Kinder Morgan (KMI) 10-Q 21 Oct 16 2016 Q3 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - USD ($)	9 Months Ended
	Sep. 30, 2016	Oct. 20, 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		2,232,364,274
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q3
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2016

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Revenues
Natural gas sales	$ 719	$ 744	$ 1,740	$ 2,206
Services	2,006	2,015	6,154	5,948
Product sales and other	605	948	1,775	2,613
Total Revenues	3,330	3,707	9,669	10,767
Operating Costs, Expenses and Other
Costs of sales	971	1,106	2,454	3,281
Operations and maintenance	576	612	1,744	1,707
Depreciation, depletion and amortization	549	617	1,652	1,725
General and administrative	171	160	550	540
Taxes, other than income taxes	106	108	324	339
Loss on impairments and divestitures, net	76	385	307	489
Other income, net	(1)	(2)	0	(5)
Total Operating Costs, Expenses and Other	2,448	2,986	7,031	8,076
Operating Income	882	721	2,638	2,691
Other Income (Expense)
Earnings from equity investments	137	114	343	330
Loss on impairments and divestitures of equity investments, net	350	0	344	26
Amortization of excess cost of equity investments	(15)	(13)	(45)	(39)
Interest, net	(472)	(540)	(1,384)	(1,524)
Other, net	12	9	42	33
Total Other Expense	(688)	(430)	(1,388)	(1,226)
Income Before Income Taxes	194	291	1,250	1,465
Income Tax Expense	(377)	(108)	(744)	(521)
Net (Loss) Income	(183)	183	506	944
Net (Income) Loss Attributable to Noncontrolling Interests	(5)	3	(7)	4
Net (Loss) Income Attributable to Kinder Morgan, Inc.	(188)	186	499	948
Preferred Stock Dividends	(39)	0	(117)	0
Net (Loss) Income Available to Common Stockholders	$ (227)	$ 186	$ 382	$ 948
Class P Shares
Basic (Loss) Earnings Per Common Share	$ (0.10)	$ 0.08	$ 0.17	$ 0.43
Basic Weighted Average Common Shares Outstanding	2,230	2,203	2,229	2,173
Diluted (Loss) Earnings Per Common Share	$ (0.10)	$ 0.08	$ 0.17	$ 0.43
Diluted Weighted Average Common Shares Outstanding	2,230	2,203	2,229	2,181
Dividends Per Common Share Declared for the Period	$ 0.125	$ 0.51	$ 0.375	$ 1.48

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Net Income
Net (loss) income	$ (183)	$ 183	$ 506	$ 944
Other comprehensive income (loss), net of tax
Change in fair value of hedge derivatives (net of tax (expense) benefit of $(29), $(60), $11 and $(25), respectively)	50	104	(19)	44
Reclassification of change in fair value of derivatives to net income (net of tax benefit of $23, $37, $92 and $111, respectively)	(39)	(63)	(158)	(192)
Foreign currency translation adjustments (net of tax benefit (expense) of $11, $45, $(38) and $98, respectively)	(20)	(79)	65	(170)
Benefit plan adjustments (net of tax expense of $(3), $-, $(9) and $(4), respectively)	6	1	16	7
Total other comprehensive loss	(3)	(37)	(96)	(311)
Comprehensive (loss) income	(186)	146	410	633
Comprehensive (income) loss attributable to noncontrolling interests	(5)	3	(7)	4
Comprehensive (loss) income attributable to KMI	$ (191)	$ 149	$ 403	$ 637

CONSOLIDATED STATEMENTS OF COM4

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Other comprehensive income (loss), net of tax
Change in fair value of hedge derivatives	$ (29)	$ (60)	$ 11	$ (25)
Reclassification of change in fair value of derivatives to net income	23	37	92	111
Foreign currency translation adjustments	11	45	(38)	98
Benefit plan adjustments	$ (3)	$ 0	$ (9)	$ (4)

CONSOLIDATED BALANCE SHEETS (Un

CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Current Assets
Cash and cash equivalents	$ 357	$ 229
Restricted deposits	888	60
Accounts receivable, net	1,282	1,315
Fair value of derivative contracts	281	507
Inventories	325	407
Other current assets	230	306
Total current assets	3,363	2,824
Property, plant and equipment, net	38,780	40,547
Investments	7,358	6,040
Goodwill	22,163	23,790
Other intangibles, net	3,384	3,551
Deferred income taxes	4,595	5,323
Deferred charges and other assets	1,961	2,029
Total Assets	81,604	84,104
Current Liabilities
Current portion of debt	2,944	821
Accounts payable	1,192	1,324
Accrued interest	505	695
Accrued contingencies	413	298
Accrued Income Taxes, Current	278	165
Other current liabilities	712	762
Total current liabilities	6,044	4,065
Long-term debt
Outstanding	36,708	40,632
Preferred interest in general partner of KMP	100	100
Debt fair value adjustments	1,710	1,674
Total long-term debt	38,518	42,406
Other long-term liabilities and deferred credits	2,074	2,230
Total long-term liabilities and deferred credits	40,592	44,636
Total Liabilities	46,636	48,701
Commitments and contingencies (Notes 3 and 9)
Stockholders’ Equity
Class P shares, $0.01 par value, 4,000,000,000 shares authorized, 2,230,085,392 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	41,701	41,661
Retained deficit	(6,560)	(6,103)
Accumulated other comprehensive loss	(557)	(461)
Total Kinder Morgan, Inc.’s stockholders’ equity	34,606	35,119
Noncontrolling interests	362	284
Total Stockholders’ Equity	34,968	35,403
Total Liabilities and Stockholders’ Equity	$ 81,604	$ 84,104

CONSOLIDATED BALANCE SHEETS (U6

CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - $ / shares	9 Months Ended	12 Months Ended
	Sep. 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)	2,230,085,392	2,229,223,864
Common stock, shares outstanding (in shares)	2,230,085,392	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	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Cash Flows From Operating Activities
Net income	$ 506	$ 944
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion and amortization	1,652	1,725
Deferred income taxes	767	524
Amortization of excess cost of equity investments	45	39
Loss on impairments and divestitures, net	307	489
Loss on impairments and divestitures of equity investments, net	344	26
Earnings from equity investments	(343)	(330)
Distributions from equity investment earnings	321	289
Noncash pension benefit credits	0	(78)
Changes in components of working capital, net of the effects of acquisitions and dispositions
Accounts receivable, net	26	304
Income tax receivable	0	195
Inventories	68	2
Other current assets	(20)	82
Accounts payable	(46)	(264)
Accrued interest, net of interest rate swaps	(158)	(72)
Accrued contingencies and other current liabilities	140	6
Rate reparations, refunds and other litigation reserve adjustments	31	3
Other, net	(145)	(377)
Net Cash Provided by Operating Activities	3,495	3,507
Cash Flows From Investing Activities
Acquisitions of assets and investments, net of cash acquired	(333)	(1,919)
Capital expenditures	(2,109)	(2,999)
Proceeds from Divestiture of Interest in Consolidated Subsidiaries	1,402	0
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	250	45
Contributions to investments	(389)	(69)
Distributions from equity investments in excess of cumulative earnings	158	181
Other, net	(26)	39
Net Cash Used in Investing Activities	(1,047)	(4,722)
Cash Flows From Financing Activities
Issuances of debt	8,485	12,281
Payments of debt	(9,135)	(11,893)
Restricted cash held in escrow for debt repayment	(776)	0
Debt issue costs	(15)	(20)
Issuances of common shares	0	3,833
Cash dividends - common shares	(839)	(3,084)
Cash dividends - preferred shares	(115)	0
Repurchases of warrants	0	(12)
Contributions from noncontrolling interests	88	7
Distributions to noncontrolling interests	(17)	(25)
Other, net	0	(1)
Net Cash (Used in) Provided by Financing Activities	(2,324)	1,086
Effect of Exchange Rate Changes on Cash and Cash Equivalents	4	(7)
Net increase (decrease) in Cash and Cash Equivalents	128	(136)
Cash and Cash Equivalents, beginning of period	229	315
Cash and Cash Equivalents, end of period	357	179
Non-cash Investing and Financing Activities
Assets acquired by the assumption or incurrence of liabilities	43	1,680
Net assets contributed to equity investment	37	46
Supplemental Disclosures of Cash Flow Information
Cash paid during the period for interest (net of capitalized interest)	1,598	1,596
Cash paid (refunded) during the period for income taxes, net	$ 4	$ (183)

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)	101,000,000
Issuances of common shares	$ 3,833	1		3,832			3,833
Repurchase of warrants	$ (12)			(12)			(12)
EP Trust I Preferred security conversions	1,000,000
EP Trust I Preferred security conversions	$ 23			23			23
Warrants exercised	$ 2			2			2
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	1,000,000
Restricted shares	$ 40			40			40
Net (loss) income	944				948		948	(4)
Distributions	(25)						0	(25)
Contributions	7						0	7
Common stock dividends	(3,084)				(3,084)		(3,084)
Stockholders' Equity, Other	(1)			(1)			(1)
Other comprehensive loss	$ (311)					(311)	(311)
Balance (in shares) Common stock at Sep. 30, 2015	2,228,000,000
Balance (in shares) Preferred stock at Sep. 30, 2015	0
Balance at Sep. 30, 2015	$ 35,842	22	0	40,062	(4,242)	(328)	35,514	328
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]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	1,000,000
Restricted shares	$ 47			47			47
Net (loss) income	506				499		499	7
Distributions	(17)						0	(17)
Contributions	88						0	88
Preferred stock dividends	(117)				(117)		(117)
Common stock dividends	(839)				(839)		(839)
Stockholders' Equity, Other	(7)			(7)			(7)
Other comprehensive loss	$ (96)					(96)	(96)
Balance (in shares) Common stock at Sep. 30, 2016	2,230,085,392
Balance (in shares) Preferred stock at Sep. 30, 2016	1,600,000
Balance at Sep. 30, 2016	$ 34,968	$ 22	$ 0	$ 41,701	$ (6,560)	$ (557)	$ 34,606	$ 362

General (Notes)

General (Notes)	9 Months Ended
	Sep. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General	General Organization We are the largest energy infrastructure company in 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. 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. Impairments and Divestitures During the three and nine months ended September 30, 2016 , we recorded non-cash pre-tax losses on impairments and divestitures netting to $76 million and $307 million , respectively. The three and nine months ended September 30, 2016 included (i) an $84 million loss on the sale of a 50% interest in our SNG natural gas pipeline system; (ii) losses of $1 million and $9 million , respectively, on a held-for-sale Transmix facility within our Products Pipelines business segment; and (iii) a $9 million net gain and a $3 million net loss, respectively, on other asset disposals. The nine months ended September 30, 2016 also included (i) $106 million of project write-offs on our Northeast Energy Direct (NED) Market project within our Natural Gas Pipelines business segment; (ii) a $21 million project write-off within our CO 2 business segment; (iii) a $20 million impairment related to certain terminals with significant coal operations within our Terminals business segment; and (iv) $64 million of write-offs associated with our Palmetto project within our Products Pipelines business segment. The project write-offs recorded in the nine months ended September 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 nine months ended September 30, 2015, we recorded non-cash pre-tax losses on impairments and divestitures netting to $385 million and $489 million , respectively. These amounts include (i) $99 million for the nine months ended September 30, 2015 of impairments and project write-offs related to certain gas gathering and processing assets within our midstream operations of our Natural Gas Pipelines business segment; (ii) $388 million and $397 million for the three and nine months ended September 30, 2015, respectively, within our CO 2 business segment primarily related to our Goldsmith oil and gas field, primarily driven by a decrease in commodity prices; and (iii) $3 million and $7 million for the three and nine months ended September 30, 2015, respectively, of net gains on other asset disposals. During the three and nine months ended September 30, 2016, we recorded $350 million and $344 million , respectively, of non-cash pre-tax net losses on impairments and divestitures of equity investments, primarily related to an impairment of our equity investment in MEP within our Natural Gas Pipelines business segment. Based on commercial discussions during the third quarter of 2016 with current and potential shippers on MEP regarding the outlook for long-term transportation contract rates, we concluded the fair value of our investment was other than temporarily impaired, thereby resulting in a write-down of our investment. During the nine months ended September 30, 2015, we recorded $26 million non-cash pre-tax losses on impairments of equity investments in certain gas gathering operations within our Natural Gas Pipelines business segment. 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 and long-term contract rate 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. For example, to the extent future commodity prices are significantly lower than current market expectations and thereby unfavorably affect our customers’ investment decisions, 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 commodity prices, 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. 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. Our May 31, 2016 annual goodwill impairment test indicated our remaining goodwill is recoverable, and no event indicating a goodwill impairment has occurred subsequent to that date. 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 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. Unfavorable changes to any one or combination of these factors, particularly for our Natural Gas Pipelines - Non-Regulated reporting unit, would result in a change to the reporting unit fair values which could lead to further impairment charges. Such potential impairment could have a significant effect on our results of operations. Earnings per Share We calculate earnings per share using the two-class method. Earnings were allocated to Class P shares of common stock and participating securities based on the amount of dividends paid in the current period plus an allocation of the undistributed earnings or excess distributions over earnings to the extent that each security participates in earnings or excess distributions over earnings. Our unvested restricted stock awards, 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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Class P shares $ (228 ) $ 182 $ 379 $ 938 Participating securities: Restricted stock awards(a) 1 4 3 10 Net (Loss) Income Available to Common Stockholders $ (227 ) $ 186 $ 382 $ 948 Three Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Basic Weighted Average Common Shares Outstanding 2,230 2,203 2,229 2,173 Effect of dilutive securities: Warrants — — — 8 Diluted Weighted Average Common Shares Outstanding 2,230 2,203 2,229 2,181 ________ (a) As of September 30, 2016 , there were approximately 9 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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Unvested restricted stock awards 9 8 8 7 Warrants to purchase our Class P shares(a) 293 296 293 290 Convertible trust preferred securities 8 8 8 8 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)	9 Months Ended
	Sep. 30, 2016
Acquisitions and Divestitures [Abstract]
Acquisitions	Acquisitions and Divestiture 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 nine months ended September 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 September 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. Sale of Equity Interest in SNG On September 1, 2016, we completed the sale of a 50% interest in our SNG natural gas pipeline system to The Southern Company (Southern Company), receiving proceeds of $1.4 billion , and the formation of a joint venture, which includes our remaining 50% interest in SNG. We used the proceeds from the sale to reduce outstanding debt (see Note 3). We recognized a pre-tax loss of $84 million on the sale of our interest in SNG which is included within “Loss on impairments and divestitures, net” on the accompanying consolidated statements of income for the three and nine months ended September 30, 2016. As a result of this transaction, we no longer hold a controlling interest in SNG or Bear Creek Storage Company, LLC (Bear Creek) ( 50% of which is owned by SNG) and, as such, we now account for our remaining equity interests in SNG and Bear Creek as equity investments.

Debt Debt (Notes)

Debt Debt (Notes)	9 Months Ended
	Sep. 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): September 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) 13,326 13,346 Credit facility due November 26, 2019 — — Commercial paper borrowings — — 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(c) — 332 CIG senior notes, 4.15% and 6.85%, due 2026 and 2037(d) 475 100 SNG notes, 4.40% through 8.00%, due 2017 through 2032(e) — 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 435 443 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 295 300 Total debt – KMI and Subsidiaries 39,752 41,553 Less: Current portion of debt(a)(e)(f) 2,944 821 Total long-term debt – KMI and Subsidiaries(g) $ 36,808 $ 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 September 30, 2016 exchange rate of 1.1235 U.S. dollars per Euro and the December 31, 2015 exchange rate of 1.0862 U.S. dollars per Euro. For the nine months ended September 30, 2016 , our debt balance increased by $47 million as a result of the change in the exchange rate of U.S. dollars per Euro. The increase in debt due to the changes in exchange rates is offset by a corresponding change in the value of cross-currency swaps reflected in “Deferred charges and other assets” and “ Other long-term liabilities and deferred credits” on our consolidated balance sheets. 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) On September 30, 2016, we repaid the $332 million principal amount of 7.125% senior notes due 2021, plus accrued interest. We recognized a $28.3 million gain from the early extinguishment of debt, included within “Interest, net” on the accompanying consolidated statements of income for the three and nine months ended September 30, 2016 consisting of an $11.8 million premium on the debt repaid and a $40.1 million gain from the write-off of unamortized purchase accounting associated with the extinguished debt. Copano continues to be a subsidiary guarantor under a cross guarantee agreement (see Note 11). (d) On August 16, 2016 , CIG completed a private offering of $375 million in principal amount of 4.15% senior notes due August 15, 2026. The net proceeds of $372 million received from the offering were used to reduce debt incurred as the result of the repayment of CIG’s senior notes that matured in 2015 and for general corporate purposes. (e) Due to the September 1, 2016 sale of a 50% interest in SNG, we no longer consolidate SNG’s accounts in our consolidated financial statements. As of the transaction date, SNG had $1,211 million of debt outstanding (including a current portion of $500 million ). (f) Amounts include outstanding credit facility borrowings, commercial paper borrowings and other debt maturing within 12 months (see “—Current Portion of Debt” below). (g) Excludes our “Debt fair value adjustments” which, as of September 30, 2016 and December 31, 2015 , increased our combined debt balances by $1,710 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 September 30, 2016 was $4,832 million , which is net of $168 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 September 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 $786 million 7.00% notes due June 2017 $749 million 7.25% notes originally due October 2020 (see “—Subsequent Event” below) As of December 31, 2015 $500 million 3.50% notes due March 2016 Long-term Debt Issuances, Repayments and Other Significant Changes in Debt The following are significant long-term debt issuances, repayments and other significant changes made during the nine months ended September 30, 2016 : Issuances $1.0 billion unsecured term loan facility due 2019 $375 million 4.15% notes due 2026 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 $332 million 7.125% notes due 2021 Other significant changes $1,211 million reduction due to the deconsolidation of SNG, including a current portion of $500 million (see Note 2) Subsequent Event On October 1, 2016, a portion of the proceeds from the sale of a 50% interest in SNG was used to repay the $749 million principal amount of Hiland’s 7.25% senior notes due 2020, plus accrued interest. As of September 30, 2016, funds for this early extinguishment were held in escrow as a restricted deposit and included in the accompanying consolidated balance sheet within “Restricted deposits.” As of September 30, 2016, we classified the $749 million of senior notes as “Current portion of debt” within the accompanying consolidated balance sheet.

Stockholders' Equity (Notes)

Stockholders' Equity (Notes)	9 Months Ended
	Sep. 30, 2016
Stockholders' Equity Note [Abstract]
Stockholders' Equity Note Disclosure [Text Block]	Stockholders’ Equity Common Equity As of September 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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Per common share cash dividend declared for the period $ 0.125 $ 0.51 $ 0.375 $ 1.48 Per common share cash dividend paid in the period $ 0.125 $ 0.49 $ 0.375 $ 1.42 On October 19, 2016 , our board of directors declared a cash dividend of $0.125 per common share for the quarterly period ended September 30, 2016 , which is payable on November 15, 2016 to common shareholders of record as of November 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 July 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 July 26, 2016 through and including October 25, 2016, which is payable on October 26, 2016 to mandatory convertible preferred shareholders of record as of October 11, 2016.

Risk Management (Notes)

Risk Management (Notes)	9 Months Ended
	Sep. 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 September 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 (19.4 ) MMBbl Crude oil basis (2.2 ) MMBbl Natural gas fixed price (27.5 ) Bcf Natural gas basis (12.8 ) Bcf Derivatives not designated as hedging contracts Crude oil fixed price (0.1 ) MMBbl Natural gas fixed price (9.9 ) Bcf Natural gas basis (3.3 ) Bcf NGL and other fixed price (2.6 ) MMBbl As of September 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 September 30, 2016 , we had a combined notional principal amount of $9,775 million of fixed-to-variable interest rate swap agreements, all of which 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 September 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 September 30, December 31, September 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) $ 153 $ 359 $ (22 ) $ (13 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 111 244 (19 ) — Subtotal 264 603 (41 ) (13 ) Interest rate swap agreements Fair value of derivative contracts/(Other current liabilities) 124 111 — — Deferred charges and other assets/(Other long-term liabilities and deferred credits) 614 273 — (9 ) Subtotal 738 384 — (9 ) Cross-currency swap agreements Fair value of derivative contracts/(Other current liabilities) — — (14 ) (6 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 41 — — (46 ) Subtotal 41 — (14 ) (52 ) Total 1,043 987 (55 ) (74 ) Derivatives not designated as hedging contracts Natural gas, crude, NGL and other derivative contracts Fair value of derivative contracts/(Other current liabilities) 4 35 (8 ) (1 ) Subtotal 4 35 (8 ) (1 ) Interest rate swap agreements Fair value of derivative contracts/(Other current liabilities) — 1 — (11 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) — — — (5 ) Subtotal — 1 — (16 ) Power derivative contracts Fair value of derivative contracts/(Other current liabilities) — 1 — (17 ) Subtotal — 1 — (17 ) Total 4 37 (8 ) (34 ) Total derivatives $ 1,047 $ 1,024 $ (63 ) $ (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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Interest rate swap agreements Interest, net $ (84 ) $ 251 $ 315 $ 163 Hedged fixed rate debt Interest, net $ 81 $ (283 ) $ (323 ) $ (166 ) 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 September 30, Three Months Ended September 30, Three Months Ended September 30, 2016 2015 2016 2015 2016 2015 Energy commodity derivative contracts $ 20 $ 119 Revenues—Natural gas sales $ (3 ) $ 4 Revenues—Natural gas sales $ — $ — Revenues—Product sales and other 34 60 Revenues—Product sales and other (2 ) (6 ) Costs of sales (1 ) (2 ) Costs of sales — — Interest rate swap agreements(c) — (4 ) Interest, net (1 ) (1 ) Interest, net — — Cross-currency swap 30 (11 ) Other, net 10 2 Other, net — — Total $ 50 $ 104 Total $ 39 $ 63 Total $ (2 ) $ (6 ) 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) Nine Months Ended September 30, Nine Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 2016 2015 Energy commodity derivative contracts $ (64 ) $ 72 Revenues—Natural gas sales $ 20 $ 29 Revenues—Natural gas sales $ — $ — Revenues—Product sales and other 124 161 Revenues—Product sales and other (7 ) 4 Costs of sales (13 ) (21 ) Costs of sales — — Interest rate swap agreements(c) (5 ) (6 ) Interest, net (2 ) (2 ) Interest, net — — Cross-currency swap 50 (22 ) Other, net 29 25 Other, net — — Total $ (19 ) $ 44 Total $ 158 $ 192 Total $ (7 ) $ 4 _____ (a) We expect to reclassify an approximate $49 million gain associated with cash flow hedge price risk management activities included in our accumulated other comprehensive loss balances as of September 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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Energy commodity derivative contracts Revenues—Natural gas sales $ 1 $ 6 $ (4 ) $ 9 Revenues—Product sales and other 7 169 (7 ) 173 Costs of sales 1 — (1 ) — Interest rate swap agreements Interest, net (14 ) — 63 — Total(a) $ (5 ) $ 175 $ 51 $ 182 _______ (a) Three and nine months ended September 30, 2016 includes an approximate gain of $20 million and $59 million , respectively, associated with natural gas, crude and NGL derivative contract settlements. Three and nine months ended September 30, 2015 includes an approximate gain of $19 million and $21 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 September 30, 2016 and December 31, 2015 , we had no and $2 million , respectively, of outstanding letters of credit supporting our commodity price risk management program. As of September 30, 2016 , we had cash margins of $16 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 September 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 (19 ) 65 16 62 Gains reclassified from accumulated other comprehensive loss (158 ) — — (158 ) Net current-period other comprehensive (loss) income (177 ) 65 16 (96 ) Balance as of September 30, 2016 $ 42 $ (257 ) $ (342 ) $ (557 ) 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 gain (loss) before reclassifications 44 (170 ) 7 (119 ) Gains reclassified from accumulated other comprehensive loss (192 ) — — (192 ) Net current-period other comprehensive (loss) income (148 ) (170 ) 7 (311 ) Balance as of September 30, 2015 $ 179 $ (278 ) $ (229 ) $ (328 )

Fair Value (Notes)

Fair Value (Notes)	9 Months Ended
	Sep. 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 September 30, 2016 Energy commodity derivative contracts(a) $ 4 $ 264 $ — $ 268 $ (25 ) $ — $ 243 Interest rate swap agreements $ — $ 738 $ — $ 738 $ — $ — $ 738 Cross-currency swap agreements $ — $ 41 $ — $ 41 $ (14 ) $ — $ 27 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 September 30, 2016 Energy commodity derivative contracts(a) $ (10 ) $ (39 ) $ — $ (49 ) $ 25 $ 16 $ (8 ) Interest rate swap agreements $ — $ — $ — $ — $ — $ — $ — Cross-currency swap agreements $ — $ (14 ) $ — $ (14 ) $ 14 $ — $ — 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 “Restricted deposits” 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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Derivatives-net asset (liability) Beginning of Period $ — $ (37 ) $ (15 ) $ (61 ) Total gains or (losses) included in earnings — (1 ) (9 ) (1 ) Settlements — 15 24 39 End of Period $ — $ (23 ) $ — $ (23 ) 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 $ — $ — $ — $ 2 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 carrying value and estimated fair value of our outstanding debt balances are disclosed below (in millions): September 30, 2016 December 31, 2015 Carrying value Estimated fair value Carrying value Estimated fair value Total debt $ 41,462 $ 42,106 $ 43,227 $ 37,481 We used Level 2 input values to measure the estimated fair value of our outstanding debt balances as of both September 30, 2016 and December 31, 2015 .

Reportable Segments (Notes)

Reportable Segments (Notes)	9 Months Ended
	Sep. 30, 2016
Segment Reporting [Abstract]
Reportable Segments	Reportable Segments Financial information by segment follows (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Revenues Natural Gas Pipelines Revenues from external customers $ 2,048 $ 2,176 $ 5,900 $ 6,444 Intersegment revenues 2 8 4 16 CO 2 310 517 916 1,316 Terminals Revenues from external customers 484 469 1,436 1,395 Intersegment revenues — — 1 1 Products Pipelines Revenues from external customers 415 467 1,204 1,388 Intersegment revenues 4 — 12 1 Kinder Morgan Canada 66 68 188 193 Other (1 ) — — 3 Total segment revenues 3,328 3,705 9,661 10,757 Other revenues 8 10 25 28 Less: Total intersegment revenues (6 ) (8 ) (17 ) (18 ) Total consolidated revenues $ 3,330 $ 3,707 $ 9,669 $ 10,767 Three Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Segment EBDA(a) Natural Gas Pipelines $ 540 $ 993 $ 2,498 $ 2,936 CO 2 217 29 606 605 Terminals 286 249 831 798 Products Pipelines 293 288 765 811 Kinder Morgan Canada 43 42 123 120 Other 2 (9 ) (11 ) (55 ) Total Segment EBDA 1,381 1,592 4,812 5,215 DD&A (549 ) (617 ) (1,652 ) (1,725 ) Amortization of excess cost of equity investments (15 ) (13 ) (45 ) (39 ) Other revenues 8 10 25 28 General and administrative expense (171 ) (160 ) (550 ) (540 ) Interest expense, net of unallocable interest income (474 ) (539 ) (1,386 ) (1,525 ) Unallocable income tax expense (363 ) (90 ) (698 ) (470 ) Total consolidated net (loss) income $ (183 ) $ 183 $ 506 $ 944 September 30, 2016 December 31, 2015 Assets Natural Gas Pipelines $ 50,428 $ 53,704 CO 2 4,211 4,706 Terminals 9,838 9,083 Products Pipelines 8,348 8,464 Kinder Morgan Canada 1,568 1,434 Other 309 418 Total segment assets 74,702 77,809 Corporate assets(b) 6,902 6,276 Assets held for sale — 19 Total consolidated assets $ 81,604 $ 84,104 _______ (a) We evaluate performance based on each segment’s EBDA. Segment EBDA includes revenues, earnings from equity investments, losses on impairments and divestitures of equity investments, net, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other expense (income), net, and losses on impairments and divestitures, 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)	9 Months Ended
	Sep. 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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Income tax expense $ 377 $ 108 $ 744 $ 521 Effective tax rate 194.3 % 37.1 % 59.5 % 35.6 % The effective tax rate for the three and nine months ended September 30, 2016 is higher than the statutory federal rate of 35% primarily due to (i) the tax impact of the sale of a 50% interest in SNG; (ii) state and foreign income taxes; and (iii) the change in the effective state tax rate as a result of the SNG sale. These increases are partially offset by dividend-received deductions from our investment in Florida Gas Pipeline (Citrus) and Plantation Pipe Line. The SNG partial sale transaction generated a taxable gain resulting from non-deductible goodwill attributable to the transaction which generated a deferred tax provision of $269 million . The effective tax rate for the three months ended September 30, 2015 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 Citrus and adjustments to our income tax reserve for uncertain tax positions. The effective tax rate for the nine months ended September 30, 2015 is marginally higher than the statutory federal rate of 35% primarily due to state and foreign income taxes, partially offset by (i) dividend-received deductions from our investment in Citrus; (ii) the change in the effective state tax rate as a result of the Hiland acquisition; and (iii) adjustments to our income tax reserve for uncertain tax positions. As of September 30, 2016 , the total amount of unrecognized tax benefits including interest and penalties relating to uncertain tax positions is $146 million , a decrease of $27 million from the December 31, 2015 balance of $173 million . This $27 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)	9 Months Ended
	Sep. 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 prevail on their arguments or claims, they are entitled to seek reparations (which may reach back up to two years prior to the filing date 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. On March 22, 2016, the D.C. Circuit issued a decision in United Airlines, Inc. v. FERC remanding to FERC for further consideration of two issues: (1) the appropriate data to be used to determine the return on equity for SFPP in the underlying docket, and (2) the just and reasonable return to be provided to a tax pass-through entity that includes an income tax allowance in its underlying cost of service. 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 FERC precedent, as applicable, to pending SFPP 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 the judicial review sought by certain intervenors has been delayed until the FERC issues an order on rehearing. 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 and oral argument was held on October 19, 2016. 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 our November 26, 2014 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. The lawsuits were 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 September 30, 2016 and December 31, 2015, our total reserve for legal matters was $502 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 laws 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, including alleged violations of the Risk Management Program and leak detection and repair requirements of the Clean Air Act. As we receive notices of non-compliance, we attempt to negotiate and settle such matters where appropriate. These alleged violations may result in fines and penalties, but we do not believe any such fines and penalties, individually or in the aggregate, will be material. 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 seven years to implement at an estimated present cost of approximately $750 million . Comments on the FS and the Proposed Plan were submitted by the LWG and on our own behalf on September 7, 2016. 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 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 from 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 June 17, 2016, the parties entered into a settlement resolving all claims related to the historical 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 investigating uranium impacts on the Navajo Reservation. The counterclaim of defendant EPA has been settled, and no viable claims for reimbursement by the other defendants are known to exist. Lower Passaic River Study Area of the Diamond Alkali Superfund Site, Essex, Hudson, Bergen and Passaic Counties, New Jersey EPEC Polymers, Inc. (EPEC Polymers) and EPEC Oil Company Liquidating Trust (EPEC Oil Trust), former

Recent Accounting Pronouncement

Recent Accounting Pronouncements (Notes)	9 Months Ended
	Sep. 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. ASU No. 2016-15 On August 26, 2016, the FASB issued ASU 2016-15, “ Statement of Cash Flows - Classification of Certain Cash Receipts and Cash Payments (Topic 230) .” This ASU is intended to reduce the diversity in practice around how certain transactions are classified within the statement of cash flows. We adopted ASU No. 2016-15 in the third quarter of 2016 with no material impact to our financial statements.

Guarantee of Securities of Subs

Guarantee of Securities of Subsidiaries (Notes)	9 Months Ended
	Sep. 30, 2016
Guarantee of Securities of Subsidiaries [Abstract]
Guarantees [Text Block]	Guarantee of Securities of Subsidiaries KMI, along with its direct subsidiary KMP, are issuers of certain public debt securities. KMI, KMP and substantially all of KMI’s wholly owned domestic subsidiaries, are parties 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. Accordingly, with the exception of certain subsidiaries identified as Subsidiary Non-Guarantors, the parent issuer, subsidiary issuer 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 or KMP are in the same position with respect to the net assets, income and cash flows of KMI and the Subsidiary Issuer 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 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 issuer in separate columns in this single set of condensed consolidating financial statements. On September 30, 2016, Copano (previously reflected as a Subsidiary Issuer and Guarantor) repaid the $332 million principal amount of its 7.125% senior notes due 2021. Copano continues to be a subsidiary guarantor under the cross guarantee agreement mentioned above. For all periods presented, financial statement balances and activities for Copano are now reflected within the Subsidiary Guarantor column, and the Subsidiary Issuer and Guarantor-Copano column has been eliminated. On September 1, 2016, we sold a 50% equity interest in SNG (see further details discussed in Note 2, “Acquisitions and Divestiture”). Subsequent to the transaction, we deconsolidated SNG and now account for our equity interest in SNG as an equity investment. Our wholly owned subsidiary which holds our interest in SNG is reflected within the Subsidiary Guarantors column of these condensed consolidating financial statements. Excluding fair value adjustments, as of September 30, 2016 , Parent Issuer and Guarantor, Subsidiary Issuer and Guarantor-KMP, and Subsidiary Guarantors had $14,325 million , $19,485 million , and $4,947 million , respectively, of Guaranteed Notes outstanding. Included in the Subsidiary Guarantors debt balance as presented in the accompanying September 30, 2016 condensed consolidating balance sheets is approximately $171 million of capital lease obligation that is not subject to the cross guarantee agreement. The accounts within the Parent Issuer and Guarantor, Subsidiary Issuer and Guarantor-KMP, 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 September 30, 2016 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 9 $ — $ 2,953 $ 386 $ (18 ) $ 3,330 Operating Costs, Expenses and Other Costs of sales — — 916 61 (6 ) 971 Depreciation, depletion and amortization 4 — 466 79 — 549 Other operating expenses 663 — 145 132 (12 ) 928 Total Operating Costs, Expenses and Other 667 — 1,527 272 (18 ) 2,448 Operating (loss) income (658 ) — 1,426 114 — 882 Other Income (Expense) Earnings from consolidated subsidiaries 963 1,004 99 14 (2,080 ) — Losses from equity investments — — (213 ) — — (213 ) Interest, net (173 ) (6 ) (281 ) (12 ) — (472 ) Amortization of excess cost of equity investments and other, net (1 ) — (6 ) 4 — (3 ) Income Before Income Taxes 131 998 1,025 120 (2,080 ) 194 Income Tax Expense (319 ) (2 ) (22 ) (34 ) — (377 ) Net (Loss) Income (188 ) 996 1,003 86 (2,080 ) (183 ) Net Income Attributable to Noncontrolling Interests — — — — (5 ) (5 ) Net (Loss) Income Attributable to Controlling Interests (188 ) 996 1,003 86 (2,085 ) (188 ) Preferred Stock Dividends (39 ) — — — — (39 ) Net (Loss) Income Available to Common Stockholders $ (227 ) $ 996 $ 1,003 $ 86 $ (2,085 ) $ (227 ) Net (Loss) Income $ (188 ) $ 996 $ 1,003 $ 86 $ (2,080 ) $ (183 ) Total other comprehensive loss (3 ) (47 ) (32 ) (31 ) 110 (3 ) Comprehensive (loss) income (191 ) 949 971 55 (1,970 ) (186 ) Comprehensive income attributable to noncontrolling interests — — — — (5 ) (5 ) Comprehensive (loss) income attributable to controlling interests $ (191 ) $ 949 $ 971 $ 55 $ (1,975 ) $ (191 ) Condensed Consolidating Statements of Income and Comprehensive Income for the Three Months Ended September 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 9 $ — $ 3,298 $ 412 $ (12 ) $ 3,707 Operating Costs, Expenses and Other Costs of sales — — 1,007 98 1 1,106 Depreciation, depletion and amortization 6 — 515 96 — 617 Other operating expenses 16 1 1,101 158 (13 ) 1,263 Total Operating Costs, Expenses and Other 22 1 2,623 352 (12 ) 2,986 Operating (loss) income (13 ) (1 ) 675 60 — 721 Other Income (Expense) Earnings from consolidated subsidiaries 498 484 40 10 (1,032 ) — Earnings from equity investments — — 114 — — 114 Interest, net (208 ) 23 (340 ) (15 ) — (540 ) Amortization of excess cost of equity investments and other, net — — (5 ) 1 — (4 ) Income Before Income Taxes 277 506 484 56 (1,032 ) 291 Income Tax Expense (91 ) (2 ) (14 ) (1 ) — (108 ) Net Income 186 504 470 55 (1,032 ) 183 Net Loss Attributable to Noncontrolling Interests — — — — 3 3 Net Income Attributable to Controlling Interests $ 186 $ 504 $ 470 $ 55 $ (1,029 ) $ 186 Net Income $ 186 $ 504 $ 470 $ 55 $ (1,032 ) $ 183 Total other comprehensive loss (37 ) (42 ) (7 ) (125 ) 174 (37 ) Comprehensive income (loss) 149 462 463 (70 ) (858 ) 146 Comprehensive loss attributable to noncontrolling interests — — — — 3 3 Comprehensive income (loss) attributable to controlling interests $ 149 $ 462 $ 463 $ (70 ) $ (855 ) $ 149 Condensed Consolidating Statements of Income and Comprehensive Income for the Nine Months Ended September 30, 2016 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 26 $ — $ 8,555 $ 1,127 $ (39 ) $ 9,669 Operating Costs, Expenses and Other Costs of sales — — 2,261 197 (4 ) 2,454 Depreciation, depletion and amortization 13 — 1,400 239 — 1,652 Other operating expenses 712 4 1,644 600 (35 ) 2,925 Total Operating Costs, Expenses and Other 725 4 5,305 1,036 (39 ) 7,031 Operating (loss) income (699 ) (4 ) 3,250 91 — 2,638 Other Income (Expense) Earnings from consolidated subsidiaries 2,373 2,335 174 45 (4,927 ) — Losses from equity investments — — (1 ) — — (1 ) Interest, net (519 ) 91 (918 ) (38 ) — (1,384 ) Amortization of excess cost of equity investments and other, net — — (17 ) 14 — (3 ) Income Before Income Taxes 1,155 2,422 2,488 112 (4,927 ) 1,250 Income Tax Expense (656 ) (5 ) (32 ) (51 ) — (744 ) Net Income 499 2,417 2,456 61 (4,927 ) 506 Net Income Attributable to Noncontrolling Interests — — — — (7 ) (7 ) Net Income Attributable to Controlling Interests 499 2,417 2,456 61 (4,934 ) 499 Preferred Stock Dividends (117 ) — — — — (117 ) Net Income Available to Common Stockholders $ 382 $ 2,417 $ 2,456 $ 61 $ (4,934 ) $ 382 Net Income $ 499 $ 2,417 $ 2,456 $ 61 $ (4,927 ) $ 506 Total other comprehensive (loss) income (96 ) (208 ) (261 ) 101 368 (96 ) Comprehensive income 403 2,209 2,195 162 (4,559 ) 410 Comprehensive income attributable to noncontrolling interests — — — — (7 ) (7 ) Comprehensive income attributable to controlling interests $ 403 $ 2,209 $ 2,195 $ 162 $ (4,566 ) $ 403 Condensed Consolidating Statements of Income and Comprehensive Income for the Nine Months Ended September 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 28 $ — $ 9,591 $ 1,184 $ (36 ) $ 10,767 Operating Costs, Expenses and Other Costs of sales — — 2,999 280 2 3,281 Depreciation, depletion and amortization 16 — 1,446 263 — 1,725 Other operating expenses 66 39 2,560 443 (38 ) 3,070 Total Operating Costs, Expenses and Other 82 39 7,005 986 (36 ) 8,076 Operating (loss) income (54 ) (39 ) 2,586 198 — 2,691 Other Income (Expense) Earnings from consolidated subsidiaries 1,980 2,033 188 41 (4,242 ) — Earnings from equity investments — — 304 — — 304 Interest, net (512 ) 30 (1,013 ) (29 ) — (1,524 ) Amortization of excess cost of equity investments and other, net — — (13 ) 7 — (6 ) Income Before Income Taxes 1,414 2,024 2,052 217 (4,242 ) 1,465 Income Tax Expense (466 ) (6 ) (39 ) (10 ) — (521 ) Net Income 948 2,018 2,013 207 (4,242 ) 944 Net Loss Attributable to Noncontrolling Interests — — — — 4 4 Net Income Attributable to Controlling Interests 948 2,018 2,013 207 (4,238 ) 948 Net Income $ 948 $ 2,018 $ 2,013 $ 207 $ (4,242 ) $ 944 Total other comprehensive loss (311 ) (419 ) (351 ) (266 ) 1,036 (311 ) Comprehensive income (loss) 637 1,599 1,662 (59 ) (3,206 ) 633 Comprehensive loss attributable to noncontrolling interests — — — — 4 4 Comprehensive income (loss) attributable to controlling interests $ 637 $ 1,599 $ 1,662 $ (59 ) $ (3,202 ) $ 637 Condensed Consolidating Balance Sheets as of December 31, 2015 (In Millions) Parent 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 9,410 688 (13,931 ) — All other current assets 126 119 2,161 195 (6 ) 2,595 Property, plant and equipment, net 252 — 33,032 7,263 — 40,547 Investments 16 2 5,906 116 — 6,040 Investments in subsidiaries 27,401 28,038 3,493 3,320 (62,252 ) — Goodwill 15,089 22 5,508 3,171 — 23,790 Notes receivable from affiliates 850 21,319 2,092 358 (24,619 ) — Deferred income taxes 7,501 — — — (2,178 ) 5,323 Other non-current assets 215 307 4,951 107 — 5,580 Total assets $ 53,806 $ 51,407 $ 66,565 $ 15,360 $ (103,034 ) $ 84,104 LIABILITIES AND STOCKHOLDERS’ EQUITY Liabilities Current portion of debt $ 67 $ 500 $ 132 $ 122 $ — $ 821 Other current liabilities - affiliates 1,328 8,682 3,210 711 (13,931 ) — All other current liabilities 321 458 1,992 527 (54 ) 3,244 Long-term debt 13,845 20,053 7,825 683 — 42,406 Notes payable to affiliates 2,404 448 20,462 1,305 (24,619 ) — Deferred income taxes — — 596 1,582 (2,178 ) — Other long-term liabilities and deferred credits 722 193 909 406 — 2,230 Total liabilities 18,687 30,334 35,126 5,336 (40,782 ) 48,701 Stockholders’ equity Total KMI equity 35,119 21,073 31,439 10,024 (62,536 ) 35,119 Noncontrolling interests — — — — 284 284 Total stockholders’ Equity 35,119 21,073 31,439 10,024 (62,252 ) 35,403 Total Liabilities and Stockholders’ Equity $ 53,806 $ 51,407 $ 66,565 $ 15,360 $ (103,034 ) $ 84,104 Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2016 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Net cash (used in) provided by operating activities $ (3,023 ) $ 3,903 $ 8,778 $ 681 $ (6,844 ) $ 3,495 Cash flows from investing activities Acquisitions of assets and investments, net of cash acquired (2 ) — (331 ) — — (333 ) Capital expenditures (39 ) — (1,550 ) (520 ) — (2,109 ) Proceeds from sale of equity interests in subsidiaries, net — — 1,402 — — 1,402 Sale of property, plant and equipment, investments and other net assets, net of removal costs — — 250 — — 250 Contributions to investments (343 ) — (36 ) (10 ) — (389 ) Distributions from equity investments in excess of cumulative earnings 1,773 298 127 — (2,040 ) 158 Funding to affiliates (2,354 ) (495 ) (3,650 ) (529 ) 7,028 — Other, net — (52 ) 37 (11 ) — (26 ) Net cash used in investing activities (965 ) (249 ) (3,751 ) (1,070 ) 4,988 (1,047 ) Cash flows from financing activities Issuances of debt 8,111 — 374 — — 8,485 Payments of debt (7,178 ) (500 ) (1,449 ) (8 ) — (9,135 ) Restricted cash held in escrow for debt repayment — — (776 ) — — (776 ) Debt issue costs (13 ) — (1 ) (1 ) — (15 ) Cash dividends - common shares (839 ) — — — — (839 ) Cash dividends - preferred shares (115 ) — — — — (115 ) Funding from affiliates 4,070 973 1,539 446 (7,028 ) — Contributions from parents — — 88 — (88 ) — Contributions from noncontrolling interests — — — — 88 88 Distributions to parents — (4,127 ) (4,801 ) (14 ) 8,942 — Distributions to noncontrolling interests — — — — (17 ) (17 ) Net cash provided by (used in) financing activities 4,036 (3,654 ) (5,026 ) 423 1,897 (2,324 ) Effect of exchange rate changes on cash and cash equivalents — — — 4 — 4 Net increase in cash and cash equivalents 48 — 1 38 41 128 Cash and cash equivalents, beginning of period 123 — 12 142 (48 ) 229 Cash and cash equivalents, end of period $ 171 $ — $ 13 $ 180 $ (7 ) $ 357 Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Net cash (used in) provided by operating activities $ (2,387 ) $ 5,917 $ 7,140 $ 134 $ (7,297 ) $ 3,507 Cash flows from investing activities Acquisitions of assets and investments, net of cash acquired (1,709 ) — (210 ) — — (1,919 ) Capital expenditures (9 ) — (2,745 ) (245 ) — (2,999 ) Sale of property, plant and equipment, investments and other net assets, net of removal costs — — 45 — — 45 Contributions to investments (5 ) — (62 ) (7 ) 5 (69 ) Distributions from equity investments in excess of cumulative earnings 1,060 — 113 — (992 ) 181 Investment in KMP (159 ) — — — 159 — Funding to affiliates (2,765 ) (7,699 ) (6,273 ) (518 ) 17,255 — Other, net — 16 5 18 — 39 Net cash used in investing activities (3,587 ) (7,683 ) (9,127 ) (752 ) 16,427 (4,722 ) Cash flows from financing activities Issuances of debt 12,281 — — — — 12,281 Payments of debt (11,544 ) (300 ) (42 ) (7 ) — (11,893 ) Debt issue costs (20 ) — — — — (20 ) Issuances of common shares 3,833 — — — — 3,833 Cash dividends - common shares (3,084 ) — — — — (3,084 ) Repurchases of warrants (12 ) — — — — (12 ) Funding from affiliates 4,528 5,602 6,514 611 (17,255 ) — Contributions from parents — 156 3 12 (171 ) — Contributions from noncontrolling interests — — — — 7 7 Distributions to parents — (3,706 ) (4,480 ) (128 ) 8,314 — Distributions to noncontrolling interests — — — — (25 ) (25 ) Other, net — (1 ) — — — (1 ) Net cash provided by financing activities 5,982 1,751 1,995 488 (9,130 ) 1,086 Effect of exchange rate changes on cash and cash equivalents — — — (7 ) — (7 ) Net increase (decrease) in cash and cash equivalents 8 (15 ) 8 (137 ) — (136 ) Cash and cash equivalents, beginning of period 4 15 17 279 — 315 Cash and cash equivalents, end of period $ 12 $ — $ 25 $ 142 $ — $ 179

General (Policies)

General (Policies)	9 Months Ended
	Sep. 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)	9 Months Ended
	Sep. 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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Class P shares $ (228 ) $ 182 $ 379 $ 938 Participating securities: Restricted stock awards(a) 1 4 3 10 Net (Loss) Income Available to Common Stockholders $ (227 ) $ 186 $ 382 $ 948 Three Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Basic Weighted Average Common Shares Outstanding 2,230 2,203 2,229 2,173 Effect of dilutive securities: Warrants — — — 8 Diluted Weighted Average Common Shares Outstanding 2,230 2,203 2,229 2,181 ________ (a) As of September 30, 2016 , there were approximately 9 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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Unvested restricted stock awards 9 8 8 7 Warrants to purchase our Class P shares(a) 293 296 293 290 Convertible trust preferred securities 8 8 8 8 Mandatory convertible preferred stock(b) 58 n/a 58 n/a

Acquisitions (Tables)

Acquisitions (Tables)	9 Months Ended
	Sep. 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 September 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)	9 Months Ended
	Sep. 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): September 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) 13,326 13,346 Credit facility due November 26, 2019 — — Commercial paper borrowings — — 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(c) — 332 CIG senior notes, 4.15% and 6.85%, due 2026 and 2037(d) 475 100 SNG notes, 4.40% through 8.00%, due 2017 through 2032(e) — 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 435 443 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 295 300 Total debt – KMI and Subsidiaries 39,752 41,553 Less: Current portion of debt(a)(e)(f) 2,944 821 Total long-term debt – KMI and Subsidiaries(g) $ 36,808 $ 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 September 30, 2016 exchange rate of 1.1235 U.S. dollars per Euro and the December 31, 2015 exchange rate of 1.0862 U.S. dollars per Euro. For the nine months ended September 30, 2016 , our debt balance increased by $47 million as a result of the change in the exchange rate of U.S. dollars per Euro. The increase in debt due to the changes in exchange rates is offset by a corresponding change in the value of cross-currency swaps reflected in “Deferred charges and other assets” and “ Other long-term liabilities and deferred credits” on our consolidated balance sheets. 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) On September 30, 2016, we repaid the $332 million principal amount of 7.125% senior notes due 2021, plus accrued interest. We recognized a $28.3 million gain from the early extinguishment of debt, included within “Interest, net” on the accompanying consolidated statements of income for the three and nine months ended September 30, 2016 consisting of an $11.8 million premium on the debt repaid and a $40.1 million gain from the write-off of unamortized purchase accounting associated with the extinguished debt. Copano continues to be a subsidiary guarantor under a cross guarantee agreement (see Note 11). (d) On August 16, 2016 , CIG completed a private offering of $375 million in principal amount of 4.15% senior notes due August 15, 2026. The net proceeds of $372 million received from the offering were used to reduce debt incurred as the result of the repayment of CIG’s senior notes that matured in 2015 and for general corporate purposes. (e) Due to the September 1, 2016 sale of a 50% interest in SNG, we no longer consolidate SNG’s accounts in our consolidated financial statements. As of the transaction date, SNG had $1,211 million of debt outstanding (including a current portion of $500 million ). (f) Amounts include outstanding credit facility borrowings, commercial paper borrowings and other debt maturing within 12 months (see “—Current Portion of Debt” below). (g) Excludes our “Debt fair value adjustments” which, as of September 30, 2016 and December 31, 2015 , increased our combined debt balances by $1,710 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]	The following are significant long-term debt issuances, repayments and other significant changes made during the nine months ended September 30, 2016 : Issuances $1.0 billion unsecured term loan facility due 2019 $375 million 4.15% notes due 2026 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 $332 million 7.125% notes due 2021 Other significant changes $1,211 million reduction due to the deconsolidation of SNG, including a current portion of $500 million (see Note 2) Subsequent Event On October 1, 2016, a portion of the proceeds from the sale of a 50% interest in SNG was used to repay the $749 million principal amount of Hiland’s 7.25% senior notes due 2020, plus accrued interest. As of September 30, 2016, funds for this early extinguishment were held in escrow as a restricted deposit and included in the accompanying consolidated balance sheet within “Restricted deposits.” As of September 30, 2016, we classified the $749 million of senior notes as “Current portion of debt” within the accompanying consolidated balance sheet.
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 September 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 $786 million 7.00% notes due June 2017 $749 million 7.25% notes originally due October 2020 (see “—Subsequent Event” below) As of December 31, 2015 $500 million 3.50% notes due March 2016

Stockholders' Equity (Tables)

Stockholders' Equity (Tables)	9 Months Ended
	Sep. 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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Per common share cash dividend declared for the period $ 0.125 $ 0.51 $ 0.375 $ 1.48 Per common share cash dividend paid in the period $ 0.125 $ 0.49 $ 0.375 $ 1.42

Risk Management (Tables)

Risk Management (Tables)	9 Months Ended
	Sep. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	As of September 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 (19.4 ) MMBbl Crude oil basis (2.2 ) MMBbl Natural gas fixed price (27.5 ) Bcf Natural gas basis (12.8 ) Bcf Derivatives not designated as hedging contracts Crude oil fixed price (0.1 ) MMBbl Natural gas fixed price (9.9 ) Bcf Natural gas basis (3.3 ) Bcf NGL and other fixed price (2.6 ) 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 September 30, December 31, September 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) $ 153 $ 359 $ (22 ) $ (13 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 111 244 (19 ) — Subtotal 264 603 (41 ) (13 ) Interest rate swap agreements Fair value of derivative contracts/(Other current liabilities) 124 111 — — Deferred charges and other assets/(Other long-term liabilities and deferred credits) 614 273 — (9 ) Subtotal 738 384 — (9 ) Cross-currency swap agreements Fair value of derivative contracts/(Other current liabilities) — — (14 ) (6 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 41 — — (46 ) Subtotal 41 — (14 ) (52 ) Total 1,043 987 (55 ) (74 ) Derivatives not designated as hedging contracts Natural gas, crude, NGL and other derivative contracts Fair value of derivative contracts/(Other current liabilities) 4 35 (8 ) (1 ) Subtotal 4 35 (8 ) (1 ) Interest rate swap agreements Fair value of derivative contracts/(Other current liabilities) — 1 — (11 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) — — — (5 ) Subtotal — 1 — (16 ) Power derivative contracts Fair value of derivative contracts/(Other current liabilities) — 1 — (17 ) Subtotal — 1 — (17 ) Total 4 37 (8 ) (34 ) Total derivatives $ 1,047 $ 1,024 $ (63 ) $ (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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Interest rate swap agreements Interest, net $ (84 ) $ 251 $ 315 $ 163 Hedged fixed rate debt Interest, net $ 81 $ (283 ) $ (323 ) $ (166 ) 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 September 30, Three Months Ended September 30, Three Months Ended September 30, 2016 2015 2016 2015 2016 2015 Energy commodity derivative contracts $ 20 $ 119 Revenues—Natural gas sales $ (3 ) $ 4 Revenues—Natural gas sales $ — $ — Revenues—Product sales and other 34 60 Revenues—Product sales and other (2 ) (6 ) Costs of sales (1 ) (2 ) Costs of sales — — Interest rate swap agreements(c) — (4 ) Interest, net (1 ) (1 ) Interest, net — — Cross-currency swap 30 (11 ) Other, net 10 2 Other, net — — Total $ 50 $ 104 Total $ 39 $ 63 Total $ (2 ) $ (6 ) 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) Nine Months Ended September 30, Nine Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 2016 2015 Energy commodity derivative contracts $ (64 ) $ 72 Revenues—Natural gas sales $ 20 $ 29 Revenues—Natural gas sales $ — $ — Revenues—Product sales and other 124 161 Revenues—Product sales and other (7 ) 4 Costs of sales (13 ) (21 ) Costs of sales — — Interest rate swap agreements(c) (5 ) (6 ) Interest, net (2 ) (2 ) Interest, net — — Cross-currency swap 50 (22 ) Other, net 29 25 Other, net — — Total $ (19 ) $ 44 Total $ 158 $ 192 Total $ (7 ) $ 4 _____ (a) We expect to reclassify an approximate $49 million gain associated with cash flow hedge price risk management activities included in our accumulated other comprehensive loss balances as of September 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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Energy commodity derivative contracts Revenues—Natural gas sales $ 1 $ 6 $ (4 ) $ 9 Revenues—Product sales and other 7 169 (7 ) 173 Costs of sales 1 — (1 ) — Interest rate swap agreements Interest, net (14 ) — 63 — Total(a) $ (5 ) $ 175 $ 51 $ 182 _______ (a) Three and nine months ended September 30, 2016 includes an approximate gain of $20 million and $59 million , respectively, associated with natural gas, crude and NGL derivative contract settlements. Three and nine months ended September 30, 2015 includes an approximate gain of $19 million and $21 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 (19 ) 65 16 62 Gains reclassified from accumulated other comprehensive loss (158 ) — — (158 ) Net current-period other comprehensive (loss) income (177 ) 65 16 (96 ) Balance as of September 30, 2016 $ 42 $ (257 ) $ (342 ) $ (557 ) 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 gain (loss) before reclassifications 44 (170 ) 7 (119 ) Gains reclassified from accumulated other comprehensive loss (192 ) — — (192 ) Net current-period other comprehensive (loss) income (148 ) (170 ) 7 (311 ) Balance as of September 30, 2015 $ 179 $ (278 ) $ (229 ) $ (328 )

Fair Value (Tables)

Fair Value (Tables)	9 Months Ended
	Sep. 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 September 30, 2016 Energy commodity derivative contracts(a) $ 4 $ 264 $ — $ 268 $ (25 ) $ — $ 243 Interest rate swap agreements $ — $ 738 $ — $ 738 $ — $ — $ 738 Cross-currency swap agreements $ — $ 41 $ — $ 41 $ (14 ) $ — $ 27 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 September 30, 2016 Energy commodity derivative contracts(a) $ (10 ) $ (39 ) $ — $ (49 ) $ 25 $ 16 $ (8 ) Interest rate swap agreements $ — $ — $ — $ — $ — $ — $ — Cross-currency swap agreements $ — $ (14 ) $ — $ (14 ) $ 14 $ — $ — 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 “Restricted deposits” 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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Derivatives-net asset (liability) Beginning of Period $ — $ (37 ) $ (15 ) $ (61 ) Total gains or (losses) included in earnings — (1 ) (9 ) (1 ) Settlements — 15 24 39 End of Period $ — $ (23 ) $ — $ (23 ) 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 $ — $ — $ — $ 2
Schedule of Debt [Table Text Block]	The carrying value and estimated fair value of our outstanding debt balances are disclosed below (in millions): September 30, 2016 December 31, 2015 Carrying value Estimated fair value Carrying value Estimated fair value Total debt $ 41,462 $ 42,106 $ 43,227 $ 37,481 We used Level 2 input values to measure the estimated fair value of our outstanding debt balances as of both September 30, 2016 and December 31, 2015 .

Reportable Segments (Tables)

Reportable Segments (Tables)	9 Months Ended
	Sep. 30, 2016
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	Financial information by segment follows (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Revenues Natural Gas Pipelines Revenues from external customers $ 2,048 $ 2,176 $ 5,900 $ 6,444 Intersegment revenues 2 8 4 16 CO 2 310 517 916 1,316 Terminals Revenues from external customers 484 469 1,436 1,395 Intersegment revenues — — 1 1 Products Pipelines Revenues from external customers 415 467 1,204 1,388 Intersegment revenues 4 — 12 1 Kinder Morgan Canada 66 68 188 193 Other (1 ) — — 3 Total segment revenues 3,328 3,705 9,661 10,757 Other revenues 8 10 25 28 Less: Total intersegment revenues (6 ) (8 ) (17 ) (18 ) Total consolidated revenues $ 3,330 $ 3,707 $ 9,669 $ 10,767 Three Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Segment EBDA(a) Natural Gas Pipelines $ 540 $ 993 $ 2,498 $ 2,936 CO 2 217 29 606 605 Terminals 286 249 831 798 Products Pipelines 293 288 765 811 Kinder Morgan Canada 43 42 123 120 Other 2 (9 ) (11 ) (55 ) Total Segment EBDA 1,381 1,592 4,812 5,215 DD&A (549 ) (617 ) (1,652 ) (1,725 ) Amortization of excess cost of equity investments (15 ) (13 ) (45 ) (39 ) Other revenues 8 10 25 28 General and administrative expense (171 ) (160 ) (550 ) (540 ) Interest expense, net of unallocable interest income (474 ) (539 ) (1,386 ) (1,525 ) Unallocable income tax expense (363 ) (90 ) (698 ) (470 ) Total consolidated net (loss) income $ (183 ) $ 183 $ 506 $ 944 September 30, 2016 December 31, 2015 Assets Natural Gas Pipelines $ 50,428 $ 53,704 CO 2 4,211 4,706 Terminals 9,838 9,083 Products Pipelines 8,348 8,464 Kinder Morgan Canada 1,568 1,434 Other 309 418 Total segment assets 74,702 77,809 Corporate assets(b) 6,902 6,276 Assets held for sale — 19 Total consolidated assets $ 81,604 $ 84,104 _______ (a) We evaluate performance based on each segment’s EBDA. Segment EBDA includes revenues, earnings from equity investments, losses on impairments and divestitures of equity investments, net, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other expense (income), net, and losses on impairments and divestitures, 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)	9 Months Ended
	Sep. 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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Income tax expense $ 377 $ 108 $ 744 $ 521 Effective tax rate 194.3 % 37.1 % 59.5 % 35.6 %

Guarantee of Securities of Su29

Guarantee of Securities of Subsidiaries (Tables)	9 Months Ended
	Sep. 30, 2016	Sep. 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 September 30, 2016 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 9 $ — $ 2,953 $ 386 $ (18 ) $ 3,330 Operating Costs, Expenses and Other Costs of sales — — 916 61 (6 ) 971 Depreciation, depletion and amortization 4 — 466 79 — 549 Other operating expenses 663 — 145 132 (12 ) 928 Total Operating Costs, Expenses and Other 667 — 1,527 272 (18 ) 2,448 Operating (loss) income (658 ) — 1,426 114 — 882 Other Income (Expense) Earnings from consolidated subsidiaries 963 1,004 99 14 (2,080 ) — Losses from equity investments — — (213 ) — — (213 ) Interest, net (173 ) (6 ) (281 ) (12 ) — (472 ) Amortization of excess cost of equity investments and other, net (1 ) — (6 ) 4 — (3 ) Income Before Income Taxes 131 998 1,025 120 (2,080 ) 194 Income Tax Expense (319 ) (2 ) (22 ) (34 ) — (377 ) Net (Loss) Income (188 ) 996 1,003 86 (2,080 ) (183 ) Net Income Attributable to Noncontrolling Interests — — — — (5 ) (5 ) Net (Loss) Income Attributable to Controlling Interests (188 ) 996 1,003 86 (2,085 ) (188 ) Preferred Stock Dividends (39 ) — — — — (39 ) Net (Loss) Income Available to Common Stockholders $ (227 ) $ 996 $ 1,003 $ 86 $ (2,085 ) $ (227 ) Net (Loss) Income $ (188 ) $ 996 $ 1,003 $ 86 $ (2,080 ) $ (183 ) Total other comprehensive loss (3 ) (47 ) (32 ) (31 ) 110 (3 ) Comprehensive (loss) income (191 ) 949 971 55 (1,970 ) (186 ) Comprehensive income attributable to noncontrolling interests — — — — (5 ) (5 ) Comprehensive (loss) income attributable to controlling interests $ (191 ) $ 949 $ 971 $ 55 $ (1,975 ) $ (191 )
Condensed Balance Sheet [Table Text Block]	Condensed Consolidating Balance Sheets as of September 30, 2016 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI ASSETS Cash and cash equivalents $ 171 $ — $ 13 $ 180 $ (7 ) $ 357 Other current assets - affiliates 4,577 1,153 12,268 612 (18,610 ) — All other current assets 150 165 2,508 187 (4 ) 3,006 Property, plant and equipment, net 264 — 30,818 7,698 — 38,780 Investments 665 2 6,567 124 — 7,358 Investments in subsidiaries 27,063 29,831 4,110 4,036 (65,040 ) — Goodwill 13,789 22 5,171 3,181 — 22,163 Notes receivable from affiliates 619 21,729 1,237 375 (23,960 ) — Deferred income taxes 6,865 — — — (2,270 ) 4,595 Other non-current assets 272 459 4,514 100 — 5,345 Total assets $ 54,435 $ 53,361 $ 67,206 $ 16,493 $ (109,891 ) $ 81,604 LIABILITIES AND STOCKHOLDERS’ EQUITY Liabilities Current portion of debt $ 786 $ 600 $ 1,435 $ 123 $ — $ 2,944 Other current liabilities - affiliates 2,303 12,885 2,893 529 (18,610 ) — All other current liabilities 415 283 1,965 448 (11 ) 3,100 Long-term debt 14,081 19,600 4,161 676 — 38,518 Notes payable to affiliates 1,601 448 20,636 1,275 (23,960 ) — Deferred income taxes — — 633 1,637 (2,270 ) — All other long-term liabilities and deferred credits 643 72 890 469 — 2,074 Total liabilities 19,829 33,888 32,613 5,157 (44,851 ) 46,636 Stockholders’ equity Total KMI equity 34,606 19,473 34,593 11,336 (65,402 ) 34,606 Noncontrolling interests — — — — 362 362 Total stockholders’ Equity 34,606 19,473 34,593 11,336 (65,040 ) 34,968 Total Liabilities and Stockholders’ Equity $ 54,435 $ 53,361 $ 67,206 $ 16,493 $ (109,891 ) $ 81,604	Condensed Consolidating Balance Sheets as of September 30, 2016 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI ASSETS Cash and cash equivalents $ 171 $ — $ 13 $ 180 $ (7 ) $ 357 Other current assets - affiliates 4,577 1,153 12,268 612 (18,610 ) — All other current assets 150 165 2,508 187 (4 ) 3,006 Property, plant and equipment, net 264 — 30,818 7,698 — 38,780 Investments 665 2 6,567 124 — 7,358 Investments in subsidiaries 27,063 29,831 4,110 4,036 (65,040 ) — Goodwill 13,789 22 5,171 3,181 — 22,163 Notes receivable from affiliates 619 21,729 1,237 375 (23,960 ) — Deferred income taxes 6,865 — — — (2,270 ) 4,595 Other non-current assets 272 459 4,514 100 — 5,345 Total assets $ 54,435 $ 53,361 $ 67,206 $ 16,493 $ (109,891 ) $ 81,604 LIABILITIES AND STOCKHOLDERS’ EQUITY Liabilities Current portion of debt $ 786 $ 600 $ 1,435 $ 123 $ — $ 2,944 Other current liabilities - affiliates 2,303 12,885 2,893 529 (18,610 ) — All other current liabilities 415 283 1,965 448 (11 ) 3,100 Long-term debt 14,081 19,600 4,161 676 — 38,518 Notes payable to affiliates 1,601 448 20,636 1,275 (23,960 ) — Deferred income taxes — — 633 1,637 (2,270 ) — All other long-term liabilities and deferred credits 643 72 890 469 — 2,074 Total liabilities 19,829 33,888 32,613 5,157 (44,851 ) 46,636 Stockholders’ equity Total KMI equity 34,606 19,473 34,593 11,336 (65,402 ) 34,606 Noncontrolling interests — — — — 362 362 Total stockholders’ Equity 34,606 19,473 34,593 11,336 (65,040 ) 34,968 Total Liabilities and Stockholders’ Equity $ 54,435 $ 53,361 $ 67,206 $ 16,493 $ (109,891 ) $ 81,604 Condensed Consolidating Balance Sheets as of December 31, 2015 (In Millions) Parent 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 9,410 688 (13,931 ) — All other current assets 126 119 2,161 195 (6 ) 2,595 Property, plant and equipment, net 252 — 33,032 7,263 — 40,547 Investments 16 2 5,906 116 — 6,040 Investments in subsidiaries 27,401 28,038 3,493 3,320 (62,252 ) — Goodwill 15,089 22 5,508 3,171 — 23,790 Notes receivable from affiliates 850 21,319 2,092 358 (24,619 ) — Deferred income taxes 7,501 — — — (2,178 ) 5,323 Other non-current assets 215 307 4,951 107 — 5,580 Total assets $ 53,806 $ 51,407 $ 66,565 $ 15,360 $ (103,034 ) $ 84,104 LIABILITIES AND STOCKHOLDERS’ EQUITY Liabilities Current portion of debt $ 67 $ 500 $ 132 $ 122 $ — $ 821 Other current liabilities - affiliates 1,328 8,682 3,210 711 (13,931 ) — All other current liabilities 321 458 1,992 527 (54 ) 3,244 Long-term debt 13,845 20,053 7,825 683 — 42,406 Notes payable to affiliates 2,404 448 20,462 1,305 (24,619 ) — Deferred income taxes — — 596 1,582 (2,178 ) — Other long-term liabilities and deferred credits 722 193 909 406 — 2,230 Total liabilities 18,687 30,334 35,126 5,336 (40,782 ) 48,701 Stockholders’ equity Total KMI equity 35,119 21,073 31,439 10,024 (62,536 ) 35,119 Noncontrolling interests — — — — 284 284 Total stockholders’ Equity 35,119 21,073 31,439 10,024 (62,252 ) 35,403 Total Liabilities and Stockholders’ Equity $ 53,806 $ 51,407 $ 66,565 $ 15,360 $ (103,034 ) $ 84,104
Condensed Cash Flow Statement [Table Text Block]	Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2016 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Net cash (used in) provided by operating activities $ (3,023 ) $ 3,903 $ 8,778 $ 681 $ (6,844 ) $ 3,495 Cash flows from investing activities Acquisitions of assets and investments, net of cash acquired (2 ) — (331 ) — — (333 ) Capital expenditures (39 ) — (1,550 ) (520 ) — (2,109 ) Proceeds from sale of equity interests in subsidiaries, net — — 1,402 — — 1,402 Sale of property, plant and equipment, investments and other net assets, net of removal costs — — 250 — — 250 Contributions to investments (343 ) — (36 ) (10 ) — (389 ) Distributions from equity investments in excess of cumulative earnings 1,773 298 127 — (2,040 ) 158 Funding to affiliates (2,354 ) (495 ) (3,650 ) (529 ) 7,028 — Other, net — (52 ) 37 (11 ) — (26 ) Net cash used in investing activities (965 ) (249 ) (3,751 ) (1,070 ) 4,988 (1,047 ) Cash flows from financing activities Issuances of debt 8,111 — 374 — — 8,485 Payments of debt (7,178 ) (500 ) (1,449 ) (8 ) — (9,135 ) Restricted cash held in escrow for debt repayment — — (776 ) — — (776 ) Debt issue costs (13 ) — (1 ) (1 ) — (15 ) Cash dividends - common shares (839 ) — — — — (839 ) Cash dividends - preferred shares (115 ) — — — — (115 ) Funding from affiliates 4,070 973 1,539 446 (7,028 ) — Contributions from parents — — 88 — (88 ) — Contributions from noncontrolling interests — — — — 88 88 Distributions to parents — (4,127 ) (4,801 ) (14 ) 8,942 — Distributions to noncontrolling interests — — — — (17 ) (17 ) Net cash provided by (used in) financing activities 4,036 (3,654 ) (5,026 ) 423 1,897 (2,324 ) Effect of exchange rate changes on cash and cash equivalents — — — 4 — 4 Net increase in cash and cash equivalents 48 — 1 38 41 128 Cash and cash equivalents, beginning of period 123 — 12 142 (48 ) 229 Cash and cash equivalents, end of period $ 171 $ — $ 13 $ 180 $ (7 ) $ 357	Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Net cash (used in) provided by operating activities $ (2,387 ) $ 5,917 $ 7,140 $ 134 $ (7,297 ) $ 3,507 Cash flows from investing activities Acquisitions of assets and investments, net of cash acquired (1,709 ) — (210 ) — — (1,919 ) Capital expenditures (9 ) — (2,745 ) (245 ) — (2,999 ) Sale of property, plant and equipment, investments and other net assets, net of removal costs — — 45 — — 45 Contributions to investments (5 ) — (62 ) (7 ) 5 (69 ) Distributions from equity investments in excess of cumulative earnings 1,060 — 113 — (992 ) 181 Investment in KMP (159 ) — — — 159 — Funding to affiliates (2,765 ) (7,699 ) (6,273 ) (518 ) 17,255 — Other, net — 16 5 18 — 39 Net cash used in investing activities (3,587 ) (7,683 ) (9,127 ) (752 ) 16,427 (4,722 ) Cash flows from financing activities Issuances of debt 12,281 — — — — 12,281 Payments of debt (11,544 ) (300 ) (42 ) (7 ) — (11,893 ) Debt issue costs (20 ) — — — — (20 ) Issuances of common shares 3,833 — — — — 3,833 Cash dividends - common shares (3,084 ) — — — — (3,084 ) Repurchases of warrants (12 ) — — — — (12 ) Funding from affiliates 4,528 5,602 6,514 611 (17,255 ) — Contributions from parents — 156 3 12 (171 ) — Contributions from noncontrolling interests — — — — 7 7 Distributions to parents — (3,706 ) (4,480 ) (128 ) 8,314 — Distributions to noncontrolling interests — — — — (25 ) (25 ) Other, net — (1 ) — — — (1 ) Net cash provided by financing activities 5,982 1,751 1,995 488 (9,130 ) 1,086 Effect of exchange rate changes on cash and cash equivalents — — — (7 ) — (7 ) Net increase (decrease) in cash and cash equivalents 8 (15 ) 8 (137 ) — (136 ) Cash and cash equivalents, beginning of period 4 15 17 279 — 315 Cash and cash equivalents, end of period $ 12 $ — $ 25 $ 142 $ — $ 179

General Organization (Details)

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

General Basis of Presentation (

General Basis of Presentation (Details) - USD ($) $ in Millions	Sep. 01, 2016	Sep. 30, 2016	Dec. 31, 2015	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Segment Reporting Information [Line Items]
Gain (Loss) on Sale of Assets and Asset Impairment Charges		$ (76)			$ (307)
Loss on impairments and divestitures, net		76		$ 385	307	$ 489
Loss on impairments and divestitures of equity investments, net		350		0	344	26
Natural Gas Pipelines
Segment Reporting Information [Line Items]
Loss on impairments and divestitures, net					106	99
CO2
Segment Reporting Information [Line Items]
Loss on impairments and divestitures, net				388	21	397
Terminals
Segment Reporting Information [Line Items]
Loss on impairments and divestitures, net					20
Products Pipelines
Segment Reporting Information [Line Items]
Loss on impairments and divestitures, net					64
Products Pipelines | Discontinued Operations, Held-for-sale [Member]
Segment Reporting Information [Line Items]
Increase (Decrease) in Assets Held-for-sale		(1)			(9)
Other Assets
Segment Reporting Information [Line Items]
Gain on Disposition of Assets				$ 3		7
Other Assets
Segment Reporting Information [Line Items]
Gain (Loss) on Sale of Assets and Asset Impairment Charges		9			(3)
Natural Gas Pipelines
Segment Reporting Information [Line Items]
Goodwill, Impairment Loss			$ 1,150
Copano Energy, L.L.C. [Member] | Natural Gas [Member]
Segment Reporting Information [Line Items]
Loss on impairments and divestitures of equity investments, net						$ 26
Southern Natural Gas Company LLC [Member] | Sale Equity Interest in SNG [Member]
Segment Reporting Information [Line Items]
Gain (Loss) on Sale of Assets and Asset Impairment Charges		$ (84)			(84)
Disposal Group, Equity Interest Sold	50.00%
Midcontinent Express Pipeline LLC [Member] | Natural Gas Pipelines
Segment Reporting Information [Line Items]
Loss on impairments and divestitures of equity investments, net					$ 350

General Earnings Per Share (Det

General Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net (Loss) Income Available to Common Stockholders	$ (227)	$ 186	$ 382	$ 948
Basic Weighted Average Common Shares Outstanding	2,230	2,203	2,229	2,173
Incremental Common Shares Attributable to Dilutive Effect of Call Options and Warrants	0	0	0	8
Diluted Weighted Average Common Shares Outstanding	2,230	2,203	2,229	2,181
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	9	8	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	296	293	290
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	8
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 shares
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net (Loss) Income Available to Common Stockholders	$ (228)	$ 182	$ 379	$ 938
Basic Weighted Average Common Shares Outstanding	2,230	2,203	2,229	2,173
Restricted stock awards(a)
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net (Loss) Income Available to Common Stockholders	$ 1	$ 4	$ 3	$ 10
Unvested Restricted Stock Awards, Issued and Non Issued	9		9

Acquisitions Acquisition of Ter

Acquisitions Acquisition of Terminal Assets from and Joint Venture With BP (Details) $ in Millions	Feb. 01, 2016USD ($)Terminals	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)
Business Acquisition [Line Items]
Contributions from noncontrolling interests | $		$ 88	$ 7
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	Sep. 30, 2016	Dec. 31, 2015
Business Acquisition [Line Items]
Goodwill		$ 22,163	$ 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 Sale of Equity Int

Acquisitions Sale of Equity Interest in SNG (Details) - USD ($) $ in Millions	Sep. 01, 2016	Sep. 30, 2016	Sep. 30, 2016	Sep. 30, 2015
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from Divestiture of Interest in Consolidated Subsidiaries			$ 1,402	$ 0
Sale Equity Interest in SNG [Member] | Sale of 50% of Southern Natural Gas Company LLC [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 Divestiture of Interest in Consolidated Subsidiaries	$ 1,400
Disposal Group, Equity Method Investment Retained after Disposal, Ownership Interest after Disposal	50.00%
Disposal Group, Not Discontinued Operation, Pre-tax Loss on Disposal		$ 84	$ 84
Sale of 50% of Southern Natural Gas Company LLC [Member] | Bear Creek Storage Company L.L.C. [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Equity Method Investment, Ownership Percentage	50.00%

Acquisitions Phantom (Details)

Acquisitions Phantom (Details) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2016USD ($)	Sep. 30, 2016USD ($)	Feb. 01, 2016Terminals
BP Terminal Assets
Business Acquisition [Line Items]
Number of terminals wholly owned | Terminals			1
Sale Equity Interest in SNG [Member] | Southern Natural Gas Company LLC [Member]
Business Acquisition [Line Items]
Disposal Group, Not Discontinued Operation, Pre-tax Loss on Disposal | $	$ 84	$ 84

Debt (Details)

Debt (Details) $ in Millions	Sep. 30, 2016USD ($)	Sep. 01, 2016USD ($)	Aug. 16, 2016USD ($)	Jan. 26, 2016USD ($)	Feb. 29, 2016USD ($)	Jan. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock	$ 100						$ 100		$ 100
Less: Current portion of debt(a)(e)(f)	2,944						2,944		821
Total long-term debt	38,518						38,518		42,406
Repayments of Debt							9,135	$ 11,893
Long-term Debt, Current Maturities									1,000
Debt Instrument, Fair Value Disclosure	1,710						1,710		1,674
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			1,000		0
Debt Instrument, Term				3 years
Proceeds from Issuance of Long-term Debt							1,000
Kinder Morgan, Inc. [Member] | Senior notes, 1.50% through 8.25%, due 2016 through 2098(b)
Debt Instrument [Line Items]
Senior Notes	13,326						13,326		13,346
Kinder Morgan, Inc. [Member] | Senior unsecured revolving credit facility [Member]
Debt Instrument [Line Items]
Credit facility due November 26, 2019	0						0		0
Kinder Morgan, Inc. [Member] | Commercial Paper [Member]
Debt Instrument [Line Items]
Commercial paper borrowings	0						0		0
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						19,485		19,985
TGP [Member] | TGP senior notes, 7.00% through 8.375%, due 2016 through 2037
Debt Instrument [Line Items]
Senior Notes	$ 1,540						$ 1,540		1,790
TGP [Member] | $250 million 8.00% notes due 2016
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	8.00%						8.00%
Repayments of Debt					$ 250		$ 250
EPNG [Member] | EPNG senior notes, 5.95% through 8.625%, due 2017 through 2032
Debt Instrument [Line Items]
Senior Notes	$ 1,115						1,115		1,115
Copano Energy, L.L.C. [Member] | Copano senior notes, 7.125%, due April 1, 2021
Debt Instrument [Line Items]
Senior Notes	$ 0						$ 0		332
Debt Instrument, Interest Rate, Stated Percentage	7.125%						7.125%
Repayments of Debt	$ 332
Gain (Loss) on Extinguishment of Debt	28.3
Colorado Interstate Gas Company, L.L.C. [Member] | KMP Senior Notes 4.15% and 6.85%, due August 16, 2026 and June 15, 2037 [Member]
Debt Instrument [Line Items]
Senior Notes	$ 475						$ 475		100
Colorado Interstate Gas Company, L.L.C. [Member] | KMP Senior Notes, 4.15% due August 15,2026 [Member]
Debt Instrument [Line Items]
Senior Notes			$ 375
Debt Instrument, Interest Rate, Stated Percentage	4.15%						4.15%
Proceeds from Issuance of Long-term Debt			$ 372				$ 375
SNG [Member] | SNG notes, 4.40% through 8.00%, due 2017 through 2032
Debt Instrument [Line Items]
Notes Payable	$ 0						0		1,211
Decrease in Debt due to Deconsolidation of SNG		$ 1,211
SNG [Member] | KMP Senior Notes, 5.90%, due April 1, 2017 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.90%
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						$ 786		1,636
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%						5.70%
Repayments of Debt						$ 850	$ 850
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		974
EPC Building LLC [Member] | EPC Building, LLC, promissory note, 3.967%, due 2016 through 2035
Debt Instrument [Line Items]
Notes Payable	$ 435						$ 435		443
Debt Instrument, Interest Rate, Stated Percentage	3.967%						3.967%
Capital Trust I [Member] | Preferred securities, 4.75%, due March 31, 2028
Debt Instrument [Line Items]
Senior Notes	$ 221						$ 221		221
Debt Instrument, Interest Rate, Stated Percentage	4.75%						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		100
KMI AND KMP [Member] | Other miscellaneous debt
Debt Instrument [Line Items]
Notes Payable	295						295		300
Kinder Morgan, Inc and Subsidiaries [Member]
Debt Instrument [Line Items]
Total debt – KMI and Subsidiaries	39,752						39,752		41,553
Total long-term debt	$ 36,808						$ 36,808		$ 40,732
Euro Member Countries, Euro | Senior Notes [Member]
Debt Instrument [Line Items]
Foreign Currency Exchange Rate, Translation	1.1235						1.1235		1.0862
Translation Adjustment Functional to Reporting Currency, Increase (Decrease), Gross of Tax							$ 47
Short-term Debt [Member] | SNG [Member] | KMP Senior Notes, 5.90%, due April 1, 2017 [Member]
Debt Instrument [Line Items]
Decrease in Debt due to Deconsolidation of SNG		$ 500
Southern Natural Gas Company LLC [Member] | Sale Equity Interest in SNG [Member]
Debt Instrument [Line Items]
Disposal Group, Equity Interest Sold		50.00%
Repayments of debt [Member] | Copano Energy, L.L.C. [Member] | Copano senior notes, 7.125%, due April 1, 2021
Debt Instrument [Line Items]
Gains (Losses) on Recourse Debt	$ 11.8
Purchase Accounting [Member] | Copano Energy, L.L.C. [Member] | Copano senior notes, 7.125%, due April 1, 2021
Debt Instrument [Line Items]
Gain (Loss) on Extinguishment of Debt	$ 40.1

Debt Credit Facilities (Details

Debt Credit Facilities (Details) - Kinder Morgan, Inc. [Member] - USD ($) $ in Millions	Sep. 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	4,832
Letters of Credit Outstanding, Amount	$ 168

Debt Current Portion of Debt (D

Debt Current Portion of Debt (Details) - USD ($) $ in Millions	Oct. 01, 2016	Sep. 30, 2016	Dec. 31, 2015
Kinder Morgan, Inc. [Member] | KMI Senior Notes, 7.0%, due June 15, 2017 [Member]
Short-term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.00%
Senior Notes, Current		$ 786
Kinder Morgan Energy Partners, L.P. [Member] | $600 million 6.00% notes due February 2017
Short-term Debt [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
Short-term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		3.50%	3.50%
Senior Notes, Current			$ 500
TGP [Member] | KMP Senior notes, 7.50%, due April 1, 2017 [Member]
Short-term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.50%
Senior Notes, Current		$ 300
EPNG [Member] | KMP Senior Notes, 5.95%, due April 15, 2017 [Member]
Short-term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.95%
Senior Notes, Current		$ 355
Hiland Partners Holdings LLC [Member] | KMI Senior Notes 7.25%, due 2020 [Member]
Short-term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.25%
Senior Notes, Current		$ 749
Subsequent Event [Member] | Hiland Partners Holdings LLC [Member] | KMI Senior Notes 7.25%, due 2020 [Member]
Short-term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	7.25%

Long-term Debt Issuances, Repay

Long-term Debt Issuances, Repayments and Other Significant Changes in Debt (Details) - USD ($) $ in Millions	Oct. 01, 2016	Sep. 30, 2016	Sep. 01, 2016	Aug. 16, 2016	Feb. 29, 2016	Jan. 31, 2016	Sep. 30, 2016	Sep. 30, 2015	Jan. 26, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Repayments of Debt							$ 9,135	$ 11,893
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
Senior Notes		$ 1,000					1,000		$ 1,000	$ 0
Kinder Morgan, Inc. [Member] | KMI 8.25% Senior Notes due February 15, 2016 [Member]
Debt Instrument [Line Items]
Repayments of Debt							$ 67
Debt Instrument, Interest Rate, Stated Percentage		8.25%					8.25%
Colorado Interstate Gas Company, L.L.C. [Member] | KMP Senior Notes, 4.15% due August 15,2026 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt				$ 372			$ 375
Debt Instrument, Interest Rate, Stated Percentage		4.15%					4.15%
Senior Notes				$ 375
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%					5.70%
Kinder Morgan Energy Partners, L.P. [Member] | $500 million 3.50% notes due 2016
Debt Instrument [Line Items]
Repayments of Debt							$ 500
Debt Instrument, Interest Rate, Stated Percentage		3.50%					3.50%			3.50%
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%					8.00%
Copano Energy, L.L.C. [Member] | Copano senior notes, 7.125%, due April 1, 2021
Debt Instrument [Line Items]
Repayments of Debt		$ 332
Debt Instrument, Interest Rate, Stated Percentage		7.125%					7.125%
Senior Notes		$ 0					$ 0			$ 332
Hiland Partners Holdings LLC [Member] | KMI Senior Notes 7.25%, due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.25%					7.25%
SNG [Member] | SNG notes, 4.40% through 8.00%, due 2017 through 2032
Debt Instrument [Line Items]
Decrease in Debt due to Deconsolidation of SNG			$ 1,211
SNG [Member] | KMP Senior Notes, 5.90%, due April 1, 2017 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			5.90%
Subsequent Event [Member] | Hiland Partners Holdings LLC [Member] | KMI Senior Notes 7.25%, due 2020 [Member]
Debt Instrument [Line Items]
Repayments of Debt	$ 749
Debt Instrument, Interest Rate, Stated Percentage	7.25%
Senior Notes	$ 749
Short-term Debt [Member] | SNG [Member] | KMP Senior Notes, 5.90%, due April 1, 2017 [Member]
Debt Instrument [Line Items]
Decrease in Debt due to Deconsolidation of SNG			$ 500

Debt Phantom (Details)

Debt Phantom (Details)	Sep. 30, 2016$ / shares
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%
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] | Colorado Interstate Gas Company, L.L.C. [Member] | CIG senior notes, 4.15% and 6.85%, due 2026 and 2037(d)
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.15%
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 Holdings 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] | Colorado Interstate Gas Company, L.L.C. [Member] | CIG senior notes, 4.15% and 6.85%, due 2026 and 2037(d)
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.85%
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 Holdings 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	Oct. 19, 2016	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Class of Stock [Line Items]
Dividends Per Common Share Declared for the Period		$ 0.125	$ 0.51	$ 0.375	$ 1.48
Per common share cash dividend paid in the period		$ 0.125	$ 0.49	$ 0.375	$ 1.42
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	Jul. 20, 2016	Oct. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Class of Stock [Line Items]
Depositary Share Offering		32,000,000
Issuances of common shares				101,000,000
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)	Sep. 30, 2016BcfMMBbls
Crude oil fixed price | Derivatives designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts | MMBbls	(19.4)
Crude oil fixed price | Derivatives not designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts | MMBbls	(0.1)
Crude oil basis | Derivatives designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts | MMBbls	(2.2)
Natural gas fixed price | Derivatives designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts | Bcf	(27.5)
Natural gas fixed price | Derivatives not designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts | Bcf	(9.9)
Natural gas basis | Derivatives designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts | Bcf	(12.8)
Natural gas basis | Derivatives not designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts | Bcf	(3.3)
Natural Gas Liquids Fixed Price [Member] | Derivatives not designated as hedging contracts
Derivative [Line Items]
Derivative, Net Nonmonetary Notional Amounts | MMBbls	(2.6)

Risk Management Interest Rate R

Risk Management Interest Rate Risk Management (Details) - Interest rate swap agreements - USD ($) $ in Millions	Sep. 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	$ 9,775	$ 9,700

Risk Management Risk Management

Risk Management Risk Management Foreign Currency Risk Management (Details) $ in Millions	9 Months Ended
	Sep. 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	Sep. 30, 2016	Dec. 31, 2015
Derivatives designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	$ 1,043	$ 987
Derivative Liability, Fair Value, Net	(55)	(74)
Derivatives not designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	1,047	1,024
Derivative Liability, Fair Value, Net	(63)	(108)
Natural gas and crude derivative contracts | Derivatives designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	264	603
Derivative Liability, Fair Value, Net	(41)	(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	153	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	(22)	(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	111	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	(19)	0
Natural gas and crude derivative contracts | Derivatives not designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	4	35
Derivative Liability, Fair Value, Net	(8)	(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	4	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	(8)	(1)
Interest rate swap agreements | Derivatives designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	738	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	0	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	0	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	0	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	41	0
Derivative Liability, Fair Value, Net	(14)	(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	4	37
Derivative Liability, Fair Value, Net	(8)	(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	124	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	614	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	(14)	(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	41	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	$ 0	$ (46)

Risk Management Effect of Deriv

Risk Management Effect of Derivative Contracts on the Income Statement (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Interest rate swap agreements | Interest, net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives not designated as accounting hedges	$ (14)	$ 0	$ 63	$ 0
Energy commodity derivative contracts(a)
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives not designated as accounting hedges	(5)	175	51	182
Derivative, Gain on Derivative	20	19	59	21
Energy commodity derivative contracts(a) | Revenues—Natural gas sales
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives not designated as accounting hedges	1	6	(4)	9
Energy commodity derivative contracts(a) | Revenues—Product sales and other
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives not designated as accounting hedges	7	169	(7)	173
Energy commodity derivative contracts(a) | Costs of sales
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives not designated as accounting hedges	1	0	(1)	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)	39	63	158	192
Gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	(2)	(6)	(7)	4
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)	50	104	(19)	44
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	(84)	251	315	163
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)	(1)	(1)	(2)	(2)
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)	0	(4)	(5)	(6)
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	81	(283)	(323)	(166)
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			49
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)	(3)	4	20	29
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)	34	60	124	161
Gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	(2)	(6)	(7)	4
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)	(1)	(2)	(13)	(21)
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)	20	119	(64)	72
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	(11)	50	(22)
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)	10	2	29	25
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 ($)	Sep. 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)	16,000,000	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 Manageme50

Risk Management Risk Management Reporting of Amounts Reclassified out of Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Sep. 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	$ 42	$ 179	$ 219	$ 327
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Adjustment, Net of Tax, Before Reclassifications, Portion Attributable to Parent	65	(170)
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(342)	(229)	(358)	(236)
Accumulated Other Comprehensive Income (Loss), Net of Tax	(557)	(328)	(461)	(17)
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, before Reclassification Adjustments, Net of Tax	16	7
Other Comprehensive Income Unrealized Gain Loss On Derivatives Arising During Period Net Of Tax Portion Attributable To Parent	(19)	44
OCI, before Reclassifications, Net of Tax, Attributable to Parent	62	(119)
Other Comprehensive Income Reclassification Adjustment On Derivatives Included In Net Income Net Of Tax Portion Attributable To Parent	(158)	(192)
Accumulated Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Net of Tax	(257)	(278)	$ (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	(158)	(192)
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax, Portion Attributable to Parent	(177)	(148)
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Adjustment and Impact of Merger Transactions, Net of Tax, Portion Attributable to Parent	65	(170)
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	16	7
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	$ (96)	$ (311)

Fair Value Fair Value of Deriva

Fair Value Fair Value of Derivative Contracts (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Energy commodity derivative contracts(a)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net amount	$ 243		$ 243		$ 590
Net amount	(8)		(8)		(19)
Interest rate swap agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net amount	738		738		377
Net amount	0		0		(17)
Cross-currency swap agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net amount	27		27		0
Net amount	0		0		(52)
Energy commodity derivative contracts(a)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	268		268		639
Contracts available for netting	(25)		(25)		(12)
Balance sheet liability fair value measurements by level	(49)		(49)		(31)
Contracts available for netting	25		25		12
Fair Value, Assets Liabilites Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Derivatives-net asset (liability)	0	$ (37)	(15)	$ (61)
Total gains or (losses) included in earnings	0	(1)	(9)	(1)
Settlements	0	15	24	39
Derivatives-net asset (liability)	0	(23)	0	(23)
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	$ 0	0	$ 2
Energy commodity derivative contracts(a) | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	4		4		48
Balance sheet liability fair value measurements by level	(10)		(10)		(4)
Energy commodity derivative contracts(a) | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	264		264		589
Balance sheet liability fair value measurements by level	(39)		(39)		(10)
Energy commodity derivative contracts(a) | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	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)	16		16		0
Interest rate swap agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	738		738		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]
Derivative Asset, Fair Value, Gross Asset	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]
Derivative Asset, Fair Value, Gross Asset	738		738		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]
Derivative Asset, Fair Value, Gross Asset	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
Cross-currency swap agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	41		41		0
Contracts available for netting	(14)		(14)		0
Balance sheet liability fair value measurements by level	(14)		(14)		(52)
Contracts available for netting	14		14		0
Cross-currency swap agreements | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	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]
Derivative Asset, Fair Value, Gross Asset	41		41		0
Balance sheet liability fair value measurements by level	(14)		(14)		(52)
Cross-currency swap agreements | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	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

Fair Value Fair Value of Financ

Fair Value Fair Value of Financial Instruments (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Debt Instrument, Fair Value Disclosure	$ 1,710	$ 1,674
Reported Value Measurement [Member]
Debt Instrument [Line Items]
Debt Instrument, Fair Value Disclosure	41,462	43,227
Estimate of Fair Value Measurement [Member]
Debt Instrument [Line Items]
Debt Instrument, Fair Value Disclosure	$ 42,106	$ 37,481

Reportable Segments Reportable

Reportable Segments Reportable Segments Revenues (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Segment Reporting Information [Line Items]
Segment Earnings Before Depreciation Depletion And Amortization	$ 1,381	$ 1,592	$ 4,812	$ 5,215
Revenues	3,330	3,707	9,669	10,767
Other revenues	605	948	1,775	2,613
Operating Segments [Member]
Segment Reporting Information [Line Items]
Revenues	3,328	3,705	9,661	10,757
Operating Segments [Member] | Natural Gas Pipelines
Segment Reporting Information [Line Items]
Segment Earnings Before Depreciation Depletion And Amortization	540	993	2,498	2,936
Operating Segments [Member] | CO2
Segment Reporting Information [Line Items]
Segment Earnings Before Depreciation Depletion And Amortization	217	29	606	605
Revenues	310	517	916	1,316
Operating Segments [Member] | Terminals
Segment Reporting Information [Line Items]
Segment Earnings Before Depreciation Depletion And Amortization	286	249	831	798
Operating Segments [Member] | Products Pipelines
Segment Reporting Information [Line Items]
Segment Earnings Before Depreciation Depletion And Amortization	293	288	765	811
Operating Segments [Member] | Kinder Morgan Canada
Segment Reporting Information [Line Items]
Segment Earnings Before Depreciation Depletion And Amortization	43	42	123	120
Revenues	66	68	188	193
Operating Segments [Member] | Other
Segment Reporting Information [Line Items]
Segment Earnings Before Depreciation Depletion And Amortization	2	(9)	(11)	(55)
Revenues	(1)	0	0	3
Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Other revenues	8	10	25	28
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	(6)	(8)	(17)	(18)
External Customer [Member] | Operating Segments [Member] | Natural Gas Pipelines
Segment Reporting Information [Line Items]
Revenues	2,048	2,176	5,900	6,444
External Customer [Member] | Operating Segments [Member] | Terminals
Segment Reporting Information [Line Items]
Revenues	484	469	1,436	1,395
External Customer [Member] | Operating Segments [Member] | Products Pipelines
Segment Reporting Information [Line Items]
Revenues	415	467	1,204	1,388
Intersegment Revenues [Member] | Operating Segments [Member] | Natural Gas Pipelines
Segment Reporting Information [Line Items]
Revenues	2	8	4	16
Intersegment Revenues [Member] | Operating Segments [Member] | Terminals
Segment Reporting Information [Line Items]
Revenues	0	0	1	1
Intersegment Revenues [Member] | Operating Segments [Member] | Products Pipelines
Segment Reporting Information [Line Items]
Revenues	$ 4	$ 0	$ 12	$ 1

Reportable Segments Reportabl54

Reportable Segments Reportable Segments EBDA (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Segment Reporting Information [Line Items]
Total Segment EBDA	$ 1,381	$ 1,592	$ 4,812	$ 5,215
DD&A	(549)	(617)	(1,652)	(1,725)
Amortization of excess cost of equity investments	(15)	(13)	(45)	(39)
Other revenues	605	948	1,775	2,613
General and administrative expense	(171)	(160)	(550)	(540)
Interest, net	(472)	(540)	(1,384)	(1,524)
Income tax expense	(377)	(108)	(744)	(521)
Net (loss) income	(183)	183	506	944
Operating Segments [Member] | Natural Gas Pipelines
Segment Reporting Information [Line Items]
Total Segment EBDA	540	993	2,498	2,936
Operating Segments [Member] | CO2
Segment Reporting Information [Line Items]
Total Segment EBDA	217	29	606	605
Operating Segments [Member] | Terminals
Segment Reporting Information [Line Items]
Total Segment EBDA	286	249	831	798
Operating Segments [Member] | Products Pipelines
Segment Reporting Information [Line Items]
Total Segment EBDA	293	288	765	811
Operating Segments [Member] | Kinder Morgan Canada
Segment Reporting Information [Line Items]
Total Segment EBDA	43	42	123	120
Operating Segments [Member] | Other
Segment Reporting Information [Line Items]
Total Segment EBDA	2	(9)	(11)	(55)
Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
DD&A	(549)	(617)	(1,652)	(1,725)
Amortization of excess cost of equity investments	(15)	(13)	(45)	(39)
Other revenues	8	10	25	28
General and administrative expense	(171)	(160)	(550)	(540)
Interest, net	(474)	(539)	(1,386)	(1,525)
Income tax expense	$ (363)	$ (90)	$ (698)	$ (470)

Reportable Segments Reportabl55

Reportable Segments Reportable Segments Assets (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Assets	$ 81,604	$ 84,104
Natural Gas Pipelines
Segment Reporting Information [Line Items]
Assets	50,428	53,704
CO2
Segment Reporting Information [Line Items]
Assets	4,211	4,706
Terminals
Segment Reporting Information [Line Items]
Assets	9,838	9,083
Products Pipelines
Segment Reporting Information [Line Items]
Assets	8,348	8,464
Kinder Morgan Canada
Segment Reporting Information [Line Items]
Assets	1,568	1,434
Other
Segment Reporting Information [Line Items]
Assets	309	418
Total segment assets
Segment Reporting Information [Line Items]
Assets	74,702	77,809
Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Disposal Group, Including Discontinued Operation, Other Assets	0	19
Corporate, Non-Segment [Member] | Corporate Segment [Member]
Segment Reporting Information [Line Items]
Assets	$ 6,902	$ 6,276

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	Sep. 01, 2016	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Deferred Income Tax Expense				$ 767	$ 524
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent		35.00%	35.00%	35.00%	35.00%
Income tax expense		$ 377	$ 108	$ 744	$ 521
Effective tax rate		194.30%	37.10%	59.50%	35.60%
Unrecognized Tax Benefits		$ 146		$ 146		$ 173
Unrecognized Tax Benefits, Reduction Resulting from Lapse of Applicable Statute of Limitations				27
Sale Equity Interest in SNG [Member] | Southern Natural Gas Company LLC [Member]
Deferred Income Tax Expense		$ 269		$ 269
Disposal Group, Equity Interest Sold	50.00%

Federal Energy Regulatory Commi

Federal Energy Regulatory Commission Proceedings (Details) - Federal Energy Regulatory Commission [Member] - Various Shippers [Member] - Unfavorable Regulatory Action [Member] $ in Millions	9 Months Ended
	Sep. 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	Sep. 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 and59

Litigation, Environmental and Other Contingencies Litigation General (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Loss Contingencies [Abstract]
Estimated Litigation Liability	$ 502	$ 463

Environmental Matters (Details)

Environmental Matters (Details) $ in Millions

Oct. 05, 2016USD ($)

Jul. 28, 2016

Jun. 17, 2016USD ($)

Jun. 08, 2016USD ($)

Nov. 08, 2013

Aug. 06, 2013Defendants

Jul. 24, 2013

Aug. 31, 2007USD ($)

Dec. 31, 2000Terminals

Sep. 30, 2016USD ($)TerminalsPartiesDefendants

Dec. 31, 2010USD ($)

Dec. 31, 1969

Dec. 31, 2015USD ($)

Loss Contingencies [Line Items]

Accrual for environmental loss contingencies

$ 312

$ 284

Environmental recoveries receivable

$ 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

Estimated Remedy Implementation Period

7 years

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

Judicial District of Louisiana [Member] | Vermilion Parish Louisiana Coastal Zone [Member] | Tennessee Gas Pipeline Company LLC [Member]

Loss Contingencies [Line Items]

Loss Contingency, Number of Defendants

52

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

$ 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

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

Loss Contingencies [Line Items]

Number of Parties at a Joint Defense Group

70

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

EPA preferred alternative estimate [Member] | Lower Passaic River Study Area [Member] | Pending Litigation [Member]

Loss Contingencies [Line Items]

Environmental Remediation Expense

$ 1,700

Subsequent Event [Member] | AOC required engineering and design work [Member] | Lower Passaic River Study Area [Member] | Pending Litigation [Member]

Loss Contingencies [Line Items]

Environmental Remediation Expense

$ 165

Subsequent Event [Member] | Design [Member] | Lower Passaic River Study Area [Member] | Environmental Protection Agency [Member]

Loss Contingencies [Line Items]

Estimated Remedy Implementation Period

4 years

Subsequent Event [Member] | Clean Up Implementation [Member] | Lower Passaic River Study Area [Member] | Environmental Protection Agency [Member]

Loss Contingencies [Line Items]

Estimated Remedy Implementation Period

6 years

Litigation, Environmental and61

Litigation, Environmental and Other Contingencies Other Contingencies (Details) $ in Millions	Sep. 01, 2016USD ($)
SNG notes, 4.40% through 8.00%, due 2017 through 2032 | SNG [Member]
Loss Contingencies [Line Items]
Decrease in Debt due to Deconsolidation	$ 1,211
Sale Equity Interest in SNG [Member] | Southern Natural Gas Company LLC [Member]
Loss Contingencies [Line Items]
Disposal Group, Equity Interest Sold	50.00%

Guarantee of Securities of Su62

Guarantee of Securities of Subsidiaries (Details) - USD ($) $ in Millions	Sep. 30, 2016	Sep. 01, 2016	Sep. 30, 2016	Sep. 30, 2015
Repayments of Debt			$ 9,135	$ 11,893
Parent Issuer and Guarantor
Repayments of Debt			7,178	11,544
Carrying value	$ 14,325		14,325
Subsidiary Issuer and Guarantor - KMP
Repayments of Debt			500	300
Carrying value	19,485		19,485
Subsidiary Guarantors
Repayments of Debt			1,449	$ 42
Carrying value	4,947		4,947
Capitalized Lease Debt Not Subject to Cross Guarantee Agreement	171		$ 171
Copano senior notes, 7.125%, due April 1, 2021 | Subsidiary Issuer and Guarantor - Copano
Repayments of Debt	$ 332
Debt Instrument, Interest Rate, Stated Percentage	7.125%		7.125%
Southern Natural Gas Company LLC [Member] | Sale Equity Interest in SNG [Member]
Disposal Group, Equity Interest Sold		50.00%

Guarantee of Securities of Su63

Guarantee of Securities of Subsidiaries Condensed Consolidated Statements of Income and Comprehensive Income (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Condensed Income Statements, Captions [Line Items]
Total Revenues	$ 3,330	$ 3,707	$ 9,669	$ 10,767
Costs of sales	971	1,106	2,454	3,281
Depreciation, depletion and amortization	549	617	1,652	1,725
Other operating expenses	(1)	(2)	0	(5)
Total Operating Costs, Expenses and Other	2,448	2,986	7,031	8,076
Operating Income	882	721	2,638	2,691
Earnings from equity investments	137	114	343	330
Interest, net	(472)	(540)	(1,384)	(1,524)
Amortization of excess cost of equity investments and other, net	12	9	42	33
Income Before Income Taxes	194	291	1,250	1,465
Income tax expense	(377)	(108)	(744)	(521)
Net (Loss) Income	(183)	183	506	944
Net (Income) Loss Attributable to Noncontrolling Interests	(5)	3	(7)	4
Net (Loss) Income Attributable to Kinder Morgan, Inc.	(188)	186	499	948
Preferred Stock Dividends	(39)	0	(117)	0
Net (Loss) Income Available to Common Stockholders	(227)	186	382	948
Total other comprehensive loss	(3)	(37)	(96)	(311)
Comprehensive (loss) income	(186)	146	410	633
Comprehensive income attributable to noncontrolling interests	(5)	3	(7)	4
Comprehensive (loss) income attributable to KMI	(191)	149	403	637
Consolidating Adjustments
Condensed Income Statements, Captions [Line Items]
Total Revenues	(18)	(12)	(39)	(36)
Costs of sales	(6)	1	(4)	2
Depreciation, depletion and amortization	0	0	0	0
Other operating expenses	(12)	(13)	(35)	(38)
Total Operating Costs, Expenses and Other	(18)	(12)	(39)	(36)
Operating Income	0	0	0	0
Earnings from consolidated subsidiaries	(2,080)	(1,032)	(4,927)	(4,242)
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	(2,080)	(1,032)	(4,927)	(4,242)
Income tax expense	0	0	0	0
Net (Loss) Income	(2,080)	(1,032)	(4,927)	(4,242)
Net (Income) Loss Attributable to Noncontrolling Interests	(5)	3	(7)	4
Net (Loss) Income Attributable to Kinder Morgan, Inc.	(2,085)	(1,029)	(4,934)	(4,238)
Preferred Stock Dividends	0		0
Net (Loss) Income Available to Common Stockholders	(2,085)		(4,934)
Total other comprehensive loss	110	174	368	1,036
Comprehensive (loss) income	(1,970)	(858)	(4,559)	(3,206)
Comprehensive income attributable to noncontrolling interests	(5)	3	(7)	4
Comprehensive (loss) income attributable to KMI	(1,975)	(855)	(4,566)	(3,202)
Parent Issuer and Guarantor
Condensed Income Statements, Captions [Line Items]
Total Revenues	9	9	26	28
Costs of sales	0	0	0	0
Depreciation, depletion and amortization	4	6	13	16
Other operating expenses	663	16	712	66
Total Operating Costs, Expenses and Other	667	22	725	82
Operating Income	(658)	(13)	(699)	(54)
Earnings from consolidated subsidiaries	963	498	2,373	1,980
Earnings from equity investments	0	0	0	0
Interest, net	(173)	(208)	(519)	(512)
Amortization of excess cost of equity investments and other, net	(1)	0	0	0
Income Before Income Taxes	131	277	1,155	1,414
Income tax expense	(319)	(91)	(656)	(466)
Net (Loss) Income	(188)	186	499	948
Net (Income) Loss Attributable to Noncontrolling Interests	0	0	0	0
Net (Loss) Income Attributable to Kinder Morgan, Inc.	(188)	186	499	948
Preferred Stock Dividends	(39)		(117)
Net (Loss) Income Available to Common Stockholders	(227)		382
Total other comprehensive loss	(3)	(37)	(96)	(311)
Comprehensive (loss) income	(191)	149	403	637
Comprehensive income attributable to noncontrolling interests	0	0	0	0
Comprehensive (loss) income attributable to KMI	(191)	149	403	637
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	0	1	4	39
Total Operating Costs, Expenses and Other	0	1	4	39
Operating Income	0	(1)	(4)	(39)
Earnings from consolidated subsidiaries	1,004	484	2,335	2,033
Earnings from equity investments	0	0	0	0
Interest, net	(6)	23	91	30
Amortization of excess cost of equity investments and other, net	0	0	0	0
Income Before Income Taxes	998	506	2,422	2,024
Income tax expense	(2)	(2)	(5)	(6)
Net (Loss) Income	996	504	2,417	2,018
Net (Income) Loss Attributable to Noncontrolling Interests	0	0	0	0
Net (Loss) Income Attributable to Kinder Morgan, Inc.	996	504	2,417	2,018
Preferred Stock Dividends	0		0
Net (Loss) Income Available to Common Stockholders	996		2,417
Total other comprehensive loss	(47)	(42)	(208)	(419)
Comprehensive (loss) income	949	462	2,209	1,599
Comprehensive income attributable to noncontrolling interests	0	0	0	0
Comprehensive (loss) income attributable to KMI	949	462	2,209	1,599
Subsidiary Guarantors
Condensed Income Statements, Captions [Line Items]
Total Revenues	2,953	3,298	8,555	9,591
Costs of sales	916	1,007	2,261	2,999
Depreciation, depletion and amortization	466	515	1,400	1,446
Other operating expenses	145	1,101	1,644	2,560
Total Operating Costs, Expenses and Other	1,527	2,623	5,305	7,005
Operating Income	1,426	675	3,250	2,586
Earnings from consolidated subsidiaries	99	40	174	188
Earnings from equity investments	(213)	114	(1)	304
Interest, net	(281)	(340)	(918)	(1,013)
Amortization of excess cost of equity investments and other, net	(6)	(5)	(17)	(13)
Income Before Income Taxes	1,025	484	2,488	2,052
Income tax expense	(22)	(14)	(32)	(39)
Net (Loss) Income	1,003	470	2,456	2,013
Net (Income) Loss Attributable to Noncontrolling Interests	0	0	0	0
Net (Loss) Income Attributable to Kinder Morgan, Inc.	1,003	470	2,456	2,013
Preferred Stock Dividends	0		0
Net (Loss) Income Available to Common Stockholders	1,003		2,456
Total other comprehensive loss	(32)	(7)	(261)	(351)
Comprehensive (loss) income	971	463	2,195	1,662
Comprehensive income attributable to noncontrolling interests	0	0	0	0
Comprehensive (loss) income attributable to KMI	971	463	2,195	1,662
Subsidiary Non-Guarantors
Condensed Income Statements, Captions [Line Items]
Total Revenues	386	412	1,127	1,184
Costs of sales	61	98	197	280
Depreciation, depletion and amortization	79	96	239	263
Other operating expenses	132	158	600	443
Total Operating Costs, Expenses and Other	272	352	1,036	986
Operating Income	114	60	91	198
Earnings from consolidated subsidiaries	14	10	45	41
Earnings from equity investments	0	0	0	0
Interest, net	(12)	(15)	(38)	(29)
Amortization of excess cost of equity investments and other, net	4	1	14	7
Income Before Income Taxes	120	56	112	217
Income tax expense	(34)	(1)	(51)	(10)
Net (Loss) Income	86	55	61	207
Net (Income) Loss Attributable to Noncontrolling Interests	0	0	0	0
Net (Loss) Income Attributable to Kinder Morgan, Inc.	86	55	61	207
Preferred Stock Dividends	0		0
Net (Loss) Income Available to Common Stockholders	86		61
Total other comprehensive loss	(31)	(125)	101	(266)
Comprehensive (loss) income	55	(70)	162	(59)
Comprehensive income attributable to noncontrolling interests	0	0	0	0
Comprehensive (loss) income attributable to KMI	55	(70)	162	(59)
Consolidated KMI
Condensed Income Statements, Captions [Line Items]
Total Revenues	3,330	3,707	9,669	10,767
Costs of sales	971	1,106	2,454	3,281
Depreciation, depletion and amortization	549	617	1,652	1,725
Other operating expenses	928	1,263	2,925	3,070
Total Operating Costs, Expenses and Other	2,448	2,986	7,031	8,076
Operating Income	882	721	2,638	2,691
Earnings from consolidated subsidiaries	0	0	0	0
Earnings from equity investments	(213)	114	(1)	304
Interest, net	(472)	(540)	(1,384)	(1,524)
Amortization of excess cost of equity investments and other, net	(3)	(4)	(3)	(6)
Income Before Income Taxes	194	291	1,250	1,465
Income tax expense	(377)	(108)	(744)	(521)
Net (Loss) Income	(183)	183	506	944
Net (Income) Loss Attributable to Noncontrolling Interests	(5)	3	(7)	4
Net (Loss) Income Attributable to Kinder Morgan, Inc.	(188)	186	499	948
Preferred Stock Dividends	(39)		(117)
Net (Loss) Income Available to Common Stockholders	(227)		382
Total other comprehensive loss	(3)	(37)	(96)	(311)
Comprehensive (loss) income	(186)	146	410	633
Comprehensive income attributable to noncontrolling interests	(5)	3	(7)	4
Comprehensive (loss) income attributable to KMI	$ (191)	$ 149	$ 403	$ 637

Guarantee of Securities of Su64

Guarantee of Securities of Subsidiaries Condensed Consolidating Balance Sheets (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015	Sep. 30, 2015	Dec. 31, 2014
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	$ 357	$ 229	$ 179	$ 315
Other current assets	230	306
Property, plant and equipment, net	38,780	40,547
Investments	7,358	6,040
Goodwill	22,163	23,790
Deferred income taxes	4,595	5,323
Other non-current assets	1,961	2,029
Total Assets	81,604	84,104
Current portion of debt		1,000
Long-term debt	38,518	42,406
Total Liabilities	46,636	48,701
Total KMI equity	34,606	35,119
Noncontrolling interests	362	284
Total Stockholders’ Equity	34,968	35,403	35,842	34,426
Total Liabilities and Stockholders’ Equity	81,604	84,104
Consolidating Adjustments
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	(7)	(48)	0	0
Other current assets - affiliates	(18,610)	(13,931)
Other current assets	(4)	(6)
Property, plant and equipment, net	0	0
Investments	0	0
Investments in subsidiaries	(65,040)	(62,252)
Goodwill	0	0
Notes receivable from affiliates	(23,960)	(24,619)
Deferred income taxes	(2,270)	(2,178)
Other non-current assets	0	0
Total Assets	(109,891)	(103,034)
Current portion of debt	0	0
Other current liabilities - affiliates	(18,610)	(13,931)
All other current liabilities	(11)	(54)
Long-term debt	0	0
Notes payable to affiliates	(23,960)	(24,619)
Deferred income taxes	(2,270)	(2,178)
All other long-term liabilities and deferred credits	0	0
Total Liabilities	(44,851)	(40,782)
Total KMI equity	(65,402)	(62,536)
Noncontrolling interests	362	284
Total Stockholders’ Equity	(65,040)	(62,252)
Total Liabilities and Stockholders’ Equity	(109,891)	(103,034)
Parent Issuer and Guarantor
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	171	123	12	4
Other current assets - affiliates	4,577	2,233
Other current assets	150	126
Property, plant and equipment, net	264	252
Investments	665	16
Investments in subsidiaries	27,063	27,401
Goodwill	13,789	15,089
Notes receivable from affiliates	619	850
Deferred income taxes	6,865	7,501
Other non-current assets	272	215
Total Assets	54,435	53,806
Current portion of debt	786	67
Other current liabilities - affiliates	2,303	1,328
All other current liabilities	415	321
Long-term debt	14,081	13,845
Notes payable to affiliates	1,601	2,404
Deferred income taxes	0	0
All other long-term liabilities and deferred credits	643	722
Total Liabilities	19,829	18,687
Total KMI equity	34,606	35,119
Noncontrolling interests	0	0
Total Stockholders’ Equity	34,606	35,119
Total Liabilities and Stockholders’ Equity	54,435	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	1,153	1,600
Other current assets	165	119
Property, plant and equipment, net	0	0
Investments	2	2
Investments in subsidiaries	29,831	28,038
Goodwill	22	22
Notes receivable from affiliates	21,729	21,319
Deferred income taxes	0	0
Other non-current assets	459	307
Total Assets	53,361	51,407
Current portion of debt	600	500
Other current liabilities - affiliates	12,885	8,682
All other current liabilities	283	458
Long-term debt	19,600	20,053
Notes payable to affiliates	448	448
Deferred income taxes	0	0
All other long-term liabilities and deferred credits	72	193
Total Liabilities	33,888	30,334
Total KMI equity	19,473	21,073
Noncontrolling interests	0	0
Total Stockholders’ Equity	19,473	21,073
Total Liabilities and Stockholders’ Equity	53,361	51,407
Subsidiary Guarantors
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	13	12	25	17
Other current assets - affiliates	12,268	9,410
Other current assets	2,508	2,161
Property, plant and equipment, net	30,818	33,032
Investments	6,567	5,906
Investments in subsidiaries	4,110	3,493
Goodwill	5,171	5,508
Notes receivable from affiliates	1,237	2,092
Deferred income taxes	0	0
Other non-current assets	4,514	4,951
Total Assets	67,206	66,565
Current portion of debt	1,435	132
Other current liabilities - affiliates	2,893	3,210
All other current liabilities	1,965	1,992
Long-term debt	4,161	7,825
Notes payable to affiliates	20,636	20,462
Deferred income taxes	633	596
All other long-term liabilities and deferred credits	890	909
Total Liabilities	32,613	35,126
Total KMI equity	34,593	31,439
Noncontrolling interests	0	0
Total Stockholders’ Equity	34,593	31,439
Total Liabilities and Stockholders’ Equity	67,206	66,565
Subsidiary Non-Guarantors
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	180	142	$ 142	$ 279
Other current assets - affiliates	612	688
Other current assets	187	195
Property, plant and equipment, net	7,698	7,263
Investments	124	116
Investments in subsidiaries	4,036	3,320
Goodwill	3,181	3,171
Notes receivable from affiliates	375	358
Deferred income taxes	0	0
Other non-current assets	100	107
Total Assets	16,493	15,360
Current portion of debt	123	122
Other current liabilities - affiliates	529	711
All other current liabilities	448	527
Long-term debt	676	683
Notes payable to affiliates	1,275	1,305
Deferred income taxes	1,637	1,582
All other long-term liabilities and deferred credits	469	406
Total Liabilities	5,157	5,336
Total KMI equity	11,336	10,024
Noncontrolling interests	0	0
Total Stockholders’ Equity	11,336	10,024
Total Liabilities and Stockholders’ Equity	16,493	15,360
Consolidated KMI
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	357	229
Other current assets - affiliates	0	0
Other current assets	3,006	2,595
Property, plant and equipment, net	38,780	40,547
Investments	7,358	6,040
Investments in subsidiaries	0	0
Goodwill	22,163	23,790
Notes receivable from affiliates	0	0
Deferred income taxes	4,595	5,323
Other non-current assets	5,345	5,580
Total Assets	81,604	84,104
Current portion of debt	2,944	821
Other current liabilities - affiliates	0	0
All other current liabilities	3,100	3,244
Long-term debt	38,518	42,406
Notes payable to affiliates	0	0
Deferred income taxes	0	0
All other long-term liabilities and deferred credits	2,074	2,230
Total Liabilities	46,636	48,701
Total KMI equity	34,606	35,119
Noncontrolling interests	362	284
Total Stockholders’ Equity	34,968	35,403
Total Liabilities and Stockholders’ Equity	$ 81,604	$ 84,104

Guarantee of Securities of Su65

Guarantee of Securities of Subsidiaries Condensed Consolidating Statements of Cash Flows (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	$ 3,495	$ 3,507
Payments to Acquire Businesses, Net of Cash Acquired	333	1,919
Capital expenditures	(2,109)	(2,999)
Proceeds from Divestiture of Interest in Consolidated Subsidiaries	1,402	0
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	250	45
Contributions to investments	(389)	(69)
Distributions from equity investments in excess of cumulative earnings	158	181
Investment in KMP		0
Payments for Advance to Affiliate	0	0
Other, net	(26)	39
Net Cash Used in Investing Activities	(1,047)	(4,722)
Issuances of debt	8,485	12,281
Payments of debt	(9,135)	(11,893)
Restricted cash held in escrow for debt repayment	(776)	0
Debt issue costs	(15)	(20)
Issuances of common shares	0	3,833
Cash dividends - common shares	(839)	(3,084)
Cash dividends - preferred shares	115	0
Repurchases of warrants	0	(12)
Proceeds from Collection of (Payments to Fund) Long-term Loans to Related Parties	0	0
Contributions from parents	0	0
Contributions from noncontrolling interests	88	7
Distributions to parents	0	0
Distributions to noncontrolling interests	(17)	(25)
Other, net	0	(1)
Net Cash (Used in) Provided by Financing Activities	(2,324)	1,086
Effect of exchange rate changes on cash and cash equivalents	4	(7)
Net increase (decrease) in Cash and Cash Equivalents	128	(136)
Cash and Cash Equivalents, beginning of period	229	315
Cash and Cash Equivalents, end of period	357	179
Consolidating Adjustments
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	(6,844)	(7,297)
Payments to Acquire Businesses, Net of Cash Acquired	0	0
Capital expenditures	0	0
Proceeds from Divestiture of Interest in Consolidated Subsidiaries	0
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	0	0
Contributions to investments	0	5
Distributions from equity investments in excess of cumulative earnings	(2,040)	(992)
Investment in KMP		159
Payments for Advance to Affiliate	(7,028)	(17,255)
Other, net	0	0
Net Cash Used in Investing Activities	4,988	16,427
Issuances of debt	0	0
Payments of debt	0	0
Restricted cash held in escrow for debt repayment	0
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
Proceeds from Collection of (Payments to Fund) Long-term Loans to Related Parties	(7,028)	(17,255)
Contributions from parents	(88)	(171)
Contributions from noncontrolling interests	88	7
Distributions to parents	8,942	8,314
Distributions to noncontrolling interests	(17)	(25)
Other, net		0
Net Cash (Used in) Provided by Financing Activities	1,897	(9,130)
Effect of exchange rate changes on cash and cash equivalents	0	0
Net increase (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	(3,023)	(2,387)
Payments to Acquire Businesses, Net of Cash Acquired	2	1,709
Capital expenditures	(39)	(9)
Proceeds from Divestiture of Interest in Consolidated Subsidiaries	0
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	0	0
Contributions to investments	(343)	(5)
Distributions from equity investments in excess of cumulative earnings	1,773	1,060
Investment in KMP		(159)
Payments for Advance to Affiliate	2,354	2,765
Other, net	0	0
Net Cash Used in Investing Activities	(965)	(3,587)
Issuances of debt	8,111	12,281
Payments of debt	(7,178)	(11,544)
Restricted cash held in escrow for debt repayment	0
Debt issue costs	(13)	(20)
Issuances of common shares		3,833
Cash dividends - common shares	(839)	(3,084)
Cash dividends - preferred shares	115
Repurchases of warrants		(12)
Proceeds from Collection of (Payments to Fund) Long-term Loans to Related Parties	4,070	4,528
Contributions from parents	0	0
Contributions from noncontrolling interests	0	0
Distributions to parents	0	0
Distributions to noncontrolling interests	0	0
Other, net		0
Net Cash (Used in) Provided by Financing Activities	4,036	5,982
Effect of exchange rate changes on cash and cash equivalents	0	0
Net increase (decrease) in Cash and Cash Equivalents	48	8
Cash and Cash Equivalents, beginning of period	123	4
Cash and Cash Equivalents, end of period	171	12
Subsidiary Issuer and Guarantor - KMP
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	3,903	5,917
Payments to Acquire Businesses, Net of Cash Acquired	0	0
Capital expenditures	0	0
Proceeds from Divestiture of Interest in Consolidated Subsidiaries	0
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	0	0
Contributions to investments	0	0
Distributions from equity investments in excess of cumulative earnings	298	0
Investment in KMP		0
Payments for Advance to Affiliate	495	7,699
Other, net	(52)	16
Net Cash Used in Investing Activities	(249)	(7,683)
Issuances of debt	0	0
Payments of debt	(500)	(300)
Restricted cash held in escrow for debt repayment	0
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
Proceeds from Collection of (Payments to Fund) Long-term Loans to Related Parties	973	5,602
Contributions from parents	0	156
Contributions from noncontrolling interests	0	0
Distributions to parents	(4,127)	(3,706)
Distributions to noncontrolling interests	0	0
Other, net		(1)
Net Cash (Used in) Provided by Financing Activities	(3,654)	1,751
Effect of exchange rate changes on cash and cash equivalents	0	0
Net increase (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 Guarantors
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	8,778	7,140
Payments to Acquire Businesses, Net of Cash Acquired	331	210
Capital expenditures	(1,550)	(2,745)
Proceeds from Divestiture of Interest in Consolidated Subsidiaries	1,402
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	250	45
Contributions to investments	(36)	(62)
Distributions from equity investments in excess of cumulative earnings	127	113
Investment in KMP		0
Payments for Advance to Affiliate	3,650	6,273
Other, net	37	5
Net Cash Used in Investing Activities	(3,751)	(9,127)
Issuances of debt	374	0
Payments of debt	(1,449)	(42)
Restricted cash held in escrow for debt repayment	(776)
Debt issue costs	(1)	0
Issuances of common shares		0
Cash dividends - common shares	0	0
Cash dividends - preferred shares	0
Repurchases of warrants		0
Proceeds from Collection of (Payments to Fund) Long-term Loans to Related Parties	1,539	6,514
Contributions from parents	88	3
Contributions from noncontrolling interests	0	0
Distributions to parents	(4,801)	(4,480)
Distributions to noncontrolling interests	0	0
Other, net		0
Net Cash (Used in) Provided by Financing Activities	(5,026)	1,995
Effect of exchange rate changes on cash and cash equivalents	0	0
Net increase (decrease) in Cash and Cash Equivalents	1	8
Cash and Cash Equivalents, beginning of period	12	17
Cash and Cash Equivalents, end of period	13	25
Subsidiary Non-Guarantors
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	681	134
Payments to Acquire Businesses, Net of Cash Acquired	0	0
Capital expenditures	(520)	(245)
Proceeds from Divestiture of Interest in Consolidated Subsidiaries	0
Sale of property, plant and equipment, investments, and other net assets, net of removal costs	0	0
Contributions to investments	(10)	(7)
Distributions from equity investments in excess of cumulative earnings	0	0
Investment in KMP		0
Payments for Advance to Affiliate	529	518
Other, net	(11)	18
Net Cash Used in Investing Activities	(1,070)	(752)
Issuances of debt	0	0
Payments of debt	(8)	(7)
Restricted cash held in escrow for debt repayment	0
Debt issue costs	(1)	0
Issuances of common shares		0
Cash dividends - common shares	0	0
Cash dividends - preferred shares	0
Repurchases of warrants		0
Proceeds from Collection of (Payments to Fund) Long-term Loans to Related Parties	446	611
Contributions from parents	0	12
Contributions from noncontrolling interests	0	0
Distributions to parents	(14)	(128)
Distributions to noncontrolling interests	0	0
Other, net		0
Net Cash (Used in) Provided by Financing Activities	423	488
Effect of exchange rate changes on cash and cash equivalents	4	(7)
Net increase (decrease) in Cash and Cash Equivalents	38	(137)
Cash and Cash Equivalents, beginning of period	142	279
Cash and Cash Equivalents, end of period	180	$ 142
Consolidated KMI
Condensed Cash Flow Statements, Captions [Line Items]
Cash and Cash Equivalents, beginning of period	229
Cash and Cash Equivalents, end of period	$ 357