Kinder Morgan (KMI) 10-Q 23 Oct 15 2015 Q3 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - USD ($)	9 Months Ended
	Sep. 30, 2015	Oct. 21, 2015	Jun. 30, 2014
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			$ 24,279,037,627
Entity Common Stock, Shares Outstanding		2,231,514,695
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q3
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2015

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Revenues
Natural gas sales	$ 744	$ 1,043	$ 2,206	$ 3,154
Services	2,015	2,050	5,948	5,655
Product sales and other	948	1,198	2,613	3,466
Total Revenues	3,707	4,291	10,767	12,275
Operating Costs, Expenses and Other
Costs of sales	1,106	1,642	3,281	4,895
Operations and maintenance	612	557	1,707	1,580
Depreciation, depletion and amortization	617	520	1,725	1,518
General and administrative	160	135	540	461
Taxes, other than income taxes	108	105	339	326
Loss on impairments and disposals of long-lived assets, net	385	0	489	3
Other income, net	(2)	0	(5)	0
Total Operating Costs, Expenses and Other	2,986	2,959	8,076	8,783
Operating Income	721	1,332	2,691	3,492
Other Income (Expense)
Earnings from equity investments	114	107	330	306
Loss on impairments of equity investments	0	0	(26)	0
Amortization of excess cost of equity investments	(13)	(12)	(39)	(33)
Interest, net	(540)	(432)	(1,524)	(1,320)
Other, net	9	30	33	56
Total Other Expense	(430)	(307)	(1,226)	(991)
Income Before Income Taxes	291	1,025	1,465	2,501
Income Tax Expense	(108)	(246)	(521)	(624)
Net Income	183	779	944	1,877
Net Loss (Income) Attributable to Noncontrolling Interests	3	(450)	4	(977)
Net Income Attributable to Kinder Morgan, Inc.	$ 186	$ 329	$ 948	$ 900
Class P Shares
Diluted Earnings Per Common Share	$ 0.08	$ 0.32	$ 0.43	$ 0.87
Diluted Weighted Average Shares Outstanding	2,203	1,028	2,181	1,028
Class P Shares
Class P Shares
Basic Earnings Per Common Share	$ 0.08	$ 0.32	$ 0.43	$ 0.87
Basic Weighted Average Shares Outstanding	2,203	1,028	2,173	1,028
Dividends Per Common Share Declared for the Period	$ 0.51	$ 0.44	$ 1.48	$ 1.29

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Total
Net income	$ 183	$ 779	$ 944	$ 1,877
Other comprehensive income (loss), net of tax
Change in fair value of hedge derivatives (net of tax (expense) benefit of $(60), $(37), $(25) and $4, respectively)	104	121	44	(20)
Reclassification of change in fair value of derivatives to net income (net of tax benefit (expense) of $37, $1, $111 and $(8), respectively)	(63)	(1)	(192)	29
Foreign currency translation adjustments (net of tax benefit of $45, $23, $98 and $24, respectively)	(79)	(73)	(170)	(79)
Benefit plan adjustments (net of tax expense of $-, $(1), $(4) and $-, respectively)	1	(1)	7	0
Total other comprehensive (loss) income	(37)	46	(311)	(70)
Comprehensive income	146	825	633	1,807
Comprehensive loss (income) attributable to noncontrolling interests	3	(478)	4	(933)
Comprehensive income attributable to KMI	$ 149	$ 347	$ 637	$ 874

CONSOLIDATED STATEMENTS OF COM4

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Total - Other comprehensive income (loss), tax
Change in fair value of derivatives utilized for hedging purposes	$ (60)	$ (37)	$ (25)	$ 4
Reclassification of change in fair value of derivatives to net income	37	1	111	(8)
Foreign currency translation adjustments	45	23	98	24
Benefit plan adjustments	$ 0	$ (1)	$ (4)	$ 0

CONSOLIDATED BALANCE SHEETS (Un

CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Current Assets
Cash and cash equivalents	$ 179	$ 315
Accounts receivable, net	1,404	1,641
Inventories	445	459
Fair value of derivative contracts	529	535
Deferred income taxes	50	56
Other current assets	460	746
Total current assets	3,067	3,752
Property, plant and equipment, net	40,608	38,564
Investments	5,943	6,036
Goodwill	24,952	24,654
Other intangibles, net	3,619	2,302
Deferred income taxes	5,327	5,651
Deferred charges and other assets	2,161	2,090
Total Assets	85,677	83,049
Current Liabilities
Current portion of debt	3,003	2,717
Accounts payable	1,226	1,588
Accrued interest	563	637
Accrued contingencies	322	383
Other current liabilities	1,077	1,037
Total current liabilities	6,191	6,362
Long-term debt
Outstanding	39,675	38,212
Preferred interest in general partner of KMP	100	100
Debt fair value adjustments	1,855	1,785
Total long-term debt	41,630	40,097
Other long-term liabilities and deferred credits	2,014	2,164
Total long-term liabilities and deferred credits	43,644	42,261
Total Liabilities	$ 49,835	$ 48,623
Commitments and contingencies (Notes 3 and 9)
Stockholders’ Equity
Class P shares, $0.01 par value, 4,000,000,000 shares authorized, 2,227,894,462 and 2,125,147,116 shares, respectively, issued and outstanding	$ 22	$ 21
Preferred stock, $0.01 par value, 10,000,000 shares authorized, none outstanding	0	0
Additional paid-in capital	40,062	36,178
Retained deficit	(4,242)	(2,106)
Accumulated other comprehensive loss	(328)	(17)
Total Kinder Morgan, Inc.’s stockholders’ equity	35,514	34,076
Noncontrolling interests	328	350
Total Stockholders’ Equity	35,842	34,426
Total Liabilities and Stockholders’ Equity	85,677	83,049
Kinder Morgan G.P., Inc. [Member] | KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock(n)
Long-term debt
Preferred interest in general partner of KMP	$ 100	$ 100

CONSOLIDATED BALANCE SHEETS (U6

CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - $ / shares	Sep. 30, 2015	Dec. 31, 2014
Stockholders' Equity
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (in shares)	10,000,000	10,000,000
Preferred stock, shares outstanding (in shares)	0	0
Class P
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)	2,227,894,462	2,125,147,116
Common stock, shares outstanding (in shares)	2,227,894,462	2,125,147,116

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Cash Flows From Operating Activities
Net income	$ 944	$ 1,877
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion and amortization	1,725	1,518
Deferred income taxes	524	369
Amortization of excess cost of equity investments	39	33
Loss on impairments and disposals of long-lived assets and equity investments, net	515	3
Earnings from equity investments	(330)	(306)
Distributions from equity investment earnings	289	294
Pension contributions and noncash pension benefit credits	(78)	(79)
Changes in components of working capital, net of the effects of acquisitions
Accounts receivable, net	304	23
Income tax receivable	195	0
Inventories	2	(29)
Other current assets	82	3
Accounts payable	(264)	(90)
Accrued interest, net of interest rate swaps	(72)	(113)
Accrued contingencies and other current liabilities	6	228
Other, net	(374)	(239)
Net Cash Provided by Operating Activities	3,507	3,492
Cash flows from investing activities
Business acquisitions, net of cash acquired	(1,864)	(961)
Acquisitions of other assets and investments	55	139
Capital expenditures	(2,999)	(2,678)
Contributions to investments	(69)	(342)
Distributions from equity investments in excess of cumulative earnings	181	138
Other, net	84	(38)
Net Cash Used in Investing Activities	(4,722)	(4,020)
Cash flows from financing activities
Issuances of debt	12,281	13,399
Payments of debt	(11,893)	(11,585)
Debt issue costs	(20)	(52)
Issuances of shares	3,833	0
Cash dividends	(3,084)	(1,304)
Repurchases of shares and warrants	(12)	(192)
Contributions from noncontrolling interests	7	1,638
Distributions to noncontrolling interests	(25)	(1,491)
Other, net	(1)	(2)
Net Cash Provided by Financing Activities	1,086	411
Effect of Exchange Rate Changes on Cash and Cash Equivalents	(7)	(9)
Net decrease in Cash and Cash Equivalents	(136)	(126)
Cash and Cash Equivalents, beginning of period	315	598
Cash and Cash Equivalents, end of period	179	472
Non-cash Investing and Financing Activities
Assets acquired by the assumption or incurrence of liabilities	1,680	73
Net assets contributed to equity investment	46	0
Supplemental Disclosures of Cash Flow Information
Cash paid during the period for interest (net of capitalized interest)	1,596	1,446
Cash (refunded) paid during the period for income taxes, net	$ (183)	$ 228

CONSOLIDATED STATEMENTS OF STOC

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Unaudited) Statement - USD ($) shares in Millions, $ in Millions	Total	Additional paid-in capital	Retained deficit	Accumulated other comprehensive loss	Stockholders’ equity attributable to KMI	Non-controlling interests	KMP, EPB and KMR [Member]Additional paid-in capital	KMP, EPB and KMR [Member]Stockholders’ equity attributable to KMI	KMP, EPB and KMR [Member]Non-controlling interests	EP Trust I Preferred [Member]Additional paid-in capital	EP Trust I Preferred [Member]Stockholders’ equity attributable to KMI	Class P	Class PPar value of common shares	Class PAdditional paid-in capital	Class PStockholders’ equity attributable to KMI	Class PEP Trust I Preferred [Member]
Outstanding shares at Dec. 31, 2013												1,031
Stockholders’ equity attributable to KMI at Dec. 31, 2013		$ 14,479	$ (1,372)	$ (24)	$ 13,093								$ 10
Non-controlling interests at Dec. 31, 2013						$ 15,192
Total Stockholders' Equity at Dec. 31, 2013	$ 28,285
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares repurchased												(3)
Shares repurchased	(94)	(94)			(94)
Warrants repurchased	(98)	(98)			(98)
Restricted shares	38	38			38
Impact from equity transactions of KMP, EPB and KMR	(15)						$ 29	$ 29	$ (44)
Net income	900		900		900
Net income	(977)					977
Net income	1,877
Distributions	(1,491)				0	(1,491)
Contributions	1,638				0	1,638
Cash dividends	(1,304)		(1,304)		(1,304)
Other	3	7			7	4
Other comprehensive loss				(26)	(26)
Other comprehensive loss						(44)
Other comprehensive loss	(70)
Outstanding shares at Sep. 30, 2014												1,028
Stockholders’ equity attributable to KMI at Sep. 30, 2014		14,361	(1,776)	(50)	12,545								10
Non-controlling interests at Sep. 30, 2014						16,224
Total Stockholders' Equity at Sep. 30, 2014	28,769
Outstanding shares at Dec. 31, 2014												2,125
Stockholders’ equity attributable to KMI at Dec. 31, 2014	34,076	36,178	(2,106)	(17)	34,076								21
Non-controlling interests at Dec. 31, 2014	350					350
Total Stockholders' Equity at Dec. 31, 2014	34,426
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuances of shares												101
Issuances of shares	3,833												1	$ 3,832	$ 3,833
Warrants repurchased	(12)	(12)			(12)
EP Trust I Preferred security conversions																1
EP Trust I Preferred security conversions	23									$ 23	$ 23
Warrants exercised	2	2			2
Restricted shares												1
Restricted shares	40	40			40
Net income	948		948		948
Net income	4					(4)
Net income	944
Distributions	(25)				0	(25)
Contributions	7				0	7
Cash dividends	(3,084)		(3,084)		(3,084)
Other	(1)	(1)			(1)
Other comprehensive loss				(311)	(311)
Other comprehensive loss	(311)
Outstanding shares at Sep. 30, 2015												2,228
Stockholders’ equity attributable to KMI at Sep. 30, 2015	35,514	$ 40,062	$ (4,242)	$ (328)	$ 35,514								$ 22
Non-controlling interests at Sep. 30, 2015	328					$ 328
Total Stockholders' Equity at Sep. 30, 2015	$ 35,842

General (Notes)

General (Notes)	9 Months Ended
	Sep. 30, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General	General Organization We are the largest energy infrastructure and the third largest energy company in North America with an enterprise value of approximately $110 billion . We own an interest in or operate approximately 84,000 miles of pipelines and 165 terminals. Our pipelines transport natural gas, refined petroleum products, crude oil, condensate, CO 2 and other products, and our terminals transload and store petroleum products, ethanol and chemicals, and handle such products as coal, petroleum coke and steel. We are also the leading producer and transporter of CO 2 , which is utilized for enhanced oil recovery projects in North America. On November 26, 2014, we completed our acquisition, pursuant to three separate merger agreements, of all of the outstanding common units of KMP and EPB and all of the outstanding shares of KMR that we did not already own. The transactions, valued at approximately $77 billion , are referred to collectively as the “Merger Transactions.” On January 1, 2015, EPB and its subsidiary, EPPOC merged with and into KMP. References to EPB refer to EPB for periods prior to its merger into KMP. Prior to the Merger Transactions, we owned an approximate 10% limited partner interest (including our interest in KMR) and the 2% general partner interest including incentive distribution rights in KMP, and an approximate 39% limited partner interest and the 2% general partner interest and incentive distribution rights in EPB. Effective with the Merger Transactions, the incentive distribution rights held by the general partner of KMP were eliminated. The earnings recorded by KMP, EPB and KMR that are attributed to their units and shares, respectively, held by the public prior to the Merger Transactions are reported as “Net loss (income) attributable to noncontrolling interests” in our accompanying consolidated statements of income. 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. Additionally, certain amounts from prior years have been reclassified to conform to the current presentation. In the nine months ended September 30, 2015, we adopted Accounting Standards Updates (ASU) 2015-03, “ Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs ” and ASU 2015-15, “ Interest—Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements—Amendments to SEC Paragraphs Pursuant to Staff Announcement at June 18, 2015 EITF Meeting (SEC Update). ” These ASUs are designed to simplify presentation of debt issuance costs. The standards require that debt issuance costs related to a recognized debt liability, except for line-of-credit debt issuance costs, be presented in the balance sheet as an offset to the carrying amount of that debt liability, consistent with debt discounts. The application of this new accounting guidance resulted in the reclassification of $149 million of debt issuance costs from “Deferred charges and other assets” to “Debt fair value adjustments” in our accompanying consolidated balance sheet as of December 31, 2014 . 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 2014 Form 10-K. Impairments During the three and nine months ended September 30, 2015 , we recorded non-cash pre-tax impairment charges of $387 million and $523 million , respectively. These amounts include $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 during the quarter. The nine months ended September 30, 2015 amount also includes $99 million of impairments, related to the sale of certain gas gathering and processing assets within our Oklahoma midstream operations and the continued deterioration of the commodity price environment, and $26 million related to our investments in Fort Union Gas Gathering L.L.C. and Bighorn Gas Gathering L.L.C., which are all included in 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 expectations, current and future commodity prices, management’s decisions to dispose of certain assets, as well as general economic conditions and the related demand for products handled or transported by our assets. In the current commodity price environment and to the extent conditions further deteriorate, we may identify additional triggering events that may necessitate further impairments to the carrying value of our assets. Such non-cash impairments 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 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 Shares Outstanding to Diluted Weighted Average Shares Outstanding (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Class P $ 182 $ 327 $ 938 $ 892 Participating securities(a) 4 2 10 8 Net Income Attributable to Kinder Morgan, Inc. $ 186 $ 329 $ 948 $ 900 Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Basic Weighted Average Shares Outstanding 2,203 1,028 2,173 1,028 Effect of dilutive securities: Warrants(b) — — 8 — Diluted Weighted Average Shares Outstanding 2,203 1,028 2,181 1,028 ________ (a) Participating securities are unvested restricted stock awards, which may be stock or stock units issued to management employees and include non-forfeitable dividend equivalent payments. As of September 30, 2015 , there were approximately 8 million such restricted stock awards. (b) 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 following potential common stock equivalents are antidilutive and, accordingly, are excluded from the determination of diluted earnings per share (in millions on a weighted-average basis): Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Unvested restricted stock awards 8 7 7 7 Warrants to purchase our Class P shares 296 298 290 316 Convertible trust preferred securities 8 10 8 10

Acquisitions (Notes)

Acquisitions (Notes)	9 Months Ended
	Sep. 30, 2015
Acquisitions and Divestitures [Abstract]
Acquisitions	Acquisitions Hiland Partners, LP On February 13, 2015, we acquired Hiland Partners, LP, a privately held Delaware limited partnership (Hiland) for aggregate consideration of approximately $3,120 million , including assumed debt. Approximately $368 million of the debt assumed was immediately paid down after closing. Hiland’s assets consist primarily of crude oil gathering and transportation pipelines and gas gathering and processing systems, primarily handling production from the Bakken Formation in North Dakota and Montana. The acquired gathering and processing assets are included in our Natural Gas Pipelines business segment while the acquired crude oil transport pipeline (Double H pipeline) is included in our Products Pipelines business segment. Vopak Terminal Assets On February 27, 2015, we acquired three U.S. terminals and one undeveloped site from Royal Vopak (Vopak) for approximately $158 million in cash. The acquisition included (i) a 36 -acre, 1,069,500 -barrel storage facility at Galena Park, Texas that handles base oils, biodiesel and crude oil and is immediately adjacent to our Galena Park terminal facility; (ii) two terminals in North Carolina: one in North Wilmington that handles chemicals and black oil and the other in South Wilmington that is not currently operating; and (iii) an undeveloped waterfront access site in Perth Amboy, New Jersey. We include the acquired assets as part of the Terminals business segment. Allocation of Purchase Price The evaluation of the assigned fair values for the above acquisitions is ongoing and subject to adjustment. Our preliminary allocation of the purchase price for each of our significant acquisitions during the nine months ended September 30, 2015 is detailed below (in millions). Acquisitions Hiland Vopak Terminal Assets Purchase Price Allocation: Current assets $ 82 $ 2 Property, plant and equipment 1,504 155 Goodwill 316 7 Other intangibles(a) 1,481 — Total assets acquired 3,383 164 Current liabilities (259 ) (2 ) Debt (1,411 ) — Other liabilities (4 ) (4 ) Cash consideration $ 1,709 $ 158 _______ (a) Relates to 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 expect our recorded goodwill associated with the above acquisitions to be deductible for tax purposes. Asset Purchase On July 15, 2015, we purchased from Shell US Gas & Power LLC (Shell) its 49% interest in a joint venture, Elba Liquefaction Company (ELC), that was in the pre-construction stage of development for liquefaction facilities at Elba Island, Georgia. The transaction was treated as an asset purchase with the net cash consideration of $185 million attributed to incremental costs of construction. The purchase gives us full ownership and control of ELC. Therefore, we prospectively changed our method of accounting for ELC from the equity method to full consolidation. Shell continues to subscribe to 100% of the liquefaction capacity.

Debt Debt (Notes)

Debt Debt (Notes)	9 Months Ended
	Sep. 30, 2015
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 and premiums (in millions): September 30, 2015 December 31, 2014 KMI Senior notes, 1.50% through 8.25%, due 2015 through 2098(a) $ 13,385 $ 11,438 Credit facility due November 26, 2019(b) 275 850 Commercial paper borrowings(b) 193 386 KMP Senior notes, 2.65% through 9.00%, due 2015 through 2044(c) 20,360 20,660 TGP senior notes, 7.00% through 8.375%, due 2016 through 2037 1,790 1,790 EPNG senior notes, 5.95% through 8.625%, due 2017 through 2032 1,115 1,115 Copano senior notes, 7.125%, due April 1, 2021 332 332 CIG senior notes, 5.95% through 6.85%, due 2015 through 2037 440 475 SNG notes, 4.40% through 8.00%, due 2017 through 2032 1,211 1,211 Other Subsidiary Borrowings (as obligor) Kinder Morgan Finance Company, LLC, senior notes, 5.70% through 6.40%, due 2016 through 2036 1,636 1,636 Hiland Partners Holdings LLC, senior notes, 5.50% and 7.25%, due 2020 and 2022 974 — EPC Building, LLC, promissory note, 3.967%, due 2015 through 2035 445 453 Preferred securities, 4.75%, due March 31, 2028 221 280 KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock 100 100 Other miscellaneous debt 301 303 Total debt – KMI and Subsidiaries 42,778 41,029 Less: Current portion of debt(d) 3,003 2,717 Total long-term debt – KMI and Subsidiaries(e) $ 39,775 $ 38,312 _______ (a) September 30, 2015 amount includes senior notes that are denominated in Euros and have been converted and are reported at the September 30, 2015 exchange rate of 1.1177 U.S. dollars per Euro. From the issuance date of these senior notes in March 2015 through September 30, 2015 , our debt increased by $40 million as a result of the change in the exchange rate of U.S. dollars per Euro. We entered into cross-currency swap agreements associated with these senior notes (see Note 5 “Risk Management— Foreign Currency Risk Management ”). (b) As of September 30, 2015 and December 31, 2014 , the weighted average interest rates on our credit facility borrowings, including commercial paper borrowings, were 1.34% and 1.54% , respectively. (c) On January 1, 2015, EPB and EPPOC merged with and into KMP. On that date, KMP succeeded EPPOC as the issuer of approximately $2.9 billion of EPPOC’s senior notes, which were guaranteed by EPB, and EPB and EPPOC ceased to be obligors for those senior notes. (d) Amounts include outstanding credit facility and commercial paper borrowings. (e) Excludes our “Debt fair value adjustments” which, as of September 30, 2015 and December 31, 2014 , increased our combined debt balances by $1,855 million and $1,785 million , respectively. In addition to all unamortized debt discount/premium amounts, debt issuance costs (resulting from the implementation of ASU Nos. 2015-03 and 2015-15) 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. Credit Facilities As of September 30, 2015 , we had $275 million outstanding under our five -year $4.0 billion revolving credit facility, $193 million outstanding under our $4.0 billion commercial paper program and $117 million in letters of credit. Our availability under this facility as of September 30, 2015 was $3,415 million . 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. On February 13, 2015, in connection with the Hiland acquisition, we entered into and made borrowings of $1,641 million under a new six -month bridge credit facility with UBS AG, Stamford Branch. Interest under this bridge credit facility was charged at the same rate as our $4.0 billion revolving credit facility. Prior to March 31, 2015, we repaid the outstanding borrowings and the facility was terminated on April 6, 2015. Hiland Debt Acquired As of the February 13, 2015 Hiland acquisition date, we assumed (i) $975 million in principal amount of senior notes (which were valued at $1,043 million as of the acquisition date) and (ii) $368 million of other borrowings that were immediately repaid after closing, primarily consisting of borrowings outstanding under a revolving credit facility. The senior notes are subject to our cross guarantee agreement discussed in Note 11. Long-term Debt Issuances and Repayments Apart from the assumption of the Hiland debt discussed above, following are significant long-term debt issuances and repayments made during the nine months ended September 30, 2015 : Issuances $800 million 5.05% notes due 2046 $815 million 1.50% notes due 2022(a) $543 million 2.25% notes due 2027(a) Repayments $300 million 5.625% notes due 2015 $250 million 5.15% notes due 2015 _______ (a) Senior notes are denominated in Euros and are presented above in U.S. dollars at the exchange rate on the issuance date of 1.0860 U.S. dollars per Euro. At the time of issuance, we entered into cross-currency swap agreements effectively converting these senior notes to U.S. dollars (see Note 5 “Risk Management— Foreign Currency Risk Management ”).

Stockholders' Equity (Notes)

Stockholders' Equity (Notes)	9 Months Ended
	Sep. 30, 2015
Stockholders' Equity Note [Abstract]
Stockholders' Equity Note Disclosure [Text Block]	Stockholders’ Equity Common Equity As of September 30, 2015 , our common equity consisted of our Class P common stock. For additional information regarding our Class P common stock, see Note 10 to our consolidated financial statements included in our 2014 Form 10-K. On June 12, 2015, we announced that our board of directors approved a warrant repurchase program authorizing us to repurchase in the aggregate up to $100 million of warrants. As of September 30, 2015 , we had $91 million of availability remaining under the above announced program. As of December 31, 2014, we had $2 million available for repurchases under our 2014 repurchase program, which was exhausted in June 2015. On December 19, 2014, we entered into an equity distribution agreement authorizing us to issue and sell through or to the managers party thereto, as sales agents and/or principals, shares of our Class P common stock having an aggregate offering of up to $5.0 billion from time to time during the term of this agreement. During the nine months ended September 30, 2015, we issued and sold 101,290,190 shares of our Class P common stock pursuant to the equity distribution agreement, and issued an additional 1,324,318 shares after September 30, 2015 to settle sales made on or before September 30, 2015 , resulting in net proceeds of $3.9 billion . Dividends Holders of our common stock share equally in any dividend declared by our board of directors, subject to the rights of the holders of any outstanding preferred stock. The following table provides information about our per share dividends: Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Per common share cash dividend declared for the period $ 0.51 $ 0.44 $ 1.48 $ 1.29 Per common share cash dividend paid in the period $ 0.49 $ 0.43 $ 1.42 $ 1.26 On October 21, 2015 , our board of directors declared a cash dividend of $0.51 per share for the quarterly period ended September 30, 2015 , which is payable on November 13, 2015 to shareholders of record as of November 2, 2015 .

Risk Management (Notes)

Risk Management (Notes)	9 Months Ended
	Sep. 30, 2015
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, we have legacy power forward and swap contracts for which we entered into offsetting positions that eliminate the price risks associated with these power contracts. As of December 31, 2014 , we had discontinued hedge accounting on certain of our crude derivative contracts as we did not expect them to continue to be highly effective, for accounting purposes, in offsetting the variability in cash flows. This was caused primarily by volatility in basis differentials. As the forecasted transactions are still probable, accumulated gains and losses remain in other comprehensive income until earnings are impacted by the forecasted transactions. Changes in the derivative contracts’ fair value subsequent to the discontinuance of hedge accounting are reported in earnings. We re-designate certain of these hedging relationships as the expected effectiveness improves to required levels. Energy Commodity Price Risk Management As of September 30, 2015 , 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 (23.0 ) MMBbl Crude oil basis (9.4 ) MMBbl Natural gas fixed price (41.2 ) Bcf Natural gas basis (16.7 ) Bcf Derivatives not designated as hedging contracts Crude oil fixed price (1.8 ) MMBbl Crude oil basis (1.7 ) MMBbl Natural gas fixed price (20.6 ) Bcf Natural gas basis (15.0 ) Bcf NGL and other fixed price (1.9 ) MMBbl As of September 30, 2015 , 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 2018. We have additional economic hedge contracts not designated as accounting hedges through December 2019. Interest Rate Risk Management As of September 30, 2015 and December 31, 2014, we had a combined notional principal amount of $9,700 million and $9,200 million , respectively, of fixed-to-variable interest rate swap agreements, effectively converting the interest expense associated with certain series of senior notes from fixed rates to variable rates based on an interest rate of London Interbank Offered Rate ( LIBOR) plus a spread. All of our swap agreements have termination dates that correspond to the maturity dates of the related series of senior notes and, as of September 30, 2015 , 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 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) $ 347 $ 309 $ (33 ) $ (34 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 233 6 (4 ) — Subtotal 580 315 (37 ) (34 ) Interest rate swap agreements Fair value of derivative contracts/(Other current liabilities) 153 143 — — Deferred charges and other assets/(Other long-term liabilities and deferred credits) 361 260 (1 ) (53 ) Subtotal 514 403 (1 ) (53 ) Cross-currency swap agreements Fair value of derivative contracts/(Other current liabilities) — — (14 ) — Deferred charges and other assets/(Other long-term liabilities and deferred credits) 1 — (21 ) — Subtotal 1 — (35 ) — Total 1,095 718 (73 ) (87 ) Derivatives not designated as hedging contracts Natural gas, crude, NGL and other derivative contracts Fair value of derivative contracts/(Other current liabilities) 23 73 (4 ) (2 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 13 196 (1 ) — Subtotal 36 269 (5 ) (2 ) Power derivative contracts Fair value of derivative contracts/(Other current liabilities) 6 10 (30 ) (57 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) — — — (16 ) Subtotal 6 10 (30 ) (73 ) Total 42 279 (35 ) (75 ) Total derivatives $ 1,137 $ 997 $ (108 ) $ (162 ) 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, 2015 2014 2015 2014 Interest rate swap agreements Interest, net $ 251 $ (25 ) $ 163 $ 87 Hedged fixed rate debt Interest, net $ (283 ) $ 25 $ (166 ) $ (87 ) 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, 2015 2014 2015 2014 2015 2014 Energy commodity derivative contracts $ 119 $ 121 Revenues—Natural gas sales $ 4 $ 9 Revenues—Natural gas sales $ — $ — Revenues—Product sales and other 60 (5 ) Revenues—Product sales and other (6 ) 26 Costs of sales (2 ) (2 ) Costs of sales — — Interest rate swap agreements (4 ) — Interest, net (1 ) (1 ) Interest, net — — Cross-currency swap (11 ) — Other, net 2 — Total $ 104 $ 121 Total $ 63 $ 1 Total $ (6 ) $ 26 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, 2015 2014 2015 2014 2015 2014 Energy commodity derivative contracts $ 72 $ (10 ) Revenues—Natural gas sales $ 29 $ — Revenues—Natural gas sales $ — $ — Revenues—Product sales and other 161 (30 ) Revenues—Product sales and other 4 (6 ) Costs of sales (21 ) 4 Costs of sales — — Interest rate swap agreements (6 ) (10 ) Interest, net (2 ) (3 ) Interest, net — — Cross-currency swap (22 ) — Other, net 25 — Total $ 44 $ (20 ) Total $ 192 $ (29 ) Total $ 4 $ (6 ) _________ (a) We expect to reclassify an approximate $161 million gain associated with cash flow hedge price risk management activities included in our accumulated other comprehensive loss balances as of September 30, 2015 into earnings during the next twelve months (when the associated forecasted sales and purchases are also expected to occur), however, actual amounts reclassified into earnings could vary materially as a result of changes in market prices. (b) Amounts reclassified were the result of the hedged forecasted transactions actually affecting earnings (i.e., when the forecasted sales and purchases actually occurred). Derivatives not designated as accounting hedges Location Gain/(loss) recognized in income on derivatives Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Energy commodity derivative contracts Revenues—Natural gas sales $ 6 $ 4 $ 9 $ (12 ) Revenues—Product sales and other 169 5 173 6 Costs of sales — (3 ) — 4 Other expense (income) — — — (2 ) Total(a) $ 175 $ 6 $ 182 $ (4 ) _______ (a) For the three and nine months ended September 30, 2015 , includes approximate gains of $19 million and $21 million , respectively, associated with natural gas, crude and NGL derivative contract settlements. Credit Risks In conjunction with the purchase of exchange-traded derivative contracts or when the market value of our derivative contracts with specific counterparties exceeds established limits, we are required to provide collateral to our counterparties, which may include posting letters of credit or placing cash in margin accounts. As of both September 30, 2015 and December 31, 2014 , we had $2 million and $20 million , respectively, of outstanding letters of credit supporting our commodity price risk management program. As of September 30, 2015 and December 31, 2014, we had cash margins of $14 million and $47 million posted as collateral and $32 million and $13 million , respectively, held as collateral. 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, 2015 , 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, 2014 $ 327 $ (108 ) $ (236 ) $ (17 ) Other comprehensive loss before reclassifications 44 (170 ) 7 (119 ) Amounts reclassified from accumulated other comprehensive loss (192 ) — — (192 ) Net current-period other comprehensive loss (148 ) (170 ) 7 (311 ) Balance as of September 30, 2015 $ 179 $ (278 ) $ (229 ) $ (328 ) 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, 2013 $ (3 ) $ 2 $ (23 ) $ (24 ) Other comprehensive loss before reclassifications (8 ) (31 ) 2 (37 ) Amounts reclassified from accumulated other comprehensive loss 11 — — 11 Net current-period other comprehensive loss 3 (31 ) 2 (26 ) Balance as of September 30, 2014 $ — $ (29 ) $ (21 ) $ (50 )

Fair Value (Notes)

Fair Value (Notes)	9 Months Ended
	Sep. 30, 2015
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, 2015 Energy commodity derivative contracts(a) $ 54 $ 561 $ 7 $ 622 $ (40 ) $ (32 ) $ 550 Interest rate swap agreements $ — $ 514 $ — $ 514 $ (1 ) $ — $ 513 Cross-currency swap agreements $ — $ 1 $ — $ 1 $ (1 ) $ — $ — As of December 31, 2014 Energy commodity derivative contracts(a) $ 49 $ 533 $ 12 $ 594 $ (46 ) $ (13 ) $ 535 Interest rate swap agreements $ — $ 403 $ — $ 403 $ (44 ) $ — $ 359 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, 2015 Energy commodity derivative contracts(a) $ (9 ) $ (33 ) $ (30 ) $ (72 ) $ 40 $ 14 $ (18 ) Interest rate swap agreements $ — $ (1 ) $ — $ (1 ) $ 1 $ — $ — Cross-currency swap agreements $ — $ (35 ) $ — $ (35 ) $ 1 $ — $ (34 ) As of December 31, 2014 Energy commodity derivative contracts(a) $ (25 ) $ (11 ) $ (73 ) $ (109 ) $ 46 $ 47 $ (16 ) Interest rate swap agreements $ — $ (53 ) $ — $ (53 ) $ 44 $ — $ (9 ) _______ (a) Level 1 consists primarily of NYMEX natural gas futures. Level 2 consists primarily of OTC West Texas Intermediate swaps and options. Level 3 consists primarily of power derivative contracts. (b) Cash margin deposits held by us associated with our energy commodity contract positions and OTC swap agreements and reported within “Other current liabilities” on our accompanying consolidated balance sheets. (c) Cash margin deposits posted by us associated with our energy commodity contract positions and OTC swap agreements and reported within “Other current assets” on our accompanying consolidated balance sheets. The table below provides a summary of changes in the fair value of our Level 3 energy commodity derivative contracts (in millions): Significant unobservable inputs (Level 3) Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Derivatives-net asset (liability) Beginning of Period $ (37 ) $ (116 ) $ (61 ) $ (110 ) Total gains or (losses) Included in earnings (1 ) 14 (1 ) — Included in other comprehensive loss — 10 — — Settlements 15 13 39 31 End of Period $ (23 ) $ (79 ) $ (23 ) $ (79 ) 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 $ — $ 16 $ 2 $ (4 ) As of September 30, 2015 , our Level 3 derivative assets and liabilities consisted primarily of power derivative contracts, where a significant portion of fair value is calculated from underlying market data that is not readily observable. The derived values use industry standard methodologies that may consider the historical relationships among various commodities, modeled market prices, time value, volatility factors and other relevant economic measures. The use of these inputs results in management’s best estimate of fair value. Fair Value of Financial Instruments The estimated fair value of our outstanding debt balances (the carrying amounts below include both short-term and long-term and debt fair value adjustments), is disclosed below (in millions): September 30, 2015 December 31, 2014 Carrying value Estimated fair value Carrying value Estimated fair value Total debt $ 44,633 $ 41,136 $ 42,814 $ 43,582 We used Level 2 input values to measure the estimated fair value of our outstanding debt balances as of both September 30, 2015 and December 31, 2014 .

Reportable Segments (Notes)

Reportable Segments (Notes)	9 Months Ended
	Sep. 30, 2015
Revenues from External Customers and Long-Lived Assets [Line Items]
Reportable Segments	Reportable Segments Financial information by segment follows (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Revenues Natural Gas Pipelines Revenues from external customers $ 2,176 $ 2,745 $ 6,444 $ 7,766 Intersegment revenues 8 6 16 11 CO 2 517 508 1,316 1,445 Terminals Revenues from external customers 469 433 1,395 1,244 Intersegment revenues — — 1 1 Products Pipelines Revenues from external customers 467 520 1,388 1,578 Intersegment revenues — — 1 — Kinder Morgan Canada 68 73 193 210 Other — 3 3 5 Total segment revenues 3,705 4,288 10,757 12,260 Other revenues 10 9 28 27 Less: Total intersegment revenues (8 ) (6 ) (18 ) (12 ) Total consolidated revenues $ 3,707 $ 4,291 $ 10,767 $ 12,275 Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Segment Earnings Before DD&A(a) Natural Gas Pipelines $ 993 $ 1,182 $ 2,936 $ 3,207 CO 2 29 388 605 1,083 Terminals 249 249 798 692 Products Pipelines 288 222 811 632 Kinder Morgan Canada 42 50 120 138 Other (9 ) 6 (55 ) 13 Total segment earnings before DD&A 1,592 2,097 5,215 5,765 DD&A expense (617 ) (520 ) (1,725 ) (1,518 ) Amortization of excess cost of equity investments (13 ) (12 ) (39 ) (33 ) Other revenues 10 9 28 27 General and administrative expense (160 ) (135 ) (540 ) (461 ) Interest expense, net of unallocable interest income (539 ) (431 ) (1,525 ) (1,325 ) Unallocable income tax expense (90 ) (229 ) (470 ) (578 ) Total consolidated net income $ 183 $ 779 $ 944 $ 1,877 September 30, December 31, Assets Natural Gas Pipelines $ 54,725 $ 52,532 CO 2 4,906 5,227 Terminals 9,212 8,850 Products Pipelines 8,471 7,179 Kinder Morgan Canada 1,452 1,593 Other 427 455 Total segment assets 79,193 75,836 Corporate assets(b) 6,438 7,157 Assets held for sale 46 56 Total consolidated assets $ 85,677 $ 83,049 _______ (a) We evaluate performance based on each segment’s earnings before DD&A. Amounts include revenues, earnings from equity investments, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other expense (income), net, and losses on impairments and disposals of long-lived assets, net and equity investments. 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, 2015
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, 2015 2014 2015 2014 Income tax expense $ 108 $ 246 $ 521 $ 624 Effective tax rate 37.1 % 24.0 % 35.6 % 25.0 % Income tax expense for the three months ended September 30, 2015 is approximately $108 million resulting in an effective tax rate of 37.1% , as compared with $246 million income tax expense and an effective tax rate of 24.0% , for the same period of 2014 . 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 Florida Gas Pipeline (Citrus) and adjustments to our income tax reserve for uncertain tax positions. Income tax expense for the nine months ended September 30, 2015 is approximately $521 million resulting in an effective tax rate of 35.6% , as compared with $624 million income tax expense and an effective tax rate of 25.0% , for the same period of 2014 . 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, 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. The effective tax rate for the three months ended September 30, 2014 is lower than the statutory federal rate of 35% primarily due to the net effect of consolidating KMP’s and EPB’s income tax provisions and dividend-received deductions from our investment in Citrus, partially offset by state income taxes. The effective tax rate for the nine months ended September 30, 2014 is lower than the statutory federal rate of 35% primarily due to the net effect of consolidating KMP’s and EPB’s income tax provisions and dividend-received deductions from our investment in Citrus. These decreases are partially offset by state income taxes and the amortization of the deferred charge recorded as a result of the drop-downs of TGP, EPNG, and the midstream assets. As of September 30, 2015 , the total amount of unrecognized tax benefits relating to uncertain tax positions is $156 million , a decrease of $33 million from the December 31, 2014 balance of $189 million . This $33 million decrease in unrecognized tax benefits resulted primarily from the settlement of a claim for refund and certain statute of limitations expiration related to state income taxes.

Litigation, Environmental and O

Litigation, Environmental and Other Contingencies (Notes)	9 Months Ended
	Sep. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
Litigation, Environmental and Other Contingencies	Litigation, Environmental, Other Contingencies and Commitments We and our subsidiaries are parties to various legal, regulatory and other matters arising from the day-to-day operations of our businesses that may result in claims against the Company. Although no assurance can be given, we believe, based on our experiences to date and taking into account established reserves, that the ultimate resolution of such items will not have a material adverse impact on our business, financial position, results of operations or dividends to our shareholders. We believe we have meritorious defenses to the matters to which we are a party and intend to vigorously defend the Company. When we determine a loss is probable of occurring and is reasonably estimable, we accrue an undiscounted liability for such contingencies based on our best estimate using information available at that time. If the estimated loss is a range of potential outcomes and there is no better estimate within the range, we accrue the amount at the low end of the range. We disclose contingencies where an adverse outcome may be material, or in the judgment of management, we conclude the matter should otherwise be disclosed. Federal Energy Regulatory Commission Proceedings SFPP The tariffs and rates charged by SFPP are subject to a number of ongoing proceedings at the FERC, including the complaints and protests of various shippers. In general, these complaints and protests allege the rates and tariffs charged by SFPP are not just and reasonable under the Interstate Commerce Act (ICA). In late June of 2014, certain shippers filed additional complaints with the FERC (docketed at OR14-35 and OR14-36) challenging SFPP’s adjustments to its rates in 2012 and 2013 for inflation under the FERC’s indexing regulations. If the shippers are successful in proving these claims or other of their claims, they are entitled to seek reparations (which may reach back up to two years prior to the filing of their complaints) or refunds of any excess rates paid, and SFPP may be required to reduce its rates going forward. These proceedings tend to be protracted, with decisions of the FERC often appealed to the federal courts. The issues involved in these proceedings include, among others, whether indexed rate increases are justified, and the appropriate level of return and income tax allowance we may include in our rates. With respect to all of the SFPP proceedings at the FERC, we estimate that the shippers are seeking approximately $20 million in annual rate reductions and approximately $119 million in refunds. However, applying the principles of several recent FERC decisions in SFPP cases, as applicable, to pending cases would result in substantially lower rate reductions and refunds than those sought by the shippers. We do not expect refunds in these cases to have an impact on our dividends to our shareholders. EPNG The tariffs and rates charged by EPNG are subject to two ongoing FERC proceedings (the “2008 rate case” and the “2010 rate case”). With respect to the 2008 rate case, the FERC issued its decision (Opinion 517-A) in July 2015. 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) on October 17, 2013. EPNG sought rehearing on certain issues in Opinion 528. As required by Opinion 528, EPNG filed revised pro forma recalculated rates consistent with the terms of Opinion 528. The FERC also required an Administrative Law Judge (ALJ) to conduct an additional hearing concerning one of the issues in Opinion 528. On September 17, 2014, the ALJ issued an initial decision finding certain shippers qualify for lower rates under a prior settlement. EPNG has sought FERC review of the ALJ decision. EPNG believes it has an appropriate reserve related to the findings in Opinions 517-A and 528 for both rate cases. We do not expect refunds in these cases to have an impact on our dividends to our shareholders. 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. Judgment was entered by the Superior Court on May 29, 2012 and 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 rehearing with the Court of Appeals, and a subsequent petition for review to the California Supreme Court, both of which were denied. On April 23, 2015, 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 the U.S. District Court for the Northern District of California (Case No. 01842) 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 have been filed in federal courts by landowners in Nevada, Arizona, New Mexico and Texas. 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 liability, 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. 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 case was removed to the United States District Court for the Southern District of Texas. The suit arises from the sale by TGP of the Cameron System in Louisiana to Kinetica Partners, LLC on September 1, 2013. Plains alleges that defendants breached a straddle agreement requiring that gas on the Cameron System be committed to Plains’ Grand Chenier gas-processing facility, that requisite daily volume reports were not provided, that TGP improperly assigned its obligations under the straddle agreement to Kinetica, and that defendants interfered with Plains’ contracts with producers. The petition alleges damages of at least $100 million . Under the Amended and Restated Purchase and Sale Agreement with Kinetica, Kinetica is obligated to defend and indemnify TGP in connection with the gas commitment and reporting claims. After agreeing initially to defend and indemnify TGP against such claims, Kinetica withdrew its defense and disputed its indemnity obligation. We intend to vigorously defend the suit and pursue Kinetica, if necessary, for indemnity and costs of defense. Brinckerhoff v. El Paso Pipeline GP Company, LLC., et al. In December 2011 ( Brinckerhoff I ), March 2012, ( Brinckerhoff II ), May 2013 ( Brinckerhoff III ) and June 2014 ( Brinckerhoff IV), derivative lawsuits were filed in Delaware Chancery Court against El Paso 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, 2014, we filed a motion to dismiss the remaining claims in Brinckerhoff II based upon our acquisition of all of the outstanding common units of EPB. Oral argument on the motion was held on September 3, 2015 and we await the Court’s decision. In the event our motion to dismiss is denied, we will consider an appeal to the Delaware Supreme Court once a final decision is issued. 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. Although damages in excess of $140 million have been alleged in total against all defendants in one of the remaining lawsuits where a damage number is provided, there remains significant uncertainty regarding the validity of the causes of action, the damages asserted and the level of damages, if any, that may be allocated to us. Therefore, our costs and legal exposure related to the remaining outstanding lawsuits and claims are not currently determinable. Kinder Morgan, Inc. Corporate Reorganization Litigation Certain unitholders of KMP and EPB filed five putative class action lawsuits in the Court of Chancery of the State of Delaware in connection with the Merger Transactions, which the Court consolidated under the caption In re Kinder Morgan, Inc. Corporate Reorganization Litigation (Consolidated Case No. 10093-VCL). The plaintiffs originally sought to enjoin one or more of the proposed Merger Transactions, which relief the Court denied on November 5, 2014. On December 12, 2014, the plaintiffs filed a Verified Second Consolidated Amended Class Action Complaint, which purports to assert claims on behalf of both the former EPB unitholders and the former KMP unitholders. The EPB plaintiff 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 allege that (i) KMR, KMGP, and individual defendants breached duties under the KMP partnership agreement, including the implied duty of good faith and fair dealing, by entering into the KMP Transaction and by failing to adequately disclose material facts related to the transaction; (ii) KMI aided and abetted such breach; and (iii) KMI, KMP, KMR, P Merger Sub LLC, and individual defendants tortiously interfered with the rights of the plaintiffs and the putative class under the KMP partnership agreement by causing KMGP to breach its duties under the KMP partnership agreement. The complaint seeks declaratory relief that the transactions were unlawful and unenforceable, reformation, rescission, rescissory or compensatory damages, interest, and attorneys’ and experts’ fees and costs. On December 30, 2014, the defendants moved to dismiss the complaint. 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). The plaintiffs are only appealing the dismissal of claims brought against defendants KMGP, Ted A. Gardner, Gary L. Hultquist, and Perry M. Waughtal and not those asserted against KMI, P. Merger Sub LLC, Richard D. Kinder, Steven J. Kean, KMP and KMR. The defendants believe the allegations against them lack merit, and they intend to vigorously defend these lawsuits. Kinder Morgan Energy Partners, L.P. Capex Litigation Putative class action and derivative complaints were filed in the Court of Chancery in the State of Delaware against defendants KMI, KMGP and nominal defendant KMEP on February 5, 2014 and March 27, 2014 captioned Slotoroff v. Kinder Morgan, Inc., Kinder Morgan G.P., Inc. et al (Case No. 9318) and Burns et al v. Kinder Morgan, Inc., Kinder Morgan G.P., Inc. et al (Case No. 9479) respectively. The cases were consolidated on April 8, 2014 (Consolidated Case No. 9318). The consolidated suit seeks to assert claims both individually and on behalf of a putative class consisting of all public holders of KMEP units during the period of February 5, 2011 through the date of the filing of the complaints. The suit alleges direct and derivative causes of action for breach of the partnership agreement, breach of the duty of good faith and fair dealing, aiding and abetting, and tortious interference. Among other things, the suit alleges that defendants made a bad faith allocation of capital expenditures to expansion capital expenditures rather than maintenance capital expenditures for the alleged purpose of “artificially” inflating KMEP’s distributions and growth rate. The suit alleges that hundreds of millions of dollars were distributed improperly and seeks disgorgement of any distributions to KMGP, KMI and any related entities, beyond amounts that would have been distributed in accordance with a “good faith” allocation of maintenance capital expenses, together with other unspecified monetary damages including punitive damages and attorney fees. On August 14, 2015, the parties entered into a Stipulation and Agreement of Settlement pursuant to which defendants will pay $27.5 million (the “Settlement Fund”) to a class of former holders of KMEP common units, and all claims asserted in the consolidated suit will be released. The settlement is subject to court approval following notice to the putative class members. If the court approves the settlement, the final judgment will also include a release of all claims asserted in the Walker litigation discussed below. Plaintiffs’ counsel is seeking an award of attorneys’ fees and litigation expenses from the Court which would be paid from the Settlement Fund. The Court has scheduled a hearing for November 23, 2015 to consider the proposed settlement as well as Plaintiff counsel’s request for fees and expenses. All of the defendants believe they acted properly, in good faith, and in a manner consistent with any and all legal, contractual and equitable duties and obligations, including those contained in the Limited Partnership Agreement. We are entering into this settlement solely to avoid the substantial burden, expense, inconvenience and distraction of continued litigation and to resolve each of the released claims. Walker v. Kinder Morgan, Inc., Kinder Morgan G.P., Inc. et al. On March 6, 2014, a putative class action and derivative complaint was filed in the District Court of Harris County, Texas (Case No. 2014-11872 in the 215th Judicial District) against KMI, KMGP, KMR, Richard D. Kinder, Steven J. Kean, Ted A. Gardner, Gary L. Hultquist, Perry M. Waughtal and nominal defendant KMEP. The suit was filed by Kenneth Walker, a purported unit holder of KMEP, and alleges derivative causes of action for alleged violation of duties owed under the partnership agreement, breach of the implied covenant of good faith and fair dealing, “abuse of control” and “gross mismanagement” in connection with the calculation of distributions and allocation of capital expenditures to expansion capital expenditures and maintenance capital expenditures. The suit seeks unspecified money damages, interest, punitive damages, attorney and expert fees, costs and expenses, unspecified equitable relief, and demands a trial by jury. By agreement of the parties, the case is stayed and all claims asserted in this action will be released with prejudice if the Delaware Court approves the settlement in the Kinder Morgan Energy Partners, L.P. Capex Litigation described above. Pipeline Integrity and Releases From time to time, despite our best efforts, our pipelines experience leaks and ruptures. These leaks and ruptures may cause explosions, fire, and damage to the environment, damage to property and/or personal injury or death. In connection with these incidents, we may be sued for damages caused by an alleged failure to properly mark the locations of our pipelines and/or to properly maintain our pipelines. Depending upon the facts and circumstances of a particular incident, state and federal regulatory authorities may seek civil and/or criminal fines and penalties. General As of September 30, 2015 and December 31, 2014, our total reserve for legal matters was $441 million and $400 million , respectively. The reserve primarily relates to various claims from regulatory rate and right-of-way proceedings arising in our products and natural gas pipeline segments and certain corporate matters. The overall increase in the reserve from December 31, 2014 is related to certain legal developments during the nine months ended September 30, 2015 on corporate matters. Environmental Matters We and our subsidiaries are subject to environmental cleanup and enforcement actions from time to time. In particular, CERCLA generally imposes joint and several liability for cleanup and enforcement costs on current and predecessor owners and operators of a site, among others, without regard to fault or the legality of the original conduct, subject to the right of a liable party to establish a “reasonable basis” for apportionment of costs. Our operations are also subject to federal, state and local laws and regulations relating to protection of the environment. Although we believe our operations are in substantial compliance with applicable environmental law and regulations, risks of additional costs and liabilities are inherent in pipeline, terminal and CO 2 field and oil field operations, and there can be no assurance that we will not incur significant costs and liabilities. Moreover, it is possible that other developments, such as increasingly stringent environmental laws, regulations and enforcement policies under the terms of authority of those laws, and claims for damages to property or persons resulting from our operations, could result in substantial costs and liabilities to us. We are currently involved in several governmental proceedings involving alleged violations of environmental and safety regulations. As we receive notices of non-compliance, we attempt to negotiate and settle such matters where appropriate. We do not believe that these alleged violations will have a material adverse effect on our business, financial position, results of operations or dividends to our shareholders. We are also currently involved in several governmental proceedings involving groundwater and soil remediation efforts under administrative orders or related state remediation programs. We have established a reserve to address the costs associated with the cleanup. In addition, we are involved with and have been identified as a potentially responsible party in several federal and state superfund sites. Environmental reserves have been established for those sites where our contribution is probable and reasonably estimable. In addition, we are from time to time involved in civil proceedings relating to damages alleged to have occurred as a result of accidental leaks or spills of refined petroleum products, NGL, natural gas and CO 2 . Portland Harbor Superfund Site, Willamette River, Portland, Oregon In December 2000, the EPA issued General Notice letters to potentially responsible parties including GATX Terminals Corporation (n/k/a KMLT). At that time, GATX owned two liquids terminals along the lower reach of the Willamette River, an industrialized area known as Portland Harbor. Portland Harbor is listed on the National Priorities List and is designated as a Superfund Site under CERCLA. A group of potentially responsible parties formed what is known as the Lower Willamette Group (LWG), of which KMLT is a non-voting member and pays a minimal fee to be part of the group. The LWG agreed to conduct the remedial investigation and feasibility study (RI/FS) leading to the proposed remedy for cleanup of the Portland Harbor site. Once the EPA determines the cleanup remedy from the remedial investigations and feasibility studies conducted during the last decade at the site, it will issue a Record of Decision (ROD). Currently, 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. We expect the RI/FS process to conclude in 2016, after which the EPA is expected to develop a proposed plan leading to a ROD targeted for 2017. The allocation process will follow the issuance of the ROD with an expected completion date of 2017. We anticipate that the cleanup activities will begin within two years after the ROD is issued. Roosevelt Irrigation District v. Kinder Morgan G.P., Inc., Kinder Morgan Energy Partners, L.P. , U.S. District Court, Arizona The Roosevelt Irrigation District sued KMGP, KMEP and others under CERCLA for alleged contamination of the water purveyor’s wells. The First Amended Complaint sought $175 million in damages against approximately 70 defendants. On August 6, 2013 plaintiffs filed their Second Amended Complaint seeking monetary damages in unspecified amounts and reducing the number of defendants to 26 including KMEP and SFPP. The claims now presented against KMEP and SFPP are related to alleged releases from a specific parcel within the SFPP Phoenix Terminal and the alleged impact of such releases on water wells owned by the plaintiffs and located in the vicinity of the Terminal. We have filed an answer, general denial, and affirmative defenses in response to the Second Amended Complaint. Mission Valley Terminal Lawsuit In August 2007, the City of San Diego, on its own behalf and purporting to act on behalf of the People of the State of California, filed a lawsuit against us and several affiliates seeking injunctive relief and unspecified damages allegedly resulting from hydrocarbon and methyl tertiary butyl ether (MTBE) impacted soils and groundwater beneath the City’s stadium property in San Diego arising from historic operations at the Mission Valley terminal facility. The case was filed in the Superior Court of California, San Diego County (Case No. 37-2007-00073033). On September 26, 2007, we removed the case to the U.S. District Court, Southern District of California (Case No. 07CV1883WCAB). The City disclosed in discovery that it is seeking approximately $170 million in damages for alleged lost value/lost profit from the redevelopment of the City’s property and alleged lost use of the water resources underlying the property. Later, in 2010, the City amended its initial disclosures to add claims for restoration of the site as well as a number of other claims that increased its claim for damages to approximately $365 million . On November 29, 2012, the Court issued a Notice of Tentative Rulings on the parties’ summary adjudication motions. The Court tentatively granted our partial motions for summary judgment on the City’s claims for water and real estate damages and the State’s claims for violations of California Business and Professions Code § 17200, tentatively denied the City’s motion for summary judgment on its claims of liability for nuisance and trespass, and tentatively granted our cross motion for summary judgment on such claims. On January 25, 2013, the Court rendered judgment in favor of all defendants on all claims asserted by the City. On February 20, 2013, the City of San Diego filed a notice of appeal to the U.S. Court of Appeals for the Ninth Circuit. 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 the District Court’s summary judgment decision in our favor on the City’s remaining claims, and also reversed the District Court’s decision to exclude the City’s expert testimony. On July 14, 2015, the Court of Appeals denied our petition for rehearing and issued a mandate returning the case to the U.S. District Court. We intend to pursue dispositive motions before the U.S. District Court and continue to vigorously defend the case. This site remains under the regulatory oversight and order of the California Regional Water Quality Control Board (RWQCB). SFPP has completed the soil and groundwater remediation at the City of San Diego’s stadium property site and conducted quarterly sampling and monitoring through 2014 as part of the compliance evaluation required by the RWQCB. SFPP expects the RWQCB to issue a notice of no further action with respect to the stadium property site. 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 will conduct a radiological assessment of the surface of the mines. On September 3, 2014, EPNG filed a complaint in the U.S. District Court for the District of Arizona (Case No. 3:14-08165-DGC) seeking cost recovery and contribution from the applicable federal government agencies toward the cost of environmental activities associated with the mines, given the pervasive control of such federal agencies over all aspects of the nuclear weapons program. 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. Lower Passaic Rive

Recent Accounting Pronouncement

Recent Accounting Pronouncements (Notes)	9 Months Ended
	Sep. 30, 2015
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 No. 2014-09, “ Revenue from Contracts with Customers (Topic 606).” This ASU is designed to create greater comparability for financial statement users across industries and jurisdictions. The provisions of ASU No. 2014-09 include a five-step process by which entities will recognize revenue to depict the transfer of goods or services to customers in amounts that reflect the payment to which an entity expects to be entitled in exchange for those goods or services. The standard also will require enhanced disclosures, provide more comprehensive guidance for transactions such as service revenue and contract modifications, and enhance guidance for multiple-element arrangements. ASU No. 2014-09 will be effective for us January 1, 2018. Early adoption is permitted for the interim periods within the adoption year. We are currently reviewing the effect of ASU No. 2014-09 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. ASU No. 2015-02 will be effective for us January 1, 2016. We are currently reviewing the effect of ASU No. 2015-02. 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 January 1, 2017. We are currently reviewing the effect of ASU No. 2015-11.

Guarantee of Securities of Subs

Guarantee of Securities of Subsidiaries (Notes)	9 Months Ended
	Sep. 30, 2015
Guarantee of Securities of Subsidiaries [Abstract]
Guarantees [Text Block]	Guarantee of Securities of Subsidiaries KMI, along with its direct and indirect subsidiaries KMP and Copano, are issuers of certain public debt securities. After the completion of the Merger Transactions, KMI, KMP, Copano and substantially all of KMI’s wholly owned domestic subsidiaries, entered into a cross guarantee agreement whereby each party to the agreement unconditionally guarantees, jointly and severally, the payment of specified indebtedness of each other party to the agreement. Accordingly, with the exception of certain subsidiaries identified as Subsidiary Non-Guarantors, the parent issuer, subsidiary issuers and other subsidiaries are all guarantors of each series of public debt. As a result of the cross guarantee agreement, a holder of any of the guaranteed public debt securities issued by KMI, KMP or Copano are in the same position with respect to the net assets, income and cash flows of KMI and the Subsidiary Issuers and Guarantors. The only amounts that are not available to the holders of each of the guaranteed public debt securities to satisfy the repayment of such securities are the net assets, income and cash flows of the Subsidiary Non-Guarantors. In lieu of providing separate financial statements for each subsidiary issuer and guarantor, we have included the accompanying condensed consolidating financial statements based on Rule 3-10 of the SEC’s Regulation S-X. We have presented each of the parent and subsidiary issuers in separate columns in this single set of condensed consolidating financial statements. Excluding fair value adjustments, as of September 30, 2015 , Parent Issuer and Guarantor, Subsidiary Issuer and Guarantor-KMP, Subsidiary Issuer and Guarantor-Copano, and Subsidiary Guarantors had $13,853 million , $20,360 million , $332 million , and $7,222 million of Guaranteed Notes outstanding, respectively. Included in the Subsidiary Guarantors debt balance as presented in the accompanying September 30, 2015 condensed consolidating balance sheets are approximately $177 million of capitalized lease debt that is not subject to the cross guarantee agreement. The accounts within the Parent Issuer and Guarantor, Subsidiary Issuer and Guarantor-KMP, Subsidiary Issuer and Guarantor-Copano, Subsidiary Guarantors and Subsidiary Non-Guarantors are presented using the equity method of accounting for investments in subsidiaries, including subsidiaries that are guarantors and non-guarantors, for purposes of these condensed consolidating financial statements only. These intercompany investments and related activity eliminate in consolidation and are presented separately in the accompanying balance sheets and statements of income and cash flows. A significant amount of each Issuers’ income and cash flow is generated by its respective subsidiaries. As a result, the funds necessary to meet its debt service and/or guarantee obligations are provided in large part by distributions or advances it receives from its respective subsidiaries. We utilize a centralized cash pooling program among our majority-owned and consolidated subsidiaries, including the Subsidiary Issuers and Guarantors and Subsidiary Non-Guarantors. The following Condensed Consolidating Statements of Cash Flows present the intercompany loan and distribution activity, as well as cash collection and payments made on behalf of our subsidiaries, as cash activities. On January 1, 2015, EPB and its subsidiary, EPPOC merged with and into KMP with KMP surviving the merger. As a result of such merger, all of the wholly owned subsidiaries of EPB became wholly owned subsidiaries of KMP and effective January 1, 2015, EPB is no longer a Subsidiary Issuer and Guarantor. The condensed consolidating financial information reflects this transaction for all periods presented below. Effective November 26, 2014, the Merger Transactions close date, KMR merged into KMI. Therefore, for all periods presented KMR’s financial statement balances and activities are reflected within the Parent Issuer and Guarantor column. Condensed Consolidating Statements of Income and Comprehensive Income for the Three Months Ended September 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 9 $ — $ — $ 3,289 $ 421 $ (12 ) $ 3,707 Operating costs, expenses and other Costs of sales — — — 1,007 98 1 1,106 Depreciation, depletion and amortization 6 — — 508 103 — 617 Other operating expenses 16 1 (2 ) 1,100 161 (13 ) 1,263 Total operating costs, expenses and other 22 1 (2 ) 2,615 362 (12 ) 2,986 Operating (loss) income (13 ) (1 ) 2 674 59 — 721 Other income (expense) Earnings from consolidated subsidiaries 366 484 48 376 10 (1,284 ) — Earnings from equity investments — — — 114 — — 114 Interest, net (155 ) 23 (12 ) (381 ) (15 ) — (540 ) Amortization of excess cost of equity investments and other, net — — — (5 ) 1 — (4 ) Income before income taxes 198 506 38 778 55 (1,284 ) 291 Income tax expense (12 ) (2 ) — (93 ) (1 ) — (108 ) Net income 186 504 38 685 54 (1,284 ) 183 Net loss attributable to noncontrolling interests — — — — — 3 3 Net income attributable to controlling interests $ 186 $ 504 $ 38 $ 685 $ 54 $ (1,281 ) $ 186 Net Income $ 186 $ 504 $ 38 $ 685 $ 54 $ (1,284 ) $ 183 Total other comprehensive loss (37 ) (42 ) — (24 ) (125 ) 191 (37 ) Comprehensive income (loss) 149 462 38 661 (71 ) (1,093 ) 146 Comprehensive loss attributable to noncontrolling interests — — — — — 3 3 Comprehensive income (loss) attributable to controlling interests $ 149 $ 462 $ 38 $ 661 $ (71 ) $ (1,090 ) $ 149 Condensed Consolidating Statements of Income and Comprehensive Income for the Three Months Ended September 30, 2014 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 9 $ — $ — $ 3,649 $ 637 $ (4 ) $ 4,291 Operating costs, expenses and other Costs of sales — — — 1,510 124 8 1,642 Depreciation, depletion and amortization 5 — — 423 92 — 520 Other operating expenses 4 2 9 667 127 (12 ) 797 Total operating costs, expenses and other 9 2 9 2,600 343 (4 ) 2,959 Operating (loss) income — (2 ) (9 ) 1,049 294 — 1,332 Other income (expense) Earnings from consolidated subsidiaries 581 1,126 59 640 487 (2,893 ) — Earnings from equity investments — — — 108 (1 ) — 107 Interest, net (111 ) (28 ) (13 ) (261 ) (19 ) — (432 ) Amortization of excess cost of equity investments and other, net — — — (6 ) 24 — 18 Income before income taxes 470 1,096 37 1,530 785 (2,893 ) 1,025 Income tax expense (57 ) (3 ) — (21 ) (165 ) — (246 ) Net income 413 1,093 37 1,509 620 (2,893 ) 779 Net income attributable to noncontrolling interests (84 ) (44 ) — — — (322 ) (450 ) Net income attributable to controlling interests $ 329 $ 1,049 $ 37 $ 1,509 $ 620 $ (3,215 ) $ 329 Net Income $ 413 $ 1,093 $ 37 $ 1,509 $ 620 $ (2,893 ) $ 779 Total other comprehensive income (loss) 24 58 — 85 (83 ) (38 ) 46 Comprehensive income 437 1,151 37 1,594 537 (2,931 ) 825 Comprehensive income attributable to noncontrolling interests (90 ) (45 ) — — — (343 ) (478 ) Comprehensive income attributable to controlling interests $ 347 $ 1,106 $ 37 $ 1,594 $ 537 $ (3,274 ) $ 347 Condensed Consolidating Statements of Income and Comprehensive Income for the Nine Months Ended September 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 28 $ — $ — $ 9,565 $ 1,210 $ (36 ) $ 10,767 Operating costs, expenses and other Costs of sales — — — 2,997 282 2 3,281 Depreciation, depletion and amortization 16 — — 1,423 286 — 1,725 Other operating expenses 66 39 (1 ) 2,552 452 (38 ) 3,070 Total operating costs, expenses and other 82 39 (1 ) 6,972 1,020 (36 ) 8,076 Operating (loss) income (54 ) (39 ) 1 2,593 190 — 2,691 Other income (expense) Earnings from consolidated subsidiaries 1,454 2,033 20 1,510 41 (5,058 ) — Earnings from equity investments — — — 304 — — 304 Interest, net (356 ) 30 (36 ) (1,133 ) (29 ) — (1,524 ) Amortization of excess cost of equity investments and other, net — — — (13 ) 7 — (6 ) Income (loss) before income taxes 1,044 2,024 (15 ) 3,261 209 (5,058 ) 1,465 Income tax expense (96 ) (6 ) — (409 ) (10 ) — (521 ) Net income (loss) 948 2,018 (15 ) 2,852 199 (5,058 ) 944 Net loss attributable to noncontrolling interests — — — — — 4 4 Net income (loss) attributable to controlling interests $ 948 $ 2,018 $ (15 ) $ 2,852 $ 199 $ (5,054 ) $ 948 Net Income (loss) $ 948 $ 2,018 $ (15 ) $ 2,852 $ 199 $ (5,058 ) $ 944 Total other comprehensive loss (311 ) (419 ) — (525 ) (266 ) 1,210 (311 ) Comprehensive income (loss) 637 1,599 (15 ) 2,327 (67 ) (3,848 ) 633 Comprehensive loss attributable to noncontrolling interests — — — — — 4 4 Comprehensive income (loss) attributable to controlling interests $ 637 $ 1,599 $ (15 ) $ 2,327 $ (67 ) $ (3,844 ) $ 637 Condensed Consolidating Statements of Income and Comprehensive Income for the Nine Months Ended September 30, 2014 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 27 $ — $ — $ 10,784 $ 1,465 $ (1 ) $ 12,275 Operating costs, expenses and other Costs of sales — — — 4,467 393 35 4,895 Depreciation, depletion and amortization 15 — — 1,232 271 — 1,518 Other operating expenses 24 5 24 1,980 373 (36 ) 2,370 Total operating costs, expenses and other 39 5 24 7,679 1,037 (1 ) 8,783 Operating (loss) income (12 ) (5 ) (24 ) 3,105 428 — 3,492 Other income (expense) Earnings from consolidated subsidiaries 1,554 2,897 159 1,432 1,414 (7,456 ) — Earnings from equity investments — — — 307 (1 ) — 306 Interest, net (373 ) (80 ) (35 ) (766 ) (66 ) — (1,320 ) Amortization of excess cost of equity investments and other, net — — — (13 ) 36 — 23 Income before income taxes 1,169 2,812 100 4,065 1,811 (7,456 ) 2,501 Income tax expense (98 ) (8 ) — (50 ) (468 ) — (624 ) Net income 1,071 2,804 100 4,015 1,343 (7,456 ) 1,877 Net income attributable to noncontrolling interests (171 ) (156 ) — — — (650 ) (977 ) Net income attributable to controlling interests $ 900 $ 2,648 $ 100 $ 4,015 $ 1,343 $ (8,106 ) $ 900 Net Income $ 1,071 $ 2,804 $ 100 $ 4,015 $ 1,343 $ (7,456 ) $ 1,877 Total other comprehensive loss (33 ) (93 ) — (106 ) (128 ) 290 (70 ) Comprehensive income 1,038 2,711 100 3,909 1,215 (7,166 ) 1,807 Comprehensive income attributable to noncontrolling interests (164 ) (152 ) — — — (617 ) (933 ) Comprehensive income attributable to controlling interests $ 874 $ 2,559 $ 100 $ 3,909 $ 1,215 $ (7,783 ) $ 874 Condensed Consolidating Balance Sheets as of December 31, 2014 (In Millions) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI ASSETS Cash and cash equivalents $ 4 $ 15 $ — $ 17 $ 279 $ — $ 315 Other current assets - affiliates 1,868 1,335 11 11,573 403 (15,190 ) — All other current assets 397 152 3 2,547 358 (20 ) 3,437 Property, plant and equipment, net 263 — 5 29,490 8,806 — 38,564 Investments 16 1 — 5,910 109 — 6,036 Investments in subsidiaries 31,372 33,414 1,911 17,868 3,337 (87,902 ) — Goodwill 15,087 22 920 5,419 3,206 — 24,654 Notes receivable from affiliates 4,459 19,832 — 2,415 496 (27,202 ) — Deferred tax assets — — — 9,256 — (3,605 ) 5,651 Other non-current assets 258 249 — 3,772 113 — 4,392 Total assets $ 53,724 $ 55,020 $ 2,850 $ 88,267 $ 17,107 $ (133,919 ) $ 83,049 LIABILITIES AND STOCKHOLDERS’ EQUITY Liabilities Current portion of debt $ 1,486 $ 699 $ — $ 381 $ 151 $ — $ 2,717 Other current liabilities - affiliates 709 11,949 115 1,551 866 (15,190 ) — All other current liabilities 319 498 12 1,812 1,024 (20 ) 3,645 Long-term debt 11,833 20,564 386 6,599 715 — 40,097 Notes payable to affiliates 2,619 153 753 22,437 1,240 (27,202 ) — Deferred income taxes 2,099 — 2 — 1,504 (3,605 ) — Other long-term liabilities and deferred credits 583 78 2 987 514 — 2,164 Total liabilities 19,648 33,941 1,270 33,767 6,014 (46,017 ) 48,623 Stockholders’ equity Total KMI equity 34,076 21,079 1,580 54,500 11,093 (88,252 ) 34,076 Noncontrolling interests — — — — — 350 350 Total stockholders’ equity 34,076 21,079 1,580 54,500 11,093 (87,902 ) 34,426 Total liabilities and stockholders’ equity $ 53,724 $ 55,020 $ 2,850 $ 88,267 $ 17,107 $ (133,919 ) $ 83,049 Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Net cash (used in) provided by operating activities $ (2,208 ) $ 5,917 $ 81 $ 6,834 $ 193 $ (7,310 ) $ 3,507 Cash flows from investing activities Funding to affiliates (1,767 ) (7,699 ) (2 ) (7,293 ) (597 ) 17,358 — Capital expenditures (9 ) — (3 ) (2,747 ) (245 ) 5 (2,999 ) Contributions to investments (5 ) — — (62 ) (7 ) 5 (69 ) Investment in KMP (159 ) — — — — 159 — Acquisitions of assets and investments (1,709 ) — — (210 ) — — (1,919 ) Distributions from equity investments in excess of cumulative earnings 1,060 — — 113 — (992 ) 181 Other, net — 16 5 50 18 (5 ) 84 Net cash used in investing activities (2,589 ) (7,683 ) — (10,149 ) (831 ) 16,530 (4,722 ) Cash flows from financing activities Issuances of debt 12,281 — — — — — 12,281 Payments of debt (11,544 ) (300 ) — (42 ) (7 ) — (11,893 ) Funding from (to) affiliates 3,351 5,602 (81 ) 7,842 644 (17,358 ) — Debt issue costs (20 ) — — — — — (20 ) Issuances of shares 3,833 — — — — — 3,833 Cash dividends (3,084 ) — — — — — (3,084 ) Repurchases of warrants (12 ) — — — — — (12 ) Contributions from parents — 156 — 3 12 (171 ) — Contributions from noncontrolling interests — — — — — 7 7 Distributions to parents — (3,706 ) — (4,480 ) (141 ) 8,327 — Distributions to noncontrolling interests — — — — — (25 ) (25 ) Other, net — (1 ) — — — — (1 ) Net cash provided by (used in) financing activities 4,805 1,751 (81 ) 3,323 508 (9,220 ) 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 Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2014 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Net cash provided by (used in) operating activities $ 1,166 $ 2,868 $ (92 ) $ 3,897 $ 1,219 $ (5,566 ) $ 3,492 Cash flows from investing activities Funding to affiliates (197 ) (5,037 ) — (2,785 ) (1,149 ) 9,168 — Capital expenditures (11 ) — (64 ) (2,254 ) (548 ) 199 (2,678 ) Contributions to investments — (118 ) — (342 ) — 118 (342 ) Investment in KMP (34 ) — — — — 34 — Drop down assets to KMP 875 (875 ) — — — — — Acquisitions of assets and investments — — — (1,085 ) (15 ) — (1,100 ) Distributions from equity investments in excess of cumulative earnings 70 367 — 139 — (438 ) 138 Other, net — (2 ) 199 23 (60 ) (198 ) (38 ) Net cash provided by (used in) investing activities 703 (5,665 ) 135 (6,304 ) (1,772 ) 8,883 (4,020 ) Cash flows from financing activities Issuances of debt 3,258 10,141 — — — — 13,399 Payments of debt (3,804 ) (7,698 ) — (76 ) (7 ) — (11,585 ) Funding from (to) affiliates 149 2,225 (44 ) 6,344 494 (9,168 ) — Debt issue costs (28 ) (24 ) — 1 (1 ) — (52 ) Cash dividends (1,304 ) — — — — — (1,304 ) Repurchases of shares and warrants (192 ) — — — — — (192 ) Contributions from parents — 1,578 — 151 62 (1,791 ) — Contributions from noncontrolling interests — — — — — 1,638 1,638 Distributions to parents — (3,322 ) — (4,021 ) (152 ) 7,495 — Distributions to noncontrolling interests — — — — — (1,491 ) (1,491 ) Other, net — (1 ) — (1 ) — — (2 ) Net cash (used in) provided by financing activities (1,921 ) 2,899 (44 ) 2,398 396 (3,317 ) 411 Effect of exchange rate changes on cash and cash equivalents — — — — (9 ) — (9 ) Net (decrease) increase in cash and cash equivalents (52 ) 102 (1 ) (9 ) (166 ) — (126 ) Cash and cash equivalents, beginning of period 83 88 1 17 409 — 598 Cash and cash equivalents, end of period $ 31 $ 190 $ — $ 8 $ 243 $ — $ 472

General (Policies)

General (Policies)	9 Months Ended
	Sep. 30, 2015
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. Additionally, certain amounts from prior years have been reclassified to conform to the current presentation. In the nine months ended September 30, 2015, we adopted Accounting Standards Updates (ASU) 2015-03, “ Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs ” and ASU 2015-15, “ Interest—Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements—Amendments to SEC Paragraphs Pursuant to Staff Announcement at June 18, 2015 EITF Meeting (SEC Update). ” These ASUs are designed to simplify presentation of debt issuance costs. The standards require that debt issuance costs related to a recognized debt liability, except for line-of-credit debt issuance costs, be presented in the balance sheet as an offset to the carrying amount of that debt liability, consistent with debt discounts. The application of this new accounting guidance resulted in the reclassification of $149 million of debt issuance costs from “Deferred charges and other assets” to “Debt fair value adjustments” in our accompanying consolidated balance sheet as of December 31, 2014 . 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 2014 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 do not participate in excess distributions over earnings.

General (Tables)

General (Tables)	9 Months Ended
	Sep. 30, 2015
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 Shares Outstanding to Diluted Weighted Average Shares Outstanding (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Class P $ 182 $ 327 $ 938 $ 892 Participating securities(a) 4 2 10 8 Net Income Attributable to Kinder Morgan, Inc. $ 186 $ 329 $ 948 $ 900 Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Basic Weighted Average Shares Outstanding 2,203 1,028 2,173 1,028 Effect of dilutive securities: Warrants(b) — — 8 — Diluted Weighted Average Shares Outstanding 2,203 1,028 2,181 1,028 ________ (a) Participating securities are unvested restricted stock awards, which may be stock or stock units issued to management employees and include non-forfeitable dividend equivalent payments. As of September 30, 2015 , there were approximately 8 million such restricted stock awards. (b) 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.
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share [Table Text Block]	The following potential common stock equivalents are antidilutive and, accordingly, are excluded from the determination of diluted earnings per share (in millions on a weighted-average basis): Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Unvested restricted stock awards 8 7 7 7 Warrants to purchase our Class P shares 296 298 290 316 Convertible trust preferred securities 8 10 8 10

Acquisitions (Tables)

Acquisitions (Tables)	9 Months Ended
	Sep. 30, 2015
Business Acquisition [Line Items]
Schedule of Purchase Price Allocation [Table Text Block]	The evaluation of the assigned fair values for the above acquisitions is ongoing and subject to adjustment. Our preliminary allocation of the purchase price for each of our significant acquisitions during the nine months ended September 30, 2015 is detailed below (in millions). Acquisitions Hiland Vopak Terminal Assets Purchase Price Allocation: Current assets $ 82 $ 2 Property, plant and equipment 1,504 155 Goodwill 316 7 Other intangibles(a) 1,481 — Total assets acquired 3,383 164 Current liabilities (259 ) (2 ) Debt (1,411 ) — Other liabilities (4 ) (4 ) Cash consideration $ 1,709 $ 158 _______ (a) Relates to customer contracts and relationships with a weighted average amortization period of 16.4 years

Debt (Tables)

Debt (Tables)	9 Months Ended
	Sep. 30, 2015
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 and premiums (in millions): September 30, 2015 December 31, 2014 KMI Senior notes, 1.50% through 8.25%, due 2015 through 2098(a) $ 13,385 $ 11,438 Credit facility due November 26, 2019(b) 275 850 Commercial paper borrowings(b) 193 386 KMP Senior notes, 2.65% through 9.00%, due 2015 through 2044(c) 20,360 20,660 TGP senior notes, 7.00% through 8.375%, due 2016 through 2037 1,790 1,790 EPNG senior notes, 5.95% through 8.625%, due 2017 through 2032 1,115 1,115 Copano senior notes, 7.125%, due April 1, 2021 332 332 CIG senior notes, 5.95% through 6.85%, due 2015 through 2037 440 475 SNG notes, 4.40% through 8.00%, due 2017 through 2032 1,211 1,211 Other Subsidiary Borrowings (as obligor) Kinder Morgan Finance Company, LLC, senior notes, 5.70% through 6.40%, due 2016 through 2036 1,636 1,636 Hiland Partners Holdings LLC, senior notes, 5.50% and 7.25%, due 2020 and 2022 974 — EPC Building, LLC, promissory note, 3.967%, due 2015 through 2035 445 453 Preferred securities, 4.75%, due March 31, 2028 221 280 KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock 100 100 Other miscellaneous debt 301 303 Total debt – KMI and Subsidiaries 42,778 41,029 Less: Current portion of debt(d) 3,003 2,717 Total long-term debt – KMI and Subsidiaries(e) $ 39,775 $ 38,312 _______ (a) September 30, 2015 amount includes senior notes that are denominated in Euros and have been converted and are reported at the September 30, 2015 exchange rate of 1.1177 U.S. dollars per Euro. From the issuance date of these senior notes in March 2015 through September 30, 2015 , our debt increased by $40 million as a result of the change in the exchange rate of U.S. dollars per Euro. We entered into cross-currency swap agreements associated with these senior notes (see Note 5 “Risk Management— Foreign Currency Risk Management ”). (b) As of September 30, 2015 and December 31, 2014 , the weighted average interest rates on our credit facility borrowings, including commercial paper borrowings, were 1.34% and 1.54% , respectively. (c) On January 1, 2015, EPB and EPPOC merged with and into KMP. On that date, KMP succeeded EPPOC as the issuer of approximately $2.9 billion of EPPOC’s senior notes, which were guaranteed by EPB, and EPB and EPPOC ceased to be obligors for those senior notes. (d) Amounts include outstanding credit facility and commercial paper borrowings. (e) Excludes our “Debt fair value adjustments” which, as of September 30, 2015 and December 31, 2014 , increased our combined debt balances by $1,855 million and $1,785 million , respectively. In addition to all unamortized debt discount/premium amounts, debt issuance costs (resulting from the implementation of ASU Nos. 2015-03 and 2015-15) and purchase accounting on our debt balances, our debt fair value adjustments also include amounts associated with the offsetting entry for hedged debt and any unamortized portion of proceeds received from the early termination of interest rate swap agreements.
Schedule of Significant Long-Term Debt Issuances and Payments [Table Text Block]	following are significant long-term debt issuances and repayments made during the nine months ended September 30, 2015 : Issuances $800 million 5.05% notes due 2046 $815 million 1.50% notes due 2022(a) $543 million 2.25% notes due 2027(a) Repayments $300 million 5.625% notes due 2015 $250 million 5.15% notes due 2015 _______ (a) Senior notes are denominated in Euros and are presented above in U.S. dollars at the exchange rate on the issuance date of 1.0860 U.S. dollars per Euro. At the time of issuance, we entered into cross-currency swap agreements effectively converting these senior notes to U.S. dollars (see Note 5 “Risk Management— Foreign Currency Risk Management ”).

Stockholders' Equity (Tables)

Stockholders' Equity (Tables)	9 Months Ended
	Sep. 30, 2015
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, 2015 2014 2015 2014 Per common share cash dividend declared for the period $ 0.51 $ 0.44 $ 1.48 $ 1.29 Per common share cash dividend paid in the period $ 0.49 $ 0.43 $ 1.42 $ 1.26

Risk Management (Tables)

Risk Management (Tables)	9 Months Ended
	Sep. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
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, 2014 $ 327 $ (108 ) $ (236 ) $ (17 ) Other comprehensive loss before reclassifications 44 (170 ) 7 (119 ) Amounts reclassified from accumulated other comprehensive loss (192 ) — — (192 ) Net current-period other comprehensive loss (148 ) (170 ) 7 (311 ) Balance as of September 30, 2015 $ 179 $ (278 ) $ (229 ) $ (328 ) 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, 2013 $ (3 ) $ 2 $ (23 ) $ (24 ) Other comprehensive loss before reclassifications (8 ) (31 ) 2 (37 ) Amounts reclassified from accumulated other comprehensive loss 11 — — 11 Net current-period other comprehensive loss 3 (31 ) 2 (26 ) Balance as of September 30, 2014 $ — $ (29 ) $ (21 ) $ (50 )
Schedule of Derivative Instruments	As of September 30, 2015 , 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 (23.0 ) MMBbl Crude oil basis (9.4 ) MMBbl Natural gas fixed price (41.2 ) Bcf Natural gas basis (16.7 ) Bcf Derivatives not designated as hedging contracts Crude oil fixed price (1.8 ) MMBbl Crude oil basis (1.7 ) MMBbl Natural gas fixed price (20.6 ) Bcf Natural gas basis (15.0 ) Bcf NGL and other fixed price (1.9 ) 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) $ 347 $ 309 $ (33 ) $ (34 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 233 6 (4 ) — Subtotal 580 315 (37 ) (34 ) Interest rate swap agreements Fair value of derivative contracts/(Other current liabilities) 153 143 — — Deferred charges and other assets/(Other long-term liabilities and deferred credits) 361 260 (1 ) (53 ) Subtotal 514 403 (1 ) (53 ) Cross-currency swap agreements Fair value of derivative contracts/(Other current liabilities) — — (14 ) — Deferred charges and other assets/(Other long-term liabilities and deferred credits) 1 — (21 ) — Subtotal 1 — (35 ) — Total 1,095 718 (73 ) (87 ) Derivatives not designated as hedging contracts Natural gas, crude, NGL and other derivative contracts Fair value of derivative contracts/(Other current liabilities) 23 73 (4 ) (2 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) 13 196 (1 ) — Subtotal 36 269 (5 ) (2 ) Power derivative contracts Fair value of derivative contracts/(Other current liabilities) 6 10 (30 ) (57 ) Deferred charges and other assets/(Other long-term liabilities and deferred credits) — — — (16 ) Subtotal 6 10 (30 ) (73 ) Total 42 279 (35 ) (75 ) Total derivatives $ 1,137 $ 997 $ (108 ) $ (162 )
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, 2015 2014 2015 2014 Interest rate swap agreements Interest, net $ 251 $ (25 ) $ 163 $ 87 Hedged fixed rate debt Interest, net $ (283 ) $ 25 $ (166 ) $ (87 ) 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, 2015 2014 2015 2014 2015 2014 Energy commodity derivative contracts $ 119 $ 121 Revenues—Natural gas sales $ 4 $ 9 Revenues—Natural gas sales $ — $ — Revenues—Product sales and other 60 (5 ) Revenues—Product sales and other (6 ) 26 Costs of sales (2 ) (2 ) Costs of sales — — Interest rate swap agreements (4 ) — Interest, net (1 ) (1 ) Interest, net — — Cross-currency swap (11 ) — Other, net 2 — Total $ 104 $ 121 Total $ 63 $ 1 Total $ (6 ) $ 26 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, 2015 2014 2015 2014 2015 2014 Energy commodity derivative contracts $ 72 $ (10 ) Revenues—Natural gas sales $ 29 $ — Revenues—Natural gas sales $ — $ — Revenues—Product sales and other 161 (30 ) Revenues—Product sales and other 4 (6 ) Costs of sales (21 ) 4 Costs of sales — — Interest rate swap agreements (6 ) (10 ) Interest, net (2 ) (3 ) Interest, net — — Cross-currency swap (22 ) — Other, net 25 — Total $ 44 $ (20 ) Total $ 192 $ (29 ) Total $ 4 $ (6 ) _________ (a) We expect to reclassify an approximate $161 million gain associated with cash flow hedge price risk management activities included in our accumulated other comprehensive loss balances as of September 30, 2015 into earnings during the next twelve months (when the associated forecasted sales and purchases are also expected to occur), however, actual amounts reclassified into earnings could vary materially as a result of changes in market prices. (b) Amounts reclassified were the result of the hedged forecasted transactions actually affecting earnings (i.e., when the forecasted sales and purchases actually occurred). Derivatives not designated as accounting hedges Location Gain/(loss) recognized in income on derivatives Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Energy commodity derivative contracts Revenues—Natural gas sales $ 6 $ 4 $ 9 $ (12 ) Revenues—Product sales and other 169 5 173 6 Costs of sales — (3 ) — 4 Other expense (income) — — — (2 ) Total(a) $ 175 $ 6 $ 182 $ (4 ) _______ (a) For the three and nine months ended September 30, 2015 , includes approximate gains of $19 million and $21 million , respectively, associated with natural gas, crude and NGL derivative contract settlements.

Fair Value (Tables)

Fair Value (Tables)	9 Months Ended
	Sep. 30, 2015
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, 2015 Energy commodity derivative contracts(a) $ 54 $ 561 $ 7 $ 622 $ (40 ) $ (32 ) $ 550 Interest rate swap agreements $ — $ 514 $ — $ 514 $ (1 ) $ — $ 513 Cross-currency swap agreements $ — $ 1 $ — $ 1 $ (1 ) $ — $ — As of December 31, 2014 Energy commodity derivative contracts(a) $ 49 $ 533 $ 12 $ 594 $ (46 ) $ (13 ) $ 535 Interest rate swap agreements $ — $ 403 $ — $ 403 $ (44 ) $ — $ 359 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, 2015 Energy commodity derivative contracts(a) $ (9 ) $ (33 ) $ (30 ) $ (72 ) $ 40 $ 14 $ (18 ) Interest rate swap agreements $ — $ (1 ) $ — $ (1 ) $ 1 $ — $ — Cross-currency swap agreements $ — $ (35 ) $ — $ (35 ) $ 1 $ — $ (34 ) As of December 31, 2014 Energy commodity derivative contracts(a) $ (25 ) $ (11 ) $ (73 ) $ (109 ) $ 46 $ 47 $ (16 ) Interest rate swap agreements $ — $ (53 ) $ — $ (53 ) $ 44 $ — $ (9 ) _______ (a) Level 1 consists primarily of NYMEX natural gas futures. Level 2 consists primarily of OTC West Texas Intermediate swaps and options. Level 3 consists primarily of power derivative contracts. (b) Cash margin deposits held by us associated with our energy commodity contract positions and OTC swap agreements and reported within “Other current liabilities” on our accompanying consolidated balance sheets. (c) Cash margin deposits posted by us associated with our energy commodity contract positions and OTC swap agreements and reported within “Other current assets” on our accompanying consolidated balance sheets.
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation	The table below provides a summary of changes in the fair value of our Level 3 energy commodity derivative contracts (in millions): Significant unobservable inputs (Level 3) Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Derivatives-net asset (liability) Beginning of Period $ (37 ) $ (116 ) $ (61 ) $ (110 ) Total gains or (losses) Included in earnings (1 ) 14 (1 ) — Included in other comprehensive loss — 10 — — Settlements 15 13 39 31 End of Period $ (23 ) $ (79 ) $ (23 ) $ (79 ) 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 $ — $ 16 $ 2 $ (4 )
Schedule of Debt [Table Text Block]	The estimated fair value of our outstanding debt balances (the carrying amounts below include both short-term and long-term and debt fair value adjustments), is disclosed below (in millions): September 30, 2015 December 31, 2014 Carrying value Estimated fair value Carrying value Estimated fair value Total debt $ 44,633 $ 41,136 $ 42,814 $ 43,582 We used Level 2 input values to measure the estimated fair value of our outstanding debt balances as of both September 30, 2015 and December 31, 2014 .

Reportable Segments (Tables)

Reportable Segments (Tables)	9 Months Ended
	Sep. 30, 2015
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, 2015 2014 2015 2014 Revenues Natural Gas Pipelines Revenues from external customers $ 2,176 $ 2,745 $ 6,444 $ 7,766 Intersegment revenues 8 6 16 11 CO 2 517 508 1,316 1,445 Terminals Revenues from external customers 469 433 1,395 1,244 Intersegment revenues — — 1 1 Products Pipelines Revenues from external customers 467 520 1,388 1,578 Intersegment revenues — — 1 — Kinder Morgan Canada 68 73 193 210 Other — 3 3 5 Total segment revenues 3,705 4,288 10,757 12,260 Other revenues 10 9 28 27 Less: Total intersegment revenues (8 ) (6 ) (18 ) (12 ) Total consolidated revenues $ 3,707 $ 4,291 $ 10,767 $ 12,275 Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Segment Earnings Before DD&A(a) Natural Gas Pipelines $ 993 $ 1,182 $ 2,936 $ 3,207 CO 2 29 388 605 1,083 Terminals 249 249 798 692 Products Pipelines 288 222 811 632 Kinder Morgan Canada 42 50 120 138 Other (9 ) 6 (55 ) 13 Total segment earnings before DD&A 1,592 2,097 5,215 5,765 DD&A expense (617 ) (520 ) (1,725 ) (1,518 ) Amortization of excess cost of equity investments (13 ) (12 ) (39 ) (33 ) Other revenues 10 9 28 27 General and administrative expense (160 ) (135 ) (540 ) (461 ) Interest expense, net of unallocable interest income (539 ) (431 ) (1,525 ) (1,325 ) Unallocable income tax expense (90 ) (229 ) (470 ) (578 ) Total consolidated net income $ 183 $ 779 $ 944 $ 1,877 September 30, December 31, Assets Natural Gas Pipelines $ 54,725 $ 52,532 CO 2 4,906 5,227 Terminals 9,212 8,850 Products Pipelines 8,471 7,179 Kinder Morgan Canada 1,452 1,593 Other 427 455 Total segment assets 79,193 75,836 Corporate assets(b) 6,438 7,157 Assets held for sale 46 56 Total consolidated assets $ 85,677 $ 83,049 _______ (a) We evaluate performance based on each segment’s earnings before DD&A. Amounts include revenues, earnings from equity investments, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other expense (income), net, and losses on impairments and disposals of long-lived assets, net and equity investments. 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, 2015
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, 2015 2014 2015 2014 Income tax expense $ 108 $ 246 $ 521 $ 624 Effective tax rate 37.1 % 24.0 % 35.6 % 25.0 %

Guarantee of Securities of Su29

Guarantee of Securities of Subsidiaries (Tables)	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
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 Nine Months Ended September 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 28 $ — $ — $ 9,565 $ 1,210 $ (36 ) $ 10,767 Operating costs, expenses and other Costs of sales — — — 2,997 282 2 3,281 Depreciation, depletion and amortization 16 — — 1,423 286 — 1,725 Other operating expenses 66 39 (1 ) 2,552 452 (38 ) 3,070 Total operating costs, expenses and other 82 39 (1 ) 6,972 1,020 (36 ) 8,076 Operating (loss) income (54 ) (39 ) 1 2,593 190 — 2,691 Other income (expense) Earnings from consolidated subsidiaries 1,454 2,033 20 1,510 41 (5,058 ) — Earnings from equity investments — — — 304 — — 304 Interest, net (356 ) 30 (36 ) (1,133 ) (29 ) — (1,524 ) Amortization of excess cost of equity investments and other, net — — — (13 ) 7 — (6 ) Income (loss) before income taxes 1,044 2,024 (15 ) 3,261 209 (5,058 ) 1,465 Income tax expense (96 ) (6 ) — (409 ) (10 ) — (521 ) Net income (loss) 948 2,018 (15 ) 2,852 199 (5,058 ) 944 Net loss attributable to noncontrolling interests — — — — — 4 4 Net income (loss) attributable to controlling interests $ 948 $ 2,018 $ (15 ) $ 2,852 $ 199 $ (5,054 ) $ 948 Net Income (loss) $ 948 $ 2,018 $ (15 ) $ 2,852 $ 199 $ (5,058 ) $ 944 Total other comprehensive loss (311 ) (419 ) — (525 ) (266 ) 1,210 (311 ) Comprehensive income (loss) 637 1,599 (15 ) 2,327 (67 ) (3,848 ) 633 Comprehensive loss attributable to noncontrolling interests — — — — — 4 4 Comprehensive income (loss) attributable to controlling interests $ 637 $ 1,599 $ (15 ) $ 2,327 $ (67 ) $ (3,844 ) $ 637 Condensed Consolidating Statements of Income and Comprehensive Income for the Three Months Ended September 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 9 $ — $ — $ 3,289 $ 421 $ (12 ) $ 3,707 Operating costs, expenses and other Costs of sales — — — 1,007 98 1 1,106 Depreciation, depletion and amortization 6 — — 508 103 — 617 Other operating expenses 16 1 (2 ) 1,100 161 (13 ) 1,263 Total operating costs, expenses and other 22 1 (2 ) 2,615 362 (12 ) 2,986 Operating (loss) income (13 ) (1 ) 2 674 59 — 721 Other income (expense) Earnings from consolidated subsidiaries 366 484 48 376 10 (1,284 ) — Earnings from equity investments — — — 114 — — 114 Interest, net (155 ) 23 (12 ) (381 ) (15 ) — (540 ) Amortization of excess cost of equity investments and other, net — — — (5 ) 1 — (4 ) Income before income taxes 198 506 38 778 55 (1,284 ) 291 Income tax expense (12 ) (2 ) — (93 ) (1 ) — (108 ) Net income 186 504 38 685 54 (1,284 ) 183 Net loss attributable to noncontrolling interests — — — — — 3 3 Net income attributable to controlling interests $ 186 $ 504 $ 38 $ 685 $ 54 $ (1,281 ) $ 186 Net Income $ 186 $ 504 $ 38 $ 685 $ 54 $ (1,284 ) $ 183 Total other comprehensive loss (37 ) (42 ) — (24 ) (125 ) 191 (37 ) Comprehensive income (loss) 149 462 38 661 (71 ) (1,093 ) 146 Comprehensive loss attributable to noncontrolling interests — — — — — 3 3 Comprehensive income (loss) attributable to controlling interests $ 149 $ 462 $ 38 $ 661 $ (71 ) $ (1,090 ) $ 149	Condensed Consolidating Statements of Income and Comprehensive Income for the Three Months Ended September 30, 2014 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 9 $ — $ — $ 3,649 $ 637 $ (4 ) $ 4,291 Operating costs, expenses and other Costs of sales — — — 1,510 124 8 1,642 Depreciation, depletion and amortization 5 — — 423 92 — 520 Other operating expenses 4 2 9 667 127 (12 ) 797 Total operating costs, expenses and other 9 2 9 2,600 343 (4 ) 2,959 Operating (loss) income — (2 ) (9 ) 1,049 294 — 1,332 Other income (expense) Earnings from consolidated subsidiaries 581 1,126 59 640 487 (2,893 ) — Earnings from equity investments — — — 108 (1 ) — 107 Interest, net (111 ) (28 ) (13 ) (261 ) (19 ) — (432 ) Amortization of excess cost of equity investments and other, net — — — (6 ) 24 — 18 Income before income taxes 470 1,096 37 1,530 785 (2,893 ) 1,025 Income tax expense (57 ) (3 ) — (21 ) (165 ) — (246 ) Net income 413 1,093 37 1,509 620 (2,893 ) 779 Net income attributable to noncontrolling interests (84 ) (44 ) — — — (322 ) (450 ) Net income attributable to controlling interests $ 329 $ 1,049 $ 37 $ 1,509 $ 620 $ (3,215 ) $ 329 Net Income $ 413 $ 1,093 $ 37 $ 1,509 $ 620 $ (2,893 ) $ 779 Total other comprehensive income (loss) 24 58 — 85 (83 ) (38 ) 46 Comprehensive income 437 1,151 37 1,594 537 (2,931 ) 825 Comprehensive income attributable to noncontrolling interests (90 ) (45 ) — — — (343 ) (478 ) Comprehensive income attributable to controlling interests $ 347 $ 1,106 $ 37 $ 1,594 $ 537 $ (3,274 ) $ 347 Condensed Consolidating Statements of Income and Comprehensive Income for the Nine Months Ended September 30, 2014 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Total Revenues $ 27 $ — $ — $ 10,784 $ 1,465 $ (1 ) $ 12,275 Operating costs, expenses and other Costs of sales — — — 4,467 393 35 4,895 Depreciation, depletion and amortization 15 — — 1,232 271 — 1,518 Other operating expenses 24 5 24 1,980 373 (36 ) 2,370 Total operating costs, expenses and other 39 5 24 7,679 1,037 (1 ) 8,783 Operating (loss) income (12 ) (5 ) (24 ) 3,105 428 — 3,492 Other income (expense) Earnings from consolidated subsidiaries 1,554 2,897 159 1,432 1,414 (7,456 ) — Earnings from equity investments — — — 307 (1 ) — 306 Interest, net (373 ) (80 ) (35 ) (766 ) (66 ) — (1,320 ) Amortization of excess cost of equity investments and other, net — — — (13 ) 36 — 23 Income before income taxes 1,169 2,812 100 4,065 1,811 (7,456 ) 2,501 Income tax expense (98 ) (8 ) — (50 ) (468 ) — (624 ) Net income 1,071 2,804 100 4,015 1,343 (7,456 ) 1,877 Net income attributable to noncontrolling interests (171 ) (156 ) — — — (650 ) (977 ) Net income attributable to controlling interests $ 900 $ 2,648 $ 100 $ 4,015 $ 1,343 $ (8,106 ) $ 900 Net Income $ 1,071 $ 2,804 $ 100 $ 4,015 $ 1,343 $ (7,456 ) $ 1,877 Total other comprehensive loss (33 ) (93 ) — (106 ) (128 ) 290 (70 ) Comprehensive income 1,038 2,711 100 3,909 1,215 (7,166 ) 1,807 Comprehensive income attributable to noncontrolling interests (164 ) (152 ) — — — (617 ) (933 ) Comprehensive income attributable to controlling interests $ 874 $ 2,559 $ 100 $ 3,909 $ 1,215 $ (7,783 ) $ 874
Condensed Balance Sheet [Table Text Block]	Condensed Consolidating Balance Sheets as of September 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI ASSETS Cash and cash equivalents $ 12 $ — $ — $ 25 $ 142 $ — $ 179 Other current assets - affiliates 1,915 1,042 19 9,399 550 (12,925 ) — All other current assets 184 129 1 2,305 276 (7 ) 2,888 Property, plant and equipment, net 258 — — 31,972 8,378 — 40,608 Investments 16 2 — 5,811 114 — 5,943 Investments in subsidiaries 33,775 29,470 2,294 18,420 3,337 (87,296 ) — Goodwill 15,089 22 920 5,743 3,178 — 24,952 Notes receivable from affiliates 4,588 22,175 — 2,228 360 (29,351 ) — Deferred tax assets — — — 8,939 — (3,612 ) 5,327 Other non-current assets 267 349 — 5,046 118 — 5,780 Total assets $ 56,104 $ 53,189 $ 3,234 $ 89,888 $ 16,453 $ (133,191 ) $ 85,677 LIABILITIES AND STOCKHOLDERS’ EQUITY Liabilities Current portion of debt $ 535 $ 875 $ — $ 1,471 $ 122 $ — $ 3,003 Other current liabilities - affiliates 664 9,654 259 1,761 587 (12,925 ) — All other current liabilities 334 260 15 1,987 599 (7 ) 3,188 Long-term debt 13,953 20,149 380 6,461 687 — 41,630 Notes payable to affiliates 2,516 448 651 24,378 1,358 (29,351 ) — Deferred income taxes 2,147 — 2 — 1,463 (3,612 ) — All other long-term liabilities and deferred credits 441 180 — 965 428 — 2,014 Total liabilities 20,590 31,566 1,307 37,023 5,244 (45,895 ) 49,835 Stockholders’ equity Total KMI equity 35,514 21,623 1,927 52,865 11,209 (87,624 ) 35,514 Noncontrolling interests — — — — — 328 328 Total stockholders’ equity 35,514 21,623 1,927 52,865 11,209 (87,296 ) 35,842 Total liabilities and stockholders’ equity $ 56,104 $ 53,189 $ 3,234 $ 89,888 $ 16,453 $ (133,191 ) $ 85,677	Condensed Consolidating Balance Sheets as of September 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI ASSETS Cash and cash equivalents $ 12 $ — $ — $ 25 $ 142 $ — $ 179 Other current assets - affiliates 1,915 1,042 19 9,399 550 (12,925 ) — All other current assets 184 129 1 2,305 276 (7 ) 2,888 Property, plant and equipment, net 258 — — 31,972 8,378 — 40,608 Investments 16 2 — 5,811 114 — 5,943 Investments in subsidiaries 33,775 29,470 2,294 18,420 3,337 (87,296 ) — Goodwill 15,089 22 920 5,743 3,178 — 24,952 Notes receivable from affiliates 4,588 22,175 — 2,228 360 (29,351 ) — Deferred tax assets — — — 8,939 — (3,612 ) 5,327 Other non-current assets 267 349 — 5,046 118 — 5,780 Total assets $ 56,104 $ 53,189 $ 3,234 $ 89,888 $ 16,453 $ (133,191 ) $ 85,677 LIABILITIES AND STOCKHOLDERS’ EQUITY Liabilities Current portion of debt $ 535 $ 875 $ — $ 1,471 $ 122 $ — $ 3,003 Other current liabilities - affiliates 664 9,654 259 1,761 587 (12,925 ) — All other current liabilities 334 260 15 1,987 599 (7 ) 3,188 Long-term debt 13,953 20,149 380 6,461 687 — 41,630 Notes payable to affiliates 2,516 448 651 24,378 1,358 (29,351 ) — Deferred income taxes 2,147 — 2 — 1,463 (3,612 ) — All other long-term liabilities and deferred credits 441 180 — 965 428 — 2,014 Total liabilities 20,590 31,566 1,307 37,023 5,244 (45,895 ) 49,835 Stockholders’ equity Total KMI equity 35,514 21,623 1,927 52,865 11,209 (87,624 ) 35,514 Noncontrolling interests — — — — — 328 328 Total stockholders’ equity 35,514 21,623 1,927 52,865 11,209 (87,296 ) 35,842 Total liabilities and stockholders’ equity $ 56,104 $ 53,189 $ 3,234 $ 89,888 $ 16,453 $ (133,191 ) $ 85,677 Condensed Consolidating Balance Sheets as of December 31, 2014 (In Millions) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI ASSETS Cash and cash equivalents $ 4 $ 15 $ — $ 17 $ 279 $ — $ 315 Other current assets - affiliates 1,868 1,335 11 11,573 403 (15,190 ) — All other current assets 397 152 3 2,547 358 (20 ) 3,437 Property, plant and equipment, net 263 — 5 29,490 8,806 — 38,564 Investments 16 1 — 5,910 109 — 6,036 Investments in subsidiaries 31,372 33,414 1,911 17,868 3,337 (87,902 ) — Goodwill 15,087 22 920 5,419 3,206 — 24,654 Notes receivable from affiliates 4,459 19,832 — 2,415 496 (27,202 ) — Deferred tax assets — — — 9,256 — (3,605 ) 5,651 Other non-current assets 258 249 — 3,772 113 — 4,392 Total assets $ 53,724 $ 55,020 $ 2,850 $ 88,267 $ 17,107 $ (133,919 ) $ 83,049 LIABILITIES AND STOCKHOLDERS’ EQUITY Liabilities Current portion of debt $ 1,486 $ 699 $ — $ 381 $ 151 $ — $ 2,717 Other current liabilities - affiliates 709 11,949 115 1,551 866 (15,190 ) — All other current liabilities 319 498 12 1,812 1,024 (20 ) 3,645 Long-term debt 11,833 20,564 386 6,599 715 — 40,097 Notes payable to affiliates 2,619 153 753 22,437 1,240 (27,202 ) — Deferred income taxes 2,099 — 2 — 1,504 (3,605 ) — Other long-term liabilities and deferred credits 583 78 2 987 514 — 2,164 Total liabilities 19,648 33,941 1,270 33,767 6,014 (46,017 ) 48,623 Stockholders’ equity Total KMI equity 34,076 21,079 1,580 54,500 11,093 (88,252 ) 34,076 Noncontrolling interests — — — — — 350 350 Total stockholders’ equity 34,076 21,079 1,580 54,500 11,093 (87,902 ) 34,426 Total liabilities and stockholders’ equity $ 53,724 $ 55,020 $ 2,850 $ 88,267 $ 17,107 $ (133,919 ) $ 83,049
Condensed Cash Flow Statement [Table Text Block]	Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2015 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Net cash (used in) provided by operating activities $ (2,208 ) $ 5,917 $ 81 $ 6,834 $ 193 $ (7,310 ) $ 3,507 Cash flows from investing activities Funding to affiliates (1,767 ) (7,699 ) (2 ) (7,293 ) (597 ) 17,358 — Capital expenditures (9 ) — (3 ) (2,747 ) (245 ) 5 (2,999 ) Contributions to investments (5 ) — — (62 ) (7 ) 5 (69 ) Investment in KMP (159 ) — — — — 159 — Acquisitions of assets and investments (1,709 ) — — (210 ) — — (1,919 ) Distributions from equity investments in excess of cumulative earnings 1,060 — — 113 — (992 ) 181 Other, net — 16 5 50 18 (5 ) 84 Net cash used in investing activities (2,589 ) (7,683 ) — (10,149 ) (831 ) 16,530 (4,722 ) Cash flows from financing activities Issuances of debt 12,281 — — — — — 12,281 Payments of debt (11,544 ) (300 ) — (42 ) (7 ) — (11,893 ) Funding from (to) affiliates 3,351 5,602 (81 ) 7,842 644 (17,358 ) — Debt issue costs (20 ) — — — — — (20 ) Issuances of shares 3,833 — — — — — 3,833 Cash dividends (3,084 ) — — — — — (3,084 ) Repurchases of warrants (12 ) — — — — — (12 ) Contributions from parents — 156 — 3 12 (171 ) — Contributions from noncontrolling interests — — — — — 7 7 Distributions to parents — (3,706 ) — (4,480 ) (141 ) 8,327 — Distributions to noncontrolling interests — — — — — (25 ) (25 ) Other, net — (1 ) — — — — (1 ) Net cash provided by (used in) financing activities 4,805 1,751 (81 ) 3,323 508 (9,220 ) 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	Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2014 (In Millions) (Unaudited) Parent Subsidiary Subsidiary Subsidiary Subsidiary Consolidating Adjustments Consolidated KMI Net cash provided by (used in) operating activities $ 1,166 $ 2,868 $ (92 ) $ 3,897 $ 1,219 $ (5,566 ) $ 3,492 Cash flows from investing activities Funding to affiliates (197 ) (5,037 ) — (2,785 ) (1,149 ) 9,168 — Capital expenditures (11 ) — (64 ) (2,254 ) (548 ) 199 (2,678 ) Contributions to investments — (118 ) — (342 ) — 118 (342 ) Investment in KMP (34 ) — — — — 34 — Drop down assets to KMP 875 (875 ) — — — — — Acquisitions of assets and investments — — — (1,085 ) (15 ) — (1,100 ) Distributions from equity investments in excess of cumulative earnings 70 367 — 139 — (438 ) 138 Other, net — (2 ) 199 23 (60 ) (198 ) (38 ) Net cash provided by (used in) investing activities 703 (5,665 ) 135 (6,304 ) (1,772 ) 8,883 (4,020 ) Cash flows from financing activities Issuances of debt 3,258 10,141 — — — — 13,399 Payments of debt (3,804 ) (7,698 ) — (76 ) (7 ) — (11,585 ) Funding from (to) affiliates 149 2,225 (44 ) 6,344 494 (9,168 ) — Debt issue costs (28 ) (24 ) — 1 (1 ) — (52 ) Cash dividends (1,304 ) — — — — — (1,304 ) Repurchases of shares and warrants (192 ) — — — — — (192 ) Contributions from parents — 1,578 — 151 62 (1,791 ) — Contributions from noncontrolling interests — — — — — 1,638 1,638 Distributions to parents — (3,322 ) — (4,021 ) (152 ) 7,495 — Distributions to noncontrolling interests — — — — — (1,491 ) (1,491 ) Other, net — (1 ) — (1 ) — — (2 ) Net cash (used in) provided by financing activities (1,921 ) 2,899 (44 ) 2,398 396 (3,317 ) 411 Effect of exchange rate changes on cash and cash equivalents — — — — (9 ) — (9 ) Net (decrease) increase in cash and cash equivalents (52 ) 102 (1 ) (9 ) (166 ) — (126 ) Cash and cash equivalents, beginning of period 83 88 1 17 409 — 598 Cash and cash equivalents, end of period $ 31 $ 190 $ — $ 8 $ 243 $ — $ 472

General Organization (Details)

General Organization (Details) $ in Billions	Nov. 25, 2014USD ($)	Sep. 30, 2015USD ($)	Nov. 25, 2014
General [Line Items]
Approximate Enterprise Market Value		$ 110
Miles Of Pipeline		84,000
Number Of Pipeline Terminals Owned Interest In And Or Operated		165
Other Significant Noncash Transaction, Value of Consideration Given	$ 77
KMP [Member]
General [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest			10.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest			2.00%
EPB [Member]
General [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest			39.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest			2.00%

General Basis of Presentation (

General Basis of Presentation (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Segment Reporting Information [Line Items]
Reclassification of Debt Issuance Costs from Deferred Charges and Other Assets to Debt Fair Value Adjustments					$ 149
Loss on impairments and disposals of long-lived assets and equity investments, net	$ 387		$ 523
Equity Method Investment, Other than Temporary Impairment	0	$ 0	26	$ 0
Natural Gas Pipelines
Segment Reporting Information [Line Items]
Loss on impairments and disposals of long-lived assets and equity investments, net			99
Natural Gas Pipelines | Fort Union Gas Gathering L.L.C. and Bighorn Gas Gathering L.L.C. [Member]
Segment Reporting Information [Line Items]
Equity Method Investment, Other than Temporary Impairment			26
CO2 [Member]
Segment Reporting Information [Line Items]
Loss on impairments and disposals of long-lived assets and equity investments, net	$ 388		$ 397

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, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net Income Attributable to Kinder Morgan, Inc.	$ 186	$ 329	$ 948	$ 900
Warrants(b)	0	0	8	0
Diluted Weighted Average Shares Outstanding	2,203	1,028	2,181	1,028
Class of Warrant or Right, Exercise Price of Warrants or Rights	$ 40		$ 40
Class P
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net Income Attributable to Kinder Morgan, Inc.	$ 182	$ 327	$ 938	$ 892
Basic Weighted Average Shares Outstanding	2,203	1,028	2,173	1,028
Participating securities(a)
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net Income Attributable to Kinder Morgan, Inc.	$ 4	$ 2	$ 10	$ 8
Unvested Restricted Stock Awards, Issued and Non Issued	8		8
Unvested restricted stock awards
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	8	7	7	7
Warrants to purchase our Class P shares
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	296	298	290	316
Convertible trust preferred securities
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	8	10	8	10

Acquisitions Acquisitions Hilan

Acquisitions Acquisitions Hiland (Details) - USD ($) $ in Millions	Feb. 13, 2015	Sep. 30, 2015	Sep. 30, 2014
Business Acquisition [Line Items]
Repayments of Debt		$ 11,893	$ 11,585
Hiland
Business Acquisition [Line Items]
Business Combination, Consideration Transferred	$ 3,120
Repayments of Debt	$ 368

Acquisitions Acquisitions Vopak

Acquisitions Acquisitions Vopak (Details) - Vopak Terminal Assets $ in Millions	Feb. 27, 2015USD ($)abbl	Sep. 30, 2015USD ($)
Business Acquisition [Line Items]
Number of terminals	3
Number of Real Estate Properties	1
Payments to Acquire Businesses, Gross	$ 158	$ 158
Galena Park, Texas [Member]
Business Acquisition [Line Items]
Area of Land (acres) | a	36
Storage Capacity (barrels) | bbl	1,069,500
NORTH CAROLINA
Business Acquisition [Line Items]
Number of terminals	2
North Wilmington, North Carolina [Member]
Business Acquisition [Line Items]
Number of terminals	1
South Wilmington, North Carolina [Member]
Business Acquisition [Line Items]
Number of terminals	1

Acquisitions Purchase Price All

Acquisitions Purchase Price Allocation (Details) - USD ($) $ in Millions	Feb. 27, 2015	Sep. 30, 2015	Dec. 31, 2014
Business Acquisition [Line Items]
Goodwill		$ 24,952	$ 24,654
Hiland
Business Acquisition [Line Items]
Current assets		82
Property, plant and equipment		1,504
Goodwill		316
Other intangibles(a)		1,481
Total assets acquired		3,383
Current liabilities		(259)
Debt		(1,411)
Other liabilities		(4)
Cash consideration		$ 1,709
Finite-Lived Intangible Asset, Useful Life		16 years 5 months
Vopak Terminal Assets
Business Acquisition [Line Items]
Current assets		$ 2
Property, plant and equipment		155
Goodwill		7
Other intangibles(a)		0
Total assets acquired		164
Current liabilities		(2)
Debt		0
Other liabilities		(4)
Cash consideration	$ 158	$ 158

Acquisitions Asset Purchase (De

Acquisitions Asset Purchase (Details) - USD ($) $ in Millions	Jul. 16, 2015	Sep. 30, 2015	Sep. 30, 2014	Jul. 15, 2015
Property, Plant and Equipment [Line Items]
Acquisitions of other assets and investments		$ 55	$ 139
Shell US Gas & Power LLC [Member] | Elba Liquification Company LLC [Member]
Property, Plant and Equipment [Line Items]
Equity Method Investment, Ownership Percentage				49.00%
Shell US Gas & Power LLC [Member] | Elba Liquification Company LLC [Member]
Property, Plant and Equipment [Line Items]
Acquisitions of other assets and investments	$ 185
Shell US Gas & Power LLC [Member] | Elba Liquification Company LLC [Member]
Property, Plant and Equipment [Line Items]
Capacity Subscribed, Percent				100.00%

Debt (Details)

Debt (Details) $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)$ / shares	Feb. 13, 2015USD ($)	Jan. 01, 2015USD ($)	Dec. 31, 2014USD ($)
Debt Instrument [Line Items]
KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock	$ 100			$ 100
Less: Current portion of debt(d)	3,003			2,717
Total long-term debt – KMI and Subsidiaries(e)	41,630			40,097
Debt fair value adjustments	1,855			1,785
Kinder Morgan, Inc. [Member] | Senior notes, 1.50% through 8.25%, due 2015 through 2098(a)
Debt Instrument [Line Items]
Senior Notes	$ 13,385			11,438
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	1.50%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	8.25%
Kinder Morgan, Inc. [Member] | Senior unsecured revolving credit facility [Member]
Debt Instrument [Line Items]
Credit facility due November 26, 2019(b)	$ 275			850
Kinder Morgan, Inc. [Member] | Commercial Paper [Member]
Debt Instrument [Line Items]
Commercial paper borrowings(b)	$ 193			$ 386
Kinder Morgan, Inc. [Member] | Revolving Credit Facility [Member] | KMI Credit Facility [Member]
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate	1.34%			1.54%
Kinder Morgan Energy Partners, L.P. [Member] | Senior notes, 2.65% through 9.00%, due 2015 through 2044
Debt Instrument [Line Items]
Senior Notes	$ 20,360			$ 20,660
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	2.65%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	9.00%
TGP [Member] | TGP senior notes, 7.00% through 8.375%, due 2016 through 2037
Debt Instrument [Line Items]
Senior Notes	$ 1,790			1,790
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	7.00%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	8.375%
EPNG [Member] | EPNG senior notes, 5.95% through 8.625%, due 2017 through 2032
Debt Instrument [Line Items]
Senior Notes	$ 1,115			1,115
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	5.95%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	8.625%
Copano Energy, L.L.C. [Member]
Debt Instrument [Line Items]
Total debt – KMI and Subsidiaries	$ 332
Total long-term debt – KMI and Subsidiaries(e)	380			386
Copano Energy, L.L.C. [Member] | Copano senior notes, 7.125% due April 1, 2021
Debt Instrument [Line Items]
Senior Notes	$ 332			332
Debt Instrument, Interest Rate, Stated Percentage	7.125%
Colorado Interstate Gas Company, L.L.C. [Member] | CIG, senior notes, 5.95% through 6.85%, due 2015 through 2037
Debt Instrument [Line Items]
Senior Notes	$ 440			475
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	5.95%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	6.85%
SNG [Member] | SNG notes, 4.40% through 8.00%, due 2017 through 2032
Debt Instrument [Line Items]
Notes Payable	$ 1,211			1,211
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	4.40%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	8.00%
Kinder Morgan Finance Company, LLC [Member] | Kinder Morgan Finance Company, LLC, senior notes, 5.70% through 6.40%, due 2016 through 2036(b)
Debt Instrument [Line Items]
Senior Notes	$ 1,636			1,636
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	5.70%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	6.40%
Hiland Partners Holdings LLC [Member] | Hiland Partners Holdings LLC, senior notes, 5.50% and 7.25%, due 2020 and 2022(d)
Debt Instrument [Line Items]
Senior Notes	$ 974	$ 975		0
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	5.50%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	7.25%
EPC Building LLC [Member] | EPC Building, LLC, promissory note, 3.967%, due 2015 through 2035
Debt Instrument [Line Items]
Notes Payable	$ 445			453
Debt Instrument, Interest Rate, Stated Percentage	3.967%
Capital Trust I [Member] | Preferred securities, 4.75%, due March 31, 2028
Debt Instrument [Line Items]
Senior Notes	$ 221			280
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(n)
Debt Instrument [Line Items]
KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock	$ 100			100
Liquidation value of note | $ / shares	$ 1,000
KMI AND KMP [Member] | Other miscellaneous debt
Debt Instrument [Line Items]
Notes Payable	$ 301			303
Kinder Morgan, Inc and Subsidiaries [Member]
Debt Instrument [Line Items]
Total debt – KMI and Subsidiaries	42,778			41,029
Total long-term debt – KMI and Subsidiaries(e)	$ 39,775			$ 38,312
Financial Guarantee [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Debt Instrument [Line Items]
Indemnified by parent of subsidiary debt			$ 2,900
Euro Member Countries, Euro | Senior Notes [Member]
Debt Instrument [Line Items]
Foreign Currency Exchange Rate, Translation	1.1177	1.086
Translation Adjustment Functional to Reporting Currency, Increase (Decrease), Gross of Tax	$ 40

Debt Credit Facilities (Details

Debt Credit Facilities (Details) - Kinder Morgan, Inc. [Member] - USD ($) $ in Millions	Feb. 13, 2015	Sep. 30, 2015	Dec. 31, 2014
Line of Credit Facility [Line Items]
Debt Instrument, Term		5 years
Line of Credit Facility, Current Borrowing Capacity		$ 4,000
Letters of Credit Outstanding, Amount		117
Line of Credit Facility, Remaining Borrowing Capacity		3,415
Senior unsecured revolving credit facility [Member]
Line of Credit Facility [Line Items]
Credit facility due November 26, 2019(b)		275	$ 850
Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial paper borrowings(b)		193	$ 386
Commercial Paper, Current Borrowing Capacity		$ 4,000
Bridge Loan [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Term	6 months
Line of Credit Facility, Maximum Amount Outstanding During Period	$ 1,641

Debt Hiland Debt Acquired (Deta

Debt Hiland Debt Acquired (Details) - USD ($) $ in Millions	Feb. 13, 2015	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Debt Instrument [Line Items]
Repayments of Debt		$ 11,893	$ 11,585
Hiland Partners Holdings LLC [Member] | Hiland Partners Holdings LLC, senior notes, 5.50% and 7.25%, due 2020 and 2022(d)
Debt Instrument [Line Items]
Senior Notes	$ 975	$ 974		$ 0
KMI Acquisition of Hiland Partners Holding LLC [Member] | Hiland Partners Holdings LLC [Member] | Hiland Partners Holdings LLC, senior notes, 5.50% and 7.25%, due 2020 and 2022(d)
Debt Instrument [Line Items]
Debt Instrument, Fair Value Disclosure	1,043
Hiland
Debt Instrument [Line Items]
Repayments of Debt	$ 368

Long-term Debt Issuances and Re

Long-term Debt Issuances and Repaymenrts (Details) $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)	Sep. 30, 2014USD ($)	Feb. 13, 2015
Debt Instrument [Line Items]
Repayments of Debt	$ 11,893	$ 11,585
Kinder Morgan, Inc. [Member] | KMI 5.05% Senior Notes Due 2046 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt	$ 800
Debt Instrument, Interest Rate, Stated Percentage	5.05%
Kinder Morgan, Inc. [Member] | KMI 1.50% Senior Notes Due 2022 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt	$ 815
Debt Instrument, Interest Rate, Stated Percentage	1.50%
Kinder Morgan, Inc. [Member] | KMI 2.25% Senior Notes Due 2027 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt	$ 543
Debt Instrument, Interest Rate, Stated Percentage	2.25%
Kinder Morgan, Inc. [Member] | KMI 5.15% Senior Notes due March 1, 2015 [Member]
Debt Instrument [Line Items]
Repayments of Debt	$ 250
Debt Instrument, Interest Rate, Stated Percentage	5.15%
Kinder Morgan Energy Partners, L.P. [Member] | KMP 5.625% Senior Notes due February 15, 2015 [Member]
Debt Instrument [Line Items]
Repayments of Debt	$ 300
Debt Instrument, Interest Rate, Stated Percentage	5.625%
Euro Member Countries, Euro | Senior Notes [Member]
Debt Instrument [Line Items]
Foreign Currency Exchange Rate, Translation	1.1177		1.086

Stockholders' Equity Common Equ

Stockholders' Equity Common Equity (Details) - USD ($) $ / shares in Units, $ in Millions	Oct. 22, 2015	Oct. 05, 2015	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Jun. 12, 2015	Dec. 31, 2014	Dec. 19, 2014
Class of Stock [Line Items]
Warrant Repurchase Program, Authorized Amount							$ 100
Warrant Repurchase Program, Remaining Authorized Repurchase Amount			$ 91		$ 91
Share and Warrant Repurchase Program, Remaining Authorized Repurchase Amount								$ 2
Stock Issued During Period, Value, New Issues					$ 3,833
Class P
Class of Stock [Line Items]
Stock Issued During Period, Shares, New Issues					101,000,000
Dividends Per Common Share Declared for the Period			$ 0.51	$ 0.44	$ 1.48	$ 1.29
Per common share cash dividend paid in the period			$ 0.49	$ 0.43	$ 1.42	$ 1.26
Dividend Declared [Member]
Class of Stock [Line Items]
Dividends Per Common Share Declared for the Period	$ 0.51
Equity distribution agreement [Member] | Class P
Class of Stock [Line Items]
Value of Stock Available for Sale Under Equity Distribution Agreement									$ 5,000
Stock Issued During Period, Shares, New Issues					101,290,190
During the nine months ended September 30, 2015, we sold Shares of Class P Stock					101,290,190
Stock Issued During Period, Value, New Issues					$ 3,900
Equity distribution agreement [Member] | Subsequent Event [Member] | Class P
Class of Stock [Line Items]
Stock Issued During Period, Shares, New Issues		1,324,318

Risk Management Energy Commodit

Risk Management Energy Commodity Price Risk Management (Details) - Energy Related Derivative [Member] - Forward Contracts [Member]	Sep. 30, 2015BcfMMBbls
Crude oil fixed price | Derivatives designated as hedging contracts
Derivative [Line Items]
Net open position long/(short)	(23)
Crude oil fixed price | Derivatives not designated as hedging contracts
Derivative [Line Items]
Net open position long/(short)	(1.8)
Crude oil basis | Derivatives designated as hedging contracts
Derivative [Line Items]
Net open position long/(short)	(9.4)
Crude oil basis | Derivatives not designated as hedging contracts
Derivative [Line Items]
Net open position long/(short)	(1.7)
Natural gas fixed price | Derivatives designated as hedging contracts
Derivative [Line Items]
Net open position long/(short) | Bcf	(41.2)
Natural gas fixed price | Derivatives not designated as hedging contracts
Derivative [Line Items]
Net open position long/(short) | Bcf	(20.6)
Natural gas basis | Derivatives designated as hedging contracts
Derivative [Line Items]
Net open position long/(short) | Bcf	(16.7)
Natural gas basis | Derivatives not designated as hedging contracts
Derivative [Line Items]
Net open position long/(short) | Bcf	(15)
NGL and other fixed price | Derivatives not designated as hedging contracts
Derivative [Line Items]
Net open position long/(short)	(1.9)

Risk Management Interest Rate R

Risk Management Interest Rate Risk Management (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Interest Rate Swap [Member]
Derivative [Line Items]
Derivative, Notional Amount	$ 9,700	$ 9,200

Risk Management Risk Management

Risk Management Risk Management Foreign Currency Risk Management (Details)	9 Months Ended
	Sep. 30, 2015
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]
Derivative [Line Items]
Debt Instrument, Term	5 years
Kinder Morgan, Inc. [Member] | KMI 1.50% Senior Notes Due 2022 [Member]
Derivative [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.50%
Debt Instrument, Term	7 years
Kinder Morgan, Inc. [Member] | KMI 2.25% Senior Notes Due 2027 [Member]
Derivative [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.25%
Debt Instrument, Term	12 years

Risk Management Fair Value of D

Risk Management Fair Value of Derivative Contracts (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Derivatives designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	$ 1,095	$ 718
Derivative Liability, Fair Value, Net	(73)	(87)
Derivatives not designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	1,137	997
Derivative Liability, Fair Value, Net	(108)	(162)
Natural gas and crude derivative contracts | Derivatives designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	580	315
Derivative Liability, Fair Value, Net	(37)	(34)
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	347	309
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	(33)	(34)
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	233	6
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	(4)	0
Natural gas and crude derivative contracts | Derivatives not designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	36	269
Derivative Liability, Fair Value, Net	(5)	(2)
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	23	73
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	(4)	(2)
Natural gas and crude derivative contracts | 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	13	196
Natural gas and crude derivative contracts | 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	(1)	0
Interest rate swap agreements | Derivatives designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	514	403
Derivative Liability, Fair Value, Net	(1)	(53)
Cross-currency swap agreements | Derivatives designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	1	0
Derivative Liability, Fair Value, Net	(35)	0
Power derivative contracts | Derivatives not designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	6	10
Derivative Liability, Fair Value, Net	(30)	(73)
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	6	10
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	(30)	(57)
Power derivative contracts | 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
Power derivative contracts | 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	(16)
Commodity Contract [Member] | Derivatives not designated as hedging contracts
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	42	279
Derivative Liability, Fair Value, Net	(35)	(75)
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	153	143
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	361	260
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	(1)	(53)
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)	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 Asset, Fair Value, Net	1	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	$ (21)	$ 0

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, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Energy Related Derivative [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives not designated as accounting hedges	$ 175	$ 6	$ 182	$ (4)
Derivative, Loss on Derivative	19		21
Energy Related Derivative [Member] | Revenues—Natural gas sales
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives not designated as accounting hedges	6	4	9	(12)
Energy Related Derivative [Member] | Revenues—Product sales and other
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives not designated as accounting hedges	169	5	173	6
Energy Related Derivative [Member] | Costs of sales
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives not designated as accounting hedges	0	(3)	0	4
Energy Related Derivative [Member] | Other Income (Expense) [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivatives not designated as accounting hedges	0	0	0	(2)
Derivatives designated as hedging contracts | Operating Income (Loss) [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b)	63	1	192	(29)
Gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	(6)	26	4	(6)
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)	104	121	44	(20)
Derivatives designated as hedging contracts | Interest Rate Swap [Member] | Interest, net | Fair Value Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) recognized in income on derivatives and related hedged item	251	(25)	163	87
Derivatives designated as hedging contracts | Interest Rate Swap [Member] | 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)	(3)
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 [Member] | 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)	(4)	0	(6)	(10)
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	(283)	25	(166)	(87)
Derivatives designated as hedging contracts | Energy Related Derivative [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Loss to be reclassified within twelve months			161
Derivatives designated as hedging contracts | Energy Related Derivative [Member] | 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)	4	9	29	0
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 Related Derivative [Member] | 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)	60	(5)	161	(30)
Gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	(6)	26	4	(6)
Derivatives designated as hedging contracts | Energy Related Derivative [Member] | Costs of sales | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b)	(2)	(2)	(21)	4
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 Related Derivative [Member] | 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)	119	121	72	(10)
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)	(11)	0	(22)	0
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)	$ 2	$ 0	$ 25	$ 0

Risk Management Credit Risks (D

Risk Management Credit Risks (Details) - Energy Related Derivative [Member] - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Credit Derivatives [Line Items]
Letters of Credit Outstanding, Amount	$ 2	$ 20
Cash collateral held(b)
Credit Derivatives [Line Items]
Collateral posted(c)	14	47
Derivative, Collateral, Obligation to Return Cash	32	$ 13
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 Reporting of Am

Risk Management Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income [Roll Forward]
Net unrealized gains/(losses) on cash flow hedge derivatives	$ 327	$ (3)
Foreign currency translation adjustments	(108)	2
Pension and other postretirement liability adjustments	(236)	(23)
Total accumulated other comprehensive loss	(17)	(24)
Other comprehensive loss before reclassifications	44	(8)
Amounts reclassified from accumulated other comprehensive loss	(192)	11
Net current-period other comprehensive loss	(148)	3
Other comprehensive loss before reclassifications	(170)	(31)
Amounts reclassified from accumulated other comprehensive loss	0	0
Net current-period other comprehensive loss	(170)	(31)
Other comprehensive loss before reclassifications	7	2
Amounts reclassified from accumulated other comprehensive loss	0	0
Net current-period other comprehensive loss	7	2
Net current-period other comprehensive loss	(311)	(26)
Net unrealized gains/(losses) on cash flow hedge derivatives	179	0
Foreign currency translation adjustments	(278)	(29)
Pension and other postretirement liability adjustments	(229)	(21)
Total accumulated other comprehensive loss	(328)	(50)
Other comprehensive loss before reclassifications
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income [Roll Forward]
Other comprehensive loss before reclassifications	(119)	(37)
Amounts reclassified from accumulated other comprehensive loss
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income [Roll Forward]
Amounts reclassified from accumulated other comprehensive loss	$ (192)	$ 11

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, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	$ 622		$ 622		$ 594
Balance sheet liability fair value measurements by level	(72)		(72)		(109)
Fair Value, Assets Liabilites Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Derivatives-net asset (liability)	(37)	$ (116)	(61)	$ (110)
Included in earnings	(1)	14	(1)	0
Included in other comprehensive loss	0	10	0	0
Settlements	15	13	39	31
Derivatives-net asset (liability)	(23)	(79)	(23)	(79)
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	$ 16	2	$ (4)
Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	514		514		403
Balance sheet liability fair value measurements by level	(1)		(1)		(53)
Cross-currency swap agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	1		1
Balance sheet liability fair value measurements by level	(35)		(35)
Level 1 | Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	54		54		49
Balance sheet liability fair value measurements by level	(9)		(9)		(25)
Level 1 | Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	0		0		0
Balance sheet liability fair value measurements by level	0		0		0
Level 1 | Cross-currency swap agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	0		0
Balance sheet liability fair value measurements by level	0		0
Level 2 | Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	561		561		533
Balance sheet liability fair value measurements by level	(33)		(33)		(11)
Level 2 | Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	514		514		403
Balance sheet liability fair value measurements by level	(1)		(1)		(53)
Level 2 | Cross-currency swap agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	1		1
Balance sheet liability fair value measurements by level	(35)		(35)
Level 3 | Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	7		7		12
Balance sheet liability fair value measurements by level	(30)		(30)		(73)
Level 3 | Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	0		0		0
Balance sheet liability fair value measurements by level	0		0		0
Level 3 | Cross-currency swap agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance sheet asset fair value measurements by level	0		0
Balance sheet liability fair value measurements by level	0		0
Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net amount	550		550		535
Net amount	(18)		(18)		(16)
Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net amount	513		513		359
Net amount	0		0		(9)
Cross-currency swap agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net amount	0		0
Net amount	(34)		(34)
Contracts available for netting | Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contracts available for netting	(40)		(40)		(46)
Contracts available for netting	40		40		46
Contracts available for netting | Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contracts available for netting	(1)		(1)		(44)
Contracts available for netting	1		1		44
Contracts available for netting | Cross-currency swap agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contracts available for netting	(1)		(1)
Contracts available for netting	1		1
Cash collateral held(b) | Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash collateral held(b)	(32)		(32)		(13)
Collateral posted(c)	14		14		47
Cash collateral held(b) | Interest Rate Swap [Member]
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
Cash collateral held(b) | Cross-currency swap agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash collateral held(b)	0		0
Collateral posted(c)	$ 0		$ 0

Fair Value Fair Value of Financ

Fair Value Fair Value of Financial Instruments (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Carrying value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	$ 44,633	$ 42,814
Estimated fair value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	$ 41,136	$ 43,582

Reportable Segments (Details)

Reportable Segments (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Segment Reporting Information [Line Items]
Revenues	$ 3,707	$ 4,291	$ 10,767	$ 12,275
Segment Earnings Before DD&A(a)	1,592	2,097	5,215	5,765
DD&A expense	(617)	(520)	(1,725)	(1,518)
Amortization of excess cost of equity investments	(13)	(12)	(39)	(33)
Other revenues	948	1,198	2,613	3,466
General and administrative expense	(160)	(135)	(540)	(461)
Interest expense, net of unallocable interest income	(540)	(432)	(1,524)	(1,320)
Income tax expense	(108)	(246)	(521)	(624)
Total consolidated net income	183	779	944	1,877
Assets	85,677		85,677		$ 83,049
Assets held for sale	46		46		56
Natural Gas Pipelines
Segment Reporting Information [Line Items]
Segment Earnings Before DD&A(a)	993	1,182	2,936	3,207
Assets	54,725		54,725		52,532
CO2
Segment Reporting Information [Line Items]
Revenues	517	508	1,316	1,445
Segment Earnings Before DD&A(a)	29	388	605	1,083
Assets	4,906		4,906		5,227
Terminals
Segment Reporting Information [Line Items]
Segment Earnings Before DD&A(a)	249	249	798	692
Assets	9,212		9,212		8,850
Products Pipelines
Segment Reporting Information [Line Items]
Segment Earnings Before DD&A(a)	288	222	811	632
Assets	8,471		8,471		7,179
Kinder Morgan Canada
Segment Reporting Information [Line Items]
Revenues	68	73	193	210
Segment Earnings Before DD&A(a)	42	50	120	138
Assets	1,452		1,452		1,593
Other
Segment Reporting Information [Line Items]
Revenues	0	3	3	5
Segment Earnings Before DD&A(a)	(9)	6	(55)	13
Assets	427		427		455
Total segment revenues
Segment Reporting Information [Line Items]
Revenues	3,705	4,288	10,757	12,260
Assets	79,193		79,193		75,836
Other revenues
Segment Reporting Information [Line Items]
Other revenues	10	9	28	27
Interest expense, net of unallocable interest income	(539)	(431)	(1,525)	(1,325)
Income tax expense	(90)	(229)	(470)	(578)
Corporate assets(b)
Segment Reporting Information [Line Items]
Assets	6,438		6,438		$ 7,157
Revenues from external customers | Natural Gas Pipelines
Segment Reporting Information [Line Items]
Revenues	2,176	2,745	6,444	7,766
Revenues from external customers | Terminals
Segment Reporting Information [Line Items]
Revenues	469	433	1,395	1,244
Revenues from external customers | Products Pipelines
Segment Reporting Information [Line Items]
Revenues	467	520	1,388	1,578
Intersegment revenues | Natural Gas Pipelines
Segment Reporting Information [Line Items]
Revenues	8	6	16	11
Intersegment revenues | Terminals
Segment Reporting Information [Line Items]
Revenues	0	0	1	1
Intersegment revenues | Products Pipelines
Segment Reporting Information [Line Items]
Revenues	0	0	1	0
Less: Total intersegment revenues
Segment Reporting Information [Line Items]
Revenues	$ (8)	$ (6)	$ (18)	$ (12)

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income tax expense	$ 108	$ 246	$ 521	$ 624
Effective tax rate	37.10%	24.00%	35.60%	25.00%
Federal statutory income tax rate	35.00%	35.00%	35.00%	35.00%
Unrecognized Tax Benefits	$ 156		$ 156		$ 189
Unrecognized Tax Benefits, Reduction Resulting from Lapse of Applicable Statute of Limitations			$ 33

Federal Energy Regulatory Commi

Federal Energy Regulatory Commission Proceedings (Details) - Regulated Operation [Member] - Federal Energy Regulatory Commission [Member] - Various Shippers [Member] - Unfavorable Regulatory Action [Member] $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)
2008 rate case and the 2010 rate case [Member] | EPNG [Member] | Opinion 517 issued and implemented (rehearing pending); and Opinion 528 issued and is awaiting filing of court document) [Member]
EPNG [Abstract]
Loss Contingency, Pending Claims, Number	2
Repreations, 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	$ 20
Revenue Subject to Refund [Member] | SFPP [Member] | Pending Litigation [Member]
SFPP [Abstract]
Loss Contingency, Damages Sought, Value	$ 119

Other Commercial Matters (Detai

Other Commercial Matters (Details) $ in Millions	Apr. 21, 2015USD ($)	Oct. 25, 2013USD ($)	Jan. 01, 2004	Sep. 30, 2015USD ($)	Sep. 30, 2013USD ($)	Sep. 01, 2011USD ($)
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
Elba Liquefaction [Member] | Brinckerhoff v. El Paso Pipeline GP Company, LLC., et al. [Member]
Loss Contingencies [Line Items]
Business Acquisition, Additional Percentage of Interest Acquired	49.00%
SNG [Member] | Brinckerhoff v. El Paso Pipeline GP Company, LLC., et al. [Member]
Loss Contingencies [Line Items]
Business Acquisition, Additional Percentage of Interest Acquired	15.00%
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
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
Price Reporting Litigation [Member] | Kinder Morgan Bulk Terminals, Inc. [Member] | Price Reporting Litigation [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value				$ 140
KMEP Capex Litigation [Member] | KMEP LP Capex Litigation [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value				$ 27.5
2008 rate case and the 2010 rate case [Member] | EPNG [Member] | Unfavorable Regulatory Action [Member] | Opinion 517 issued and implemented (rehearing pending); and Opinion 528 issued and is awaiting filing of court document) [Member] | Regulated Operation [Member] | Various Shippers [Member] | Federal Energy Regulatory Commission [Member]
Loss Contingencies [Line Items]
Loss Contingency, Pending Claims, Number				2

Litigation, Environmental and55

Litigation, Environmental and Other Contingencies Litigation General (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Loss Contingency, Information about Litigation Matters [Abstract]
Estimated Litigation Liability	$ 441	$ 400

Environmental Matters (Details)

Environmental Matters (Details) $ in Millions	Jul. 30, 2015USD ($)	Nov. 08, 2013	Aug. 06, 2013Defendants	Jul. 24, 2013	Aug. 31, 2015USD ($)	Aug. 31, 2007USD ($)	Dec. 31, 2000Terminals	Sep. 30, 2015USD ($)PartiesTerminalsDefendants	Dec. 31, 2010USD ($)	Dec. 31, 1969	Dec. 31, 2014USD ($)
Loss Contingencies [Line Items]
Accrual for environmental loss contingencies								$ 306			$ 340
Environmental recoveries receivable								13			$ 14
Rare Metals Inc. [Member]
Loss Contingencies [Line Items]
Number of Uranium Mines										20
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
Lower Passaic River Study Area [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Number of Parties at a Joint Defense Group								70
Number of Facilities								100
Philadelphia Terminal, Notice of Violation [Member] [Member] | Tentative Settlement [Member]
Loss Contingencies [Line Items]
Environmental Remediation Expense								$ 0.6
Philadelphia and Point Breeze Terminals, Notice of Violation [Member] | Tentative Settlement [Member]
Loss Contingencies [Line Items]
Environmental Remediation Expense	$ 0.2
Percent of reduced capacity	10.00%
Central Florida Pipeline LLC [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Environmental Remediation Expense					$ 0.9
Portland Harbor Superfund Site, Willamette River, Portland, Oregon [Member] | Environmental Protection Agency [Member] | Regulated Operation [Member] | Portland Harbor Superfund Site, Willamette River, Portland, Oregon [Member] | GATX Terminals Corporation (n/k/a KMLT) [Member]
Loss Contingencies [Line Items]
Number of Liquid Terminals | Terminals							2	4
Number of Parties Involved In Site Cleanup Allocation Negotiations | Parties								90
Southeast Louisiana Flood Protection Litigation [Member] | Board of Commissioners of the Southeast Louisiana Flood Protection Authority - East [Member] | TGP and SNG [Member]
Loss Contingencies [Line Items]
Loss Contingency, Number of Defendants				100
Plaquemines Parish, Louisiana (Docket No. 60-999) [Member] | 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
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
Preferred alternative [Member] | Lower Passaic River Study Area [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Environmental Remediation Expense								$ 1,700

Litigation, Environmental and57

Litigation, Environmental and Other Contingencies Commitments (Details) - Philly Tankers LLC [Member] $ in Millions	Sep. 30, 2015USD ($)
Long-term Purchase Commitment [Line Items]
Unrecorded Unconditional Purchase Obligation, Total	$ 568
Unrecorded Unconditional Purchase Obligation, Due in Remainder of Fiscal Year	14
Unrecorded Unconditional Purchase Obligation, Due in Next Twelve Months	170
Unrecorded Unconditional Purchase Obligation, Due within Two Years	$ 384

Guarantee of Securities of Su58

Guarantee of Securities of Subsidiaries (Details) $ in Millions	Sep. 30, 2015USD ($)
Parent Issuer and Guarantor
Long-term Debt	$ 13,853
Subsidiary Issuer and Guarantor - KMP
Long-term Debt	20,360
Subsidiary Issuer and Guarantor - Copano
Long-term Debt	332
Subsidiary Guarantors [Member]
Long-term Debt	7,222
Capitalized Lease Debt Not Subject to Cross Guarantee Agreement	$ 177

Guarantee of Securities of Su59

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, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Condensed Income Statements, Captions [Line Items]
Total Revenues	$ 3,707	$ 4,291	$ 10,767	$ 12,275
Costs of sales	1,106	1,642	3,281	4,895
Depreciation, depletion and amortization	617	520	1,725	1,518
Other operating expenses	(2)	0	(5)	0
Total operating costs, expenses and other	2,986	2,959	8,076	8,783
Operating (loss) income	721	1,332	2,691	3,492
Earnings from equity investments	114	107	330	306
Interest, net	(540)	(432)	(1,524)	(1,320)
Amortization of excess cost of equity investments and other, net	9	30	33	56
Income before income taxes	291	1,025	1,465	2,501
Income tax expense	(108)	(246)	(521)	(624)
Net income	183	779	944	1,877
Net Loss (Income) Attributable to Noncontrolling Interests	3	(450)	4	(977)
Net income attributable to controlling interests	186	329	948	900
Total other comprehensive loss	(37)	46	(311)	(70)
Comprehensive income (loss)	146	825	633	1,807
Comprehensive income attributable to noncontrolling interests	3	(478)	4	(933)
Comprehensive income (loss) attributable to controlling interests	149	347	637	874
Consolidating Adjustments [Member]
Condensed Income Statements, Captions [Line Items]
Total Revenues	(12)	(4)	(36)	(1)
Costs of sales	1	8	2	35
Depreciation, depletion and amortization	0	0	0	0
Other operating expenses	(13)	(12)	(38)	(36)
Total operating costs, expenses and other	(12)	(4)	(36)	(1)
Operating (loss) income	0	0	0	0
Earnings from consolidated subsidiaries	(1,284)	(2,893)	(5,058)	(7,456)
Earnings from equity investments	0	0	0	0
Interest, net	0	0	0	0
Amortization of excess cost of equity investments and other, net	0	0	0	0
Income before income taxes	(1,284)	(2,893)	(5,058)	(7,456)
Income tax expense	0	0	0	0
Net income	(1,284)	(2,893)	(5,058)	(7,456)
Net Loss (Income) Attributable to Noncontrolling Interests	3	(322)	4	(650)
Net income attributable to controlling interests	(1,281)	(3,215)	(5,054)	(8,106)
Total other comprehensive loss	191	(38)	1,210	290
Comprehensive income (loss)	(1,093)	(2,931)	(3,848)	(7,166)
Comprehensive income attributable to noncontrolling interests	3	(343)	4	(617)
Comprehensive income (loss) attributable to controlling interests	(1,090)	(3,274)	(3,844)	(7,783)
Parent Issuer and Guarantor
Condensed Income Statements, Captions [Line Items]
Total Revenues	9	9	28	27
Costs of sales	0	0	0	0
Depreciation, depletion and amortization	6	5	16	15
Other operating expenses	16	4	66	24
Total operating costs, expenses and other	22	9	82	39
Operating (loss) income	(13)	0	(54)	(12)
Earnings from consolidated subsidiaries	366	581	1,454	1,554
Earnings from equity investments	0	0	0	0
Interest, net	(155)	(111)	(356)	(373)
Amortization of excess cost of equity investments and other, net	0	0	0	0
Income before income taxes	198	470	1,044	1,169
Income tax expense	(12)	(57)	(96)	(98)
Net income	186	413	948	1,071
Net Loss (Income) Attributable to Noncontrolling Interests	0	(84)	0	(171)
Net income attributable to controlling interests	186	329	948	900
Total other comprehensive loss	(37)	24	(311)	(33)
Comprehensive income (loss)	149	437	637	1,038
Comprehensive income attributable to noncontrolling interests	0	(90)	0	(164)
Comprehensive income (loss) attributable to controlling interests	149	347	637	874
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	1	2	39	5
Total operating costs, expenses and other	1	2	39	5
Operating (loss) income	(1)	(2)	(39)	(5)
Earnings from consolidated subsidiaries	484	1,126	2,033	2,897
Earnings from equity investments	0	0	0	0
Interest, net	23	(28)	30	(80)
Amortization of excess cost of equity investments and other, net	0	0	0	0
Income before income taxes	506	1,096	2,024	2,812
Income tax expense	(2)	(3)	(6)	(8)
Net income	504	1,093	2,018	2,804
Net Loss (Income) Attributable to Noncontrolling Interests	0	(44)	0	(156)
Net income attributable to controlling interests	504	1,049	2,018	2,648
Total other comprehensive loss	(42)	58	(419)	(93)
Comprehensive income (loss)	462	1,151	1,599	2,711
Comprehensive income attributable to noncontrolling interests	0	(45)	0	(152)
Comprehensive income (loss) attributable to controlling interests	462	1,106	1,599	2,559
Subsidiary Issuer and Guarantor - Copano
Condensed Income Statements, Captions [Line Items]
Total Revenues	0	0	0	0
Costs of sales	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Other operating expenses	(2)	9	(1)	24
Total operating costs, expenses and other	(2)	9	(1)	24
Operating (loss) income	2	(9)	1	(24)
Earnings from consolidated subsidiaries	48	59	20	159
Earnings from equity investments	0	0	0	0
Interest, net	(12)	(13)	(36)	(35)
Amortization of excess cost of equity investments and other, net	0	0	0	0
Income before income taxes	38	37	(15)	100
Income tax expense	0	0	0	0
Net income	38	37	(15)	100
Net Loss (Income) Attributable to Noncontrolling Interests	0	0	0	0
Net income attributable to controlling interests	38	37	(15)	100
Total other comprehensive loss	0	0	0	0
Comprehensive income (loss)	38	37	(15)	100
Comprehensive income attributable to noncontrolling interests	0	0	0	0
Comprehensive income (loss) attributable to controlling interests	38	37	(15)	100
Subsidiary Guarantors
Condensed Income Statements, Captions [Line Items]
Total Revenues	3,289	3,649	9,565	10,784
Costs of sales	1,007	1,510	2,997	4,467
Depreciation, depletion and amortization	508	423	1,423	1,232
Other operating expenses	1,100	667	2,552	1,980
Total operating costs, expenses and other	2,615	2,600	6,972	7,679
Operating (loss) income	674	1,049	2,593	3,105
Earnings from consolidated subsidiaries	376	640	1,510	1,432
Earnings from equity investments	114	108	304	307
Interest, net	(381)	(261)	(1,133)	(766)
Amortization of excess cost of equity investments and other, net	(5)	(6)	(13)	(13)
Income before income taxes	778	1,530	3,261	4,065
Income tax expense	(93)	(21)	(409)	(50)
Net income	685	1,509	2,852	4,015
Net Loss (Income) Attributable to Noncontrolling Interests	0	0	0	0
Net income attributable to controlling interests	685	1,509	2,852	4,015
Total other comprehensive loss	(24)	85	(525)	(106)
Comprehensive income (loss)	661	1,594	2,327	3,909
Comprehensive income attributable to noncontrolling interests	0	0	0	0
Comprehensive income (loss) attributable to controlling interests	661	1,594	2,327	3,909
Subsidiary Non-Guarantors
Condensed Income Statements, Captions [Line Items]
Total Revenues	421	637	1,210	1,465
Costs of sales	98	124	282	393
Depreciation, depletion and amortization	103	92	286	271
Other operating expenses	161	127	452	373
Total operating costs, expenses and other	362	343	1,020	1,037
Operating (loss) income	59	294	190	428
Earnings from consolidated subsidiaries	10	487	41	1,414
Earnings from equity investments	0	(1)	0	(1)
Interest, net	(15)	(19)	(29)	(66)
Amortization of excess cost of equity investments and other, net	1	24	7	36
Income before income taxes	55	785	209	1,811
Income tax expense	(1)	(165)	(10)	(468)
Net income	54	620	199	1,343
Net Loss (Income) Attributable to Noncontrolling Interests	0	0	0	0
Net income attributable to controlling interests	54	620	199	1,343
Total other comprehensive loss	(125)	(83)	(266)	(128)
Comprehensive income (loss)	(71)	537	(67)	1,215
Comprehensive income attributable to noncontrolling interests	0	0	0	0
Comprehensive income (loss) attributable to controlling interests	(71)	537	(67)	1,215
Consolidated KMI
Condensed Income Statements, Captions [Line Items]
Total Revenues	3,707	4,291	10,767	12,275
Costs of sales	1,106	1,642	3,281	4,895
Depreciation, depletion and amortization	617	520	1,725	1,518
Other operating expenses	1,263	797	3,070	2,370
Total operating costs, expenses and other	2,986	2,959	8,076	8,783
Operating (loss) income	721	1,332	2,691	3,492
Earnings from consolidated subsidiaries	0	0	0	0
Earnings from equity investments	114	107	304	306
Interest, net	(540)	(432)	(1,524)	(1,320)
Amortization of excess cost of equity investments and other, net	(4)	18	(6)	23
Income before income taxes	291	1,025	1,465	2,501
Income tax expense	(108)	(246)	(521)	(624)
Net income	183	779	944	1,877
Net Loss (Income) Attributable to Noncontrolling Interests	3	(450)	4	(977)
Net income attributable to controlling interests	186	329	948	900
Total other comprehensive loss	(37)	46	(311)	(70)
Comprehensive income (loss)	146	825	633	1,807
Comprehensive income attributable to noncontrolling interests	3	(478)	4	(933)
Comprehensive income (loss) attributable to controlling interests	$ 149	$ 347	$ 637	$ 874

Guarantee of Securities of Su60

Guarantee of Securities of Subsidiaries Condensed Consolidating Balance Sheets (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014	Sep. 30, 2014	Dec. 31, 2013
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	$ 179	$ 315	$ 472	$ 598
Other current assets	460	746
Property, plant and equipment, net	40,608	38,564
Investments	5,943	6,036
Goodwill	24,952	24,654
Other non-current assets	2,161	2,090
Deferred tax assets	5,327	5,651
Total assets	85,677	83,049
Long-term debt	41,630	40,097
Total liabilities	49,835	48,623
Total KMI equity	35,514	34,076
Noncontrolling interests	328	350
Total stockholders’ equity	35,842	34,426	28,769	28,285
Total liabilities and stockholders’ equity	85,677	83,049
Consolidating Adjustments [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	0	0	0	0
Other current assets	(7)	(20)
Property, plant and equipment, net	0	0
Investments	0	0
Goodwill	0	0
Other non-current assets	0	0
Deferred tax assets	(3,612)	(3,605)
Total assets	(133,191)	(133,919)
Current portion of debt	0	0
All other current liabilities	(7)	(20)
Long-term debt	0	0
Notes payable to affiliates	(29,351)	(27,202)
Deferred income taxes	(3,612)	(3,605)
All other long-term liabilities and deferred credits	0	0
Total liabilities	(45,895)	(46,017)
Total KMI equity	(87,624)	(88,252)
Noncontrolling interests	328	350
Total stockholders’ equity	(87,296)	(87,902)
Total liabilities and stockholders’ equity	(133,191)	(133,919)
Parent Issuer and Guarantor
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	12	4	31	83
Other current assets	184	397
Property, plant and equipment, net	258	263
Investments	16	16
Goodwill	15,089	15,087
Other non-current assets	267	258
Deferred tax assets	0	0
Total assets	56,104	53,724
Current portion of debt	535	1,486
All other current liabilities	334	319
Long-term debt	13,953	11,833
Notes payable to affiliates	2,516	2,619
Deferred income taxes	2,147	2,099
All other long-term liabilities and deferred credits	441	583
Total liabilities	20,590	19,648
Total KMI equity	35,514	34,076
Noncontrolling interests	0	0
Total stockholders’ equity	35,514	34,076
Total liabilities and stockholders’ equity	56,104	53,724
Subsidiary Issuer and Guarantor - KMP
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	0	15	190	88
Other current assets	129	152
Property, plant and equipment, net	0	0
Investments	2	1
Goodwill	22	22
Other non-current assets	349	249
Deferred tax assets	0	0
Total assets	53,189	55,020
Current portion of debt	875	699
All other current liabilities	260	498
Long-term debt	20,149	20,564
Notes payable to affiliates	448	153
Deferred income taxes	0	0
All other long-term liabilities and deferred credits	180	78
Total liabilities	31,566	33,941
Total KMI equity	21,623	21,079
Noncontrolling interests	0	0
Total stockholders’ equity	21,623	21,079
Total liabilities and stockholders’ equity	53,189	55,020
Subsidiary Issuer and Guarantor - Copano
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	0	0	0	1
Other current assets	1	3
Property, plant and equipment, net	0	5
Investments	0	0
Goodwill	920	920
Other non-current assets	0	0
Deferred tax assets	0	0
Total assets	3,234	2,850
Current portion of debt	0	0
All other current liabilities	15	12
Long-term debt	380	386
Notes payable to affiliates	651	753
Deferred income taxes	2	2
All other long-term liabilities and deferred credits	0	2
Total liabilities	1,307	1,270
Total KMI equity	1,927	1,580
Noncontrolling interests	0	0
Total stockholders’ equity	1,927	1,580
Total liabilities and stockholders’ equity	3,234	2,850
Subsidiary Guarantors
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	25	17	8	17
Other current assets	2,305	2,547
Property, plant and equipment, net	31,972	29,490
Investments	5,811	5,910
Goodwill	5,743	5,419
Other non-current assets	5,046	3,772
Deferred tax assets	8,939	9,256
Total assets	89,888	88,267
Current portion of debt	1,471	381
All other current liabilities	1,987	1,812
Long-term debt	6,461	6,599
Notes payable to affiliates	24,378	22,437
Deferred income taxes	0	0
All other long-term liabilities and deferred credits	965	987
Total liabilities	37,023	33,767
Total KMI equity	52,865	54,500
Noncontrolling interests	0	0
Total stockholders’ equity	52,865	54,500
Total liabilities and stockholders’ equity	89,888	88,267
Subsidiary Non-Guarantors
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	142	279	243	409
Other current assets	276	358
Property, plant and equipment, net	8,378	8,806
Investments	114	109
Goodwill	3,178	3,206
Other non-current assets	118	113
Deferred tax assets	0	0
Total assets	16,453	17,107
Current portion of debt	122	151
All other current liabilities	599	1,024
Long-term debt	687	715
Notes payable to affiliates	1,358	1,240
Deferred income taxes	1,463	1,504
All other long-term liabilities and deferred credits	428	514
Total liabilities	5,244	6,014
Total KMI equity	11,209	11,093
Noncontrolling interests	0	0
Total stockholders’ equity	11,209	11,093
Total liabilities and stockholders’ equity	16,453	17,107
Consolidated KMI
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	179	315	$ 472	$ 598
Other current assets	2,888	3,437
Property, plant and equipment, net	40,608	38,564
Investments	5,943	6,036
Goodwill	24,952	24,654
Other non-current assets	5,780	4,392
Deferred tax assets	5,327	5,651
Total assets	85,677	83,049
Current portion of debt	3,003	2,717
All other current liabilities	3,188	3,645
Long-term debt	41,630	40,097
Notes payable to affiliates	0	0
Deferred income taxes	0	0
All other long-term liabilities and deferred credits	2,014	2,164
Total liabilities	49,835	48,623
Total KMI equity	35,514	34,076
Noncontrolling interests	328	350
Total stockholders’ equity	35,842	34,426
Total liabilities and stockholders’ equity	85,677	83,049
Affiliated Entity [Member] | Consolidating Adjustments [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Other current assets	(12,925)	(15,190)
Investments	(87,296)	(87,902)
Other non-current assets	(29,351)	(27,202)
All other current liabilities	(12,925)	(15,190)
Affiliated Entity [Member] | Parent Issuer and Guarantor
Condensed Balance Sheet Statements, Captions [Line Items]
Other current assets	1,915	1,868
Investments	33,775	31,372
Other non-current assets	4,588	4,459
All other current liabilities	664	709
Affiliated Entity [Member] | Subsidiary Issuer and Guarantor - KMP
Condensed Balance Sheet Statements, Captions [Line Items]
Other current assets	1,042	1,335
Investments	29,470	33,414
Other non-current assets	22,175	19,832
All other current liabilities	9,654	11,949
Affiliated Entity [Member] | Subsidiary Issuer and Guarantor - Copano
Condensed Balance Sheet Statements, Captions [Line Items]
Other current assets	19	11
Investments	2,294	1,911
Other non-current assets	0	0
All other current liabilities	259	115
Affiliated Entity [Member] | Subsidiary Guarantors
Condensed Balance Sheet Statements, Captions [Line Items]
Other current assets	9,399	11,573
Investments	18,420	17,868
Other non-current assets	2,228	2,415
All other current liabilities	1,761	1,551
Affiliated Entity [Member] | Subsidiary Non-Guarantors
Condensed Balance Sheet Statements, Captions [Line Items]
Other current assets	550	403
Investments	3,337	3,337
Other non-current assets	360	496
All other current liabilities	587	866
Affiliated Entity [Member] | Consolidated KMI
Condensed Balance Sheet Statements, Captions [Line Items]
Other current assets	0	0
Investments	0	0
Other non-current assets	0	0
All other current liabilities	$ 0	$ 0

Guarantee of Securities of Su61

Guarantee of Securities of Subsidiaries Condensed Consolidating Statements of Cash Flows (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	$ 3,507	$ 3,492
Capital expenditures	(2,999)	(2,678)
Contributions to investments	(69)	(342)
Acquisitions of assets and investments	(1,864)	(961)
Distributions from equity investments in excess of cumulative earnings	181	138
Other, net	84	(38)
Net cash used in investing activities	(4,722)	(4,020)
Issuances of debt	12,281	13,399
Payments of debt	(11,893)	(11,585)
Debt issue costs	(20)	(52)
Issuances of shares	3,833	0
Cash dividends	(3,084)	(1,304)
Repurchases of shares and warrants	(12)	(192)
Contributions from noncontrolling interests	7	1,638
Distributions to noncontrolling interests	(25)	(1,491)
Other, net	(1)	(2)
Net cash provided by (used in) financing activities	1,086	411
Effect of exchange rate changes on cash and cash equivalents	(7)	(9)
Net increase (decrease) in cash and cash equivalents	(136)	(126)
Cash and Cash Equivalents, beginning of period	315	598
Cash and Cash Equivalents, end of period	179	472
Consolidating Adjustments [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	(7,310)	(5,566)
Funding to affiliates	17,358	9,168
Capital expenditures	5	199
Contributions to investments	5	118
Investment in KMP	159	34
Drop down assets to KMP		0
Acquisitions of assets and investments	0	0
Distributions from equity investments in excess of cumulative earnings	(992)	(438)
Other, net	(5)	(198)
Net cash used in investing activities	16,530	8,883
Issuances of debt	0	0
Payments of debt	0	0
Funding from (to) affiliates	(17,358)	(9,168)
Debt issue costs	0	0
Issuances of shares	0
Cash dividends	0	0
Repurchases of shares and warrants		0
Repurchases of warrants	0
Contributions from parents	(171)	(1,791)
Contributions from noncontrolling interests	7	1,638
Distributions to parents	8,327	7,495
Distributions to noncontrolling interests	(25)	(1,491)
Other, net	0	0
Net cash provided by (used in) financing activities	(9,220)	(3,317)
Effect of exchange rate changes on cash and cash equivalents	0	0
Net increase (decrease) in cash and cash equivalents	0	0
Cash and Cash Equivalents, beginning of period	0	0
Cash and Cash Equivalents, end of period	0	0
Parent Issuer and Guarantor
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	(2,208)	1,166
Funding to affiliates	(1,767)	(197)
Capital expenditures	(9)	(11)
Contributions to investments	(5)	0
Investment in KMP	(159)	(34)
Drop down assets to KMP		875
Acquisitions of assets and investments	(1,709)	0
Distributions from equity investments in excess of cumulative earnings	1,060	70
Other, net	0	0
Net cash used in investing activities	(2,589)	703
Issuances of debt	12,281	3,258
Payments of debt	(11,544)	(3,804)
Funding from (to) affiliates	3,351	149
Debt issue costs	(20)	(28)
Issuances of shares	3,833
Cash dividends	(3,084)	(1,304)
Repurchases of shares and warrants		(192)
Repurchases of warrants	(12)
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	0
Net cash provided by (used in) financing activities	4,805	(1,921)
Effect of exchange rate changes on cash and cash equivalents	0	0
Net increase (decrease) in cash and cash equivalents	8	(52)
Cash and Cash Equivalents, beginning of period	4	83
Cash and Cash Equivalents, end of period	12	31
Subsidiary Issuer and Guarantor - KMP
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	5,917	2,868
Funding to affiliates	(7,699)	(5,037)
Capital expenditures	0	0
Contributions to investments	0	(118)
Investment in KMP	0	0
Drop down assets to KMP		(875)
Acquisitions of assets and investments	0	0
Distributions from equity investments in excess of cumulative earnings	0	367
Other, net	16	(2)
Net cash used in investing activities	(7,683)	(5,665)
Issuances of debt	0	10,141
Payments of debt	(300)	(7,698)
Funding from (to) affiliates	5,602	2,225
Debt issue costs	0	(24)
Issuances of shares	0
Cash dividends	0	0
Repurchases of shares and warrants		0
Repurchases of warrants	0
Contributions from parents	156	1,578
Contributions from noncontrolling interests	0	0
Distributions to parents	(3,706)	(3,322)
Distributions to noncontrolling interests	0	0
Other, net	(1)	(1)
Net cash provided by (used in) financing activities	1,751	2,899
Effect of exchange rate changes on cash and cash equivalents	0	0
Net increase (decrease) in cash and cash equivalents	(15)	102
Cash and Cash Equivalents, beginning of period	15	88
Cash and Cash Equivalents, end of period	0	190
Subsidiary Issuer and Guarantor - Copano
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	81	(92)
Funding to affiliates	(2)	0
Capital expenditures	(3)	(64)
Contributions to investments	0	0
Investment in KMP	0	0
Drop down assets to KMP		0
Acquisitions of assets and investments	0	0
Distributions from equity investments in excess of cumulative earnings	0	0
Other, net	5	199
Net cash used in investing activities	0	135
Issuances of debt	0	0
Payments of debt	0	0
Funding from (to) affiliates	(81)	(44)
Debt issue costs	0	0
Issuances of shares	0
Cash dividends	0	0
Repurchases of shares and warrants		0
Repurchases of warrants	0
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	0
Net cash provided by (used in) financing activities	(81)	(44)
Effect of exchange rate changes on cash and cash equivalents	0	0
Net increase (decrease) in cash and cash equivalents	0	(1)
Cash and Cash Equivalents, beginning of period	0	1
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	6,834	3,897
Funding to affiliates	(7,293)	(2,785)
Capital expenditures	(2,747)	(2,254)
Contributions to investments	(62)	(342)
Investment in KMP	0	0
Drop down assets to KMP		0
Acquisitions of assets and investments	(210)	(1,085)
Distributions from equity investments in excess of cumulative earnings	113	139
Other, net	50	23
Net cash used in investing activities	(10,149)	(6,304)
Issuances of debt	0	0
Payments of debt	(42)	(76)
Funding from (to) affiliates	7,842	6,344
Debt issue costs	0	1
Issuances of shares	0
Cash dividends	0	0
Repurchases of shares and warrants		0
Repurchases of warrants	0
Contributions from parents	3	151
Contributions from noncontrolling interests	0	0
Distributions to parents	(4,480)	(4,021)
Distributions to noncontrolling interests	0	0
Other, net	0	(1)
Net cash provided by (used in) financing activities	3,323	2,398
Effect of exchange rate changes on cash and cash equivalents	0	0
Net increase (decrease) in cash and cash equivalents	8	(9)
Cash and Cash Equivalents, beginning of period	17	17
Cash and Cash Equivalents, end of period	25	8
Subsidiary Non-Guarantors
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	193	1,219
Funding to affiliates	(597)	(1,149)
Capital expenditures	(245)	(548)
Contributions to investments	(7)	0
Investment in KMP	0	0
Drop down assets to KMP		0
Acquisitions of assets and investments	0	(15)
Distributions from equity investments in excess of cumulative earnings	0	0
Other, net	18	(60)
Net cash used in investing activities	(831)	(1,772)
Issuances of debt	0	0
Payments of debt	(7)	(7)
Funding from (to) affiliates	644	494
Debt issue costs	0	(1)
Issuances of shares	0
Cash dividends	0	0
Repurchases of shares and warrants		0
Repurchases of warrants	0
Contributions from parents	12	62
Contributions from noncontrolling interests	0	0
Distributions to parents	(141)	(152)
Distributions to noncontrolling interests	0	0
Other, net	0	0
Net cash provided by (used in) financing activities	508	396
Effect of exchange rate changes on cash and cash equivalents	(7)	(9)
Net increase (decrease) in cash and cash equivalents	(137)	(166)
Cash and Cash Equivalents, beginning of period	279	409
Cash and Cash Equivalents, end of period	142	243
Consolidated KMI
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	3,507	3,492
Funding to affiliates	0	0
Capital expenditures	(2,999)	(2,678)
Contributions to investments	(69)	(342)
Investment in KMP	0	0
Drop down assets to KMP		0
Acquisitions of assets and investments	(1,919)	(1,100)
Distributions from equity investments in excess of cumulative earnings	181	138
Other, net	84	(38)
Net cash used in investing activities	(4,722)	(4,020)
Issuances of debt	12,281	13,399
Payments of debt	(11,893)	(11,585)
Funding from (to) affiliates	0	0
Debt issue costs	(20)	(52)
Issuances of shares	3,833
Cash dividends	(3,084)	(1,304)
Repurchases of shares and warrants		(192)
Repurchases of warrants	(12)
Contributions from parents	0	0
Contributions from noncontrolling interests	7	1,638
Distributions to parents	0	0
Distributions to noncontrolling interests	(25)	(1,491)
Other, net	(1)	(2)
Net cash provided by (used in) financing activities	1,086	411
Effect of exchange rate changes on cash and cash equivalents	(7)	(9)
Net increase (decrease) in cash and cash equivalents	(136)	(126)
Cash and Cash Equivalents, beginning of period	315	598
Cash and Cash Equivalents, end of period	$ 179	$ 472