Kinder Morgan (KMI) 10-Q 22 Jul 16 2016 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - USD ($)	6 Months Ended
	Jun. 30, 2016	Jul. 21, 2016	Jun. 30, 2015
Entity [Abstract]
Entity Registrant Name	KINDER MORGAN, INC.
Entity Central Index Key	1,506,307
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			$ 69,734,282,635
Entity Common Stock, Shares Outstanding		2,232,323,355
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q2
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Revenues
Natural gas sales	$ 478	$ 677	$ 1,021	$ 1,462
Services	2,034	1,963	4,148	3,933
Product sales and other	632	823	1,170	1,665
Total Revenues	3,144	3,463	6,339	7,060
Operating Costs, Expenses and Other
Costs of sales	752	1,085	1,483	2,175
Operations and maintenance	603	590	1,168	1,095
Depreciation, depletion and amortization	552	570	1,103	1,108
General and administrative	189	164	379	380
Taxes, other than income taxes	110	116	218	231
(Gain) loss on impairments and disposals of long-lived assets, net	(4)	50	231	104
Other expense (income), net	2	(4)	1	(3)
Total Operating Costs, Expenses and Other	2,204	2,571	4,583	5,090
Operating Income	940	892	1,756	1,970
Other Income (Expense)
Earnings from equity investments	106	114	200	190
Amortization of excess cost of equity investments	(16)	(14)	(30)	(26)
Interest, net	(471)	(472)	(912)	(984)
Other, net	29	11	42	24
Total Other Expense	(352)	(361)	(700)	(796)
Income Before Income Taxes	588	531	1,056	1,174
Income Tax Expense	(213)	(189)	(367)	(413)
Net Income	375	342	689	761
Net (Income) Loss Attributable to Noncontrolling Interests	(3)	(9)	(2)	1
Net Income Attributable to Kinder Morgan, Inc.	372	333	687	762
Preferred Stock Dividends	(39)	0	(78)	0
Net Income Available to Common Stockholders	$ 333	$ 333	$ 609	$ 762
Class P Shares
Basic Earnings Per Common Share	$ 0.15	$ 0.15	$ 0.27	$ 0.35
Basic Weighted Average Common Shares Outstanding	2,229	2,175	2,229	2,158
Diluted Earnings Per Common Share	$ 0.15	$ 0.15	$ 0.27	$ 0.35
Diluted Weighted Average Common Shares Outstanding	2,229	2,187	2,229	2,169
Dividends Per Common Share Declared for the Period	$ 0.125	$ 0.490	$ 0.250	$ 0.970

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Net Income
Net income	$ 375	$ 342	$ 689	$ 761
Other comprehensive income (loss), net of tax
Change in fair value of hedge derivatives (net of tax benefit of $82, $34, $40 and $35, respectively)	(142)	(58)	(69)	(60)
Reclassification of change in fair value of derivatives to net income (net of tax benefit of $6, $33, $69 and $74, respectively)	(11)	(57)	(119)	(129)
Foreign currency translation adjustments (net of tax (expense) benefit of $(4), $(9), $(49) and $53, respectively)	7	17	85	(91)
Benefit plan adjustments (net of tax expense of $(3), $-, $(6) and $(4), respectively)	6	0	10	6
Total other comprehensive loss	(140)	(98)	(93)	(274)
Comprehensive income	235	244	596	487
Comprehensive (income) loss attributable to noncontrolling interests	(3)	(9)	(2)	1
Comprehensive income attributable to KMI	$ 232	$ 235	$ 594	$ 488

CONSOLIDATED STATEMENTS OF COM4

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Other comprehensive income (loss), net of tax
Change in fair value of hedge derivatives	$ 82	$ 34	$ 40	$ 35
Reclassification of change in fair value of derivatives to net income	6	33	69	74
Foreign currency translation adjustments	(4)	(9)	(49)	53
Benefit plan adjustments	$ (3)	$ 0	$ (6)	$ (4)

CONSOLIDATED BALANCE SHEETS (Un

CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Current Assets
Cash and cash equivalents	$ 180	$ 229
Accounts receivable, net	1,278	1,315
Fair value of derivative contracts	313	507
Inventories	361	407
Other current assets	338	366
Total current assets	2,470	2,824
Property, plant and equipment, net	41,199	40,547
Investments	6,202	6,040
Goodwill	23,802	23,790
Other intangibles, net	3,440	3,551
Deferred income taxes	4,975	5,323
Deferred charges and other assets	2,229	2,029
Total Assets	84,317	84,104
Current Liabilities
Current portion of debt	3,419	821
Accounts payable	1,087	1,324
Accrued interest	630	695
Accrued contingencies	405	298
Other current liabilities	1,025	927
Total current liabilities	6,566	4,065
Long-term debt
Outstanding	38,113	40,632
Preferred interest in general partner of KMP	100	100
Debt fair value adjustments	1,988	1,674
Total long-term debt	40,201	42,406
Other long-term liabilities and deferred credits	2,077	2,230
Total long-term liabilities and deferred credits	42,278	44,636
Total Liabilities	48,844	48,701
Commitments and contingencies (Notes 3 and 9)
Stockholders’ Equity
Class P shares, $0.01 par value, 4,000,000,000 shares authorized, 2,229,330,134 and 2,229,223,864 shares, respectively, issued and outstanding	22	22
Preferred stock, $0.01 par value, 10,000,000 shares authorized, 9.75% Series A Mandatory Convertible, $1,000 per share liquidation preference, 1,600,000 shares issued and outstanding	0	0
Additional paid-in capital	41,696	41,661
Retained deficit	(6,053)	(6,103)
Accumulated other comprehensive loss	(554)	(461)
Total Kinder Morgan, Inc.’s stockholders’ equity	35,111	35,119
Noncontrolling interests	362	284
Total Stockholders’ Equity	35,473	35,403
Total Liabilities and Stockholders’ Equity	$ 84,317	$ 84,104

CONSOLIDATED BALANCE SHEETS (U6

CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - $ / shares	6 Months Ended	12 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Stockholders’ Equity
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	4,000,000,000	4,000,000,000
Common stock, shares issued (in shares)	2,229,330,134	2,229,223,864
Common stock, shares outstanding (in shares)	2,229,330,134	2,229,223,864
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (in shares)	10,000,000	10,000,000
Preferred stock, shares issued (in shares)	1,600,000	1,600,000
Preferred stock, shares outstanding (in shares)	1,600,000	1,600,000
9.75% Series A Mandatory Convertible, $1,000 per share liquidation preference	$ 1,000	$ 1,000
9.75% Series A Mandatory Convertible, $1,000 per share liquidation preference	9.75%	9.75%

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Cash Flows From Operating Activities
Net income	$ 689	$ 761
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion and amortization	1,103	1,108
Deferred income taxes	388	413
Amortization of excess cost of equity investments	30	26
Loss on impairments and disposals of long-lived assets, net	231	104
Earnings from equity investments	(200)	(190)
Distributions from equity investment earnings	203	187
Noncash pension benefit credits	0	(23)
Changes in components of working capital, net of the effects of acquisitions and dispositions
Accounts receivable, net	81	366
Income tax receivable	0	195
Inventories	49	(34)
Other current assets	7	50
Accounts payable	(144)	(222)
Accrued interest, net of interest rate swaps	(49)	9
Accrued contingencies and other current liabilities	72	(7)
Rate reparations, refunds and other litigation reserve adjustments	31	27
Other, net	(147)	(232)
Net Cash Provided by Operating Activities	2,344	2,538
Cash Flows From Investing Activities
Acquisitions of assets and investments, net of cash acquired	(333)	(1,919)
Capital expenditures	(1,470)	(1,909)
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	220	4
Contributions to investments	(363)	(45)
Distributions from equity investments in excess of cumulative earnings	81	114
Other, net	(15)	11
Net Cash Used in Investing Activities	(1,880)	(3,744)
Cash Flows From Financing Activities
Issuances of debt	6,847	9,485
Payments of debt	(6,800)	(8,941)
Debt issue costs	(6)	(20)
Issuances of common shares	0	2,562
Cash dividends - common shares	(559)	(2,006)
Cash dividends - preferred shares	(76)	0
Repurchases of warrants	0	(5)
Contributions from noncontrolling interests	87	0
Distributions to noncontrolling interests	(11)	(16)
Other, net	0	(1)
Net Cash (Used in) Provided by Financing Activities	(518)	1,058
Effect of Exchange Rate Changes on Cash and Cash Equivalents	5	(4)
Net decrease in Cash and Cash Equivalents	(49)	(152)
Cash and Cash Equivalents, beginning of period	229	315
Cash and Cash Equivalents, end of period	180	163
Non-cash Investing and Financing Activities
Assets acquired by the assumption or incurrence of liabilities	43	1,671
Net assets contributed to equity investment	37	34
Supplemental Disclosures of Cash Flow Information
Cash paid during the period for interest (net of capitalized interest)	1,047	1,002
Cash paid (refunded) during the period for income taxes, net	$ 5	$ (185)

CONSOLIDATED STATEMENTS OF STOC

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Unaudited) Statement - USD ($) $ in Millions	Total	Common stock	Preferred stock	Additional paid-in capital	Retained deficit	Accumulated other comprehensive loss	Stockholders’ equity attributable to KMI	Non-controlling interests
Balance (in shares) Common stock at Dec. 31, 2014	2,125,000,000
Balance (in shares) Preferred stock at Dec. 31, 2014	0
Balance at Dec. 31, 2014	$ 34,426	$ 21	$ 0	$ 36,178	$ (2,106)	$ (17)	$ 34,076	$ 350
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuances of common shares (shares)	62,000,000
Issuances of common shares	$ 2,562	1		2,561			2,562
Repurchase of warrants	$ (5)			(5)			(5)
EP Trust I Preferred security conversions	1,000,000
EP Trust I Preferred security conversions	$ 23			23			23
Warrants exercised	2			2			2
Restricted shares	32			32			32
Net income	761				762		762	(1)
Distributions	(16)						0	(16)
Common stock dividends	(2,006)				(2,006)		(2,006)
Other comprehensive loss	$ (274)					(274)	(274)
Balance (in shares) Common stock at Jun. 30, 2015	2,188,000,000
Balance (in shares) Preferred stock at Jun. 30, 2015	0
Balance at Jun. 30, 2015	$ 35,505	22	0	38,791	(3,350)	(291)	35,172	333
Balance (in shares) Common stock at Dec. 31, 2015	2,229,223,864
Balance (in shares) Preferred stock at Dec. 31, 2015	1,600,000
Balance at Dec. 31, 2015	$ 35,403	22	0	41,661	(6,103)	(461)	35,119	284
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Restricted shares	35			35			35
Net income	689				687		687	2
Distributions	(11)						0	(11)
Contributions	87						0	87
Preferred stock dividends	(78)				(78)		(78)
Common stock dividends	(559)				(559)		(559)
Other comprehensive loss	$ (93)					(93)	(93)
Balance (in shares) Common stock at Jun. 30, 2016	2,229,330,134
Balance (in shares) Preferred stock at Jun. 30, 2016	1,600,000
Balance at Jun. 30, 2016	$ 35,473	$ 22	$ 0	$ 41,696	$ (6,053)	$ (554)	$ 35,111	$ 362

General (Notes)

General (Notes)	6 Months Ended
	Jun. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General	General Organization We are the largest energy infrastructure company in North America. We own an interest in or operate approximately 84,000 miles of pipelines and 180 terminals. Our pipelines transport natural gas, refined petroleum products, crude oil, condensate, CO 2 and other products, and our terminals transload and store petroleum products, ethanol and chemicals, and handle such products as coal, petroleum coke and steel. We are also the leading producer and transporter of CO 2 , which is utilized for enhanced oil recovery projects in North America. On November 26, 2014, we completed our acquisition, pursuant to three separate merger agreements, of all of the outstanding common units of KMP and EPB and all of the outstanding shares of KMR that we did not already own, which transactions are referred to collectively as the “Merger Transactions.” Basis of Presentation General Our reporting currency is U.S. dollars, and all references to dollars are U.S. dollars, unless stated otherwise. Our accompanying unaudited consolidated financial statements have been prepared under the rules and regulations of the United States Securities and Exchange Commission (SEC). These rules and regulations conform to the accounting principles contained in the FASB’s Accounting Standards Codification, the single source of GAAP. Under such rules and regulations, all significant intercompany items have been eliminated in consolidation. In our opinion, all adjustments, which are of a normal and recurring nature, considered necessary for a fair presentation of our financial position and operating results for the interim periods have been included in the accompanying consolidated financial statements, and certain amounts from prior periods have been reclassified to conform to the current presentation. Interim results are not necessarily indicative of results for a full year; accordingly, you should read these consolidated financial statements in conjunction with our consolidated financial statements and related notes included in our 2015 Form 10-K. Goodwill Goodwill is the cost of an acquisition in excess of the fair value of acquired assets and liabilities and is recorded as an asset on our balance sheet. Goodwill is not subject to amortization but must be tested for impairment at least annually. This test requires us to assign goodwill to an appropriate reporting unit and to determine if the implied fair value of the reporting unit’s goodwill is less than its carrying amount. We evaluate goodwill for impairment on May 31 of each year. For this purpose, we have seven reporting units as follows: (i) Products Pipelines (excluding associated terminals); (ii) Products Pipelines Terminals (evaluated separately from Products Pipelines for goodwill purposes); (iii) Natural Gas Pipelines Regulated; (iv) Natural Gas Pipelines Non-Regulated; (v) CO 2 ; (vi) Terminals; and (vii) Kinder Morgan Canada. We also evaluate goodwill for impairment to the extent events or conditions indicate a risk of possible impairment during the interim periods subsequent to our annual impairment test. Generally, the evaluation of goodwill for impairment involves a two-step test, although under certain circumstance an initial qualitative evaluation may be sufficient to conclude that goodwill is not impaired without conducting the quantitative test. Step 1 involves comparing the estimated fair value of each respective reporting unit to its carrying value, including goodwill. If the estimated fair value exceeds the carrying value, the reporting unit’s goodwill is not considered impaired. If the carrying value exceeds the estimated fair value, step 2 must be performed to determine whether goodwill is impaired and, if so, the amount of the impairment. Step 2 involves calculating an implied fair value of goodwill by performing a hypothetical allocation of the estimated fair value of the reporting unit determined in step 1 to the respective tangible and intangible net assets of the reporting unit. The remaining implied goodwill is then compared to the actual carrying amount of the goodwill for the reporting unit. To the extent the carrying amount of goodwill exceeds the implied goodwill, the difference is the amount of the goodwill impairment. A large portion of our goodwill is non-deductible for tax purposes, and as such, to the extent there are impairments, all or a portion of the impairment may not result in a corresponding tax benefit. In the fourth quarter 2015, we recorded a $1,150 million impairment of goodwill associated with our Natural Gas Pipeline - Non-Regulated reporting unit triggered by decreases in market valuations in our industry which were caused by the commodity price environment at that time. The results of our May 31, 2016 annual impairment test indicated that for each of our reporting units other than our Natural Gas Pipelines - Non-Regulated, the reporting unit fair value exceeded the carrying value. For our Natural Gas Pipelines - Non-Regulated, and similar to December 31, 2015, the fair value of the reporting unit continues to be slightly less than the carrying value of the reporting unit, thereby necessitating a step 2 evaluation. The hypothetical fair value allocation to the assets and liabilities of the reporting unit in the step 2 evaluation, resulted in an amount of implied goodwill exceeding the carrying amount of the reporting unit’s goodwill and, as a result, no adjustment to the reporting unit’s goodwill carrying value was warranted. The fair value estimates used in the step 1 and step 2 goodwill tests are based on Level 3 inputs of the fair value hierarchy. The methodologies and key inputs used by management were substantially consistent with those utilized in the fourth quarter 2015. We expect that the carrying value of our Natural Gas Pipelines - Non-Regulated reporting unit will continue to approximate fair value so long as our estimate of future cash flows and the market valuation remain consistent with current levels. A continued or prolonged period of lower commodity prices could result in further deterioration of market multiples, comparable sales transactions prices, weighted average costs of capital, and our cash flow estimates. Changes to any one or combination of these factors, particularly for our Natural Gas Pipelines - Non-Regulated reporting unit given that the carrying value slightly exceeds the current estimated fair value, would result in a change to the reporting unit fair values discussed above which could lead to further impairment charges. Such potential impairment could have a significant effect on our results of operations. Impairments and Disposals During the six months ended June 30, 2016, we had non-cash pre-tax impairment charges and losses on disposals of assets of $257 million substantially all of which was recorded in the first quarter of 2016 comprised of (i) $106 million of project write-offs on our Northeast Energy Direct (NED) Market project and $13 million related to an equity investment in a gas gathering entity within our Natural Gas Pipelines business segment; (ii) $33 million of project write-offs within our CO 2 business segment; (iii) $20 million related to certain terminals with significant coal operations within our Terminals business segment; (iv) $64 million of write-offs associated with our Palmetto project and an $8 million loss on a held-for-sale Transmix facility both within our Products Pipelines business segment; and (v) $13 million net losses on other disposals of assets. The project write-offs recorded in the six months ended June 30, 2016 were driven by management's assessment of the probability of those projects moving forward based on insufficient progress in obtaining contractual commitments from customers in the New England market, in the case of the NED Market project, and an unfavorable action by the Georgia legislature regarding permitting for refined products pipelines affecting the Palmetto project. During the three and six months ended June 30, 2015 we had non-cash pre-tax impairment charges and losses on disposals of assets of $50 million and $130 million , respectively. These amounts include (i) $48 million and $99 million for the three and six months ended June 30, 2015, respectively, of impairments and project write-offs, related to certain gas gathering and processing assets within our midstream operations and $26 million for the six months ended June 30, 2015 primarily related to an equity investment in a gathering entity, both within our Natural Gas Pipelines business segment; (ii) $9 million for both the three and six months ended June 30, 2015 related to an impairment charge associated with the pending sale of excess construction pipe within our CO 2 business segment; and (iii) $7 million and $4 million for the three and six months ended June 30, 2015, respectively, of net gains on other disposals of assets. In addition, during the three and six months ended June 30, 2016 we recognized a $12 million gain on the sale of an equity investment, which is included in “Other, net” on the accompanying consolidated statements of income. As conditions warrant, we routinely evaluate our assets for potential triggering events that could impact the fair value of certain assets or our ability to recover the carrying value of long-lived assets. Such assets include accounts receivable, equity investments, goodwill, other intangibles and property plant and equipment, including oil and gas properties and in-process construction. Depending on the nature of the asset, these evaluations require the use of significant judgments including but not limited to judgments related to customer credit worthiness, future cash flow estimates, future volume expectations, current and future commodity prices, regulatory environment, management’s decisions to dispose of certain assets and estimates of the fair values of our reporting units, as well as general economic conditions and the related demand for products handled or transported by our assets. In the current commodity price environment and to the extent conditions further deteriorate, we may identify additional triggering events that may require future evaluations of the recoverability of the carrying value of our long-lived assets, investments and goodwill which could result in further impairment charges. Because certain of our assets, including our oil and gas producing properties have been written down to fair value, any deterioration in fair value that exceeds the rate of depletion of the related asset would result in further impairments. Such non-cash impairments could have a significant effect on our results of operations, which would be recognized in the period in which the carrying value is determined to not be recoverable. Certain of these impairments are based on Level 3 estimates of fair value using income approach valuation methodologies which include assumptions regarding future cash flows, terminal values and discount rates. We believe our methodologies are standard techniques and results would not vary materially using a reasonable range of assumptions. Earnings per Share We calculate earnings per share using the two-class method. Earnings were allocated to Class P shares of common stock and participating securities based on the amount of dividends paid in the current period plus an allocation of the undistributed earnings or excess distributions over earnings to the extent that each security participates in earnings or excess distributions over earnings. Our unvested restricted stock awards, which may be stock or stock units issued to management employees and include dividend equivalent payments, do not participate in excess distributions over earnings. The following tables set forth the allocation of net income available to shareholders of Class P shares and participating securities and the reconciliation of Basic Weighted Average Common Shares Outstanding to Diluted Weighted Average Common Shares Outstanding (in millions): Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Class P $ 332 $ 330 $ 607 $ 756 Participating securities: Restricted stock awards(a) 1 3 2 6 Net Income Available to Common Stockholders $ 333 $ 333 $ 609 $ 762 Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Basic Weighted Average Common Shares Outstanding 2,229 2,175 2,229 2,158 Effect of dilutive securities: Warrants — 12 — 11 Diluted Weighted Average Common Shares Outstanding 2,229 2,187 2,229 2,169 ________ (a) As of June 30, 2016 , there were approximately 8 million such restricted stock awards. The following maximum number of potential common stock equivalents are antidilutive and, accordingly, are excluded from the determination of diluted earnings per share (in millions on a weighted-average basis): Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Unvested restricted stock awards 8 7 8 7 Warrants to purchase our Class P shares(a) 293 287 293 288 Convertible trust preferred securities 8 8 8 9 Mandatory convertible preferred stock(b) 58 n/a 58 n/a _______ n/a - not applicable (a) Each warrant entitles the holder to purchase one share of our common stock for an exercise price of $40 per share, payable in cash or by cashless exercise, at any time until May 25, 2017. The potential dilutive effect of the warrants does not consider the assumed proceeds to KMI upon exercise. (b) Until our mandatory convertible preferred shares are converted to common shares, on or before the expected mandatory conversion date of October 26, 2018, the holder of each preferred share participates in our earnings by receiving preferred dividends.

Acquisitions (Notes)

Acquisitions (Notes)	6 Months Ended
	Jun. 30, 2016
Acquisitions and Divestitures [Abstract]
Acquisitions	Acquisitions and Divestitures Acquisition of Terminal Assets from and Joint Venture With BP Products North America Inc. (BP) On February 1, 2016, we completed the acquisition of 15 products terminals and associated infrastructure from BP for $349 million , including a transaction deposit paid in 2015 and working capital adjustments paid in 2016. In conjunction with this transaction, we and BP formed a joint venture, with an equity ownership interest of 75% and 25% , respectively. Subsequent to the acquisition, we contributed 14 of the acquired terminals to the joint venture, which we operate, and the remaining terminal is solely owned by us. BP acquired its 25% interest in the joint venture for $84 million , which we reported as “Contributions from noncontrolling interests” within our accompanying consolidated statement of cash flows for the six months ended June 30, 2016 . Of the acquired assets, 10 terminals are included in our Terminals business segment and 5 terminals are included in our Products Pipelines business segment based on synergies with each segment’s respective existing operations. Allocation of Purchase Price The evaluation of the assigned fair values for the BP terminals acquisition is ongoing and subject to adjustment. As of June 30, 2016 , our preliminary allocation of the purchase price for the BP terminals acquisition and the adjusted purchase price allocations for the Hiland acquisition and Royal Vopak terminals acquisition, both completed in February 2015, are detailed below (in millions). Acquisitions BP Terminal Assets Hiland Royal Vopak Terminal Assets Purchase Price Allocation: Current assets $ 2 $ 79 $ 2 Property, plant and equipment 396 1,492 155 Goodwill — 310 6 Deferred charges and other assets(a) — 1,498 — Total assets acquired 398 3,379 163 Current liabilities — (253 ) (1 ) Debt — (1,413 ) — Other liabilities (49 ) (4 ) (4 ) Cash consideration $ 349 $ 1,709 $ 158 _______ (a) Primarily consists of customer contracts and relationships with a weighted average amortization period of 16.4 years . After measuring all of the identifiable tangible and intangible assets acquired and liabilities assumed at fair value on the acquisition date, goodwill is an intangible asset representing the future economic benefits expected to be derived from an acquisition that are not assigned to other identifiable, separately recognizable assets. We believe the primary items that generated our goodwill are both the value of the synergies created between the acquired assets and our pre-existing assets, and our expected ability to grow the business we acquired by leveraging our pre-existing business experience. We apply a look through method of recording deferred income taxes on the outside book-tax basis differences in our investments. As a result, no deferred income taxes are recorded associated with non-deductible goodwill recorded at the investee level. Subsequent Event—Sale of Equity Interest in SNG On July 10, 2016, we announced the anticipated sale of a 50% interest in our SNG natural gas pipeline system to The Southern Company (Southern Company) for an expected $1.47 billion and the formation of a joint venture, which will include our remaining 50% interest in SNG, which we will operate. Inclusive of existing SNG debt, the transaction equates to an SNG total enterprise value of $4.15 billion . Subject to customary closing conditions and regulatory approvals, the transaction is expected to close in the third or early fourth quarter of 2016, at which time, any difference between the sales price and the proportionate carrying value of the interests in SNG being sold would be recognized.

Debt Debt (Notes)

Debt Debt (Notes)	6 Months Ended
	Jun. 30, 2016
Debt Disclosure [Abstract]
Debt [Text Block]	Debt We classify our debt based on the contractual maturity dates of the underlying debt instruments. We defer costs associated with debt issuance over the applicable term. These costs are then amortized as interest expense in our accompanying consolidated statements of income. The following table provides detail on the principal amount of our outstanding debt balances. The table amounts exclude all debt fair value adjustments, including debt discounts, premiums and issuance costs (in millions): June 30, 2016 December 31, 2015 KMI Unsecured term loan facility, variable rate, due January 26, 2019(a) $ 1,000 $ — Senior notes, 1.50% through 8.25%, due 2016 through 2098(b) 13,309 13,346 Credit facility due November 26, 2019(c) 700 — Commercial paper borrowings(c) 24 — KMP Senior notes, 2.65% through 9.00%, due 2016 through 2044 19,485 19,985 TGP senior notes, 7.00% through 8.375%, due 2016 through 2037(a) 1,540 1,790 EPNG senior notes, 5.95% through 8.625%, due 2017 through 2032 1,115 1,115 Copano senior notes, 7.125%, due April 1, 2021 332 332 CIG senior notes, 6.85%, due June 15, 2037 100 100 SNG notes, 4.40% through 8.00%, due 2017 through 2032 1,211 1,211 Other Subsidiary Borrowings (as obligor) Kinder Morgan Finance Company, LLC, senior notes, 5.70% through 6.40%, due 2016 through 2036(a) 786 1,636 Hiland Partners Holdings LLC, senior notes, 5.50% and 7.25%, due 2020 and 2022 974 974 EPC Building, LLC, promissory note, 3.967%, due 2016 through 2035 438 443 Trust I preferred securities, 4.75%, due March 31, 2028 221 221 KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock 100 100 Other miscellaneous debt 297 300 Total debt – KMI and Subsidiaries 41,632 41,553 Less: Current portion of debt(a)(d) 3,419 821 Total long-term debt – KMI and Subsidiaries(e) $ 38,213 $ 40,732 _______ (a) On January 26, 2016, we entered into a $1.0 billion three -year unsecured term loan facility with a variable interest rate, which is determined in the same manner as interest on our revolving credit facility borrowings. In January 2016, we repaid $850 million of maturing 5.70% senior notes, and in February 2016, we repaid $250 million of maturing 8.00% senior notes primarily using proceeds from the three-year term loan. Since we refinanced a portion of the maturing debt with proceeds from long-term debt, we classified $1 billion of the maturing debt within “Long-term debt” on our consolidated balance sheet as of December 31, 2015. (b) Amount includes senior notes that are denominated in Euros and have been converted and are respectively reported above at the June 30, 2016 exchange rate of 1.1106 U.S. dollars per Euro and the December 31, 2015 exchange rate of 1.0862 U.S. dollars per Euro. For the six months ended June 30, 2016, our debt increased by $31 million as a result of the change in the exchange rate of U.S. dollars per Euro. At the time of issuance, we entered into cross-currency swap agreements associated with these senior notes, effectively converting these Euro-denominated senior notes to U.S. dollars (see Note 5 “Risk Management— Foreign Currency Risk Management ”). (c) As of June 30, 2016 , the weighted average interest rate on our credit facility borrowings, including commercial paper borrowings, was 1.91% . (d) Amounts include outstanding credit facility borrowings, commercial paper borrowings and other debt maturing within 12 months (see “—Current Portion of Debt” below). (e) Excludes our “Debt fair value adjustments” which, as of June 30, 2016 and December 31, 2015 , increased our combined debt balances by $1,988 million and $1,674 million , respectively. In addition to all unamortized debt discount/premium amounts, debt issuance costs and purchase accounting on our debt balances, our debt fair value adjustments also include amounts associated with the offsetting entry for hedged debt and any unamortized portion of proceeds received from the early termination of interest rate swap agreements. We and substantially all of our wholly owned domestic subsidiaries are a party to a cross guarantee agreement whereby each party to the agreement unconditionally guarantees, jointly and severally, the payment of specified indebtedness of each other party to the agreement. Also, see Note 11. Credit Facilities On January 26, 2016, in accordance with the terms of our revolving credit agreement, we increased the capacity of our revolving credit agreement from $4.0 billion to $5.0 billion . The other terms of the revolving credit agreement remain the same. Our availability under this facility as of June 30, 2016 was $4,102 million , which is net of borrowings, and $174 million in letters of credit. Borrowings under our revolving credit facility can be used for working capital and other general corporate purposes and as a backup to our commercial paper program. Borrowings under our commercial paper program reduce the borrowings allowed under our credit facility. Current Portion of Debt In addition to outstanding credit facility borrowings, commercial paper borrowings, and other debt maturing within 12 months, our current portion of debt includes the current portion of the following significant series of long-term notes: As of June 30, 2016 $600 million 6.00% notes due February 2017 $300 million 7.50% notes due April 2017 $355 million 5.95% notes due April 2017 $500 million 5.90% notes due April 2017 $786 million 7.00% notes due June 2017 As of December 31, 2015 $500 million 3.50% notes due March 2016 Long-term Debt Issuances and Repayments The following are significant long-term debt issuances and repayments made during the six months ended June 30, 2016 : Issuances $1.0 billion unsecured term loan facility due 2019 Repayments $850 million 5.70% notes due 2016 $500 million 3.50% notes due 2016 $250 million 8.00% notes due 2016 $67 million 8.25% notes due 2016

Stockholders' Equity (Notes)

Stockholders' Equity (Notes)	6 Months Ended
	Jun. 30, 2016
Stockholders' Equity Note [Abstract]
Stockholders' Equity Note Disclosure [Text Block]	Stockholders’ Equity Common Equity As of June 30, 2016 , our common equity consisted of our Class P common stock. For additional information regarding our Class P common stock, see Note 11 to our consolidated financial statements included in our 2015 Form 10-K. Common Dividends Holders of our common stock participate in any dividend declared by our board of directors, subject to the rights of the holders of any outstanding preferred stock. The following table provides information about our per share dividends: Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Per common share cash dividend declared for the period $ 0.125 $ 0.49 $ 0.250 $ 0.97 Per common share cash dividend paid in the period $ 0.125 $ 0.48 $ 0.250 $ 0.93 On July 20, 2016 , our board of directors declared a cash dividend of $0.125 per common share for the quarterly period ended June 30, 2016 , which is payable on August 15, 2016 to common shareholders of record as of August 1, 2016 . Mandatory Convertible Preferred Stock On October 30, 2015, we completed an offering of 32,000,000 depositary shares, each of which represents a 1/20th interest in a share of our 1,600,000 shares of 9.750% Series A mandatory convertible preferred stock, with a liquidating preference of $1,000 per share (equal to a $50 liquidation preference per depositary share). For additional information regarding our mandatory convertible preferred stock, see Note 11 to our consolidated financial statements included in our 2015 Form 10-K. Preferred Dividends On April 20, 2016, our board of directors declared a cash dividend of $24.375 per share of our mandatory convertible preferred stock (equivalent of $1.21875 per depositary share) for the period from and including April 26, 2016 through and including July 25, 2016, which is payable on July 26, 2016 to mandatory convertible preferred shareholders of record as of July 11, 2016.

Risk Management (Notes)

Risk Management (Notes)	6 Months Ended
	Jun. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Risk Management	Risk Management Certain of our business activities expose us to risks associated with unfavorable changes in the market price of natural gas, NGL and crude oil. We also have exposure to interest rate and foreign currency risk as a result of the issuance of our debt obligations. Pursuant to our management’s approved risk management policy, we use derivative contracts to hedge or reduce our exposure to certain of these risks. In addition, prior to May 2016, we had power forward and swap contracts related to legacy operations of acquired businesses. Energy Commodity Price Risk Management As of June 30, 2016 , 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 (21.2 ) MMBbl Crude oil basis (4.1 ) MMBbl Natural gas fixed price (31.9 ) Bcf Natural gas basis (21.8 ) Bcf Derivatives not designated as hedging contracts Crude oil fixed price (0.3 ) MMBbl Crude oil basis (0.4 ) MMBbl Natural gas fixed price (12.8 ) Bcf Natural gas basis (2.6 ) Bcf NGL and other fixed price (3.4 ) MMBbl As of June 30, 2016 , the maximum length of time over which we have hedged, for accounting purposes, our exposure to the variability in future cash flows associated with energy commodity price risk is through December 2020. Interest Rate Risk Management As of June 30, 2016 , we had a combined notional principal amount of $9,775 million of fixed-to-variable interest rate swap agreements, of which $8,475 million were designated as fair value hedges. As of December 31, 2015 , we had a combined notional principal amount of $11,000 million of fixed-to-variable interest rate swap agreements, of which $9,700 million were designated as fair value hedges. All of our swap agreements effectively convert the interest expense associated with certain series of senior notes from fixed rates to variable rates based on an interest rate of London Interbank Offered Rate plus a spread and have termination dates that correspond to the maturity dates of the related series of senior notes. As of June 30, 2016 , 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. Foreign Currency Risk Management In connection with the issuance of our Euro denominated senior notes in March 2015 (see Note 3), we entered into $1,358 million cross-currency swap agreements to manage the related foreign currency risk by effectively converting all of the fixed-rate Euro denominated debt, including annual interest payments and the payment of principal at maturity, to U.S. dollar denominated debt at fixed rates equivalent to approximately 3.79% and 4.67% for the 7 -year and 12 -year senior notes, respectively. These cross-currency swaps are accounted for as cash flow hedges. The terms of the cross-currency swap agreements correspond to the related hedged senior notes, and such agreements have the same maturities as the hedged senior notes. Fair Value of Derivative Contracts The following table summarizes the fair values of our derivative contracts included in our accompanying consolidated balance sheets (in millions): Fair Value of Derivative Contracts Asset derivatives Liability derivatives June 30, December 31, June 30, December 31, Location Fair value Fair value Derivatives designated as hedging contracts Natural gas and crude derivative contracts Fair value of derivative contracts/(Other current liabilities) $ 177 $ 359 $ (38 ) $ (13 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 139 244 (18 ) — Subtotal 316 603 (56 ) (13 ) Interest rate swap agreements Fair value of derivative contracts/(Other current liabilities) 117 111 — — Deferred charges and other assets/(Other long-term liabilities and deferred credits) 657 273 — (9 ) Subtotal 774 384 — (9 ) Cross-currency swap agreements Fair value of derivative contracts/(Other current liabilities) — — (22 ) (6 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 13 — (12 ) (46 ) Subtotal 13 — (34 ) (52 ) Total 1,103 987 (90 ) (74 ) Derivatives not designated as hedging contracts Natural gas, crude, NGL and other derivative contracts Fair value of derivative contracts/(Other current liabilities) 7 35 (10 ) (1 ) Subtotal 7 35 (10 ) (1 ) Interest rate swap agreements Fair value of derivative contracts/(Other current liabilities) 12 1 — (11 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 50 — — (5 ) Subtotal 62 1 — (16 ) Power derivative contracts Fair value of derivative contracts/(Other current liabilities) — 1 — (17 ) Subtotal — 1 — (17 ) Total 69 37 (10 ) (34 ) Total derivatives $ 1,172 $ 1,024 $ (100 ) $ (108 ) Effect of Derivative Contracts on the Income Statement The following tables summarize the impact of our derivative contracts on our accompanying consolidated statements of income (in millions): Derivatives in fair value hedging relationships Location Gain/(loss) recognized in income on derivatives and related hedged item Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Interest rate swap agreements Interest, net $ 119 $ (233 ) $ 399 $ (88 ) Hedged fixed rate debt Interest, net $ (120 ) $ 256 $ (404 ) $ 117 Derivatives in cash flow hedging relationships Gain/(loss) recognized in OCI on derivative (effective portion)(a) Location Gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b) Location Gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing) Three Months Ended June 30, Three Months Ended June 30, Three Months Ended June 30, 2016 2015 2016 2015 2016 2015 Energy commodity derivative contracts $ (111 ) $ (82 ) Revenues—Natural gas sales $ 2 $ 1 Revenues—Natural gas sales $ — $ — Revenues—Product sales and other 33 37 Revenues—Product sales and other (6 ) 3 Costs of sales (2 ) (14 ) Costs of sales — — Interest rate swap agreements(c) (1 ) 1 Interest, net — — Interest, net — — Cross-currency swap (30 ) 23 Other, net (22 ) 33 Other, net — — Total $ (142 ) $ (58 ) Total $ 11 $ 57 Total $ (6 ) $ 3 Derivatives in cash flow hedging relationships Gain/(loss) recognized in OCI on derivative (effective portion)(a) Location Gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b) Location Gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing) Six Months Ended June 30, Six Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 2016 2015 Energy commodity derivative contracts $ (84 ) $ (47 ) Revenues—Natural gas sales $ 23 $ 25 Revenues—Natural gas sales $ — $ — Revenues—Product sales and other 90 101 Revenues—Product sales and other (5 ) 10 Costs of sales (12 ) (19 ) Costs of sales — — Interest rate swap agreements(c) (5 ) (2 ) Interest, net (1 ) (1 ) Interest, net — — Cross-currency swap 20 (11 ) Other, net 19 23 Other, net — — Total $ (69 ) $ (60 ) Total $ 119 $ 129 Total $ (5 ) $ 10 _____ (a) We expect to reclassify an approximate $46 million gain associated with cash flow hedge price risk management activities included in our accumulated other comprehensive loss balances as of June 30, 2016 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). (c) Amounts represent our share of an equity investee’s accumulated other comprehensive loss. Derivatives not designated as accounting hedges Location Gain/(loss) recognized in income on derivatives Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Energy commodity derivative contracts Revenues—Natural gas sales $ (11 ) $ (2 ) $ (5 ) $ 3 Revenues—Product sales and other (12 ) (40 ) (14 ) 4 Costs of sales 3 3 (2 ) — Interest rate swap agreements Interest, net 24 — 77 — Total(a) $ 4 $ (39 ) $ 56 $ 7 _______ (a) Three and six months ended June 30, 2016 includes an approximate gain of $20 million and $39 million , respectively, associated with natural gas, crude and NGL derivative contract settlements. Three and six months ended June 30, 2015 includes an approximate gain of $7 million and $2 million , respectively, associated with natural gas, crude and NGL derivative contract settlements. Credit Risks In conjunction with certain derivative contracts, we are required to provide collateral to our counterparties, which may include posting letters of credit or placing cash in margin accounts. As of June 30, 2016 and December 31, 2015 , we had no and $2 million of outstanding letters of credit supporting our commodity price risk management program. As of June 30, 2016 , we had cash margins of $18 million posted by us as collateral and no amounts posted by our counterparties as collateral. As of December 31, 2015, we had no cash margins posted by us as collateral and cash margins of $37 million posted by our counterparties as collateral. We also use industry standard commercial agreements which allow for the netting of exposures associated with transactions executed under a single commercial agreement. Additionally, we generally utilize master netting agreements to offset credit exposure across multiple commercial agreements with a single counterparty. We also have agreements with certain counterparties to our derivative contracts that contain provisions requiring the posting of additional collateral upon a decrease in our credit rating. As of June 30, 2016 , based on our current mark to market positions and posted collateral, we estimate that if our credit rating were downgraded one or two notches, we would not be required to post additional collateral. Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Loss Cumulative revenues, expenses, gains and losses that under GAAP are included within our comprehensive income but excluded from our earnings are reported as “Accumulated other comprehensive loss” within “Stockholders’ Equity” in our consolidated balance sheets. Changes in the components of our “Accumulated other comprehensive loss” not including non-controlling interests are summarized as follows (in millions): Net unrealized gains/(losses) on cash flow hedge derivatives Foreign currency translation adjustments Pension and other postretirement liability adjustments Total accumulated other comprehensive loss Balance as of December 31, 2015 $ 219 $ (322 ) $ (358 ) $ (461 ) Other comprehensive (loss) gain before reclassifications (69 ) 85 10 26 Gains reclassified from accumulated other comprehensive income (loss) (119 ) — — (119 ) Net current-period other comprehensive (loss) income (188 ) 85 10 (93 ) Balance as of June 30, 2016 $ 31 $ (237 ) $ (348 ) $ (554 ) Net unrealized gains/(losses) on cash flow hedge derivatives Foreign currency translation adjustments Pension and other postretirement liability adjustments Total accumulated other comprehensive loss Balance as of December 31, 2014 $ 327 $ (108 ) $ (236 ) $ (17 ) Other comprehensive (loss) gain before reclassifications (60 ) (91 ) 6 (145 ) Gains reclassified from accumulated other comprehensive income (loss) (129 ) — — (129 ) Net current-period other comprehensive (loss) income (189 ) (91 ) 6 (274 ) Balance as of June 30, 2015 $ 138 $ (199 ) $ (230 ) $ (291 )

Fair Value (Notes)

Fair Value (Notes)	6 Months Ended
	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Fair Value	Fair Value The fair values of our financial instruments are separated into three broad levels (Levels 1, 2 and 3) based on our assessment of the availability of observable market data and the significance of non-observable data used to determine fair value. Each fair value measurement must be assigned to a level corresponding to the lowest level input that is significant to the fair value measurement in its entirety. The three broad levels of inputs defined by the fair value hierarchy are as follows: • Level 1 Inputs—quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity has the ability to access at the measurement date; • Level 2 Inputs—inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. If the asset or liability has a specified (contractual) term, a Level 2 input must be observable for substantially the full term of the asset or liability; and • Level 3 Inputs—unobservable inputs for the asset or liability. These unobservable inputs reflect the entity’s own assumptions about the assumptions that market participants would use in pricing the asset or liability, and are developed based on the best information available in the circumstances (which might include the reporting entity’s own data). Fair Value of Derivative Contracts The following two tables summarize the fair value measurements of our (i) energy commodity derivative contracts; (ii) interest rate swap agreements; and (iii) cross-currency swap agreements, based on the three levels established by the Codification (in millions). The tables also identify the impact of derivative contracts which we have elected to present on our accompanying consolidated balance sheets on a gross basis that are eligible for netting under master netting agreements. Balance sheet asset fair value measurements by level Net amount Level 1 Level 2 Level 3 Gross amount Contracts available for netting Cash collateral held(b) As of June 30, 2016 Energy commodity derivative contracts(a) $ 6 $ 317 $ — $ 323 $ (32 ) $ — $ 291 Interest rate swap agreements $ — $ 836 $ — $ 836 $ — $ — $ 836 Cross-currency swap agreements $ — $ 13 $ — $ 13 $ (13 ) $ — $ — As of December 31, 2015 Energy commodity derivative contracts(a) $ 48 $ 589 $ 2 $ 639 $ (12 ) $ (37 ) $ 590 Interest rate swap agreements $ — $ 385 $ — $ 385 $ (8 ) $ — $ 377 Cross-currency swap agreements $ — $ — $ — $ — $ — $ — $ — Balance sheet liability fair value measurements by level Net amount Level 1 Level 2 Level 3 Gross amount Contracts available for netting Collateral posted(c) As of June 30, 2016 Energy commodity derivative contracts(a) $ (19 ) $ (47 ) $ — $ (66 ) $ 32 $ 18 $ (16 ) Interest rate swap agreements $ — $ — $ — $ — $ — $ — $ — Cross-currency swap agreements $ — $ (34 ) $ — $ (34 ) $ 13 $ — $ (21 ) As of December 31, 2015 Energy commodity derivative contracts(a) $ (4 ) $ (10 ) $ (17 ) $ (31 ) $ 12 $ — $ (19 ) Interest rate swap agreements $ — $ (25 ) $ — $ (25 ) $ 8 $ — $ (17 ) Cross-currency swap agreements $ — $ (52 ) $ — $ (52 ) $ — $ — $ (52 ) _______ (a) Level 1 consists primarily of New York Mercantile Exchange natural gas futures. Level 2 consists primarily of OTC West Texas Intermediate swaps and options. Level 3 consists primarily of power derivative contracts. (b) Cash margin deposits held by us associated with our energy commodity contract positions and OTC swap agreements and reported within “Other current liabilities” on our accompanying consolidated balance sheets. (c) Cash margin deposits posted by us associated with our energy commodity contract positions and OTC swap agreements and reported within “Other current assets” on our accompanying consolidated balance sheets. The table below provides a summary of changes in the fair value of our Level 3 energy commodity derivative contracts (in millions): Significant unobservable inputs (Level 3) Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Derivatives-net asset (liability) Beginning of Period $ (2 ) $ (49 ) $ (15 ) $ (61 ) Total gains or (losses) included in earnings (3 ) — (9 ) — Settlements 5 12 24 24 End of Period $ — $ (37 ) $ — $ (37 ) The amount of total gains or (losses) for the period included in earnings attributable to the change in unrealized gains or (losses) relating to assets held at the reporting date $ — $ 1 $ — $ 3 As of December 31, 2015, our Level 3 derivative assets and liabilities consisted primarily of power derivative contracts (which expired in April 2016), where a significant portion of fair value is calculated from underlying market data that is not readily observable. The derived values use industry standard methodologies that may consider the historical relationships among various commodities, modeled market prices, time value, volatility factors and other relevant economic measures. The use of these inputs results in management’s best estimate of fair value and management would not expect materially different valuation results were we to use different input amounts within reasonable ranges. Fair Value of Financial Instruments The estimated fair value of our outstanding debt balances is disclosed below (in millions): June 30, 2016 December 31, 2015 Carrying value Estimated fair value Carrying value Estimated fair value Total debt $ 43,620 $ 43,061 $ 43,227 $ 37,481 We used Level 2 input values to measure the estimated fair value of our outstanding debt balances as of both June 30, 2016 and December 31, 2015 .

Reportable Segments (Notes)

Reportable Segments (Notes)	6 Months Ended
	Jun. 30, 2016
Segment Reporting [Abstract]
Reportable Segments	Reportable Segments Financial information by segment follows (in millions): Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Revenues Natural Gas Pipelines Revenues from external customers $ 1,882 $ 2,091 $ 3,852 $ 4,268 Intersegment revenues 1 5 2 8 CO 2 304 353 606 799 Terminals Revenues from external customers 487 469 952 926 Intersegment revenues 1 1 1 1 Products Pipelines Revenues from external customers 398 477 789 921 Intersegment revenues 3 1 8 1 Kinder Morgan Canada 63 65 122 125 Other 1 (1 ) 1 3 Total segment revenues 3,140 3,461 6,333 7,052 Other revenues 9 9 17 18 Less: Total intersegment revenues (5 ) (7 ) (11 ) (10 ) Total consolidated revenues $ 3,144 $ 3,463 $ 6,339 $ 7,060 Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Segment EBDA(a) Natural Gas Pipelines $ 966 $ 928 $ 1,958 $ 1,943 CO 2 203 240 389 576 Terminals 292 279 545 549 Products Pipelines 293 277 472 523 Kinder Morgan Canada 40 37 80 78 Other (5 ) (40 ) (13 ) (46 ) Total Segment EBDA 1,789 1,721 3,431 3,623 Total segment DD&A (552 ) (570 ) (1,103 ) (1,108 ) Total segment amortization of excess cost of equity investments (16 ) (14 ) (30 ) (26 ) Other revenues 9 9 17 18 General and administrative expense (189 ) (164 ) (379 ) (380 ) Interest expense, net of unallocable interest income (470 ) (472 ) (912 ) (986 ) Unallocable income tax expense (196 ) (168 ) (335 ) (380 ) Total consolidated net income $ 375 $ 342 $ 689 $ 761 June 30, 2016 December 31, 2015 Assets Natural Gas Pipelines $ 53,677 $ 53,704 CO 2 4,317 4,706 Terminals 9,673 9,083 Products Pipelines 8,360 8,464 Kinder Morgan Canada 1,586 1,434 Other 317 418 Total segment assets 77,930 77,809 Corporate assets(b) 6,360 6,276 Assets held for sale 27 19 Total consolidated assets $ 84,317 $ 84,104 _______ (a) We evaluate performance based on each segment’s EBDA. Segment EBDA includes revenues, earnings from equity investments, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other expense (income), net, and losses on impairments and disposals of long-lived assets, net. Operating expenses include natural gas purchases and other costs of sales, operations and maintenance expenses, and taxes, other than income taxes. (b) Includes cash and cash equivalents, margin and restricted deposits, unallocable interest receivable, prepaid assets and deferred charges, deferred tax assets, risk management assets related to debt fair value adjustments and miscellaneous corporate assets (such as information technology and telecommunications equipment) not allocated to individual segments.

Income Taxes (Notes)

Income Taxes (Notes)	6 Months Ended
	Jun. 30, 2016
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes Income tax expense included in our accompanying consolidated statements of income were as follows (in millions, except percentages): Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Income tax expense $ 213 $ 189 $ 367 $ 413 Effective tax rate 36.2 % 35.6 % 34.8 % 35.2 % The effective tax rate for the three months ended June 30, 2016 is higher than the statutory federal rate of 35% primarily due to state and foreign income taxes, partially offset by dividend-received deductions from our investment in Florida Gas Pipeline (Citrus) and Plantation Pipe Line, and the change in the effective state tax rate. The effective tax rate for the six months ended June 30, 2016 is slightly lower than the statutory federal rate of 35% primarily due to dividend-received deductions from our investment in Citrus and Plantation Pipe Line, and adjustments to our income tax reserve for uncertain tax positions, partially offset by state and foreign income taxes. The effective tax rate for the three months ended June 30, 2015 is slightly higher than the statutory federal rate of 35% primarily due to state and foreign income taxes, partially offset by dividend-received deductions from our investment in Citrus. The effective tax rate for the six months ended June 30, 2015 is marginally higher than the statutory federal rate of 35% primarily due to state and foreign income taxes, partially offset by dividend-received deductions from our investment in Citrus and the change in the effective state tax rate as a result of the Hiland acquisition. As of June 30, 2016 , the total amount of unrecognized tax benefits including interest and penalties relating to uncertain tax positions is $144 million , a decrease of $29 million from the December 31, 2015 balance of $173 million . This $29 million decrease in unrecognized tax benefits resulted primarily from the settlement of a state tax audit and a certain statute of limitations expiration on another matter.

Litigation, Environmental and O

Litigation, Environmental and Other Contingencies (Notes)	6 Months Ended
	Jun. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Litigation, Environmental and Other Contingencies	Litigation, Environmental and Other Contingencies We and our subsidiaries are parties to various legal, regulatory and other matters arising from the day-to-day operations of our businesses or certain predecessor operations that may result in claims against the Company. Although no assurance can be given, we believe, based on our experiences to date and taking into account established reserves and insurance, that the ultimate resolution of such items will not have a material adverse impact on our business, financial position, results of operations or dividends to our shareholders. We believe we have meritorious defenses to the matters to which we are a party and intend to vigorously defend the Company. When we determine a loss is probable of occurring and is reasonably estimable, we accrue an undiscounted liability for such contingencies based on our best estimate using information available at that time. If the estimated loss is a range of potential outcomes and there is no better estimate within the range, we accrue the amount at the low end of the range. We disclose contingencies where an adverse outcome may be material, or in the judgment of management, we conclude the matter should otherwise be disclosed. Federal Energy Regulatory Commission Proceedings SFPP The tariffs and rates charged by SFPP are subject to a number of ongoing proceedings at the FERC, including the complaints and protests of various shippers the most recent of which was filed in late 2015 with the FERC (docketed at OR16-6) challenging SFPP’s filed East Line rates. 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 some of these proceedings shippers have challenged the overall rate being charged by SFPP, and in others the shippers have challenged SFPP’s index-based rate increases. 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 SFPP may include in its rates. With respect to the various SFPP related complaints and protest proceedings at the FERC, we estimate that the shippers are seeking approximately $40 million in annual rate reductions and approximately $169 million in refunds. Management believes SFPP has meritorious arguments supporting SFPP’s rates and intends to vigorously defend SFPP against these complaints and protests. However, to the extent the shippers are successful in one or more of the complaints or protest proceedings, SFPP estimates that applying the principles of several recent FERC decisions in SFPP cases, as applicable, to pending cases would result in rate reductions and refunds substantially lower than those sought by the shippers. 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-A) in July 2015. The FERC generally upheld its prior determinations, ordered refunds to be paid within 60 days, and stated that it will apply its findings in Opinion 517-A to the same issues in the 2010 rate case. EPNG has sought federal appellate review of Opinion 517-A. With respect to the 2010 rate case, the FERC issued its decision (Opinion 528-A) on February 18, 2016. The FERC generally upheld its prior determinations, affirmed prior findings of an Administrative Law Judge that certain shippers qualify for lower rates, and required EPNG to file revised pro forma recalculated rates consistent with the terms of Opinions 517-A and 528-A. EPNG and two intervenors sought rehearing of certain aspects of the decision, and certain intervenors sought judicial review. All refund obligations related to the 2008 rate case were satisfied during calendar year 2015. With respect to the 2010 rate case, EPNG believes it has an appropriate reserve related to the findings in Opinions 517-A and 528-A. Other Commercial Matters Union Pacific Railroad Company Easements & Related Litigation SFPP and Union Pacific Railroad Company (UPRR) are engaged in a proceeding to determine the extent, if any, to which the rent payable by SFPP for the use of pipeline easements on rights-of-way held by UPRR should be adjusted pursuant to existing contractual arrangements for the ten -year period beginning January 1, 2004 ( Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al., Superior Court of the State of California for the County of Los Angeles, filed July 28, 2004). In September 2011, the trial judge determined that the annual rent payable as of January 1, 2004 was $14 million , subject to annual consumer price index increases. SFPP appealed the judgment. By notice dated October 25, 2013, UPRR demanded the payment of $22.3 million in rent for the first year of the next ten -year period beginning January 1, 2014, which SFPP rejected. On November 5, 2014, the Court of Appeals issued an opinion which reversed the judgment, including the award of prejudgment interest, and remanded the matter to the trial court for a determination of UPRR’s property interest in its right-of-way, including whether UPRR has sufficient interest to grant SFPP’s easements. UPRR filed a petition for review to the California Supreme Court which was denied. The trial court has not set a date for the retrial. After the above-referenced decision by the California Court of Appeals which held that UPRR does not own the subsurface rights to grant certain easements and may not be able to collect rent from those easements, a purported class action lawsuit was filed in 2015 in the U.S. District Court for the Southern District of California by private landowners in California who claim to be the lawful owners of subsurface real property allegedly used or occupied by UPRR or SFPP. Substantially similar follow-on lawsuits were filed and are pending in federal courts by landowners in Nevada, Arizona and New Mexico. These suits, which are brought purportedly as class actions on behalf of all landowners who own land in fee adjacent to and underlying the railroad easement under which the SFPP pipeline is located in those respective states, assert claims against UPRR, SFPP, KMGP, and Kinder Morgan Operating L.P. “D” for declaratory judgment, trespass, ejectment, quiet title, unjust enrichment, accounting, and alleged unlawful business acts and practices arising from defendants’ alleged improper use or occupation of subsurface real property. SFPP views these cases as primarily a dispute between UPRR and the plaintiffs. UPRR purported to grant SFPP a network of subsurface pipeline easements along UPRR’s railroad right-of-way. SFPP relied on the validity of those easements and paid rent to UPRR for the value of those easements. We believe we have recorded a right-of-way liability sufficient to cover our potential obligation, if any, for back rent. SFPP and UPRR have engaged in multiple disputes over the circumstances under which SFPP must pay for relocations of its pipeline within the UPRR right-of-way and the safety standards that govern relocations. In 2006, following a bench trial regarding the circumstances under which SFPP must pay for relocations, the judge determined that SFPP must pay for any relocations resulting from any legitimate business purpose of the UPRR. The decision was affirmed on appeal. 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 has sought declaratory relief with respect to its positions regarding the application of these standards with respect to relocations. In 2011, a jury verdict was reached that SFPP was obligated to comply with AREMA standards in connection with a railroad project in Beaumont Hills, California. In 2014, the trial court entered judgment against SFPP, consistent with the jury’s verdict. On June 29, 2015, the parties entered into a confidential settlement of all of the claims relating to the project in Beaumont Hills and the case was dismissed. Since SFPP does not know UPRR’s plans for projects or other activities that would cause pipeline relocations, it is difficult to quantify the effects of the outcome of these cases on SFPP. Even if SFPP is successful in advancing its positions, significant relocations for which SFPP must nonetheless bear the cost (i.e., for railroad purposes, with the standards in the federal Pipeline Safety Act applying) could have an adverse effect on our financial position, results of operations, cash flows, and our dividends to our shareholders. These effects could be even greater in the event SFPP is unsuccessful in one or more of these lawsuits. Gulf LNG Facility Arbitration On March 1, 2016, Gulf LNG Energy, LLC and Gulf LNG Pipeline, LLC (GLNG) received a Notice of Disagreement and Disputed Statements and a Notice of Arbitration from Eni USA Gas Marketing LLC (Eni USA), one of two companies that entered into a terminal use agreement for capacity of the Gulf LNG Facility in Mississippi for an initial term that is not scheduled to expire until the year 2031. Eni USA is an indirect subsidiary of Eni S.p.A., a multi-national integrated energy company headquartered in Milan, Italy. Pursuant to its Notice of Arbitration, Eni USA seeks declaratory and monetary relief based upon its assertion that (i) the terminal use agreement should be terminated because changes in the U.S. natural gas market since the execution of the agreement in December 2007 have “frustrated the essential purpose” of the agreement and (ii) activities allegedly undertaken by affiliates of Gulf LNG Holdings Group LLC “in connection with a plan to convert the LNG Facility into a liquefaction/export facility have given rise to a contractual right on the part of Eni USA to terminate” the agreement. As set forth in the terminal use agreement, disputes are meant to be resolved by final and binding arbitration. A three-member arbitration panel has been selected and the arbitration hearing is scheduled for January 2017. Eni USA has indicated that it will continue to pay the amounts claimed to be due pending resolution of the dispute. The successful assertion by Eni USA of its claim to terminate or amend its payment obligations under the agreement prior to the expiration of its initial term could have an adverse effect on the business, financial position, results of operations, or cash flows of GLNG and distributions to KMI, a 50% shareholder of GLNG. We view the allegations in the demand for arbitration to be without merit, and we intend to vigorously contest them in the arbitration. 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 151 st Judicial District Court for Harris County, Texas (Case No. 62528) against TGP, Kinetica Partners, LLC and two other Kinetica entities. The suit arises from the sale by TGP of the Cameron System in Louisiana to Kinetica Partners, LLC on September 1, 2013. Plains alleges that defendants breached a straddle agreement requiring that gas on the Cameron System be committed to Plains’ Grand Chenier gas-processing facility, that requisite daily volume reports were not provided, that TGP improperly assigned its obligations under the straddle agreement to Kinetica, and that defendants interfered with Plains’ contracts with producers. The petition alleges damages of at least $100 million . Under the Amended and Restated Purchase and Sale Agreement with Kinetica, Kinetica is obligated to defend and indemnify TGP in connection with the gas commitment and reporting claims. After agreeing initially to defend and indemnify TGP against such claims, Kinetica withdrew its defense, disputed its indemnity obligation, and settled with Plains. Trial of the remaining claims against TGP is scheduled for January 2017. We intend to vigorously defend the suit and pursue Kinetica, if necessary, for indemnity and costs of defense. Brinckerhoff v. El Paso Pipeline GP Company, LLC., et al. In December 2011 ( Brinckerhoff I ), March 2012, ( Brinckerhoff II ), May 2013 ( Brinckerhoff III ) and June 2014 ( Brinckerhoff IV), derivative lawsuits were filed in Delaware Chancery Court against El Paso Corporation, El Paso Pipeline GP Company, L.L.C., the general partner of EPB, and the directors of the general partner at the time of the relevant transactions. EPB was named in these lawsuits as a “Nominal Defendant.” The lawsuits arise from the March 2010, November 2010, May 2012 and June 2011 drop-down transactions involving EPB’s purchase of SLNG, Elba Express, CPG and interests in SNG and CIG. The lawsuits allege various conflicts of interest and that the consideration paid by EPB was excessive. Brinckerhoff I and II were consolidated into one proceeding. Motions to dismiss were filed in Brinckerhoff III and Brinckerhoff IV, and such motions remain pending. On June 12, 2014, defendants’ motion for summary judgment was granted in Brinckerhoff I, dismissing the case in its entirety. Defendants’ motion for summary judgment in Brinckerhoff II was granted in part, dismissing certain claims and allowing the matter to go to trial in late 2014 on the remaining claims. On April 20, 2015, the Court issued a post-trial memorandum opinion (Memorandum Opinion) in Brinckerhoff II entering judgment in favor of all of the defendants other than the general partner of EPB, but finding the general partner liable for breach of contract in connection with EPB’s purchase of 49% interests in Elba and SLNG and a 15% interest in SNG in a $1.13 billion drop-down transaction that closed on November 19, 2010 (Fall Dropdown), prior to our acquisition of El Paso Corporation in 2012. In its Memorandum Opinion, the Court determined that EPB suffered damages of $171 million from the Fall Dropdown, which the Court determined to be the amount that EPB overpaid for Elba. We believe the claim is derivative in nature and was extinguished by our acquisition on November 26, 2014, pursuant to a merger agreement, of all of the outstanding common units of EPB that we did not already own. On December 2, 2015, the Court denied our motion to dismiss the remaining claims in Brinckerhoff II based upon our acquisition of all of the outstanding common units of EPB, and held that damages should be calculated by considering the unaffiliated unitholders’ ownership percentage as of the effective date of the merger. Based on this ruling, the Court entered judgment on February 4, 2016 in the amount of $100.2 million plus interest at the legal rate for the period from November 15, 2010 until the date of payment, if any payment is ultimately required. We filed an appeal to the Delaware Supreme Court and Brinckerhoff filed a cross-appeal challenging the dismissal of Brinckerhoff I. The appeal has been fully briefed. Execution on the judgment has been stayed until the appeal is decided. At the present time, we do not believe that an ultimate award, if any, will have a material financial impact on our Company. We continue to believe the transactions at issue were appropriate and in the best interests of EPB and we intend to continue to defend the lawsuits vigorously. Price Reporting Litigation Beginning in 2003, several lawsuits were filed by purchasers of natural gas against El Paso Corporation, El Paso Marketing L.P. and numerous other energy companies based on a claim under state antitrust law that such defendants conspired to manipulate the price of natural gas by providing false price information to industry trade publications that published gas indices. Several of the cases have been settled or dismissed. The remaining cases, which were pending in Nevada federal court, were dismissed, but the dismissal was reversed by the 9 th Circuit Court of Appeals. The U.S. Supreme Court affirmed the 9 th Circuit Court of Appeals in a decision dated April 21, 2015, and the cases were then remanded to the Nevada federal court for further consideration and trial, if necessary, of numerous remaining issues. On May 24, 2016, the Court granted a motion for summary judgment dismissing one of the cases in which approximately $500 million in damages has been alleged. In the remaining cases, approximately $1.5 billion in damages have been alleged against all defendants. There remains significant uncertainty regarding the validity of the causes of action, the damages asserted and the level of damages, if any, which may be allocated to us. Therefore, our costs and legal exposure related to the remaining outstanding lawsuits and claims are not currently determinable. Kinder Morgan, Inc. Corporate Reorganization Litigation Certain unitholders of KMP and EPB filed five putative class action lawsuits in the Court of Chancery of the State of Delaware in connection with the Merger Transactions, which the Court consolidated under the caption In re Kinder Morgan, Inc. Corporate Reorganization Litigation (Consolidated Case No. 10093-VCL). On December 12, 2014, the plaintiffs filed a Verified Second Consolidated Amended Class Action Complaint, which purported to assert claims on behalf of both the former EPB unitholders and the former KMP unitholders. The EPB plaintiff alleged that (i) El Paso Pipeline GP Company, L.L.C. ( EPGP ), the general partner of EPB, and the directors of EPGP breached duties under the EPB partnership agreement, including the implied covenant of good faith and fair dealing, by entering into the EPB Transaction; (ii) EPB, E Merger Sub LLC, KMI and individual defendants aided and abetted such breaches; and (iii) EPB, E Merger Sub LLC, KMI, and individual defendants tortiously interfered with the EPB partnership agreement by causing EPGP to breach its duties under the EPB partnership agreement. The KMP plaintiffs alleged that (i) KMR, KMGP, and individual defendants breached duties under the KMP partnership agreement, including the implied duty of good faith and fair dealing, by entering into the KMP Transaction and by failing to adequately disclose material facts related to the transaction; (ii) KMI aided and abetted such breach; and (iii) KMI, KMP, KMR, P Merger Sub LLC, and individual defendants tortiously interfered with the rights of the plaintiffs and the putative class under the KMP partnership agreement by causing KMGP to breach its duties under the KMP partnership agreement. The complaint sought declaratory relief that the transactions were unlawful and unenforceable, reformation, rescission, rescissory or compensatory damages, interest, and attorneys’ and experts’ fees and costs. On December 30, 2014, the defendants moved to dismiss the complaint. On April 2, 2015, the EPB plaintiff and the defendants submitted a stipulation and proposed order of dismissal, agreeing to dismiss all claims brought by the EPB plaintiff with prejudice as to the EPB lead plaintiff and without prejudice to all other members of the putative EPB class. The Court entered such order on April 2, 2015. On August 24, 2015, the Court issued an order granting the defendants’ motion to dismiss the remaining counts of the complaint for failure to state a claim. On September 21, 2015, plaintiffs filed a notice of appeal to the Supreme Court of the State of Delaware, captioned Haynes Family Trust et al. v. Kinder Morgan G.P., Inc. et al. (Case No. 515). On March 10, 2016, the Delaware Supreme Court affirmed the dismissal of all claims on appeal and this matter is now concluded. 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, 2016 and December 31, 2015, our total reserve for legal matters was $490 million and $463 million , respectively. The reserve primarily relates to various claims from regulatory proceedings arising in our products and natural gas pipeline segments and certain corporate matters. Environmental Matters We and our subsidiaries are subject to environmental cleanup and enforcement actions from time to time. In particular, CERCLA generally imposes joint and several liability for cleanup and enforcement costs on current and predecessor owners and operators of a site, among others, without regard to fault or the legality of the original conduct, subject to the right of a liable party to establish a “reasonable basis” for apportionment of costs. Our operations are also subject to federal, state and local laws and regulations relating to protection of the environment. Although we believe our operations are in substantial compliance with applicable environmental law and regulations, risks of additional costs and liabilities are inherent in pipeline, terminal and CO 2 field and oil field operations, and there can be no assurance that we will not incur significant costs and liabilities. Moreover, it is possible that other developments, such as increasingly stringent environmental laws, regulations and enforcement policies under the terms of authority of those laws, and claims for damages to property or persons resulting from our operations, could result in substantial costs and liabilities to us. We are currently involved in several governmental proceedings involving alleged violations of environmental and safety regulations. As we receive notices of non-compliance, we attempt to negotiate and settle such matters where appropriate. We do not believe that these alleged violations will have a material adverse effect on our business, financial position, results of operations or dividends to our shareholders. We are also currently involved in several governmental proceedings involving groundwater and soil remediation efforts under administrative orders or related state remediation programs. We have established a reserve to address the costs associated with the cleanup. In addition, we are involved with and have been identified as a potentially responsible party in several federal and state superfund sites. Environmental reserves have been established for those sites where our contribution is probable and reasonably estimable. In addition, we are from time to time involved in civil proceedings relating to damages alleged to have occurred as a result of accidental leaks or spills of refined petroleum products, NGL, natural gas and CO 2 . 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. After a dispute with the EPA concerning certain provision of the FS, the parties agreed that the EPA would complete the FS and that the LWG may dispute the FS within 14 days of the publication of the proposed remedy for cleanup. EPA issued the FS and the Proposed Plan on June 8, 2016. The EPA’s Proposed Plan includes a combination of dredging, capping, and enhanced natural recovery. It is expected to take approximately 7 years to implement at an estimated present cost of approximately $750 million . Comments on the FS and the Proposed Plan are due on September 7, 2016. We will submit comments with the LWG and on our own behalf. We anticipate the EPA will issue a Record of Decision (ROD) in mid-2017. KMLT and 90 other parties are involved in a non-judicial allocation process to determine each party’s respective share of the cleanup costs. We are participating in the allocation process on behalf of KMLT and KMBT in connection with their current or former ownership or operation of four facilities located in Portland Harbor. The allocation process will follow the issuance of the ROD with an expected completion date of 2018. Until the allocation process is completed, we are unable at this time to reasonably estimate the extent of our liability for the costs related to the design of the proposed remedy and cleanup of the site. Roosevelt Irrigation District v. Kinder Morgan G.P., Inc., Kinder Morgan Energy Partners, L.P. , U.S. District Court, Arizona The Roosevelt Irrigation District sued KMGP, KMEP and others under CERCLA for alleged contamination of the water purveyor’s wells. The First Amended Complaint sought $175 million in damages against approximately 70 defendants. On August 6, 2013 plaintiffs filed their Second Amended Complaint seeking monetary damages in unspecified amounts and reducing the number of defendants to 26 including KMEP and SFPP. The claims now presented against KMEP and SFPP are related to alleged releases from a specific parcel within the SFPP Phoenix Terminal and the alleged impact of such releases on water wells owned by the plaintiffs and located in the vicinity of the Terminal. We have filed an answer, general denial, and affirmative defenses in response to the Second Amended Complaint and fact discovery is proceeding. 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 and was removed in 2007 to the U.S. District Court, Southern District of California (Case No. 07CV1883WCAB). The City disclosed in discovery that it was seeking approximately $170 million in damages for alleged lost value/lost profit from the redevelopment of the City’s property and alleged lost use of the water resources underlying the property. Later, in 2010, the City amended its initial disclosures to add claims for restoration of the site as well as a number of other claims that increased its claim for damages to approximately $365 million . On November 29, 2012, the Court issued a Notice of Tentative Rulings on the parties’ summary adjudication motions. The Court tentatively granted our partial motions for summary judgment on the City’s claims for water and real estate damages and the State’s claims for violations of California Business and Professions Code § 17200, tentatively denied the City’s motion for summary judgment on its claims of liability for nuisance and trespass, and tentatively granted our cross motion for summary judgment on such claims. On January 25, 2013, the Court rendered judgment in favor of all defendants on all claims asserted by the City. On February 20, 2013, the City of San Diego filed a notice of appeal to the U.S. Court of Appeals for the Ninth Circuit. On May 21, 2015, the Court of Appeals issued a memorandum decision which affirmed the District Court’s summary judgment in our favor with respect to the City’s claim under California Safe Drinking Water and Toxic Enforcement Act, but reversed both the District Court’s summary judgment decision in our favor on the City’s remaining claims and the District Court’s decision to exclude the City’s expert testimony. The Court of Appeals issued a mandate returning the case to the U.S. District Court. On January 25, 2016, the District Court heard oral argument on motions we previously filed to exclude certain expert testimony offered by the City and for partial summary judgment on the City’s claims. By its Order dated February 2, 2016, the Court granted in part and denied in part our motion to exclude certain expert testimony, granted in part and denied in part our motion for partial summary judgment, found that the City is limited to seeking alleged damages relating to the three year period immediately preceding the filing of the lawsuit, found that the City lacks expert opinions or testimony to support its claim for water damages, including the alleged loss of use of the Mission Valley aquifer as a source of both supply and storage of potable water, and denied our motion for partial summary judgment on the City’s alleged real estate and restoration damages. As a result of the Court’s Order, the City’s alleged damages were reduced from approximately $365 million to approximately $160 million . On May 10, 2016, the City filed another lawsuit seeking damages for the three year period immediately preceding the filing of the lawsuit. On June 17, 2016, the parties entered into a settlement resolving all claims related to the historic contamination at the City’s stadium property. The settlement provides for a $20 million payment to the City, a waiver and release by the City of all claims which were asserted or could have been asserted in the litigation, and an agreement by defendants to indemnify the City for additional, incremental costs, if any, incurred by the City in the redevelopment of the stadium property or the development of groundwater beneath the stadium property, that would not have been incurred but for the historical releases from the Mission Valley Terminal. By Order dated June 17, 2016, the District Court granted dismissal of the litigation. This site remains under the regulatory oversight and order of the California Regional Water Quality Control Board (RWQCB). SFPP completed the soil and groundwater remediation at the City of San Diego’s stadium property site and conducted quarterly sampling and monitoring through 2015 as part of the compliance evaluation required by the RWQCB. The RWQCB issued a notice of no further action with respect to the stadium property site on May 4, 2016. SFPP’s remediation effort is now focused on its adjacent Mission Valley Terminal site. Uranium Mines in Vicinity of Cameron, Arizona In the 1950s and 1960s, Rare Metals Inc., a historical subsidiary of EPNG, mined approximately twenty uranium mines in the vicinity of Cameron, Arizona, many of which are located on the Navajo Indian Reservation. The mining activities were in response to numerous incentives provided to industry by the U.S. to locate and produce domestic sources of uranium to support the Cold War-era nuclear weapons program. In May 2012, EPNG received a general notice letter from the EPA notifying EPNG of the EPA’s investigation of certain sites and its determination that the EPA considers EPNG to be a potentially responsible party within the meaning of CERCLA. In August 2013, EPNG and the EPA entered into an Administrative Order on Consent and Scope of Work pursuant to which EPNG is conducting a radiological assessment of the surface of the mines. On September 3, 2014, EPNG filed a complaint in the U.S. District Court for the District of Arizona (Case No. 3:14-08165-DGC) seeking cost recovery and contribution from the applicable federal government agencies toward the cost of environmental activities associated with the mines, given the pervasive control of such federal agencies over all aspects of the nuclear weapons program. Defendants filed an answer and counterclaims seeking contribution and recovery of response costs allegedly incurred by the federal agencies in investiga

Recent Accounting Pronouncement

Recent Accounting Pronouncements (Notes)	6 Months Ended
	Jun. 30, 2016
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recent Accounting Pronouncements	Recent Accounting Pronouncements ASU No. 2014-09 On May 28, 2014, the FASB issued ASU Nos. 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 us as of January 1, 2018. Early adoption is permitted for the interim periods within the adoption year. We are currently reviewing the effect of this ASU on our revenue recognition and assessing the timing of our adoption. ASU No. 2015-02 On February 18, 2015, the FASB issued ASU No. 2015-02, “ Consolidation (Topic 810) - Amendments to the Consolidated Analysis. ” This ASU focuses on the consolidation evaluation for reporting organizations that are required to evaluate whether they should consolidate certain legal entities. We adopted ASU No. 2015-02 effective January 1, 2016 with no material impact to our financial statements. ASU No. 2015-11 On July 22, 2015, the FASB issued ASU No. 2015-11, “ Inventory (Topic 330): Simplifying the Measurement of Inventory .” This ASU requires entities to subsequently measure inventory at the lower of cost and net realizable value, and defines net realizable value as the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. ASU No. 2015-11 will be effective for us as of January 1, 2017. We are currently reviewing the effect of ASU No. 2015-11. ASU No. 2016-02 On February 25, 2016, the FASB issued ASU 2016-02, “ Leases (Topic 842) .” This ASU requires that lessees will be required to recognize assets and liabilities on the balance sheet for the present value of the rights and obligations created by all leases with terms of more than 12 months. The ASU also will require disclosures designed to give financial statement users information on the amount, timing, and uncertainty of cash flows arising from leases. ASU 2016-02 will be effective for us as of January 1, 2019. We are currently reviewing the effect of ASU No. 2016-02. ASU No. 2016-05 On March 10, 2016, the FASB issued ASU 2016-05, “ Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships .” This ASU clarifies that for the purposes of applying the guidance in Topic 815, a change in the counterparty to a derivative instrument that has been designated as the hedging instrument in an existing hedging relationship would not, in and of itself, be considered a termination of the derivative instrument. We adopted ASU 2016-05 in the first quarter of 2016 with no material impact to our financial statements. ASU No. 2016-09 On March 30, 2016, the FASB issued ASU 2016-09, “Compensation - Stock Compensation (Topic 718).” This ASU was issued as part of the FASB’s simplification initiative and affects all entities that issue share-based payment awards to their employees. This ASU covers accounting for income taxes, forfeitures, and statutory tax withholding requirements, as well as classification in the statement of cash flows. ASU No. 2016-09 will be effective for us as of January 1, 2017. We are currently reviewing the effect of ASU No. 2016-09. ASU No. 2016-13 On June 16, 2016, the FASB issued ASU 2016-13, “ Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments .” This ASU modifies the impairment model to utilize an expected loss methodology in place of the currently used incurred loss methodology, which will result in the more timely recognition of losses. ASU No. 2016-13 will be effective for us as of January 1, 2020. We are currently reviewing the effect of ASU No. 2016-13.

Guarantee of Securities of Subs

Guarantee of Securities of Subsidiaries (Notes)	6 Months Ended
	Jun. 30, 2016
Guarantee of Securities of Subsidiaries [Abstract]
Guarantees [Text Block]	Guarantee of Securities of Subsidiaries KMI, along with its direct and indirect subsidiaries KMP and Copano, are issuers of certain public debt securities. After the completion of the Merger Transactions, KMI, KMP, Copano and substantially all of KMI’s wholly owned domestic subsidiaries, entered into a cross guarantee agreement whereby each party to the agreement unconditionally guarantees, jointly and severally, the payment of specified indebtedness of each other party to the agreement. Accordingly, with the exception of certain subsidiaries identified as Subsidiary Non-Guarantors, the parent issuer, subsidiary issuers and other subsidiaries are all guarantors of each series of public debt. As a result of the cross guarantee agreement, a holder of any of the guaranteed public debt securities issued by KMI, KMP or Copano are in the same position with respect to the net assets, income and cash flows of KMI and the Subsidiary Issuers and Guarantors. The only amounts that are not available to the holders of each of the guaranteed public debt securities to satisfy the repayment of such securities are the net assets, income and cash flows of the Subsidiary Non-Guarantors. In lieu of providing separate financial statements for each subsidiary issuer and guarantor, we have included the accompanying condensed consolidating financial statements based on Rule 3-10 of the SEC’s Regulation S-X. We have presented each of the parent and subsidiary issuers in separate columns in this single set of condensed consolidating financial statements. Excluding fair value adjustments, as of June 30, 2016 , Parent Issuer and Guarantor, Subsidiary Issuer and Guarantor-KMP, Subsidiary Issuer and Guarantor-Copano, and Subsidiary Guarantors had $15,032 million , $19,485 million , $332 million , and $5,783 million , respectively, of Guaranteed Notes outstanding. Included in the Subsidiary Guarantors debt balance as presented in the accompanying June 30, 2016 condensed consolidating balance sheets is approximately $173 million of capitalized lease debt that is not subject to the cross guarantee agreement. The accounts within the Parent Issuer and Guarantor, Subsidiary Issuer and Guarantor-KMP, Subsidiary Issuer and Guarantor-Copano, Subsidiary Guarantors and Subsidiary Non-Guarantors are presented using the equity method of accounting for investments in subsidiaries, including subsidiaries that are guarantors and non-guarantors, for purposes of these condensed consolidating financial statements only. These intercompany investments and related activity eliminate in consolidation and are presented separately in the accompanying balance sheets and statements of income and cash flows. A significant amount of each Issuers’ income and cash flow is generated by its respective subsidiaries. As a result, the funds necessary to meet its debt service and/or guarantee obligations are provided in large part by distributions or advances it receives from its respective subsidiaries. We utilize a centralized cash pooling program among our majority-owned and consolidated subsidiaries, including the Subsidiary Issuers and Guarantors and Subsidiary Non-Guarantors. The following Condensed Consolidating Statements of Cash Flows present the intercompany loan and distribution activity, as well as cash collection and payments made on behalf of our subsidiaries, as cash activities. Effective December 31, 2015, Kinder Morgan (Delaware), Inc. and Kinder Morgan Services LLC merged into KMI. As a result of such merger, both entities are no longer Subsidiary Guarantors, and for all periods presented, financial statement balances and activities for Kinder Morgan (Delaware), Inc. and Kinder Morgan Services LLC are reflected within the Parent Issuer and Guarantor column. Condensed Consolidating Statements of Income and Comprehensive Income for the Three Months Ended June 30, 2016 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 8 $ — $ — $ 2,777 $ 371 $ (12 ) $ 3,144 Operating Costs, Expenses and Other Costs of sales — — — 693 60 (1 ) 752 Depreciation, depletion and amortization 4 — — 462 86 — 552 Other operating expenses 30 2 — 681 198 (11 ) 900 Total Operating Costs, Expenses and Other 34 2 — 1,836 344 (12 ) 2,204 Operating (loss) income (26 ) (2 ) — 941 27 — 940 Other Income (Expense) Earnings (losses) from consolidated subsidiaries 752 734 (3 ) 41 17 (1,541 ) — Earnings from equity investments — — — 106 — — 106 Interest, net (176 ) 34 (12 ) (304 ) (13 ) — (471 ) Amortization of excess cost of equity investments and other, net 1 — — 6 6 — 13 Income (Loss) Before Income Taxes 551 766 (15 ) 790 37 (1,541 ) 588 Income Tax Expense (179 ) (1 ) — (16 ) (17 ) — (213 ) Net Income (Loss) 372 765 (15 ) 774 20 (1,541 ) 375 Net Income Attributable to Noncontrolling Interests — — — — — (3 ) (3 ) Net Income (Loss) Attributable to Controlling Interests 372 765 (15 ) 774 20 (1,544 ) 372 Preferred Stock Dividends (39 ) — — — — — (39 ) Net Income (Loss) Available to Common Stockholders $ 333 $ 765 $ (15 ) $ 774 $ 20 $ (1,544 ) $ 333 Net Income (loss) $ 372 $ 765 $ (15 ) $ 774 $ 20 $ (1,541 ) $ 375 Total other comprehensive (loss) income (140 ) (213 ) — (223 ) 8 428 (140 ) Comprehensive income (loss) 232 552 (15 ) 551 28 (1,113 ) 235 Comprehensive income attributable to noncontrolling interests — — — — — (3 ) (3 ) Comprehensive income (loss) attributable to controlling interests $ 232 $ 552 $ (15 ) $ 551 $ 28 $ (1,116 ) $ 232 Condensed Consolidating Statements of Income and Comprehensive Income for the Three Months Ended June 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 10 $ — $ — $ 3,050 $ 414 $ (11 ) $ 3,463 Operating Costs, Expenses and Other Costs of sales — — — 989 95 1 1,085 Depreciation, depletion and amortization 5 — — 473 92 — 570 Other operating expenses 38 — — 767 123 (12 ) 916 Total Operating Costs, Expenses and Other 43 — — 2,229 310 (11 ) 2,571 Operating (loss) income (33 ) — — 821 104 — 892 Other Income (Expense) Earnings (losses) from consolidated subsidiaries 683 666 (5 ) 127 15 (1,486 ) — Earnings from equity investments — — — 114 — — 114 Interest, net (149 ) 34 (12 ) (345 ) — — (472 ) Amortization of excess cost of equity investments and other, net — — — (5 ) 2 — (3 ) Income (Loss) Before Income Taxes 501 700 (17 ) 712 121 (1,486 ) 531 Income Tax Expense (168 ) (2 ) — (11 ) (8 ) — (189 ) Net Income (Loss) 333 698 (17 ) 701 113 (1,486 ) 342 Net Income Attributable to Noncontrolling Interests — — — — — (9 ) (9 ) Net Income (Loss) Attributable to Controlling Interests $ 333 $ 698 $ (17 ) $ 701 $ 113 $ (1,495 ) $ 333 Net Income (loss) $ 333 $ 698 $ (17 ) $ 701 $ 113 $ (1,486 ) $ 342 Total other comprehensive (loss) income (98 ) (139 ) — (148 ) 23 264 (98 ) Comprehensive income (loss) 235 559 (17 ) 553 136 (1,222 ) 244 Comprehensive income attributable to noncontrolling interests — — — — — (9 ) (9 ) Comprehensive income (loss) attributable to controlling interests $ 235 $ 559 $ (17 ) $ 553 $ 136 $ (1,231 ) $ 235 Condensed Consolidating Statements of Income and Comprehensive Income for the Six Months Ended June 30, 2016 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 17 $ — $ — $ 5,602 $ 741 $ (21 ) $ 6,339 Operating Costs, Expenses and Other Costs of sales — — — 1,345 136 2 1,483 Depreciation, depletion and amortization 9 — — 918 176 — 1,103 Other operating expenses 49 4 — 1,494 473 (23 ) 1,997 Total Operating Costs, Expenses and Other 58 4 — 3,757 785 (21 ) 4,583 Operating (loss) income (41 ) (4 ) — 1,845 (44 ) — 1,756 Other Income (Expense) Earnings from consolidated subsidiaries 1,410 1,331 4 54 31 (2,830 ) — Earnings from equity investments — — — 200 — — 200 Interest, net (346 ) 97 (24 ) (613 ) (26 ) — (912 ) Amortization of excess cost of equity investments and other, net 1 — — 1 10 — 12 Income (Loss) Before Income Taxes 1,024 1,424 (20 ) 1,487 (29 ) (2,830 ) 1,056 Income Tax Expense (337 ) (3 ) — (10 ) (17 ) — (367 ) Net Income (Loss) 687 1,421 (20 ) 1,477 (46 ) (2,830 ) 689 Net Income Attributable to Noncontrolling Interests — — — — — (2 ) (2 ) Net Income (Loss) Attributable to Controlling Interests 687 1,421 (20 ) 1,477 (46 ) (2,832 ) 687 Preferred Stock Dividends (78 ) — — — — — (78 ) Net Income (Loss) Available to Common Stockholders $ 609 $ 1,421 $ (20 ) $ 1,477 $ (46 ) $ (2,832 ) $ 609 Net Income (loss) $ 687 $ 1,421 $ (20 ) $ 1,477 $ (46 ) $ (2,830 ) $ 689 Total other comprehensive (loss) income (93 ) (161 ) — (229 ) 132 258 (93 ) Comprehensive income (loss) 594 1,260 (20 ) 1,248 86 (2,572 ) 596 Comprehensive income attributable to noncontrolling interests — — — — — (2 ) (2 ) Comprehensive income (loss) attributable to controlling interests $ 594 $ 1,260 $ (20 ) $ 1,248 $ 86 $ (2,574 ) $ 594 Condensed Consolidating Statements of Income and Comprehensive Income for the Six Months Ended June 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 19 $ — $ — $ 6,276 $ 789 $ (24 ) $ 7,060 Operating Costs, Expenses and Other Costs of sales — — — 1,990 184 1 2,175 Depreciation, depletion and amortization 10 — — 915 183 — 1,108 Other operating expenses 50 38 1 1,452 291 (25 ) 1,807 Total Operating Costs, Expenses and Other 60 38 1 4,357 658 (24 ) 5,090 Operating (loss) income (41 ) (38 ) (1 ) 1,919 131 — 1,970 Other Income (Expense) Earnings (loss) from consolidated subsidiaries 1,482 1,549 (28 ) 141 31 (3,175 ) — Earnings from equity investments — — — 190 — — 190 Interest, net (304 ) 7 (24 ) (649 ) (14 ) — (984 ) Amortization of excess cost of equity investments and other, net — — — (8 ) 6 — (2 ) Income (Loss) Before Income Taxes 1,137 1,518 (53 ) 1,593 154 (3,175 ) 1,174 Income Tax Expense (375 ) (4 ) — (25 ) (9 ) — (413 ) Net Income (Loss) 762 1,514 (53 ) 1,568 145 (3,175 ) 761 Net Loss Attributable to Noncontrolling Interests — — — — — 1 1 Net Income (Loss) Attributable to Controlling Interests 762 1,514 (53 ) 1,568 145 (3,174 ) 762 Net Income (loss) $ 762 $ 1,514 $ (53 ) $ 1,568 $ 145 $ (3,175 ) $ 761 Total other comprehensive loss (274 ) (377 ) — (344 ) (141 ) 862 (274 ) Comprehensive income (loss) 488 1,137 (53 ) 1,224 4 (2,313 ) 487 Comprehensive loss attributable to noncontrolling interests — — — — — 1 1 Comprehensive income (loss) attributable to controlling interests $ 488 $ 1,137 $ (53 ) $ 1,224 $ 4 $ (2,312 ) $ 488 Condensed Consolidating Balance Sheets as of December 31, 2015 (In Millions) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI ASSETS Cash and cash equivalents $ 123 $ — $ — $ 12 $ 142 $ (48 ) $ 229 Other current assets - affiliates 2,233 1,600 — 9,451 695 (13,979 ) — All other current assets 126 119 — 2,163 195 (8 ) 2,595 Property, plant and equipment, net 252 — — 32,195 8,100 — 40,547 Investments 16 2 — 5,906 116 — 6,040 Investments in subsidiaries 27,401 28,038 2,341 4,361 3,320 (65,461 ) — Goodwill 15,089 22 287 5,221 3,171 — 23,790 Notes receivable from affiliates 850 21,319 — 2,070 380 (24,619 ) — Deferred income taxes 7,501 — — — — (2,178 ) 5,323 Other non-current assets 215 307 1 4,943 114 — 5,580 Total assets $ 53,806 $ 51,407 $ 2,629 $ 66,322 $ 16,233 $ (106,293 ) $ 84,104 LIABILITIES AND STOCKHOLDERS’ EQUITY Liabilities Current portion of debt $ 67 $ 500 $ — $ 132 $ 122 $ — $ 821 Other current liabilities - affiliates 1,328 8,682 39 3,216 714 (13,979 ) — All other current liabilities 321 458 7 1,987 527 (56 ) 3,244 Long-term debt 13,845 20,053 378 7,447 683 — 42,406 Notes payable to affiliates 2,404 448 622 19,840 1,305 (24,619 ) — Deferred income taxes — — 2 594 1,582 (2,178 ) — Other long-term liabilities and deferred credits 722 193 — 907 408 — 2,230 Total liabilities 18,687 30,334 1,048 34,123 5,341 (40,832 ) 48,701 Stockholders’ equity Total KMI equity 35,119 21,073 1,581 32,199 10,892 (65,745 ) 35,119 Noncontrolling interests — — — — — 284 284 Total stockholders’ Equity 35,119 21,073 1,581 32,199 10,892 (65,461 ) 35,403 Total Liabilities and Stockholders’ Equity $ 53,806 $ 51,407 $ 2,629 $ 66,322 $ 16,233 $ (106,293 ) $ 84,104 Condensed Consolidating Statements of Cash Flows for the Six Months Ended June 30, 2016 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Net cash (used in) provided by operating activities $ (1,950 ) $ 2,976 $ (143 ) $ 5,616 $ 221 $ (4,376 ) $ 2,344 Cash flows from investing activities Funding to affiliates (1,670 ) (770 ) (1 ) (2,455 ) (219 ) 5,115 — Capital expenditures (37 ) — — (929 ) (504 ) — (1,470 ) Contributions to investments (343 ) — — (13 ) (7 ) — (363 ) Acquisitions of assets and investments, net of cash acquired (2 ) — — (331 ) — — (333 ) Sale of property, plant and equipment, investments and other net assets, net of removal costs — — — 220 — — 220 Distributions from equity investments in excess of cumulative earnings 1,443 298 — 68 — (1,728 ) 81 Other, net — (54 ) — 37 2 — (15 ) Net cash used in investing activities (609 ) (526 ) (1 ) (3,403 ) (728 ) 3,387 (1,880 ) Cash flows from financing activities Issuances of debt 6,847 — — — — — 6,847 Payments of debt (5,191 ) (500 ) — (1,104 ) (5 ) — (6,800 ) Funding from affiliates 1,429 882 144 2,124 536 (5,115 ) — Debt issue costs (6 ) — — — — — (6 ) Cash dividends - common shares (559 ) — — — — — (559 ) Cash dividends - preferred shares (76 ) — — — — — (76 ) Contributions from parents — — — — 87 (87 ) — Contributions from noncontrolling interests — — — — — 87 87 Distributions to parents — (2,832 ) — (3,234 ) (90 ) 6,156 — Distributions to noncontrolling interests — — — — — (11 ) (11 ) Net cash provided by (used in) financing activities 2,444 (2,450 ) 144 (2,214 ) 528 1,030 (518 ) Effect of exchange rate changes on cash and cash equivalents — — — — 5 — 5 Net (decrease) increase in cash and cash equivalents (115 ) — — (1 ) 26 41 (49 ) Cash and cash equivalents, beginning of period 123 — — 12 142 (48 ) 229 Cash and cash equivalents, end of period $ 8 $ — $ — $ 11 $ 168 $ (7 ) $ 180 Condensed Consolidating Statements of Cash Flows for the Six Months Ended June 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Net cash (used in) provided by operating activities $ (1,147 ) $ 5,190 $ 72 $ 3,755 $ (26 ) $ (5,306 ) $ 2,538 Cash flows from investing activities Funding to affiliates (2,118 ) (6,486 ) (1 ) (4,387 ) (351 ) 13,343 — Capital expenditures (23 ) — (3 ) (1,705 ) (183 ) 5 (1,909 ) Contributions to investments — — — (45 ) — — (45 ) Investment in KMP (159 ) — — — — 159 — Acquisitions of assets and investments, net of cash acquired (1,709 ) — — (210 ) — — (1,919 ) Sale of property, plant and equipment, investments and other net assets, net of removal costs — — 5 4 — (5 ) 4 Distributions from equity investments in excess of cumulative earnings 292 — — 80 — (258 ) 114 Other, net — (2 ) — 4 9 — 11 Net cash (used in) provided by investing activities (3,717 ) (6,488 ) 1 (6,259 ) (525 ) 13,244 (3,744 ) Cash flows from financing activities Issuances of debt 9,485 — — — — — 9,485 Payments of debt (8,598 ) (300 ) — (38 ) (5 ) — (8,941 ) Funding from (to) affiliates 3,471 3,906 (73 ) 5,546 493 (13,343 ) — Debt issue costs (20 ) — — — — — (20 ) Issuances of common shares 2,562 — — — — — 2,562 Cash dividends (2,006 ) — — — — — (2,006 ) Repurchases of warrants (5 ) — — — — — (5 ) Contributions from parents — 156 — 3 — (159 ) — Distributions to parents — (2,478 ) — (3,010 ) (92 ) 5,580 — Distributions to noncontrolling interests — — — — — (16 ) (16 ) Other, net — (1 ) — — — — (1 ) Net cash provided by (used in) financing activities 4,889 1,283 (73 ) 2,501 396 (7,938 ) 1,058 Effect of exchange rate changes on cash and cash equivalents — — — — (4 ) — (4 ) Net increase (decrease) in cash and cash equivalents 25 (15 ) — (3 ) (159 ) — (152 ) Cash and cash equivalents, beginning of period 4 15 — 17 279 — 315 Cash and cash equivalents, end of period $ 29 $ — $ — $ 14 $ 120 $ — $ 163

General (Policies)

General (Policies)	6 Months Ended
	Jun. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Accounting, Policy [Policy Text Block]	Basis of Presentation General Our reporting currency is U.S. dollars, and all references to dollars are U.S. dollars, unless stated otherwise. Our accompanying unaudited consolidated financial statements have been prepared under the rules and regulations of the United States Securities and Exchange Commission (SEC). These rules and regulations conform to the accounting principles contained in the FASB’s Accounting Standards Codification, the single source of GAAP. Under such rules and regulations, all significant intercompany items have been eliminated in consolidation. In our opinion, all adjustments, which are of a normal and recurring nature, considered necessary for a fair presentation of our financial position and operating results for the interim periods have been included in the accompanying consolidated financial statements, and certain amounts from prior periods have been reclassified to conform to the current presentation. Interim results are not necessarily indicative of results for a full year; accordingly, you should read these consolidated financial statements in conjunction with our consolidated financial statements and related notes included in our 2015 Form 10-K.
Earnings Per Share [Policy Text Block]	Earnings per Share We calculate earnings per share using the two-class method. Earnings were allocated to Class P shares of common stock and participating securities based on the amount of dividends paid in the current period plus an allocation of the undistributed earnings or excess distributions over earnings to the extent that each security participates in earnings or excess distributions over earnings. Our unvested restricted stock awards, which may be stock or stock units issued to management employees and include dividend equivalent payments, do not participate in excess distributions over earnings.

General (Tables)

General (Tables)	6 Months Ended
	Jun. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Net Income for Shareholders and Participating Securities [Table Text Block]	The following tables set forth the allocation of net income available to shareholders of Class P shares and participating securities and the reconciliation of Basic Weighted Average Common Shares Outstanding to Diluted Weighted Average Common Shares Outstanding (in millions): Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Class P $ 332 $ 330 $ 607 $ 756 Participating securities: Restricted stock awards(a) 1 3 2 6 Net Income Available to Common Stockholders $ 333 $ 333 $ 609 $ 762 Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Basic Weighted Average Common Shares Outstanding 2,229 2,175 2,229 2,158 Effect of dilutive securities: Warrants — 12 — 11 Diluted Weighted Average Common Shares Outstanding 2,229 2,187 2,229 2,169 ________ (a) As of June 30, 2016 , there were approximately 8 million such restricted stock awards.
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share [Table Text Block]	The following maximum number of potential common stock equivalents are antidilutive and, accordingly, are excluded from the determination of diluted earnings per share (in millions on a weighted-average basis): Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Unvested restricted stock awards 8 7 8 7 Warrants to purchase our Class P shares(a) 293 287 293 288 Convertible trust preferred securities 8 8 8 9 Mandatory convertible preferred stock(b) 58 n/a 58 n/a

Acquisitions (Tables)

Acquisitions (Tables)	6 Months Ended
	Jun. 30, 2016
Business Acquisition [Line Items]
Schedule of Purchase Price Allocation [Table Text Block]	The evaluation of the assigned fair values for the BP terminals acquisition is ongoing and subject to adjustment. As of June 30, 2016 , our preliminary allocation of the purchase price for the BP terminals acquisition and the adjusted purchase price allocations for the Hiland acquisition and Royal Vopak terminals acquisition, both completed in February 2015, are detailed below (in millions). Acquisitions BP Terminal Assets Hiland Royal Vopak Terminal Assets Purchase Price Allocation: Current assets $ 2 $ 79 $ 2 Property, plant and equipment 396 1,492 155 Goodwill — 310 6 Deferred charges and other assets(a) — 1,498 — Total assets acquired 398 3,379 163 Current liabilities — (253 ) (1 ) Debt — (1,413 ) — Other liabilities (49 ) (4 ) (4 ) Cash consideration $ 349 $ 1,709 $ 158 _______ (a) Primarily consists of customer contracts and relationships with a weighted average amortization period of 16.4 years

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2016
Debt Disclosure [Abstract]
Schedule of Debt [Table Text Block]	The following table provides detail on the principal amount of our outstanding debt balances. The table amounts exclude all debt fair value adjustments, including debt discounts, premiums and issuance costs (in millions): June 30, 2016 December 31, 2015 KMI Unsecured term loan facility, variable rate, due January 26, 2019(a) $ 1,000 $ — Senior notes, 1.50% through 8.25%, due 2016 through 2098(b) 13,309 13,346 Credit facility due November 26, 2019(c) 700 — Commercial paper borrowings(c) 24 — KMP Senior notes, 2.65% through 9.00%, due 2016 through 2044 19,485 19,985 TGP senior notes, 7.00% through 8.375%, due 2016 through 2037(a) 1,540 1,790 EPNG senior notes, 5.95% through 8.625%, due 2017 through 2032 1,115 1,115 Copano senior notes, 7.125%, due April 1, 2021 332 332 CIG senior notes, 6.85%, due June 15, 2037 100 100 SNG notes, 4.40% through 8.00%, due 2017 through 2032 1,211 1,211 Other Subsidiary Borrowings (as obligor) Kinder Morgan Finance Company, LLC, senior notes, 5.70% through 6.40%, due 2016 through 2036(a) 786 1,636 Hiland Partners Holdings LLC, senior notes, 5.50% and 7.25%, due 2020 and 2022 974 974 EPC Building, LLC, promissory note, 3.967%, due 2016 through 2035 438 443 Trust I preferred securities, 4.75%, due March 31, 2028 221 221 KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock 100 100 Other miscellaneous debt 297 300 Total debt – KMI and Subsidiaries 41,632 41,553 Less: Current portion of debt(a)(d) 3,419 821 Total long-term debt – KMI and Subsidiaries(e) $ 38,213 $ 40,732 _______ (a) On January 26, 2016, we entered into a $1.0 billion three -year unsecured term loan facility with a variable interest rate, which is determined in the same manner as interest on our revolving credit facility borrowings. In January 2016, we repaid $850 million of maturing 5.70% senior notes, and in February 2016, we repaid $250 million of maturing 8.00% senior notes primarily using proceeds from the three-year term loan. Since we refinanced a portion of the maturing debt with proceeds from long-term debt, we classified $1 billion of the maturing debt within “Long-term debt” on our consolidated balance sheet as of December 31, 2015. (b) Amount includes senior notes that are denominated in Euros and have been converted and are respectively reported above at the June 30, 2016 exchange rate of 1.1106 U.S. dollars per Euro and the December 31, 2015 exchange rate of 1.0862 U.S. dollars per Euro. For the six months ended June 30, 2016, our debt increased by $31 million as a result of the change in the exchange rate of U.S. dollars per Euro. At the time of issuance, we entered into cross-currency swap agreements associated with these senior notes, effectively converting these Euro-denominated senior notes to U.S. dollars (see Note 5 “Risk Management— Foreign Currency Risk Management ”). (c) As of June 30, 2016 , the weighted average interest rate on our credit facility borrowings, including commercial paper borrowings, was 1.91% . (d) Amounts include outstanding credit facility borrowings, commercial paper borrowings and other debt maturing within 12 months (see “—Current Portion of Debt” below). (e) Excludes our “Debt fair value adjustments” which, as of June 30, 2016 and December 31, 2015 , increased our combined debt balances by $1,988 million and $1,674 million , respectively. In addition to all unamortized debt discount/premium amounts, debt issuance costs and purchase accounting on our debt balances, our debt fair value adjustments also include amounts associated with the offsetting entry for hedged debt and any unamortized portion of proceeds received from the early termination of interest rate swap agreements.
Schedule of Significant Long-Term Debt Issuances and Payments [Table Text Block]	following are significant long-term debt issuances and repayments made during the six months ended June 30, 2016 : Issuances $1.0 billion unsecured term loan facility due 2019 Repayments $850 million 5.70% notes due 2016 $500 million 3.50% notes due 2016 $250 million 8.00% notes due 2016 $67 million 8.25% notes due 2016
Schedule of Short-term Debt [Table Text Block]	In addition to outstanding credit facility borrowings, commercial paper borrowings, and other debt maturing within 12 months, our current portion of debt includes the current portion of the following significant series of long-term notes: As of June 30, 2016 $600 million 6.00% notes due February 2017 $300 million 7.50% notes due April 2017 $355 million 5.95% notes due April 2017 $500 million 5.90% notes due April 2017 $786 million 7.00% notes due June 2017 As of December 31, 2015 $500 million 3.50% notes due March 2016

Stockholders' Equity (Tables)

Stockholders' Equity (Tables)	6 Months Ended
	Jun. 30, 2016
Stockholders' Equity Note [Abstract]
Schedule of Dividends Payable [Table Text Block]	The following table provides information about our per share dividends: Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Per common share cash dividend declared for the period $ 0.125 $ 0.49 $ 0.250 $ 0.97 Per common share cash dividend paid in the period $ 0.125 $ 0.48 $ 0.250 $ 0.93

Risk Management (Tables)

Risk Management (Tables)	6 Months Ended
	Jun. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	As of June 30, 2016 , 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 (21.2 ) MMBbl Crude oil basis (4.1 ) MMBbl Natural gas fixed price (31.9 ) Bcf Natural gas basis (21.8 ) Bcf Derivatives not designated as hedging contracts Crude oil fixed price (0.3 ) MMBbl Crude oil basis (0.4 ) MMBbl Natural gas fixed price (12.8 ) Bcf Natural gas basis (2.6 ) Bcf NGL and other fixed price (3.4 ) MMBbl
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table summarizes the fair values of our derivative contracts included in our accompanying consolidated balance sheets (in millions): Fair Value of Derivative Contracts Asset derivatives Liability derivatives June 30, December 31, June 30, December 31, Location Fair value Fair value Derivatives designated as hedging contracts Natural gas and crude derivative contracts Fair value of derivative contracts/(Other current liabilities) $ 177 $ 359 $ (38 ) $ (13 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 139 244 (18 ) — Subtotal 316 603 (56 ) (13 ) Interest rate swap agreements Fair value of derivative contracts/(Other current liabilities) 117 111 — — Deferred charges and other assets/(Other long-term liabilities and deferred credits) 657 273 — (9 ) Subtotal 774 384 — (9 ) Cross-currency swap agreements Fair value of derivative contracts/(Other current liabilities) — — (22 ) (6 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 13 — (12 ) (46 ) Subtotal 13 — (34 ) (52 ) Total 1,103 987 (90 ) (74 ) Derivatives not designated as hedging contracts Natural gas, crude, NGL and other derivative contracts Fair value of derivative contracts/(Other current liabilities) 7 35 (10 ) (1 ) Subtotal 7 35 (10 ) (1 ) Interest rate swap agreements Fair value of derivative contracts/(Other current liabilities) 12 1 — (11 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 50 — — (5 ) Subtotal 62 1 — (16 ) Power derivative contracts Fair value of derivative contracts/(Other current liabilities) — 1 — (17 ) Subtotal — 1 — (17 ) Total 69 37 (10 ) (34 ) Total derivatives $ 1,172 $ 1,024 $ (100 ) $ (108 )
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance	The following tables summarize the impact of our derivative contracts on our accompanying consolidated statements of income (in millions): Derivatives in fair value hedging relationships Location Gain/(loss) recognized in income on derivatives and related hedged item Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Interest rate swap agreements Interest, net $ 119 $ (233 ) $ 399 $ (88 ) Hedged fixed rate debt Interest, net $ (120 ) $ 256 $ (404 ) $ 117 Derivatives in cash flow hedging relationships Gain/(loss) recognized in OCI on derivative (effective portion)(a) Location Gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b) Location Gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing) Three Months Ended June 30, Three Months Ended June 30, Three Months Ended June 30, 2016 2015 2016 2015 2016 2015 Energy commodity derivative contracts $ (111 ) $ (82 ) Revenues—Natural gas sales $ 2 $ 1 Revenues—Natural gas sales $ — $ — Revenues—Product sales and other 33 37 Revenues—Product sales and other (6 ) 3 Costs of sales (2 ) (14 ) Costs of sales — — Interest rate swap agreements(c) (1 ) 1 Interest, net — — Interest, net — — Cross-currency swap (30 ) 23 Other, net (22 ) 33 Other, net — — Total $ (142 ) $ (58 ) Total $ 11 $ 57 Total $ (6 ) $ 3 Derivatives in cash flow hedging relationships Gain/(loss) recognized in OCI on derivative (effective portion)(a) Location Gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b) Location Gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing) Six Months Ended June 30, Six Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 2016 2015 Energy commodity derivative contracts $ (84 ) $ (47 ) Revenues—Natural gas sales $ 23 $ 25 Revenues—Natural gas sales $ — $ — Revenues—Product sales and other 90 101 Revenues—Product sales and other (5 ) 10 Costs of sales (12 ) (19 ) Costs of sales — — Interest rate swap agreements(c) (5 ) (2 ) Interest, net (1 ) (1 ) Interest, net — — Cross-currency swap 20 (11 ) Other, net 19 23 Other, net — — Total $ (69 ) $ (60 ) Total $ 119 $ 129 Total $ (5 ) $ 10 _____ (a) We expect to reclassify an approximate $46 million gain associated with cash flow hedge price risk management activities included in our accumulated other comprehensive loss balances as of June 30, 2016 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). (c) Amounts represent our share of an equity investee’s accumulated other comprehensive loss. Derivatives not designated as accounting hedges Location Gain/(loss) recognized in income on derivatives Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Energy commodity derivative contracts Revenues—Natural gas sales $ (11 ) $ (2 ) $ (5 ) $ 3 Revenues—Product sales and other (12 ) (40 ) (14 ) 4 Costs of sales 3 3 (2 ) — Interest rate swap agreements Interest, net 24 — 77 — Total(a) $ 4 $ (39 ) $ 56 $ 7 _______ (a) Three and six months ended June 30, 2016 includes an approximate gain of $20 million and $39 million , respectively, associated with natural gas, crude and NGL derivative contract settlements.
Reclassification out of Accumulated Other Comprehensive Income [Table Text Block]	Changes in the components of our “Accumulated other comprehensive loss” not including non-controlling interests are summarized as follows (in millions): Net unrealized gains/(losses) on cash flow hedge derivatives Foreign currency translation adjustments Pension and other postretirement liability adjustments Total accumulated other comprehensive loss Balance as of December 31, 2015 $ 219 $ (322 ) $ (358 ) $ (461 ) Other comprehensive (loss) gain before reclassifications (69 ) 85 10 26 Gains reclassified from accumulated other comprehensive income (loss) (119 ) — — (119 ) Net current-period other comprehensive (loss) income (188 ) 85 10 (93 ) Balance as of June 30, 2016 $ 31 $ (237 ) $ (348 ) $ (554 ) Net unrealized gains/(losses) on cash flow hedge derivatives Foreign currency translation adjustments Pension and other postretirement liability adjustments Total accumulated other comprehensive loss Balance as of December 31, 2014 $ 327 $ (108 ) $ (236 ) $ (17 ) Other comprehensive (loss) gain before reclassifications (60 ) (91 ) 6 (145 ) Gains reclassified from accumulated other comprehensive income (loss) (129 ) — — (129 ) Net current-period other comprehensive (loss) income (189 ) (91 ) 6 (274 ) Balance as of June 30, 2015 $ 138 $ (199 ) $ (230 ) $ (291 )

Fair Value (Tables)

Fair Value (Tables)	6 Months Ended
	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The following two tables summarize the fair value measurements of our (i) energy commodity derivative contracts; (ii) interest rate swap agreements; and (iii) cross-currency swap agreements, based on the three levels established by the Codification (in millions). The tables also identify the impact of derivative contracts which we have elected to present on our accompanying consolidated balance sheets on a gross basis that are eligible for netting under master netting agreements. Balance sheet asset fair value measurements by level Net amount Level 1 Level 2 Level 3 Gross amount Contracts available for netting Cash collateral held(b) As of June 30, 2016 Energy commodity derivative contracts(a) $ 6 $ 317 $ — $ 323 $ (32 ) $ — $ 291 Interest rate swap agreements $ — $ 836 $ — $ 836 $ — $ — $ 836 Cross-currency swap agreements $ — $ 13 $ — $ 13 $ (13 ) $ — $ — As of December 31, 2015 Energy commodity derivative contracts(a) $ 48 $ 589 $ 2 $ 639 $ (12 ) $ (37 ) $ 590 Interest rate swap agreements $ — $ 385 $ — $ 385 $ (8 ) $ — $ 377 Cross-currency swap agreements $ — $ — $ — $ — $ — $ — $ — Balance sheet liability fair value measurements by level Net amount Level 1 Level 2 Level 3 Gross amount Contracts available for netting Collateral posted(c) As of June 30, 2016 Energy commodity derivative contracts(a) $ (19 ) $ (47 ) $ — $ (66 ) $ 32 $ 18 $ (16 ) Interest rate swap agreements $ — $ — $ — $ — $ — $ — $ — Cross-currency swap agreements $ — $ (34 ) $ — $ (34 ) $ 13 $ — $ (21 ) As of December 31, 2015 Energy commodity derivative contracts(a) $ (4 ) $ (10 ) $ (17 ) $ (31 ) $ 12 $ — $ (19 ) Interest rate swap agreements $ — $ (25 ) $ — $ (25 ) $ 8 $ — $ (17 ) Cross-currency swap agreements $ — $ (52 ) $ — $ (52 ) $ — $ — $ (52 ) _______ (a) Level 1 consists primarily of New York Mercantile Exchange natural gas futures. Level 2 consists primarily of OTC West Texas Intermediate swaps and options. Level 3 consists primarily of power derivative contracts. (b) Cash margin deposits held by us associated with our energy commodity contract positions and OTC swap agreements and reported within “Other current liabilities” on our accompanying consolidated balance sheets. (c) Cash margin deposits posted by us associated with our energy commodity contract positions and OTC swap agreements and reported within “Other current assets” on our accompanying consolidated balance sheets.
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation	The table below provides a summary of changes in the fair value of our Level 3 energy commodity derivative contracts (in millions): Significant unobservable inputs (Level 3) Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Derivatives-net asset (liability) Beginning of Period $ (2 ) $ (49 ) $ (15 ) $ (61 ) Total gains or (losses) included in earnings (3 ) — (9 ) — Settlements 5 12 24 24 End of Period $ — $ (37 ) $ — $ (37 ) The amount of total gains or (losses) for the period included in earnings attributable to the change in unrealized gains or (losses) relating to assets held at the reporting date $ — $ 1 $ — $ 3
Schedule of Debt [Table Text Block]	The estimated fair value of our outstanding debt balances is disclosed below (in millions): June 30, 2016 December 31, 2015 Carrying value Estimated fair value Carrying value Estimated fair value Total debt $ 43,620 $ 43,061 $ 43,227 $ 37,481 We used Level 2 input values to measure the estimated fair value of our outstanding debt balances as of both June 30, 2016 and December 31, 2015 .

Reportable Segments (Tables)

Reportable Segments (Tables)	6 Months Ended
	Jun. 30, 2016
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, 2016 2015 2016 2015 Revenues Natural Gas Pipelines Revenues from external customers $ 1,882 $ 2,091 $ 3,852 $ 4,268 Intersegment revenues 1 5 2 8 CO 2 304 353 606 799 Terminals Revenues from external customers 487 469 952 926 Intersegment revenues 1 1 1 1 Products Pipelines Revenues from external customers 398 477 789 921 Intersegment revenues 3 1 8 1 Kinder Morgan Canada 63 65 122 125 Other 1 (1 ) 1 3 Total segment revenues 3,140 3,461 6,333 7,052 Other revenues 9 9 17 18 Less: Total intersegment revenues (5 ) (7 ) (11 ) (10 ) Total consolidated revenues $ 3,144 $ 3,463 $ 6,339 $ 7,060 Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Segment EBDA(a) Natural Gas Pipelines $ 966 $ 928 $ 1,958 $ 1,943 CO 2 203 240 389 576 Terminals 292 279 545 549 Products Pipelines 293 277 472 523 Kinder Morgan Canada 40 37 80 78 Other (5 ) (40 ) (13 ) (46 ) Total Segment EBDA 1,789 1,721 3,431 3,623 Total segment DD&A (552 ) (570 ) (1,103 ) (1,108 ) Total segment amortization of excess cost of equity investments (16 ) (14 ) (30 ) (26 ) Other revenues 9 9 17 18 General and administrative expense (189 ) (164 ) (379 ) (380 ) Interest expense, net of unallocable interest income (470 ) (472 ) (912 ) (986 ) Unallocable income tax expense (196 ) (168 ) (335 ) (380 ) Total consolidated net income $ 375 $ 342 $ 689 $ 761 June 30, 2016 December 31, 2015 Assets Natural Gas Pipelines $ 53,677 $ 53,704 CO 2 4,317 4,706 Terminals 9,673 9,083 Products Pipelines 8,360 8,464 Kinder Morgan Canada 1,586 1,434 Other 317 418 Total segment assets 77,930 77,809 Corporate assets(b) 6,360 6,276 Assets held for sale 27 19 Total consolidated assets $ 84,317 $ 84,104 _______ (a) We evaluate performance based on each segment’s EBDA. Segment EBDA includes revenues, earnings from equity investments, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other expense (income), net, and losses on impairments and disposals of long-lived assets, net. Operating expenses include natural gas purchases and other costs of sales, operations and maintenance expenses, and taxes, other than income taxes. (b) Includes cash and cash equivalents, margin and restricted deposits, unallocable interest receivable, prepaid assets and deferred charges, deferred tax assets, risk management assets related to debt fair value adjustments and miscellaneous corporate assets (such as information technology and telecommunications equipment) not allocated to individual segments.

Income Taxes (Tables)

Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2016
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	Income tax expense included in our accompanying consolidated statements of income were as follows (in millions, except percentages): Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Income tax expense $ 213 $ 189 $ 367 $ 413 Effective tax rate 36.2 % 35.6 % 34.8 % 35.2 %

Guarantee of Securities of Su29

Guarantee of Securities of Subsidiaries (Tables)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Guarantee of Securities of Subsidiaries [Abstract]
Condensed Consolidating Statements of Income and Comprehensive Income [Table Text Block]	Condensed Consolidating Statements of Income and Comprehensive Income for the Three Months Ended June 30, 2016 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 8 $ — $ — $ 2,777 $ 371 $ (12 ) $ 3,144 Operating Costs, Expenses and Other Costs of sales — — — 693 60 (1 ) 752 Depreciation, depletion and amortization 4 — — 462 86 — 552 Other operating expenses 30 2 — 681 198 (11 ) 900 Total Operating Costs, Expenses and Other 34 2 — 1,836 344 (12 ) 2,204 Operating (loss) income (26 ) (2 ) — 941 27 — 940 Other Income (Expense) Earnings (losses) from consolidated subsidiaries 752 734 (3 ) 41 17 (1,541 ) — Earnings from equity investments — — — 106 — — 106 Interest, net (176 ) 34 (12 ) (304 ) (13 ) — (471 ) Amortization of excess cost of equity investments and other, net 1 — — 6 6 — 13 Income (Loss) Before Income Taxes 551 766 (15 ) 790 37 (1,541 ) 588 Income Tax Expense (179 ) (1 ) — (16 ) (17 ) — (213 ) Net Income (Loss) 372 765 (15 ) 774 20 (1,541 ) 375 Net Income Attributable to Noncontrolling Interests — — — — — (3 ) (3 ) Net Income (Loss) Attributable to Controlling Interests 372 765 (15 ) 774 20 (1,544 ) 372 Preferred Stock Dividends (39 ) — — — — — (39 ) Net Income (Loss) Available to Common Stockholders $ 333 $ 765 $ (15 ) $ 774 $ 20 $ (1,544 ) $ 333 Net Income (loss) $ 372 $ 765 $ (15 ) $ 774 $ 20 $ (1,541 ) $ 375 Total other comprehensive (loss) income (140 ) (213 ) — (223 ) 8 428 (140 ) Comprehensive income (loss) 232 552 (15 ) 551 28 (1,113 ) 235 Comprehensive income attributable to noncontrolling interests — — — — — (3 ) (3 ) Comprehensive income (loss) attributable to controlling interests $ 232 $ 552 $ (15 ) $ 551 $ 28 $ (1,116 ) $ 232
Condensed Balance Sheet [Table Text Block]	Condensed Consolidating Balance Sheets as of June 30, 2016 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI ASSETS Cash and cash equivalents $ 8 $ — $ — $ 11 $ 168 $ (7 ) $ 180 Other current assets - affiliates 5,859 6,192 115 13,171 745 (26,082 ) — All other current assets 141 186 — 1,787 184 (8 ) 2,290 Property, plant and equipment, net 270 — — 32,366 8,563 — 41,199 Investments 16 2 — 6,062 122 — 6,202 Investments in subsidiaries 25,221 25,762 2,345 4,926 3,973 (62,227 ) — Goodwill 15,089 22 287 5,220 3,184 — 23,802 Notes receivable from affiliates 1,024 21,741 — 1,239 319 (24,323 ) — Deferred income taxes 7,211 — — — — (2,236 ) 4,975 Other non-current assets 373 537 1 4,646 112 — 5,669 Total assets $ 55,212 $ 54,442 $ 2,748 $ 69,428 $ 17,370 $ (114,883 ) $ 84,317 LIABILITIES AND STOCKHOLDERS’ EQUITY Liabilities Current portion of debt $ 1,510 $ 600 $ — $ 1,187 $ 122 $ — $ 3,419 Other current liabilities - affiliates 1,788 14,623 51 9,133 487 (26,082 ) — All other current liabilities 373 481 7 1,831 470 (15 ) 3,147 Long-term debt 14,226 19,662 374 5,260 679 — 40,201 Notes payable to affiliates 1,547 448 753 20,217 1,358 (24,323 ) — Deferred income taxes — — 2 625 1,609 (2,236 ) — All other long-term liabilities and deferred credits 657 70 — 889 461 — 2,077 Total liabilities 20,101 35,884 1,187 39,142 5,186 (52,656 ) 48,844 Stockholders’ equity Total KMI equity 35,111 18,558 1,561 30,286 12,184 (62,589 ) 35,111 Noncontrolling interests — — — — — 362 362 Total stockholders’ Equity 35,111 18,558 1,561 30,286 12,184 (62,227 ) 35,473 Total Liabilities and Stockholders’ Equity $ 55,212 $ 54,442 $ 2,748 $ 69,428 $ 17,370 $ (114,883 ) $ 84,317	Condensed Consolidating Balance Sheets as of June 30, 2016 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI ASSETS Cash and cash equivalents $ 8 $ — $ — $ 11 $ 168 $ (7 ) $ 180 Other current assets - affiliates 5,859 6,192 115 13,171 745 (26,082 ) — All other current assets 141 186 — 1,787 184 (8 ) 2,290 Property, plant and equipment, net 270 — — 32,366 8,563 — 41,199 Investments 16 2 — 6,062 122 — 6,202 Investments in subsidiaries 25,221 25,762 2,345 4,926 3,973 (62,227 ) — Goodwill 15,089 22 287 5,220 3,184 — 23,802 Notes receivable from affiliates 1,024 21,741 — 1,239 319 (24,323 ) — Deferred income taxes 7,211 — — — — (2,236 ) 4,975 Other non-current assets 373 537 1 4,646 112 — 5,669 Total assets $ 55,212 $ 54,442 $ 2,748 $ 69,428 $ 17,370 $ (114,883 ) $ 84,317 LIABILITIES AND STOCKHOLDERS’ EQUITY Liabilities Current portion of debt $ 1,510 $ 600 $ — $ 1,187 $ 122 $ — $ 3,419 Other current liabilities - affiliates 1,788 14,623 51 9,133 487 (26,082 ) — All other current liabilities 373 481 7 1,831 470 (15 ) 3,147 Long-term debt 14,226 19,662 374 5,260 679 — 40,201 Notes payable to affiliates 1,547 448 753 20,217 1,358 (24,323 ) — Deferred income taxes — — 2 625 1,609 (2,236 ) — All other long-term liabilities and deferred credits 657 70 — 889 461 — 2,077 Total liabilities 20,101 35,884 1,187 39,142 5,186 (52,656 ) 48,844 Stockholders’ equity Total KMI equity 35,111 18,558 1,561 30,286 12,184 (62,589 ) 35,111 Noncontrolling interests — — — — — 362 362 Total stockholders’ Equity 35,111 18,558 1,561 30,286 12,184 (62,227 ) 35,473 Total Liabilities and Stockholders’ Equity $ 55,212 $ 54,442 $ 2,748 $ 69,428 $ 17,370 $ (114,883 ) $ 84,317 Condensed Consolidating Balance Sheets as of December 31, 2015 (In Millions) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI ASSETS Cash and cash equivalents $ 123 $ — $ — $ 12 $ 142 $ (48 ) $ 229 Other current assets - affiliates 2,233 1,600 — 9,451 695 (13,979 ) — All other current assets 126 119 — 2,163 195 (8 ) 2,595 Property, plant and equipment, net 252 — — 32,195 8,100 — 40,547 Investments 16 2 — 5,906 116 — 6,040 Investments in subsidiaries 27,401 28,038 2,341 4,361 3,320 (65,461 ) — Goodwill 15,089 22 287 5,221 3,171 — 23,790 Notes receivable from affiliates 850 21,319 — 2,070 380 (24,619 ) — Deferred income taxes 7,501 — — — — (2,178 ) 5,323 Other non-current assets 215 307 1 4,943 114 — 5,580 Total assets $ 53,806 $ 51,407 $ 2,629 $ 66,322 $ 16,233 $ (106,293 ) $ 84,104 LIABILITIES AND STOCKHOLDERS’ EQUITY Liabilities Current portion of debt $ 67 $ 500 $ — $ 132 $ 122 $ — $ 821 Other current liabilities - affiliates 1,328 8,682 39 3,216 714 (13,979 ) — All other current liabilities 321 458 7 1,987 527 (56 ) 3,244 Long-term debt 13,845 20,053 378 7,447 683 — 42,406 Notes payable to affiliates 2,404 448 622 19,840 1,305 (24,619 ) — Deferred income taxes — — 2 594 1,582 (2,178 ) — Other long-term liabilities and deferred credits 722 193 — 907 408 — 2,230 Total liabilities 18,687 30,334 1,048 34,123 5,341 (40,832 ) 48,701 Stockholders’ equity Total KMI equity 35,119 21,073 1,581 32,199 10,892 (65,745 ) 35,119 Noncontrolling interests — — — — — 284 284 Total stockholders’ Equity 35,119 21,073 1,581 32,199 10,892 (65,461 ) 35,403 Total Liabilities and Stockholders’ Equity $ 53,806 $ 51,407 $ 2,629 $ 66,322 $ 16,233 $ (106,293 ) $ 84,104
Condensed Cash Flow Statement [Table Text Block]	Condensed Consolidating Statements of Cash Flows for the Six Months Ended June 30, 2016 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Net cash (used in) provided by operating activities $ (1,950 ) $ 2,976 $ (143 ) $ 5,616 $ 221 $ (4,376 ) $ 2,344 Cash flows from investing activities Funding to affiliates (1,670 ) (770 ) (1 ) (2,455 ) (219 ) 5,115 — Capital expenditures (37 ) — — (929 ) (504 ) — (1,470 ) Contributions to investments (343 ) — — (13 ) (7 ) — (363 ) Acquisitions of assets and investments, net of cash acquired (2 ) — — (331 ) — — (333 ) Sale of property, plant and equipment, investments and other net assets, net of removal costs — — — 220 — — 220 Distributions from equity investments in excess of cumulative earnings 1,443 298 — 68 — (1,728 ) 81 Other, net — (54 ) — 37 2 — (15 ) Net cash used in investing activities (609 ) (526 ) (1 ) (3,403 ) (728 ) 3,387 (1,880 ) Cash flows from financing activities Issuances of debt 6,847 — — — — — 6,847 Payments of debt (5,191 ) (500 ) — (1,104 ) (5 ) — (6,800 ) Funding from affiliates 1,429 882 144 2,124 536 (5,115 ) — Debt issue costs (6 ) — — — — — (6 ) Cash dividends - common shares (559 ) — — — — — (559 ) Cash dividends - preferred shares (76 ) — — — — — (76 ) Contributions from parents — — — — 87 (87 ) — Contributions from noncontrolling interests — — — — — 87 87 Distributions to parents — (2,832 ) — (3,234 ) (90 ) 6,156 — Distributions to noncontrolling interests — — — — — (11 ) (11 ) Net cash provided by (used in) financing activities 2,444 (2,450 ) 144 (2,214 ) 528 1,030 (518 ) Effect of exchange rate changes on cash and cash equivalents — — — — 5 — 5 Net (decrease) increase in cash and cash equivalents (115 ) — — (1 ) 26 41 (49 ) Cash and cash equivalents, beginning of period 123 — — 12 142 (48 ) 229 Cash and cash equivalents, end of period $ 8 $ — $ — $ 11 $ 168 $ (7 ) $ 180	Condensed Consolidating Statements of Cash Flows for the Six Months Ended June 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Net cash (used in) provided by operating activities $ (1,147 ) $ 5,190 $ 72 $ 3,755 $ (26 ) $ (5,306 ) $ 2,538 Cash flows from investing activities Funding to affiliates (2,118 ) (6,486 ) (1 ) (4,387 ) (351 ) 13,343 — Capital expenditures (23 ) — (3 ) (1,705 ) (183 ) 5 (1,909 ) Contributions to investments — — — (45 ) — — (45 ) Investment in KMP (159 ) — — — — 159 — Acquisitions of assets and investments, net of cash acquired (1,709 ) — — (210 ) — — (1,919 ) Sale of property, plant and equipment, investments and other net assets, net of removal costs — — 5 4 — (5 ) 4 Distributions from equity investments in excess of cumulative earnings 292 — — 80 — (258 ) 114 Other, net — (2 ) — 4 9 — 11 Net cash (used in) provided by investing activities (3,717 ) (6,488 ) 1 (6,259 ) (525 ) 13,244 (3,744 ) Cash flows from financing activities Issuances of debt 9,485 — — — — — 9,485 Payments of debt (8,598 ) (300 ) — (38 ) (5 ) — (8,941 ) Funding from (to) affiliates 3,471 3,906 (73 ) 5,546 493 (13,343 ) — Debt issue costs (20 ) — — — — — (20 ) Issuances of common shares 2,562 — — — — — 2,562 Cash dividends (2,006 ) — — — — — (2,006 ) Repurchases of warrants (5 ) — — — — — (5 ) Contributions from parents — 156 — 3 — (159 ) — Distributions to parents — (2,478 ) — (3,010 ) (92 ) 5,580 — Distributions to noncontrolling interests — — — — — (16 ) (16 ) Other, net — (1 ) — — — — (1 ) Net cash provided by (used in) financing activities 4,889 1,283 (73 ) 2,501 396 (7,938 ) 1,058 Effect of exchange rate changes on cash and cash equivalents — — — — (4 ) — (4 ) Net increase (decrease) in cash and cash equivalents 25 (15 ) — (3 ) (159 ) — (152 ) Cash and cash equivalents, beginning of period 4 15 — 17 279 — 315 Cash and cash equivalents, end of period $ 29 $ — $ — $ 14 $ 120 $ — $ 163

General Organization (Details)

General Organization (Details)	Jun. 30, 2016
General [Line Items]
Miles Of Pipeline	84,000
Number Of Pipeline Terminals Owned Interest In And Or Operated	180

General Basis of Presentation (

General Basis of Presentation (Details) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2016USD ($)	Dec. 31, 2015USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)
Segment Reporting Information [Line Items]
Number of Operating Segments				7
Loss on impairments and disposals of long-lived assets and equity investments, net			$ 50	$ 257	$ 130
Equity Method Investment, Realized Gain (Loss) on Disposal	$ 12			12
Natural Gas Pipelines
Segment Reporting Information [Line Items]
Loss on impairments and disposals of long-lived assets and equity investments, net			48	106	99
Natural Gas Pipelines | Fort Union Gas Gathering L.L.C. and Bighorn Gas Gathering L.L.C. [Member]
Segment Reporting Information [Line Items]
Loss on impairments of equity investments				13	26
CO2
Segment Reporting Information [Line Items]
Loss on impairments and disposals of long-lived assets and equity investments, net			9	33	9
Terminals
Segment Reporting Information [Line Items]
Loss on impairments and disposals of long-lived assets and equity investments, net				20
Products Pipelines
Segment Reporting Information [Line Items]
Loss on impairments and disposals of long-lived assets and equity investments, net				64
Products Pipelines | Discontinued Operations, Held-for-sale [Member]
Segment Reporting Information [Line Items]
Loss on impairments and disposals of long-lived assets and equity investments, net				8
Other Assets
Segment Reporting Information [Line Items]
Loss on impairments and disposals of long-lived assets and equity investments, net			$ 7	$ 13	$ 4
Natural Gas Pipelines
Segment Reporting Information [Line Items]
Goodwill, Impairment Loss		$ 1,150

General Earnings Per Share (Det

General Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net Income Available to Common Stockholders	$ 333	$ 333	$ 609	$ 762
Basic Weighted Average Common Shares Outstanding	2,229	2,175	2,229	2,158
Warrants	0	12	0	11
Diluted Weighted Average Common Shares Outstanding	2,229	2,187	2,229	2,169
Class of Warrant or Right, Exercise Price of Warrants or Rights	$ 40		$ 40
Unvested restricted stock awards
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	8	7	8	7
Warrants to purchase our Class P shares(a)
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	293	287	293	288
Convertible trust preferred securities
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	8	8	8	9
Mandatory convertible preferred stock(b)
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	58		58
Class P
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net Income Available to Common Stockholders	$ 332	$ 330	$ 607	$ 756
Basic Weighted Average Common Shares Outstanding	2,229	2,175	2,229	2,158
Restricted stock awards(a)
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net Income Available to Common Stockholders	$ 1	$ 3	$ 2	$ 6
Unvested Restricted Stock Awards, Issued and Non Issued	8		8

Acquisitions Acquisition of Ter

Acquisitions Acquisition of Terminal Assets from and Joint Venture With BP (Details) $ in Millions	Feb. 01, 2016USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)
Business Acquisition [Line Items]
Contributions from noncontrolling interests		$ 87	$ 0
BP Terminal Assets
Business Acquisition [Line Items]
Number of terminals	15
Payments to Acquire Businesses, Gross	$ 349	349
New Joint Venture with BP [Member] | BP Terminal Assets
Business Acquisition [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	75.00%
Number of terminals contributed to equity investment	14
BP [Member] | New Joint Venture with BP [Member] | BP Terminal Assets
Business Acquisition [Line Items]
Jointly Owned Utility Plant, Proportionate Ownership Share	25.00%
Contributions from noncontrolling interests		$ 84
Terminals | New Joint Venture with BP [Member] | BP Terminal Assets
Business Acquisition [Line Items]
Number of terminals contributed to equity investment	10
Products Pipelines | New Joint Venture with BP [Member] | BP Terminal Assets
Business Acquisition [Line Items]
Number of terminals contributed to equity investment	5

Acquisitions Purchase Price All

Acquisitions Purchase Price Allocation (Details) - USD ($) $ in Millions	Feb. 01, 2016	Jun. 30, 2016	Dec. 31, 2015
Business Acquisition [Line Items]
Goodwill		$ 23,802	$ 23,790
BP Terminal Assets
Business Acquisition [Line Items]
Current assets		2
Property, plant and equipment		396
Goodwill		0
Deferred charges and other assets(a)		0
Total assets acquired		398
Current liabilities		0
Debt		0
Other liabilities		(49)
Cash consideration	$ 349	349
Hiland
Business Acquisition [Line Items]
Current assets		79
Property, plant and equipment		1,492
Goodwill		310
Deferred charges and other assets(a)		1,498
Total assets acquired		3,379
Current liabilities		(253)
Debt		(1,413)
Other liabilities		(4)
Cash consideration		$ 1,709
Finite-Lived Intangible Asset, Useful Life		16 years 5 months
Royal Vopak Terminal Assets
Business Acquisition [Line Items]
Current assets		$ 2
Property, plant and equipment		155
Goodwill		6
Deferred charges and other assets(a)		0
Total assets acquired		163
Current liabilities		(1)
Debt		0
Other liabilities		(4)
Cash consideration		$ 158

Acquisitions Phantom (Details)

Acquisitions Phantom (Details)	Feb. 01, 2016
BP Terminal Assets
Business Acquisition [Line Items]
Number of terminals wholly owned	1

Acquisitions Subsequent Event -

Acquisitions Subsequent Event - Sale of Equity Interest in SNG (Details) - USD ($) $ in Millions	Jul. 10, 2016	Jun. 30, 2016	Jun. 30, 2015
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale or casualty of property, plant and equipment, investments and other net assets, net of removal of costs		$ 220	$ 4
Anticipated Sale of 50% of Southern Natural Gas Company LLC [Member] | Subsequent Event [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal Group, Equity Interest Sold	50.00%
Proceeds from sale or casualty of property, plant and equipment, investments and other net assets, net of removal of costs	$ 1,470
Disposal Group, Equity Method Investment Retained after Disposal, Ownership Interest after Disposal	50.00%
Total Enterprise Value	$ 4,150

Debt (Details)

Debt (Details) $ in Millions	Jan. 26, 2016USD ($)	Feb. 29, 2016USD ($)	Jan. 31, 2016USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock				$ 100		$ 100
Less: Current portion of debt(a)(d)				3,419		821
Long-term debt				40,201		42,406
Debt Instrument, Fair Value Disclosure				1,988		1,674
Repayments of Debt				6,800	$ 8,941
Long-term Debt, Current Maturities						1,000
Kinder Morgan, Inc. [Member] | Unsecured term loan facility, variable rate, due January 26, 2019(a)
Debt Instrument [Line Items]
Senior Notes	$ 1,000			1,000		0
Debt Instrument, Term	3 years
Kinder Morgan, Inc. [Member] | Senior notes, 1.50% through 8.25%, due 2016 through 2098(b)
Debt Instrument [Line Items]
Senior Notes				13,309		13,346
Kinder Morgan, Inc. [Member] | Senior unsecured revolving credit facility [Member]
Debt Instrument [Line Items]
Credit facility due November 26, 2019(c)				700		0
Kinder Morgan, Inc. [Member] | Commercial Paper [Member]
Debt Instrument [Line Items]
Commercial paper borrowings(c)				$ 24		0
Kinder Morgan, Inc. [Member] | Revolving Credit Facility [Member] | KMI Credit Facility [Member]
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate				1.91%
Kinder Morgan Energy Partners, L.P. [Member] | Senior notes, 2.65% through 9.00%, due 2016 through 2044
Debt Instrument [Line Items]
Senior Notes				$ 19,485		19,985
TGP [Member] | TGP senior notes, 7.00% through 8.375%, due 2016 through 2037
Debt Instrument [Line Items]
Senior Notes				1,540		1,790
TGP [Member] | $250 million 8.00% notes due 2016
Debt Instrument [Line Items]
Repayments of Debt		$ 250		$ 250
Debt Instrument, Interest Rate, Stated Percentage				8.00%
EPNG [Member] | EPNG senior notes, 5.95% through 8.625%, due 2017 through 2032
Debt Instrument [Line Items]
Senior Notes				$ 1,115		1,115
Copano Energy, L.L.C. [Member]
Debt Instrument [Line Items]
Total debt – KMI and Subsidiaries				332
Long-term debt				374		378
Repayments of Debt				0	$ 0
Long-term Debt, Current Maturities				0		0
Copano Energy, L.L.C. [Member] | Copano senior notes, 7.125%, due April 1, 2021
Debt Instrument [Line Items]
Senior Notes				$ 332		332
Debt Instrument, Interest Rate, Stated Percentage				7.125%
Colorado Interstate Gas Company, L.L.C. [Member] | CIG senior notes, 6.85%, due June 15, 2037
Debt Instrument [Line Items]
Senior Notes				$ 100		100
Debt Instrument, Interest Rate, Stated Percentage				6.85%
SNG [Member] | SNG notes, 4.40% through 8.00%, due 2017 through 2032
Debt Instrument [Line Items]
Notes Payable				$ 1,211		1,211
Kinder Morgan Finance Company, LLC [Member] | Kinder Morgan Finance Company, LLC, senior notes, 5.70% through 6.40%, due 2016 through 2036
Debt Instrument [Line Items]
Senior Notes				786		1,636
Kinder Morgan Finance Company, LLC [Member] | 5.70% Senior Notes due January 5, 2016 [Member]
Debt Instrument [Line Items]
Repayments of Debt			$ 850	$ 850
Debt Instrument, Interest Rate, Stated Percentage				5.70%
Hiland Partners Holdings LLC [Member] | Hiland Partners Holdings LLC, senior notes, 5.50% and 7.25%, due 2020 and 2022
Debt Instrument [Line Items]
Senior Notes				$ 974		974
EPC Building LLC [Member] | EPC Building, LLC, promissory note, 3.967%, due 2016 through 2035
Debt Instrument [Line Items]
Notes Payable				$ 438		443
Debt Instrument, Interest Rate, Stated Percentage				3.967%
Capital Trust I [Member] | Preferred securities, 4.75%, due March 31, 2028
Debt Instrument [Line Items]
Senior Notes				$ 221		221
Debt Instrument, Interest Rate, Stated Percentage				4.75%
Kinder Morgan G.P., Inc. [Member] | KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock
Debt Instrument [Line Items]
KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock				$ 100		100
KMI AND KMP [Member] | Other miscellaneous debt
Debt Instrument [Line Items]
Notes Payable				297		300
Kinder Morgan, Inc and Subsidiaries [Member]
Debt Instrument [Line Items]
Total debt – KMI and Subsidiaries				41,632		41,553
Long-term debt				$ 38,213		$ 40,732
Euro Member Countries, Euro | Senior Notes [Member]
Debt Instrument [Line Items]
Foreign Currency Exchange Rate, Translation				1.1106		1.0862
Translation Adjustment Functional to Reporting Currency, Increase (Decrease), Gross of Tax				$ 31

Debt Credit Facilities (Details

Debt Credit Facilities (Details) - Kinder Morgan, Inc. [Member] - USD ($) $ in Millions	Jun. 30, 2016	Jan. 26, 2016
Line of Credit Facility [Line Items]
Line of Credit Facility, Prior Borrowing Capacity		$ 4,000
Line of Credit Facility, Current Borrowing Capacity	$ 5,000
Line of Credit Facility, Remaining Borrowing Capacity	4,102
Letters of Credit Outstanding, Amount	$ 174

Long-term Debt Issuances and Re

Long-term Debt Issuances and Repaymenrts (Details) - USD ($) $ in Millions	1 Months Ended		6 Months Ended
	Feb. 29, 2016	Jan. 31, 2016	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Debt Instrument [Line Items]
Repayments of Debt			$ 6,800	$ 8,941
Kinder Morgan, Inc. [Member] | Unsecured term loan facility, variable rate, due January 26, 2019(a)
Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt			$ 1,000
Kinder Morgan, Inc. [Member] | KMI 8.25% Senior Notes due February 15, 2016 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			8.25%
Repayments of Debt			$ 67
Kinder Morgan Energy Partners, L.P. [Member] | $500 million 3.50% notes due 2016
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			3.50%		3.50%
Repayments of Debt			$ 500
TGP [Member] | $250 million 8.00% notes due 2016
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			8.00%
Repayments of Debt	$ 250		$ 250
Kinder Morgan Finance Company, LLC [Member] | 5.70% Senior Notes due January 5, 2016 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			5.70%
Repayments of Debt		$ 850	$ 850

Debt Phantom (Details)

Debt Phantom (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	6 Months Ended
	Feb. 29, 2016	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Debt Instrument [Line Items]
Repayments of Debt		$ 6,800	$ 8,941
Kinder Morgan, Inc. [Member] | Unsecured term loan facility, variable rate, due January 26, 2019(a)
Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt		$ 1,000
Kinder Morgan, Inc. [Member] | $786 million 7.00% notes due June 2017
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		0.00%
Senior Notes, Current		$ 786
Kinder Morgan Energy Partners, L.P. [Member] | $600 million 6.00% notes due February 2017
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.00%
Senior Notes, Current		$ 600
Kinder Morgan Energy Partners, L.P. [Member] | $500 million 3.50% notes due 2016
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		3.50%		3.50%
Repayments of Debt		$ 500
Senior Notes, Current				$ 500
TGP [Member] | $300 million 7.50% notes due April 2017
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		0.00%
Senior Notes, Current		$ 300
TGP [Member] | $250 million 8.00% notes due 2016
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.00%
Repayments of Debt	$ 250	$ 250
EPNG [Member] | $355 million 5.95% notes due April 2017
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		0.00%
Senior Notes, Current		$ 355
Copano Energy, L.L.C. [Member]
Debt Instrument [Line Items]
Repayments of Debt		$ 0	$ 0
Copano Energy, L.L.C. [Member] | Copano senior notes, 7.125%, due April 1, 2021
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.125%
Colorado Interstate Gas Company, L.L.C. [Member] | CIG senior note, 6.85%, due June 15, 2037
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.85%
SNG [Member] | $500 million 5.90% notes due April 2017
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		0.00%
Senior Notes, Current		$ 500
EPC Building LLC [Member] | EPC Building, LLC, promissory note, 3.967%, due 2016 through 2035
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		3.967%
Capital Trust I [Member] | Preferred securities, 4.75%, due March 31, 2028
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		4.75%
Kinder Morgan G.P., Inc. [Member] | KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock
Debt Instrument [Line Items]
Preferred Interest of General Partner, Par or Stated Value Per Share		$ 1,000
Minimum [Member] | Kinder Morgan, Inc. [Member] | Senior notes, 1.50% through 8.25%, due 2016 through 2098(b)
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		1.50%
Minimum [Member] | Kinder Morgan Energy Partners, L.P. [Member] | Senior notes, 2.65% through 9.00%, due 2016 through 2044
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		2.65%
Minimum [Member] | TGP [Member] | TGP senior notes, 7.00% through 8.375%, due 2016 through 2037
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.00%
Minimum [Member] | EPNG [Member] | EPNG senior notes, 5.95% through 8.625%, due 2017 through 2032
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.95%
Minimum [Member] | SNG [Member] | SNG notes, 4.40% through 8.00%, due 2017 through 2032
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		4.40%
Minimum [Member] | Kinder Morgan Finance Company, LLC [Member] | Kinder Morgan Finance Company, LLC, senior notes, 5.70% through 6.40%, due 2016 through 2036
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.70%
Minimum [Member] | Hiland Partners Holding LLC [Member] | Hiland Partners Holdings LLC, senior notes, 5.50% and 7.25%, due 2020 and 2022
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.50%
Maximum [Member] | Kinder Morgan, Inc. [Member] | Senior notes, 1.50% through 8.25%, due 2016 through 2098(b)
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.25%
Maximum [Member] | Kinder Morgan Energy Partners, L.P. [Member] | Senior notes, 2.65% through 9.00%, due 2016 through 2044
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		9.00%
Maximum [Member] | TGP [Member] | TGP senior notes, 7.00% through 8.375%, due 2016 through 2037
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.375%
Maximum [Member] | EPNG [Member] | EPNG senior notes, 5.95% through 8.625%, due 2017 through 2032
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.625%
Maximum [Member] | SNG [Member] | SNG notes, 4.40% through 8.00%, due 2017 through 2032
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.00%
Maximum [Member] | Kinder Morgan Finance Company, LLC [Member] | Kinder Morgan Finance Company, LLC, senior notes, 5.70% through 6.40%, due 2016 through 2036
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.40%
Maximum [Member] | Hiland Partners Holding LLC [Member] | Hiland Partners Holdings LLC, senior notes, 5.50% and 7.25%, due 2020 and 2022
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.25%

Stockholders' Equity Common Equ

Stockholders' Equity Common Equity (Details) - $ / shares	Jul. 20, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Class of Stock [Line Items]
Dividends Per Common Share Declared for the Period		$ 0.125	$ 0.490	$ 0.250	$ 0.970
Class P
Class of Stock [Line Items]
Dividends Per Common Share Declared for the Period		0.125	0.49	0.250	0.97
Per common share cash dividend paid in the period		$ 0.125	$ 0.48	$ 0.250	$ 0.93
Subsequent Event [Member]
Class of Stock [Line Items]
Dividends Per Common Share Declared for the Period	$ 0.125

Stockholders' Equity Stockholde

Stockholders' Equity Stockholders' Equity Mandatory Convertible Preferred Stock (Details) - $ / shares	Apr. 20, 2016	Oct. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Class of Stock [Line Items]
Depositary Share Offering		32,000,000
Issuances of common shares				62,000,000
9.75% Series A Mandatory Convertible, $1,000 per share liquidation preference			9.75%		9.75%
Preferred Stock, Liquidation Preference Per Share			$ 1,000		$ 1,000
Depositary Shares, Liquidation Preference Per Share		$ 50
9.75% Series A Mandatory Convertible, $1,000 per share liquidation preference
Class of Stock [Line Items]
Issuances of common shares		1,600,000
9.75% Series A Mandatory Convertible, $1,000 per share liquidation preference		9.75%
Preferred Stock, Liquidation Preference Per Share		$ 1,000
Preferred Stock, Dividends Per Share, Declared	$ 24.375
Depositary Stock, Dividends Per Share, Declared	$ 1.21875

Risk Management Energy Commodit

Risk Management Energy Commodity Price Risk Management (Details) - Energy commodity derivative contracts(a)	Jun. 30, 2016MMBblsBcf
Crude oil fixed price | Derivatives designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts	(21.2)
Crude oil fixed price | Derivatives not designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts	(0.3)
Crude oil basis | Derivatives designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts	(4.1)
Crude oil basis | Derivatives not designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts	(0.4)
Natural gas fixed price | Derivatives designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts | Bcf	(31.9)
Natural gas fixed price | Derivatives not designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts | Bcf	(12.8)
Natural gas basis | Derivatives designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts | Bcf	(21.8)
Natural gas basis | Derivatives not designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts | Bcf	(2.6)
NGL and other fixed price | Derivatives not designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts	(3.4)

Risk Management Interest Rate R

Risk Management Interest Rate Risk Management (Details) - Interest rate swap agreements - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Derivative [Line Items]
Derivative, Notional Amount	$ 9,775	$ 11,000
Fair Value Hedging [Member]
Derivative [Line Items]
Derivative, Notional Amount	$ 8,475	$ 9,700

Risk Management Risk Management

Risk Management Risk Management Foreign Currency Risk Management (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016USD ($)
Cross-currency swap agreements
Derivative [Line Items]
Cross-currency Swap Agreements	$ 1,358
KMI 1.50% Senior Notes Due 2022 [Member] | Cross-currency swap agreements
Derivative [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.79%
KMI 2.25% Senior Notes Due 2027 [Member] | Cross-currency swap agreements
Derivative [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.67%
Kinder Morgan, Inc. [Member] | KMI 1.50% Senior Notes Due 2022 [Member]
Derivative [Line Items]
Debt Instrument, Term	7 years
Kinder Morgan, Inc. [Member] | KMI 2.25% Senior Notes Due 2027 [Member]
Derivative [Line Items]
Debt Instrument, Term	12 years

Risk Management Fair Value of D

Risk Management Fair Value of Derivative Contracts (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Derivatives designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	$ 1,103	$ 987
Derivative Liability, Fair Value, Net	(90)	(74)
Derivatives not designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	1,172	1,024
Derivative Liability, Fair Value, Net	(100)	(108)
Natural gas and crude derivative contracts | Derivatives designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	316	603
Derivative Liability, Fair Value, Net	(56)	(13)
Natural gas and crude derivative contracts | Derivatives designated as hedging contracts | Fair value of derivative contracts/(Other current liabilities)
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	177	359
Natural gas and crude derivative contracts | Derivatives designated as hedging contracts | Fair value of derivative contracts/(Other current liabilities)
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	(38)	(13)
Natural gas and crude derivative contracts | Derivatives designated as hedging contracts | Deferred charges and other assets/(Other long-term liabilities and deferred credits)
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	139	244
Natural gas and crude derivative contracts | Derivatives designated as hedging contracts | Deferred charges and other assets/(Other long-term liabilities and deferred credits)
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	(18)	0
Natural gas and crude derivative contracts | Derivatives not designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	7	35
Derivative Liability, Fair Value, Net	(10)	(1)
Natural gas and crude derivative contracts | Derivatives not designated as hedging contracts | Fair value of derivative contracts/(Other current liabilities)
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	7	35
Natural gas and crude derivative contracts | Derivatives not designated as hedging contracts | Fair value of derivative contracts/(Other current liabilities)
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	(10)	(1)
Interest rate swap agreements | Derivatives designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	774	384
Derivative Liability, Fair Value, Net	0	(9)
Interest rate swap agreements | Derivatives not designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	62	1
Derivative Liability, Fair Value, Net	0	(16)
Interest rate swap agreements | Derivatives not designated as hedging contracts | Fair value of derivative contracts/(Other current liabilities)
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	12	1
Interest rate swap agreements | Derivatives not designated as hedging contracts | Fair value of derivative contracts/(Other current liabilities)
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	0	(11)
Interest rate swap agreements | Derivatives not designated as hedging contracts | Deferred charges and other assets/(Other long-term liabilities and deferred credits)
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	50	0
Interest rate swap agreements | Derivatives not designated as hedging contracts | Deferred charges and other assets/(Other long-term liabilities and deferred credits)
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	0	(5)
Cross-currency swap agreements | Derivatives designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	13	0
Derivative Liability, Fair Value, Net	(34)	(52)
Power derivative contracts | Derivatives not designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	0	1
Derivative Liability, Fair Value, Net	0	(17)
Power derivative contracts | Derivatives not designated as hedging contracts | Fair value of derivative contracts/(Other current liabilities)
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	0	1
Power derivative contracts | Derivatives not designated as hedging contracts | Fair value of derivative contracts/(Other current liabilities)
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	0	(17)
Commodity Contract [Member] | Derivatives not designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	69	37
Derivative Liability, Fair Value, Net	(10)	(34)
Fair Value Hedging [Member] | Interest rate swap agreements | Derivatives designated as hedging contracts | Fair value of derivative contracts/(Other current liabilities)
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	117	111
Fair Value Hedging [Member] | Interest rate swap agreements | Derivatives designated as hedging contracts | Fair value of derivative contracts/(Other current liabilities)
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	0	0
Fair Value Hedging [Member] | Interest rate swap agreements | Derivatives designated as hedging contracts | Deferred charges and other assets/(Other long-term liabilities and deferred credits)
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	657	273
Fair Value Hedging [Member] | Interest rate swap agreements | Derivatives designated as hedging contracts | Deferred charges and other assets/(Other long-term liabilities and deferred credits)
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	0	(9)
Fair Value Hedging [Member] | Cross-currency swap agreements | Derivatives designated as hedging contracts | Fair value of derivative contracts/(Other current liabilities)
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	0	0
Fair Value Hedging [Member] | Cross-currency swap agreements | Derivatives designated as hedging contracts | Fair value of derivative contracts/(Other current liabilities)
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	(22)	(6)
Fair Value Hedging [Member] | Cross-currency swap agreements | Derivatives designated as hedging contracts | Deferred charges and other assets/(Other long-term liabilities and deferred credits)
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	13	0
Fair Value Hedging [Member] | Cross-currency swap agreements | Derivatives designated as hedging contracts | Deferred charges and other assets/(Other long-term liabilities and deferred credits)
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	$ (12)	$ (46)

Risk Management Effect of Deriv

Risk Management Effect of Derivative Contracts on the Income Statement (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Interest rate swap agreements | Interest, net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives not designated as accounting hedges	$ 24	$ 0	$ 77	$ 0
Energy commodity derivative contracts(a)
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives not designated as accounting hedges	4	(39)	56	7
Derivative, Gain on Derivative	20	7	39	2
Energy commodity derivative contracts(a) | Revenues—Natural gas sales
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives not designated as accounting hedges	(11)	(2)	(5)	3
Energy commodity derivative contracts(a) | Revenues—Product sales and other
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives not designated as accounting hedges	(12)	(40)	(14)	4
Energy commodity derivative contracts(a) | Costs of sales
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives not designated as accounting hedges	3	3	(2)	0
Derivatives designated as hedging contracts | Total | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b)	11	57	119	129
Gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	(6)	3	(5)	10
Derivatives designated as hedging contracts | Gain/(loss) recognized in OCI on derivative (effective portion)(a) | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) recognized in OCI on derivative (effective portion)(a)	(142)	(58)	(69)	(60)
Derivatives designated as hedging contracts | Interest rate swap agreements | Interest, net | Fair Value Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) recognized in income on derivatives and related hedged item	119	(233)	399	(88)
Derivatives designated as hedging contracts | Interest rate swap agreements | Interest, net | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b)	0	0	(1)	(1)
Gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	0	0	0	0
Derivatives designated as hedging contracts | Interest rate swap agreements | Gain/(loss) recognized in OCI on derivative (effective portion)(a) | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) recognized in OCI on derivative (effective portion)(a)	(1)	1	(5)	(2)
Derivatives designated as hedging contracts | Hedged fixed rate debt | Interest, net | Fair Value Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) recognized in income on derivatives and related hedged item	(120)	256	(404)	117
Derivatives designated as hedging contracts | Energy commodity derivative contracts(a) | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) to be reclassified within twelve months			46
Derivatives designated as hedging contracts | Energy commodity derivative contracts(a) | Revenues—Natural gas sales | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b)	2	1	23	25
Gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	0	0	0	0
Derivatives designated as hedging contracts | Energy commodity derivative contracts(a) | Revenues—Product sales and other | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b)	33	37	90	101
Gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	(6)	3	(5)	10
Derivatives designated as hedging contracts | Energy commodity derivative contracts(a) | Costs of sales | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b)	(2)	(14)	(12)	(19)
Gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	0	0	0	0
Derivatives designated as hedging contracts | Energy commodity derivative contracts(a) | Gain/(loss) recognized in OCI on derivative (effective portion)(a) | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) recognized in OCI on derivative (effective portion)(a)	(111)	(82)	(84)	(47)
Derivatives designated as hedging contracts | Cross-currency swap agreements | Gain/(loss) recognized in OCI on derivative (effective portion)(a) | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) recognized in OCI on derivative (effective portion)(a)	(30)	23	20	(11)
Derivatives designated as hedging contracts | Other Credit Derivatives [Member] | Other, net | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b)	(22)	33	19	23
Gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	$ 0	$ 0	$ 0	$ 0

Risk Management Credit Risks (D

Risk Management Credit Risks (Details) - Energy commodity derivative contracts(a) - USD ($)	Jun. 30, 2016	Dec. 31, 2015
Credit Derivatives [Line Items]
Letters of Credit Outstanding, Amount	$ 0	$ 2,000,000
Cash collateral held(b)
Credit Derivatives [Line Items]
Collateral posted(c)	18,000,000	0
Derivative, Collateral, Obligation to Return Cash	0	$ (37,000,000)
One notch credit downgrade [Member]
Credit Derivatives [Line Items]
Additional Collateral, Aggregate Fair Value	0
Two notch credit downgrade [Member]
Credit Derivatives [Line Items]
Additional Collateral, Aggregate Fair Value	$ 0

Risk Management Risk Manageme49

Risk Management Risk Management Reporting of Amounts Reclassified out of Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015	Dec. 31, 2014
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	$ 31	$ 138	$ 219	$ 327
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Adjustment, Net of Tax, Before Reclassifications, Portion Attributable to Parent	85	(91)
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(348)	(230)	(358)	(236)
Accumulated Other Comprehensive Income (Loss), Net of Tax	(554)	(291)	(461)	(17)
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, before Reclassification Adjustments, Net of Tax	10	6
Other Comprehensive Income Unrealized Gain Loss On Derivatives Arising During Period Net Of Tax Portion Attributable To Parent	(69)	(60)
OCI, before Reclassifications, Net of Tax, Attributable to Parent	26	(145)
Other Comprehensive Income Reclassification Adjustment On Derivatives Included In Net Income Net Of Tax Portion Attributable To Parent	(119)	(129)
Accumulated Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Net of Tax	(237)	(199)	$ (322)	$ (108)
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
Reclassification from AOCI, Current Period, Net of Tax, Attributable to Parent	(119)	(129)
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax, Portion Attributable to Parent	(188)	(189)
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Adjustment and Impact of Merger Transactions, Net of Tax, Portion Attributable to Parent	85	(91)
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	10	6
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	$ (93)	$ (274)

Fair Value Fair Value of Deriva

Fair Value Fair Value of Derivative Contracts (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Cross-currency swap agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net amount	$ 0		$ 0		$ 0
Net amount	(21)		(21)		(52)
Energy commodity derivative contracts(a)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net amount	291		291		590
Net amount	(16)		(16)		(19)
Interest rate swap agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net amount	836		836		377
Net amount	0		0		(17)
Cross-currency swap agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	13		13		0
Contracts available for netting	13		13		0
Balance sheet liability fair value measurements by level	(34)		(34)		(52)
Contracts available for netting	13		13		0
Cross-currency swap agreements | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	0		0		0
Balance sheet liability fair value measurements by level	0		0		0
Cross-currency swap agreements | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	13		13		0
Balance sheet liability fair value measurements by level	(34)		(34)		(52)
Cross-currency swap agreements | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	0		0		0
Balance sheet liability fair value measurements by level	0		0		0
Cross-currency swap agreements | Cash collateral held(b)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash collateral held(b)	0		0		0
Collateral posted(c)	0		0		0
Interest rate swap agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	836		836		385
Contracts available for netting	0		0		8
Balance sheet liability fair value measurements by level	0		0		(25)
Contracts available for netting	0		0		8
Interest rate swap agreements | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	0		0		0
Balance sheet liability fair value measurements by level	0		0		0
Interest rate swap agreements | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	836		836		385
Balance sheet liability fair value measurements by level	0		0		(25)
Interest rate swap agreements | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	0		0		0
Balance sheet liability fair value measurements by level	0		0		0
Interest rate swap agreements | Cash collateral held(b)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash collateral held(b)	0		0		0
Collateral posted(c)	0		0		0
Energy commodity derivative contracts(a)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	323		323		639
Contracts available for netting	32		32		12
Balance sheet liability fair value measurements by level	(66)		(66)		(31)
Contracts available for netting	32		32		12
Fair Value, Assets Liabilites Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Derivatives-net asset (liability)	(2)	$ (49)	(15)	$ (61)
Total gains or (losses) included in earnings	(3)	0	(9)	0
Settlements	5	12	24	24
Derivatives-net asset (liability)	0	(37)	0	(37)
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	0	$ 1	0	$ 3
Energy commodity derivative contracts(a) | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	6		6		48
Balance sheet liability fair value measurements by level	(19)		(19)		(4)
Energy commodity derivative contracts(a) | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	317		317		589
Balance sheet liability fair value measurements by level	(47)		(47)		(10)
Energy commodity derivative contracts(a) | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	0		0		2
Balance sheet liability fair value measurements by level	0		0		(17)
Energy commodity derivative contracts(a) | Cash collateral held(b)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash collateral held(b)	0		0		37
Collateral posted(c)	$ 18		$ 18		$ 0

Fair Value Fair Value of Financ

Fair Value Fair Value of Financial Instruments (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Debt Instrument, Fair Value Disclosure	$ 1,988	$ 1,674
Reported Value Measurement [Member]
Debt Instrument [Line Items]
Debt Instrument, Fair Value Disclosure	43,620	43,227
Estimate of Fair Value Measurement [Member]
Debt Instrument [Line Items]
Debt Instrument, Fair Value Disclosure	$ 43,061	$ 37,481

Reportable Segments Reportable

Reportable Segments Reportable Segments Revenues (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Segment Reporting Information [Line Items]
Revenues	$ 3,144	$ 3,463	$ 6,339	$ 7,060
Other revenues	632	823	1,170	1,665
Less: Total intersegment revenues
Segment Reporting Information [Line Items]
Revenues	(5)	(7)	(11)	(10)
Natural Gas Pipelines | Revenues from external customers
Segment Reporting Information [Line Items]
Revenues	1,882	2,091	3,852	4,268
Natural Gas Pipelines | Intersegment revenues
Segment Reporting Information [Line Items]
Revenues	1	5	2	8
CO2
Segment Reporting Information [Line Items]
Revenues	304	353	606	799
Terminals | Revenues from external customers
Segment Reporting Information [Line Items]
Revenues	487	469	952	926
Terminals | Intersegment revenues
Segment Reporting Information [Line Items]
Revenues	1	1	1	1
Products Pipelines | Revenues from external customers
Segment Reporting Information [Line Items]
Revenues	398	477	789	921
Products Pipelines | Intersegment revenues
Segment Reporting Information [Line Items]
Revenues	3	1	8	1
Kinder Morgan Canada
Segment Reporting Information [Line Items]
Revenues	63	65	122	125
Other
Segment Reporting Information [Line Items]
Revenues	1	(1)	1	3
Total segment revenues
Segment Reporting Information [Line Items]
Revenues	3,140	3,461	6,333	7,052
Unallocated [Member]
Segment Reporting Information [Line Items]
Other revenues	$ 9	$ 9	$ 17	$ 18

Reportable Segments Reportabl53

Reportable Segments Reportable Segments EBDA (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Segment Reporting Information [Line Items]
Total Segment EBDA	$ 1,789	$ 1,721	$ 3,431	$ 3,623
Total segment DD&A	(552)	(570)	(1,103)	(1,108)
Amortization of excess cost of equity investments	(16)	(14)	(30)	(26)
Other revenues	632	823	1,170	1,665
General and administrative expense	(189)	(164)	(379)	(380)
Interest, net	(471)	(472)	(912)	(984)
Income tax expense	(213)	(189)	(367)	(413)
Net income	375	342	689	761
Natural Gas Pipelines
Segment Reporting Information [Line Items]
Total Segment EBDA	966	928	1,958	1,943
CO2
Segment Reporting Information [Line Items]
Total Segment EBDA	203	240	389	576
Terminals
Segment Reporting Information [Line Items]
Total Segment EBDA	292	279	545	549
Products Pipelines
Segment Reporting Information [Line Items]
Total Segment EBDA	293	277	472	523
Kinder Morgan Canada
Segment Reporting Information [Line Items]
Total Segment EBDA	40	37	80	78
Other
Segment Reporting Information [Line Items]
Total Segment EBDA	(5)	(40)	(13)	(46)
Unallocated [Member]
Segment Reporting Information [Line Items]
Other revenues	9	9	17	18
Interest, net	(470)	(472)	(912)	(986)
Income tax expense	$ (196)	$ (168)	$ (335)	$ (380)

Reportable Segments Reportabl54

Reportable Segments Reportable Segments Assets (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Assets	$ 84,317	$ 84,104
Disposal Group, Including Discontinued Operation, Other Assets	27	19
Natural Gas Pipelines
Segment Reporting Information [Line Items]
Assets	53,677	53,704
CO2
Segment Reporting Information [Line Items]
Assets	4,317	4,706
Terminals
Segment Reporting Information [Line Items]
Assets	9,673	9,083
Products Pipelines
Segment Reporting Information [Line Items]
Assets	8,360	8,464
Kinder Morgan Canada
Segment Reporting Information [Line Items]
Assets	1,586	1,434
Other
Segment Reporting Information [Line Items]
Assets	317	418
Total segment assets
Segment Reporting Information [Line Items]
Assets	77,930	77,809
Corporate Segment [Member]
Segment Reporting Information [Line Items]
Assets	$ 6,360	$ 6,276

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Income tax expense	$ 213	$ 189	$ 367	$ 413
Effective tax rate	36.20%	35.60%	34.80%	35.20%
Federal statutory income tax rate	35.00%	35.00%	35.00%	35.00%
Unrecognized Tax Benefits	$ 144		$ 144		$ 173
Unrecognized Tax Benefits, Reduction Resulting from Lapse of Applicable Statute of Limitations			$ 29

Federal Energy Regulatory Commi

Federal Energy Regulatory Commission Proceedings (Details) - Federal Energy Regulatory Commission [Member] - Various Shippers [Member] - Unfavorable Regulatory Action [Member] $ in Millions	6 Months Ended
	Jun. 30, 2016USD ($)
EPNG [Member] | Opinion 517 issued and implemented (rehearing pending); and Opinion 528 issued and is awaiting filing of court document) [Member]
EPNG [Abstract]
Loss Contingency, Pending Claims, Number	2
Reparations, Refunds, and Rate Reductions [Member] | SFPP [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency Period of Time Litigation Concerns	2 years
Annual Rate Reductions [Member] | SFPP [Member] | Pending Litigation [Member]
SFPP [Abstract]
Loss Contingency, Damages Sought, Value	$ 40
Revenue Subject to Refund [Member] | SFPP [Member] | Pending Litigation [Member]
SFPP [Abstract]
Loss Contingency, Damages Sought, Value	$ 169

Other Commercial Matters (Detai

Other Commercial Matters (Details) - USD ($) $ in Millions	May 24, 2016	Feb. 04, 2016	Apr. 21, 2015	Oct. 25, 2013	Jan. 01, 2004	Sep. 30, 2013	Jun. 30, 2016	Sep. 01, 2011
Gulf LNG Holdings Group LLC [Member]
Loss Contingencies [Line Items]
Equity Method Investment, Ownership Percentage							50.00%
Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al. [Member] | SFPP L.P. [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Lessee Leasing Arrangements, Operating Leases, Term of Contract				10 years	10 years
Loss Contingency, Damages Sought, Value				$ 22.3
Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al. [Member] | SFPP L.P. [Member] | Loss on Long-term Purchase Commitment [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Initial Award Amount, Annual Rent Payable								$ 14
Plains Gas Solutions, LLC v. Tennessee Gas Pipeline Company, L.L.C. et al [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value						$ 100
Brinckerhoff v. El Paso Pipeline GP Company, LLC., et al. [Member]
Loss Contingencies [Line Items]
Payments to Acquire Businesses, Gross			$ 1,130
Brinckerhoff v. El Paso Pipeline GP Company, LLC., et al. [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value			$ 171
Brinckerhoff v. El Paso Pipeline GP Company, LLC., et al. [Member] | Tentative Settlement [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value		$ 100.2
Brinckerhoff v. El Paso Pipeline GP Company, LLC., et al. [Member] | Elba Liquefaction & SLNG [Member]
Loss Contingencies [Line Items]
Business Acquisition, Additional Percentage of Interest Acquired			49.00%
Brinckerhoff v. El Paso Pipeline GP Company, LLC., et al. [Member] | SNG [Member]
Loss Contingencies [Line Items]
Business Acquisition, Additional Percentage of Interest Acquired			15.00%
Price Reporting Litigation [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value	$ 1,500
Price Reporting Litigation [Member] | Dismissed [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value	$ 500
Merger Transactions [Member] | Kinder Morgan Energy Partners, L.P. and El Paso Pipeline Partners, L.P. [Member]
Loss Contingencies [Line Items]
Loss Contingency, Pending Claims, Number							5

Litigation, Environmental and58

Litigation, Environmental and Other Contingencies Litigation General (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Loss Contingencies [Line Items]
Estimated Litigation Liability	$ 490	$ 463

Environmental Matters (Details)

Environmental Matters (Details) $ in Millions

Jun. 17, 2016USD ($)

Jun. 08, 2016USD ($)

Feb. 02, 2016USD ($)

Nov. 08, 2013

Aug. 06, 2013Defendants

Jul. 24, 2013

Jun. 30, 2016USD ($)

Aug. 31, 2007USD ($)

Dec. 31, 2000Terminals

Jun. 30, 2016USD ($)TerminalsPartiesDefendants

Dec. 31, 2010USD ($)

Dec. 31, 1969

Dec. 31, 2015USD ($)

Loss Contingencies [Line Items]

Accrual for environmental loss contingencies

$ 318

$ 318

$ 284

Environmental recoveries receivable

13

$ 13

$ 13

Rare Metals Inc. [Member]

Loss Contingencies [Line Items]

Number of Uranium Mines

20

Environmental Protection Agency [Member] | Portland Harbor Superfund Site, Willamette River, Portland, Oregon [Member] | GATX Terminals Corporation (n/k/a KMLT) [Member]

Loss Contingencies [Line Items]

Number of Liquid Terminals | Terminals

2

4

Number of Parties Involved In Site Cleanup Allocation Negotiations | Parties

90

Loss Contingency, Damages Sought, Value

$ 750

Board of Commissioners of the Southeast Louisiana Flood Protection Authority - East [Member] | TGP and SNG [Member]

Loss Contingencies [Line Items]

Loss Contingency, Number of Defendants

100

Parish of Plaquemines, Louisiana [Member] | Bastian Bay, Buras, Empire and Fort Jackson oil and gas fields of Plaquemines Parish [Member] | Tennessee Gas Pipeline Company LLC [Member]

Loss Contingencies [Line Items]

Loss Contingency, Number of Defendants

17

Environmental Protection Agency [Member] | Settlement [Member] | Central Florida Pipeline LLC [Member]

Loss Contingencies [Line Items]

Loss Contingency, Damages Sought, Value

$ 0.5

Roosevelt Irrigation District v. Kinder Morgan G.P., Inc., Kinder Morgan Energy Partners, L.P. , U.S. District Court, Arizona [Member] | Pending Litigation [Member] | SFPP Phoenix Terminal [Member] | Unfavorable Regulatory Action [Member] | KMEP and SFPP [Member]

Loss Contingencies [Line Items]

Loss Contingency, Damages Sought, Value

$ 175

Loss Contingency, Number of Defendants | Defendants

26

70

United States District Court, Southern District of California, case number 07CV1883WCAB [Member] | Pending Litigation [Member] | Mission Valley Terminal Facility [Member] | Kinder Morgan Energy Partners, L.P. [Member]

Loss Contingencies [Line Items]

Loss Contingency, Damages Sought, Value

$ 365

$ 170

$ 365

United States District Court, Southern District of California, case number 07CV1883WCAB [Member] | Tentative Settlement [Member] | Mission Valley Terminal Facility [Member] | Kinder Morgan Energy Partners, L.P. [Member]

Loss Contingencies [Line Items]

Loss Contingency, Damages Sought, Value

$ 20

$ 160

Lower Passaic River Study Area [Member] | Pending Litigation [Member]

Loss Contingencies [Line Items]

Number of Parties at a Joint Defense Group

70

70

Environmental Remediation Expense

$ 1,700

Lower Passaic River Study Area [Member] | Pending Litigation [Member] | Environmental Protection Agency [Member]

Loss Contingencies [Line Items]

Number of Parties at a Joint Defense Group

80

80

Minimum [Member] | Lower Passaic River Study Area [Member] | Pending Litigation [Member]

Loss Contingencies [Line Items]

Environmental Remediation Expense

$ 365

Maximum [Member] | Lower Passaic River Study Area [Member] | Pending Litigation [Member]

Loss Contingencies [Line Items]

Environmental Remediation Expense

$ 3,200

Guarantee of Securities of Su60

Guarantee of Securities of Subsidiaries (Details) $ in Millions	Jun. 30, 2016USD ($)
Parent Issuer and Guarantor
Carrying value	$ 15,032
Subsidiary Issuer and Guarantor - KMP
Carrying value	19,485
Subsidiary Issuer and Guarantor - Copano
Carrying value	332
Subsidiary Guarantors
Carrying value	5,783
Capitalized Lease Debt Not Subject to Cross Guarantee Agreement	$ 173

Guarantee of Securities of Su61

Guarantee of Securities of Subsidiaries Condensed Consolidated Statements of Income and Comprehensive Income (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Condensed Income Statements, Captions [Line Items]
Total Revenues	$ 3,144	$ 3,463	$ 6,339	$ 7,060
Costs of sales	752	1,085	1,483	2,175
Depreciation, depletion and amortization	552	570	1,103	1,108
Other operating expenses	2	(4)	1	(3)
Total Operating Costs, Expenses and Other	2,204	2,571	4,583	5,090
Operating Income	940	892	1,756	1,970
Earnings from equity investments	106	114	200	190
Interest, net	(471)	(472)	(912)	(984)
Amortization of excess cost of equity investments and other, net	29	11	42	24
Income Before Income Taxes	588	531	1,056	1,174
Income tax expense	(213)	(189)	(367)	(413)
Net Income	375	342	689	761
Net (Income) Loss Attributable to Noncontrolling Interests	(3)	(9)	(2)	1
Net Income Attributable to Kinder Morgan, Inc.	372	333	687	762
Preferred Stock Dividends	(39)	0	(78)	0
Net Income Available to Common Stockholders	333	333	609	762
Total other comprehensive loss	(140)	(98)	(93)	(274)
Comprehensive income	235	244	596	487
Comprehensive income attributable to noncontrolling interests	(3)	(9)	(2)	1
Comprehensive income attributable to KMI	232	235	594	488
Consolidating Adjustments
Condensed Income Statements, Captions [Line Items]
Total Revenues	(12)	(11)	(21)	(24)
Costs of sales	(1)	1	2	1
Depreciation, depletion and amortization	0	0	0	0
Other operating expenses	(11)	(12)	(23)	(25)
Total Operating Costs, Expenses and Other	(12)	(11)	(21)	(24)
Operating Income	0	0	0	0
Earnings from consolidated subsidiaries	(1,541)	(1,486)	(2,830)	(3,175)
Earnings from equity investments	0	0	0	0
Interest, net	0	0	0	0
Amortization of excess cost of equity investments and other, net	0	0	0	0
Income Before Income Taxes	(1,541)	(1,486)	(2,830)	(3,175)
Income tax expense	0	0	0	0
Net Income	(1,541)	(1,486)	(2,830)	(3,175)
Net (Income) Loss Attributable to Noncontrolling Interests	(3)	(9)	(2)	1
Net Income Attributable to Kinder Morgan, Inc.	(1,544)	(1,495)	(2,832)	(3,174)
Preferred Stock Dividends	0		0
Net Income Available to Common Stockholders	(1,544)		(2,832)
Total other comprehensive loss	428	264	258	862
Comprehensive income	(1,113)	(1,222)	(2,572)	(2,313)
Comprehensive income attributable to noncontrolling interests	(3)	(9)	(2)	1
Comprehensive income attributable to KMI	(1,116)	(1,231)	(2,574)	(2,312)
Parent Issuer and Guarantor
Condensed Income Statements, Captions [Line Items]
Total Revenues	8	10	17	19
Costs of sales	0	0	0	0
Depreciation, depletion and amortization	4	5	9	10
Other operating expenses	30	38	49	50
Total Operating Costs, Expenses and Other	34	43	58	60
Operating Income	(26)	(33)	(41)	(41)
Earnings from consolidated subsidiaries	752	683	1,410	1,482
Earnings from equity investments	0	0	0	0
Interest, net	(176)	(149)	(346)	(304)
Amortization of excess cost of equity investments and other, net	1	0	1	0
Income Before Income Taxes	551	501	1,024	1,137
Income tax expense	(179)	(168)	(337)	(375)
Net Income	372	333	687	762
Net (Income) Loss Attributable to Noncontrolling Interests	0	0	0	0
Net Income Attributable to Kinder Morgan, Inc.	372	333	687	762
Preferred Stock Dividends	(39)		(78)
Net Income Available to Common Stockholders	333		609
Total other comprehensive loss	(140)	(98)	(93)	(274)
Comprehensive income	232	235	594	488
Comprehensive income attributable to noncontrolling interests	0	0	0	0
Comprehensive income attributable to KMI	232	235	594	488
Subsidiary Issuer and Guarantor - KMP
Condensed Income Statements, Captions [Line Items]
Total Revenues	0	0	0	0
Costs of sales	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Other operating expenses	2	0	4	38
Total Operating Costs, Expenses and Other	2	0	4	38
Operating Income	(2)	0	(4)	(38)
Earnings from consolidated subsidiaries	734	666	1,331	1,549
Earnings from equity investments	0	0	0	0
Interest, net	34	34	97	7
Amortization of excess cost of equity investments and other, net	0	0	0	0
Income Before Income Taxes	766	700	1,424	1,518
Income tax expense	(1)	(2)	(3)	(4)
Net Income	765	698	1,421	1,514
Net (Income) Loss Attributable to Noncontrolling Interests	0	0	0	0
Net Income Attributable to Kinder Morgan, Inc.	765	698	1,421	1,514
Preferred Stock Dividends	0		0
Net Income Available to Common Stockholders	765		1,421
Total other comprehensive loss	(213)	(139)	(161)	(377)
Comprehensive income	552	559	1,260	1,137
Comprehensive income attributable to noncontrolling interests	0	0	0	0
Comprehensive income attributable to KMI	552	559	1,260	1,137
Subsidiary Issuer and Guarantor - Copano
Condensed Income Statements, Captions [Line Items]
Total Revenues	0	0	0	0
Costs of sales	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Other operating expenses	0	0	0	1
Total Operating Costs, Expenses and Other	0	0	0	1
Operating Income	0	0	0	(1)
Earnings from consolidated subsidiaries	(3)	(5)	4	(28)
Earnings from equity investments	0	0	0	0
Interest, net	(12)	(12)	(24)	(24)
Amortization of excess cost of equity investments and other, net	0	0	0	0
Income Before Income Taxes	(15)	(17)	(20)	(53)
Income tax expense	0	0	0	0
Net Income	(15)	(17)	(20)	(53)
Net (Income) Loss Attributable to Noncontrolling Interests	0	0	0	0
Net Income Attributable to Kinder Morgan, Inc.	(15)	(17)	(20)	(53)
Preferred Stock Dividends	0		0
Net Income Available to Common Stockholders	(15)		(20)
Total other comprehensive loss	0	0	0	0
Comprehensive income	(15)	(17)	(20)	(53)
Comprehensive income attributable to noncontrolling interests	0	0	0	0
Comprehensive income attributable to KMI	(15)	(17)	(20)	(53)
Subsidiary Guarantors
Condensed Income Statements, Captions [Line Items]
Total Revenues	2,777	3,050	5,602	6,276
Costs of sales	693	989	1,345	1,990
Depreciation, depletion and amortization	462	473	918	915
Other operating expenses	681	767	1,494	1,452
Total Operating Costs, Expenses and Other	1,836	2,229	3,757	4,357
Operating Income	941	821	1,845	1,919
Earnings from consolidated subsidiaries	41	127	54	141
Earnings from equity investments	106	114	200	190
Interest, net	(304)	(345)	(613)	(649)
Amortization of excess cost of equity investments and other, net	6	(5)	1	(8)
Income Before Income Taxes	790	712	1,487	1,593
Income tax expense	(16)	(11)	(10)	(25)
Net Income	774	701	1,477	1,568
Net (Income) Loss Attributable to Noncontrolling Interests	0	0	0	0
Net Income Attributable to Kinder Morgan, Inc.	774	701	1,477	1,568
Preferred Stock Dividends	0		0
Net Income Available to Common Stockholders	774		1,477
Total other comprehensive loss	(223)	(148)	(229)	(344)
Comprehensive income	551	553	1,248	1,224
Comprehensive income attributable to noncontrolling interests	0	0	0	0
Comprehensive income attributable to KMI	551	553	1,248	1,224
Subsidiary Non-Guarantors
Condensed Income Statements, Captions [Line Items]
Total Revenues	371	414	741	789
Costs of sales	60	95	136	184
Depreciation, depletion and amortization	86	92	176	183
Other operating expenses	198	123	473	291
Total Operating Costs, Expenses and Other	344	310	785	658
Operating Income	27	104	(44)	131
Earnings from consolidated subsidiaries	17	15	31	31
Earnings from equity investments	0	0	0	0
Interest, net	(13)	0	(26)	(14)
Amortization of excess cost of equity investments and other, net	6	2	10	6
Income Before Income Taxes	37	121	(29)	154
Income tax expense	(17)	(8)	(17)	(9)
Net Income	20	113	(46)	145
Net (Income) Loss Attributable to Noncontrolling Interests	0	0	0	0
Net Income Attributable to Kinder Morgan, Inc.	20	113	(46)	145
Preferred Stock Dividends	0		0
Net Income Available to Common Stockholders	20		(46)
Total other comprehensive loss	8	23	132	(141)
Comprehensive income	28	136	86	4
Comprehensive income attributable to noncontrolling interests	0	0	0	0
Comprehensive income attributable to KMI	28	136	86	4
Consolidated KMI
Condensed Income Statements, Captions [Line Items]
Total Revenues	3,144	3,463	6,339	7,060
Costs of sales	752	1,085	1,483	2,175
Depreciation, depletion and amortization	552	570	1,103	1,108
Other operating expenses	900	916	1,997	1,807
Total Operating Costs, Expenses and Other	2,204	2,571	4,583	5,090
Operating Income	940	892	1,756	1,970
Earnings from consolidated subsidiaries	0	0	0	0
Earnings from equity investments	106	114	200	190
Interest, net	(471)	(472)	(912)	(984)
Amortization of excess cost of equity investments and other, net	13	(3)	12	(2)
Income Before Income Taxes	588	531	1,056	1,174
Income tax expense	(213)	(189)	(367)	(413)
Net Income	375	342	689	761
Net (Income) Loss Attributable to Noncontrolling Interests	(3)	(9)	(2)	1
Net Income Attributable to Kinder Morgan, Inc.	372	333	687	762
Preferred Stock Dividends	(39)		(78)
Net Income Available to Common Stockholders	333		609
Total other comprehensive loss	(140)	(98)	(93)	(274)
Comprehensive income	235	244	596	487
Comprehensive income attributable to noncontrolling interests	(3)	(9)	(2)	1
Comprehensive income attributable to KMI	$ 232	$ 235	$ 594	$ 488

Guarantee of Securities of Su62

Guarantee of Securities of Subsidiaries Condensed Consolidating Balance Sheets (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	$ 180	$ 229	$ 163	$ 315
Other current assets	338	366
Property, plant and equipment, net	41,199	40,547
Investments	6,202	6,040
Goodwill	23,802	23,790
Other non-current assets	2,229	2,029
Deferred income taxes	4,975	5,323
Total Assets	84,317	84,104
Current portion of debt		1,000
Long-term debt	40,201	42,406
Total Liabilities	48,844	48,701
Total KMI equity	35,111	35,119
Noncontrolling interests	362	284
Total Stockholders’ Equity	35,473	35,403	35,505	34,426
Total Liabilities and Stockholders’ Equity	84,317	84,104
Consolidating Adjustments
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	(7)	(48)	0	0
Other current assets - affiliates	(26,082)	(13,979)
Other current assets	(8)	(8)
Property, plant and equipment, net	0	0
Investments	0	0
Investments in subsidiaries	(62,227)	(65,461)
Goodwill	0	0
Notes receivable from affiliates	(24,323)	(24,619)
Other non-current assets	0	0
Deferred income taxes	(2,236)	(2,178)
Total Assets	(114,883)	(106,293)
Current portion of debt	0	0
Other current liabilities - affiliates	(26,082)	(13,979)
All other current liabilities	(15)	(56)
Long-term debt	0	0
Notes payable to affiliates	(24,323)	(24,619)
Deferred income taxes	(2,236)	(2,178)
All other long-term liabilities and deferred credits	0	0
Total Liabilities	(52,656)	(40,832)
Total KMI equity	(62,589)	(65,745)
Noncontrolling interests	362	284
Total Stockholders’ Equity	(62,227)	(65,461)
Total Liabilities and Stockholders’ Equity	(114,883)	(106,293)
Parent Issuer and Guarantor
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	8	123	29	4
Other current assets - affiliates	5,859	2,233
Other current assets	141	126
Property, plant and equipment, net	270	252
Investments	16	16
Investments in subsidiaries	25,221	27,401
Goodwill	15,089	15,089
Notes receivable from affiliates	1,024	850
Other non-current assets	373	215
Deferred income taxes	7,211	7,501
Total Assets	55,212	53,806
Current portion of debt	1,510	67
Other current liabilities - affiliates	1,788	1,328
All other current liabilities	373	321
Long-term debt	14,226	13,845
Notes payable to affiliates	1,547	2,404
Deferred income taxes	0	0
All other long-term liabilities and deferred credits	657	722
Total Liabilities	20,101	18,687
Total KMI equity	35,111	35,119
Noncontrolling interests	0	0
Total Stockholders’ Equity	35,111	35,119
Total Liabilities and Stockholders’ Equity	55,212	53,806
Subsidiary Issuer and Guarantor - KMP
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	0	0	0	15
Other current assets - affiliates	6,192	1,600
Other current assets	186	119
Property, plant and equipment, net	0	0
Investments	2	2
Investments in subsidiaries	25,762	28,038
Goodwill	22	22
Notes receivable from affiliates	21,741	21,319
Other non-current assets	537	307
Deferred income taxes	0	0
Total Assets	54,442	51,407
Current portion of debt	600	500
Other current liabilities - affiliates	14,623	8,682
All other current liabilities	481	458
Long-term debt	19,662	20,053
Notes payable to affiliates	448	448
Deferred income taxes	0	0
All other long-term liabilities and deferred credits	70	193
Total Liabilities	35,884	30,334
Total KMI equity	18,558	21,073
Noncontrolling interests	0	0
Total Stockholders’ Equity	18,558	21,073
Total Liabilities and Stockholders’ Equity	54,442	51,407
Subsidiary Issuer and Guarantor - Copano
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	0	0	0	0
Other current assets - affiliates	115	0
Other current assets	0	0
Property, plant and equipment, net	0	0
Investments	0	0
Investments in subsidiaries	2,345	2,341
Goodwill	287	287
Notes receivable from affiliates	0	0
Other non-current assets	1	1
Deferred income taxes	0	0
Total Assets	2,748	2,629
Current portion of debt	0	0
Other current liabilities - affiliates	51	39
All other current liabilities	7	7
Long-term debt	374	378
Notes payable to affiliates	753	622
Deferred income taxes	2	2
All other long-term liabilities and deferred credits	0	0
Total Liabilities	1,187	1,048
Total KMI equity	1,561	1,581
Noncontrolling interests	0	0
Total Stockholders’ Equity	1,561	1,581
Total Liabilities and Stockholders’ Equity	2,748	2,629
Subsidiary Guarantors
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	11	12	14	17
Other current assets - affiliates	13,171	9,451
Other current assets	1,787	2,163
Property, plant and equipment, net	32,366	32,195
Investments	6,062	5,906
Investments in subsidiaries	4,926	4,361
Goodwill	5,220	5,221
Notes receivable from affiliates	1,239	2,070
Other non-current assets	4,646	4,943
Deferred income taxes	0	0
Total Assets	69,428	66,322
Current portion of debt	1,187	132
Other current liabilities - affiliates	9,133	3,216
All other current liabilities	1,831	1,987
Long-term debt	5,260	7,447
Notes payable to affiliates	20,217	19,840
Deferred income taxes	625	594
All other long-term liabilities and deferred credits	889	907
Total Liabilities	39,142	34,123
Total KMI equity	30,286	32,199
Noncontrolling interests	0	0
Total Stockholders’ Equity	30,286	32,199
Total Liabilities and Stockholders’ Equity	69,428	66,322
Subsidiary Non-Guarantors
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	168	142	120	279
Other current assets - affiliates	745	695
Other current assets	184	195
Property, plant and equipment, net	8,563	8,100
Investments	122	116
Investments in subsidiaries	3,973	3,320
Goodwill	3,184	3,171
Notes receivable from affiliates	319	380
Other non-current assets	112	114
Deferred income taxes	0	0
Total Assets	17,370	16,233
Current portion of debt	122	122
Other current liabilities - affiliates	487	714
All other current liabilities	470	527
Long-term debt	679	683
Notes payable to affiliates	1,358	1,305
Deferred income taxes	1,609	1,582
All other long-term liabilities and deferred credits	461	408
Total Liabilities	5,186	5,341
Total KMI equity	12,184	10,892
Noncontrolling interests	0	0
Total Stockholders’ Equity	12,184	10,892
Total Liabilities and Stockholders’ Equity	17,370	16,233
Consolidated KMI
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	180	229	$ 163	$ 315
Other current assets - affiliates	0	0
Other current assets	2,290	2,595
Property, plant and equipment, net	41,199	40,547
Investments	6,202	6,040
Investments in subsidiaries	0	0
Goodwill	23,802	23,790
Notes receivable from affiliates	0	0
Other non-current assets	5,669	5,580
Deferred income taxes	4,975	5,323
Total Assets	84,317	84,104
Current portion of debt	3,419	821
Other current liabilities - affiliates	0	0
All other current liabilities	3,147	3,244
Long-term debt	40,201	42,406
Notes payable to affiliates	0	0
Deferred income taxes	0	0
All other long-term liabilities and deferred credits	2,077	2,230
Total Liabilities	48,844	48,701
Total KMI equity	35,111	35,119
Noncontrolling interests	362	284
Total Stockholders’ Equity	35,473	35,403
Total Liabilities and Stockholders’ Equity	$ 84,317	$ 84,104

Guarantee of Securities of Su63

Guarantee of Securities of Subsidiaries Condensed Consolidating Statements of Cash Flows (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	$ 2,344	$ 2,538
Capital expenditures	(1,470)	(1,909)
Contributions to investments	(363)	(45)
Acquisitions of assets and investments, net of cash acquired	(333)	(1,919)
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	220	4
Distributions from equity investments in excess of cumulative earnings	81	114
Other, net	(15)	11
Net Cash Used in Investing Activities	(1,880)	(3,744)
Issuances of debt	6,847	9,485
Payments of debt	(6,800)	(8,941)
Debt issue costs	(6)	(20)
Issuances of common shares	0	2,562
Cash dividends - common shares	(559)	(2,006)
Cash dividends - preferred shares	76	0
Repurchases of warrants	0	(5)
Contributions from noncontrolling interests	87	0
Distributions to noncontrolling interests	(11)	(16)
Other, net	0	(1)
Net Cash (Used in) Provided by Financing Activities	(518)	1,058
Effect of exchange rate changes on cash and cash equivalents	5	(4)
Net decrease in Cash and Cash Equivalents	(49)	(152)
Cash and Cash Equivalents, beginning of period	229	315
Cash and Cash Equivalents, end of period	180	163
Consolidating Adjustments
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	(4,376)	(5,306)
Funding to affiliates	5,115	13,343
Capital expenditures	0	5
Contributions to investments	0	0
Investment in KMP		159
Acquisitions of assets and investments, net of cash acquired	0	0
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	0	(5)
Distributions from equity investments in excess of cumulative earnings	(1,728)	(258)
Other, net	0	0
Net Cash Used in Investing Activities	3,387	13,244
Issuances of debt	0	0
Payments of debt	0	0
Funding from affiliates	(5,115)	(13,343)
Debt issue costs	0	0
Issuances of common shares		0
Cash dividends - common shares	0	0
Cash dividends - preferred shares	0
Repurchases of warrants		0
Contributions from parents	(87)	(159)
Contributions from noncontrolling interests	87
Distributions to parents	6,156	5,580
Distributions to noncontrolling interests	(11)	(16)
Other, net		0
Net Cash (Used in) Provided by Financing Activities	1,030	(7,938)
Effect of exchange rate changes on cash and cash equivalents	0	0
Net decrease in Cash and Cash Equivalents	41	0
Cash and Cash Equivalents, beginning of period	(48)	0
Cash and Cash Equivalents, end of period	(7)	0
Parent Issuer and Guarantor
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	(1,950)	(1,147)
Funding to affiliates	(1,670)	(2,118)
Capital expenditures	(37)	(23)
Contributions to investments	(343)	0
Investment in KMP		(159)
Acquisitions of assets and investments, net of cash acquired	(2)	(1,709)
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	0	0
Distributions from equity investments in excess of cumulative earnings	1,443	292
Other, net	0	0
Net Cash Used in Investing Activities	(609)	(3,717)
Issuances of debt	6,847	9,485
Payments of debt	(5,191)	(8,598)
Funding from affiliates	1,429	3,471
Debt issue costs	(6)	(20)
Issuances of common shares		2,562
Cash dividends - common shares	(559)	(2,006)
Cash dividends - preferred shares	76
Repurchases of warrants		(5)
Contributions from parents	0	0
Contributions from noncontrolling interests	0
Distributions to parents	0	0
Distributions to noncontrolling interests	0	0
Other, net		0
Net Cash (Used in) Provided by Financing Activities	2,444	4,889
Effect of exchange rate changes on cash and cash equivalents	0	0
Net decrease in Cash and Cash Equivalents	(115)	25
Cash and Cash Equivalents, beginning of period	123	4
Cash and Cash Equivalents, end of period	8	29
Subsidiary Issuer and Guarantor - KMP
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	2,976	5,190
Funding to affiliates	(770)	(6,486)
Capital expenditures	0	0
Contributions to investments	0	0
Investment in KMP		0
Acquisitions of assets and investments, net of cash acquired	0	0
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	0	0
Distributions from equity investments in excess of cumulative earnings	298	0
Other, net	(54)	(2)
Net Cash Used in Investing Activities	(526)	(6,488)
Issuances of debt	0	0
Payments of debt	(500)	(300)
Funding from affiliates	882	3,906
Debt issue costs	0	0
Issuances of common shares		0
Cash dividends - common shares	0	0
Cash dividends - preferred shares	0
Repurchases of warrants		0
Contributions from parents	0	156
Contributions from noncontrolling interests	0
Distributions to parents	(2,832)	(2,478)
Distributions to noncontrolling interests	0	0
Other, net		(1)
Net Cash (Used in) Provided by Financing Activities	(2,450)	1,283
Effect of exchange rate changes on cash and cash equivalents	0	0
Net decrease in Cash and Cash Equivalents	0	(15)
Cash and Cash Equivalents, beginning of period	0	15
Cash and Cash Equivalents, end of period	0	0
Subsidiary Issuer and Guarantor - Copano
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	(143)	72
Funding to affiliates	(1)	(1)
Capital expenditures	0	(3)
Contributions to investments	0	0
Investment in KMP		0
Acquisitions of assets and investments, net of cash acquired	0	0
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	0	5
Distributions from equity investments in excess of cumulative earnings	0	0
Other, net	0	0
Net Cash Used in Investing Activities	(1)	1
Issuances of debt	0	0
Payments of debt	0	0
Funding from affiliates	144	(73)
Debt issue costs	0	0
Issuances of common shares		0
Cash dividends - common shares	0	0
Cash dividends - preferred shares	0
Repurchases of warrants		0
Contributions from parents	0	0
Contributions from noncontrolling interests	0
Distributions to parents	0	0
Distributions to noncontrolling interests	0	0
Other, net		0
Net Cash (Used in) Provided by Financing Activities	144	(73)
Effect of exchange rate changes on cash and cash equivalents	0	0
Net decrease in Cash and Cash Equivalents	0	0
Cash and Cash Equivalents, beginning of period	0	0
Cash and Cash Equivalents, end of period	0	0
Subsidiary Guarantors
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	5,616	3,755
Funding to affiliates	(2,455)	(4,387)
Capital expenditures	(929)	(1,705)
Contributions to investments	(13)	(45)
Investment in KMP		0
Acquisitions of assets and investments, net of cash acquired	(331)	(210)
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	220	4
Distributions from equity investments in excess of cumulative earnings	68	80
Other, net	37	4
Net Cash Used in Investing Activities	(3,403)	(6,259)
Issuances of debt	0	0
Payments of debt	(1,104)	(38)
Funding from affiliates	2,124	5,546
Debt issue costs	0	0
Issuances of common shares		0
Cash dividends - common shares	0	0
Cash dividends - preferred shares	0
Repurchases of warrants		0
Contributions from parents	0	3
Contributions from noncontrolling interests	0
Distributions to parents	(3,234)	(3,010)
Distributions to noncontrolling interests	0	0
Other, net		0
Net Cash (Used in) Provided by Financing Activities	(2,214)	2,501
Effect of exchange rate changes on cash and cash equivalents	0	0
Net decrease in Cash and Cash Equivalents	(1)	(3)
Cash and Cash Equivalents, beginning of period	12	17
Cash and Cash Equivalents, end of period	11	14
Subsidiary Non-Guarantors
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	221	(26)
Funding to affiliates	(219)	(351)
Capital expenditures	(504)	(183)
Contributions to investments	(7)	0
Investment in KMP		0
Acquisitions of assets and investments, net of cash acquired	0	0
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	0	0
Distributions from equity investments in excess of cumulative earnings	0	0
Other, net	2	9
Net Cash Used in Investing Activities	(728)	(525)
Issuances of debt	0	0
Payments of debt	(5)	(5)
Funding from affiliates	536	493
Debt issue costs	0	0
Issuances of common shares		0
Cash dividends - common shares	0	0
Cash dividends - preferred shares	0
Repurchases of warrants		0
Contributions from parents	87	0
Contributions from noncontrolling interests	0
Distributions to parents	(90)	(92)
Distributions to noncontrolling interests	0	0
Other, net		0
Net Cash (Used in) Provided by Financing Activities	528	396
Effect of exchange rate changes on cash and cash equivalents	5	(4)
Net decrease in Cash and Cash Equivalents	26	(159)
Cash and Cash Equivalents, beginning of period	142	279
Cash and Cash Equivalents, end of period	168	120
Consolidated KMI
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	2,344	2,538
Funding to affiliates	0	0
Capital expenditures	(1,470)	(1,909)
Contributions to investments	(363)	(45)
Investment in KMP		0
Acquisitions of assets and investments, net of cash acquired	(333)	(1,919)
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	220	4
Distributions from equity investments in excess of cumulative earnings	81	114
Other, net	(15)	11
Net Cash Used in Investing Activities	(1,880)	(3,744)
Issuances of debt	6,847	9,485
Payments of debt	(6,800)	(8,941)
Funding from affiliates	0	0
Debt issue costs	(6)	(20)
Issuances of common shares		2,562
Cash dividends - common shares	(559)	(2,006)
Cash dividends - preferred shares	76
Repurchases of warrants		(5)
Contributions from parents	0	0
Contributions from noncontrolling interests	87
Distributions to parents	0	0
Distributions to noncontrolling interests	(11)	(16)
Other, net		(1)
Net Cash (Used in) Provided by Financing Activities	(518)	1,058
Effect of exchange rate changes on cash and cash equivalents	5	(4)
Net decrease in Cash and Cash Equivalents	(49)	(152)
Cash and Cash Equivalents, beginning of period	229	315
Cash and Cash Equivalents, end of period	$ 180	$ 163