0	'	'	2,193	2,233	'	'
Investments in subsidiaries	'	'	'	'	14,017	13,931	'	'	4,434	4,430	'	'	0	0	'	'	-18,451	-18,361	'	'	0	0	'	'
Goodwill	6,721	6,547	'	'	0	0	'	'	920	813	'	'	5,801	5,734	'	'	0	0	'	'	6,721	6,547	'	'
Notes receivables from affiliates	'	'	'	'	18,279	17,284	'	'	0	0	'	'	0	0	'	'	-18,279	-17,284	'	'	0	0	'	'
Other non-current assets	1,487	1,497	'	'	290	233	'	'	0	0	'	'	3,542	3,678	'	'	0	0	'	'	3,832	3,911	'	'
Total Assets	44,551	42,764	'	'	36,047	34,529	'	'	5,376	5,427	'	'	43,206	41,424	'	'	-40,078	-38,616	'	'	44,551	42,764	'	'
Current portion of debt	1,337	1,504	'	'	1,337	1,504	'	'	0	0	'	'	0	0	'	'	0	0	'	'	1,337	1,504	'	'
All other current liabilities	'	'	'	'	355	407	'	'	137	107	'	'	6,057	5,530	'	'	-3,348	-2,971	'	'	3,201	3,073	'	'
Total long-term debt	20,877	19,624	'	'	16,931	15,644	'	'	389	393	'	'	3,557	3,587	'	'	0	0	'	'	20,877	19,624	'	'
Notes payable to affiliates	'	'	'	'	0	0	'	'	765	907	'	'	17,514	16,377	'	'	-18,279	-17,284	'	'	0	0	'	'
Deferred income taxes	297	285	'	'	0	0	'	'	2	2	'	'	295	283	'	'	0	0	'	'	297	285	'	'
Other long-term liabilities and deferred credits	'	'	'	'	107	173	'	'	2	0	'	'	945	884	'	'	0	0	'	'	1,054	1,057	'	'
Total Liabilities	26,766	25,543	'	'	18,730	17,728	'	'	1,295	1,409	'	'	28,368	26,661	'	'	-21,627	-20,255	'	'	26,766	25,543	'	'
Total KMEP Partners’ Capital	17,317	16,801	16,453	'	17,317	16,801	'	'	4,081	4,018	'	'	14,370	14,343	'	'	-18,451	-18,361	'	'	17,317	16,801	'	'
Noncontrolling interests	468	420	'	'	0	0	'	'	0	0	'	'	468	420	'	'	0	0	'	'	468	420	'	'
Total Partners’ Capital	17,785	17,221	16,808	'	17,317	16,801	'	'	4,081	4,018	'	'	14,838	14,763	'	'	-18,451	-18,361	'	'	17,785	17,221	'	'
Total Liabilities and Partners’ Capital	$44,551	$42,764	'	'	$36,047	$34,529	'	'	$5,376	$5,427	'	'	$43,206	$41,424	'	'	($40,078)	($38,616)	'	'	$44,551	$42,764	'	'

Guarantee_of_Securities_of_Sub5

Guarantee of Securities of Subsidiaries Statements of Cash Flows (Details) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Net Cash Provided by Operating Activities	$2,249	$1,742
Payment to parent as consideration for assets dropped down	0	-994
Acquisitions of assets and investments, net of cash acquired	-993	-286
Capital expenditures	-1,658	-1,268
Proceeds from sale of investments in Express pipeline system	0	403
Contributions to investments	-89	-93
Distributions from equity investments in excess of cumulative earnings	37	36
Natural gas storage and natural gas and liquids line-fill	22	0
Sale or casualty of property, plant and equipment, investments and other net assets, net of removal costs	11	23
Other, net	-5	5
Net Cash Used in Investing Activities	-2,675	-2,174
Issuance of debt	6,083	4,858
Payment of debt	-5,060	-3,860
Debt issue costs	-11	-11
Proceeds from issuance of common units	938	834
Proceeds from issuance of i-units	97	73
Contributions from noncontrolling interests	57	99
Contributions from General Partner	0	38
Pre-acquisition contributions from KMI to March 2013 drop-down asset group	0	35
Distributions to partners and noncontrolling interests	-1,813	-1,487
Other, net	-2	0
Net Cash Provided by Financing Activities	289	579
Effect of Exchange Rate Changes on Cash and Cash Equivalents	-4	-20
Net (decrease) increase in Cash and Cash Equivalents	-141	127
Cash and Cash Equivalents, beginning of period	404	529
Cash and Cash Equivalents, end of period	263	656
Parent Company [Member]	'	'
Net Cash Provided by Operating Activities	1,723	1,548
Payment to parent as consideration for assets dropped down	'	0
Acquisitions of assets and investments, net of cash acquired	0	0
Capital expenditures	0	0
Proceeds from sale of investments in Express pipeline system	'	0
Contributions to investments	0	0
Distributions from equity investments in excess of cumulative earnings	0	0
Funding (to) from affiliates	1,571	3,690
Natural gas storage and natural gas and liquids line-fill	0	'
Sale or casualty of property, plant and equipment, investments and other net assets, net of removal costs	0	0
Other, net	0	5
Net Cash Used in Investing Activities	-1,571	-3,685
Issuance of debt	6,083	4,844
Payment of debt	-5,059	-3,100
Debt issue costs	-11	-11
Funding from affiliates	-392	832
Proceeds from issuance of common units	938	834
Proceeds from issuance of i-units	97	73
Contributions from noncontrolling interests	0	0
Contributions from General Partner	'	38
Pre-acquisition contributions from KMI to March 2013 drop-down asset group	'	0
Distributions to partners and noncontrolling interests	-1,789	-1,468
Other, net	-1	'
Net Cash Provided by Financing Activities	-134	2,042
Effect of Exchange Rate Changes on Cash and Cash Equivalents	0	0
Net (decrease) increase in Cash and Cash Equivalents	18	-95
Cash and Cash Equivalents, beginning of period	10	95
Cash and Cash Equivalents, end of period	28	'
Subsidiary Issuer [Member]	'	'
Net Cash Provided by Operating Activities	-29	6
Payment to parent as consideration for assets dropped down	'	0
Acquisitions of assets and investments, net of cash acquired	0	5
Capital expenditures	-47	-60
Proceeds from sale of investments in Express pipeline system	'	0
Contributions to investments	0	0
Distributions from equity investments in excess of cumulative earnings	0	0
Funding (to) from affiliates	-72	501
Natural gas storage and natural gas and liquids line-fill	0	'
Sale or casualty of property, plant and equipment, investments and other net assets, net of removal costs	192	0
Other, net	0	0
Net Cash Used in Investing Activities	217	-556
Issuance of debt	0	0
Payment of debt	0	-663
Debt issue costs	0	0
Funding from affiliates	-189	1,214
Proceeds from issuance of common units	0	0
Proceeds from issuance of i-units	0	0
Contributions from noncontrolling interests	0	0
Pre-acquisition contributions from KMI to March 2013 drop-down asset group	'	0
Distributions to partners and noncontrolling interests	0	0
Other, net	0	'
Net Cash Provided by Financing Activities	-189	551
Effect of Exchange Rate Changes on Cash and Cash Equivalents	0	0
Net (decrease) increase in Cash and Cash Equivalents	-1	1
Cash and Cash Equivalents, beginning of period	1	0
Cash and Cash Equivalents, end of period	0	'
Non-Guarantor Subsidiaries [Member]	'	'
Net Cash Provided by Operating Activities	2,691	1,956
Payment to parent as consideration for assets dropped down	'	-994
Acquisitions of assets and investments, net of cash acquired	-993	-291
Capital expenditures	-1,803	-1,208
Proceeds from sale of investments in Express pipeline system	'	403
Contributions to investments	-89	-93
Distributions from equity investments in excess of cumulative earnings	37	36
Funding (to) from affiliates	-420	1,234
Natural gas storage and natural gas and liquids line-fill	22	'
Sale or casualty of property, plant and equipment, investments and other net assets, net of removal costs	11	23
Other, net	-5	0
Net Cash Used in Investing Activities	-2,400	-3,358
Issuance of debt	0	14
Payment of debt	-1	-97
Debt issue costs	0	0
Funding from affiliates	1,660	3,379
Proceeds from issuance of common units	0	0
Proceeds from issuance of i-units	0	0
Contributions from noncontrolling interests	57	99
Pre-acquisition contributions from KMI to March 2013 drop-down asset group	'	35
Distributions to partners and noncontrolling interests	-2,160	-1,787
Other, net	-1	'
Net Cash Provided by Financing Activities	-445	1,643
Effect of Exchange Rate Changes on Cash and Cash Equivalents	-4	-20
Net (decrease) increase in Cash and Cash Equivalents	-158	221
Cash and Cash Equivalents, beginning of period	393	434
Cash and Cash Equivalents, end of period	235	'
Consolidation, Eliminations [Member]	'	'
Net Cash Provided by Operating Activities	-2,136	-1,768
Payment to parent as consideration for assets dropped down	'	0
Acquisitions of assets and investments, net of cash acquired	0	0
Capital expenditures	192	0
Proceeds from sale of investments in Express pipeline system	'	0
Contributions to investments	0	0
Distributions from equity investments in excess of cumulative earnings	0	0
Funding (to) from affiliates	-1,079	-5,425
Natural gas storage and natural gas and liquids line-fill	0	'
Sale or casualty of property, plant and equipment, investments and other net assets, net of removal costs	-192	0
Other, net	0	0
Net Cash Used in Investing Activities	1,079	5,425
Issuance of debt	0	0
Payment of debt	0	0
Debt issue costs	0	0
Funding from affiliates	-1,079	-5,425
Proceeds from issuance of common units	0	0
Proceeds from issuance of i-units	0	0
Contributions from noncontrolling interests	0	0
Pre-acquisition contributions from KMI to March 2013 drop-down asset group	'	0
Distributions to partners and noncontrolling interests	2,136	1,768
Other, net	0	'
Net Cash Provided by Financing Activities	1,057	-3,657
Effect of Exchange Rate Changes on Cash and Cash Equivalents	0	0
Net (decrease) increase in Cash and Cash Equivalents	0	0
Cash and Cash Equivalents, beginning of period	0	0
Cash and Cash Equivalents, end of period	0	'
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]	'	'
Net Cash Provided by Operating Activities	2,249	1,742
Payment to parent as consideration for assets dropped down	'	-994
Acquisitions of assets and investments, net of cash acquired	-993	-286
Capital expenditures	-1,658	-1,268
Proceeds from sale of investments in Express pipeline system	'	403
Contributions to investments	-89	-93
Distributions from equity investments in excess of cumulative earnings	37	36
Funding (to) from affiliates	0	0
Natural gas storage and natural gas and liquids line-fill	22	'
Sale or casualty of property, plant and equipment, investments and other net assets, net of removal costs	11	23
Other, net	-5	5
Net Cash Used in Investing Activities	-2,675	-2,174
Issuance of debt	6,083	4,858
Payment of debt	-5,060	-3,860
Debt issue costs	-11	-11
Funding from affiliates	0	0
Proceeds from issuance of common units	938	834
Proceeds from issuance of i-units	97	73
Contributions from noncontrolling interests	57	99
Contributions from General Partner	'	38
Pre-acquisition contributions from KMI to March 2013 drop-down asset group	'	35
Distributions to partners and noncontrolling interests	-1,813	-1,487
Other, net	-2	'
Net Cash Provided by Financing Activities	289	579
Effect of Exchange Rate Changes on Cash and Cash Equivalents	-4	-20
Net (decrease) increase in Cash and Cash Equivalents	-141	127
Cash and Cash Equivalents, beginning of period	404	529
Cash and Cash Equivalents, end of period	263	'
General Partner [Member] | Subsidiary Issuer [Member]	'	'
Contributions from General Partner	'	0
General Partner [Member] | Non-Guarantor Subsidiaries [Member]	'	'
Contributions from General Partner	'	0
General Partner [Member] | Consolidation, Eliminations [Member]	'	'
Contributions from General Partner	'	$0

Guarantee_of_Securities_of_Sub6

Guarantee of Securities of Subsidiaries Details (Details) (USD $)

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

In Millions, unless otherwise specified

Subsidiaries [Member]

Subsidiaries [Member]

Parent Company [Member]

Parent Company [Member]

Subsidiary Issuer [Member]

Subsidiary Issuer [Member]

Non-Guarantor Subsidiaries [Member]

Non-Guarantor Subsidiaries [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]

Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]

Copano Energy, LLC [Member]

Copano Energy, LLC [Member]

Funding (to) from Affiliates

'

'

($1,571)

($3,690)

$72

($501)

$420

($1,234)

$1,079

$5,425

$0

$0

Notes Payable

$332

$332

'

'

'

'

'

'

'

'

'

'