Kinder Morgan (KMI) 10-K 24 Feb 14 2013 Q4 Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Jan. 31, 2014	Jun. 28, 2013
Entity Information [Line Items]	'	'	'
Entity Registrant Name	'Kinder Morgan, Inc.	'	'
Entity Central Index Key	'0001506307	'	'
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	'	'	$25,669,830,461
Entity Common Stock, Shares Outstanding	'	1,030,677,290	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'Q4	'	'
Document Type	'10-K	'	'
Amendment Flag	'false	'	'
Document Period End Date	31-Dec-13	'	'

CONSOLIDATED_STATEMENTS_OF_INC

CONSOLIDATED STATEMENTS OF INCOME (USD $)	12 Months Ended
Share data in Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Revenues	'	'	'
Natural gas sales	$3,605,000,000	$2,511,000,000	$3,305,000,000
Services	6,677,000,000	5,013,000,000	3,050,000,000
Product sales and other	3,788,000,000	2,449,000,000	1,588,000,000
Total Revenues	14,070,000,000	9,973,000,000	7,943,000,000
Operating Costs, Expenses and Other	'	'	'
Costs of sales	5,253,000,000	3,057,000,000	3,278,000,000
Operations and maintenance	2,112,000,000	1,702,000,000	1,491,000,000
Depreciation, depletion and amortization	1,806,000,000	1,419,000,000	1,068,000,000
General and administrative	613,000,000	929,000,000	515,000,000
Taxes, other than income taxes	395,000,000	286,000,000	174,000,000
Other income, net	-99,000,000	-13,000,000	-6,000,000
Total Operating Costs, Expenses and Other	10,080,000,000	7,380,000,000	6,520,000,000
Operating Income	3,990,000,000	2,593,000,000	1,423,000,000
Other Income (Expense)	'	'	'
Earnings from equity investments	327,000,000	153,000,000	226,000,000
Amortization of excess cost of equity investments	-39,000,000	-23,000,000	-7,000,000
Interest, net	-1,675,000,000	-1,399,000,000	-682,000,000
Gain (loss) on remeasurement of previously held equity investments to fair value (Note 3)	558,000,000	0	-167,000,000
Other, net	53,000,000	19,000,000	17,000,000
Total Other Income (Expense)	-552,000,000	-1,250,000,000	-613,000,000
Income from Continuing Operations Before Income Taxes	3,438,000,000	1,343,000,000	810,000,000
Income Tax Expense	-742,000,000	-139,000,000	-361,000,000
Income from Continuing Operations	2,696,000,000	1,204,000,000	449,000,000
Discontinued Operations (Note 3)	'	'	'
Income from operations of KMP’s FTC Natural Gas Pipelines disposal group and other, net of tax	0	160,000,000	211,000,000
Loss on sale and the remeasurement of KMP’s FTC Natural Gas Pipelines disposal group to fair value, net of tax	-4,000,000	-937,000,000	0
(Loss) Income from Discontinued Operations, Net of Tax	-4,000,000	-777,000,000	211,000,000
Net Income	2,692,000,000	427,000,000	660,000,000
Net Income Attributable to Noncontrolling Interests	-1,499,000,000	-112,000,000	-66,000,000
Net Income Attributable to Kinder Morgan, Inc.	$1,193,000,000	$315,000,000	$594,000,000
Diluted Weighted-Average Number of Shares Outstanding	'	'	'
Dividends Per Common Share Declared for the Period	$1.60	$1.40	$1.05
Class P [Member]	'	'	'
Earnings Per Share	'	'	'
Basic and Diluted Earnings Per Common Share From Continuing Operations	$1.15	$0.56	$0.70
Basic and Diluted (Loss) Earnings Per Common Share From Discontinued Operations	$0	($0.21)	$0.04
Total Basic and Diluted Earnings Per Common Share	$1.15	$0.35	$0.74
Basic Weighted-Average Number of Shares Outstanding	'	'	'
Basic Weighted-Average Number of Shares Outstanding	1,036	461	118
Diluted Weighted-Average Number of Shares Outstanding	'	'	'
Diluted Weighted-Average Number of Shares Outstanding	1,036	908	708
Common Class A [Member]	'	'	'
Earnings Per Share	'	'	'
Basic and Diluted Earnings Per Common Share From Continuing Operations	'	$0.47	$0.64
Basic and Diluted (Loss) Earnings Per Common Share From Discontinued Operations	'	($0.21)	$0.04
Total Basic and Diluted Earnings Per Common Share	'	$0.26	$0.68
Basic Weighted-Average Number of Shares Outstanding	'	'	'
Basic Weighted-Average Number of Shares Outstanding	'	446	589
Diluted Weighted-Average Number of Shares Outstanding	'	'	'
Diluted Weighted-Average Number of Shares Outstanding	'	446	589

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Kinder Morgan, Inc.	'	'	'
Net income	$1,193	$315	$594
Other comprehensive income (loss), net of tax	'	'	'
Change in fair value of derivatives utilized for hedging purposes (net of tax benefit (expense) of $6, $(19) and $(5), respectively)	-14	32	6
Reclassification of change in fair value of derivatives to net income (net of tax (expense) benefit of $(2), $3 and $(36), respectively)	4	-5	67
Foreign currency translation adjustments (net of tax benefit (expense) of $22, $(8), and $8, respectively)	-49	14	-14
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, before Reclassification Adjustments, Net of Tax	-151	53	45
Benefit plan amortization (net of tax expense of $(2), $(4) and $(4), respectively)	2	9	7
Total other comprehensive income (loss)	94	-3	21
Total comprehensive income	1,287	312	615
Noncontrolling Interests	'	'	'
Net income	1,499	112	66
Other comprehensive income (loss), net of tax (see Note 10)	'	'	'
Change in fair value of derivatives utilized for hedging purposes (net of tax benefit (expense) of $4, $(7) and $(1), respectively)	-24	50	7
Reclassification of change in fair value of derivatives to net income (net of tax (expense) benefit of $(1), $- and $(13), respectively)	7	-3	117
Foreign currency translation adjustments (net of tax benefit (expense) of $9, $(2) and $2, respectively)	-54	18	-21
Benefit plan adjustments (net of tax (expense) benefit of $(3), $- and $2, respectively)	15	13	-16
Benefit plan amortization (net of tax benefit (expense) of $-, $- and $-, respectively)	2	-4	0
Total other comprehensive (loss) income	-54	74	87
Total comprehensive income	1,445	186	153
Total	'	'	'
Net income	2,692	427	660
Other comprehensive loss, net of tax	'	'	'
Change in fair value of derivatives utilized for hedging purposes (net of tax benefit (expense) of $10, $(26) and $(6), respectively)	-38	82	13
Reclassification of change in fair value of derivatives to net income (net of tax (expense) benefit of $(3), $3 and $(49), respectively)	11	-8	184
Foreign currency translation adjustments (net of tax benefit (expense) of $31, $(10) and $10, respectively)	-103	32	-35
Benefit plan adjustments (net of tax (expense) benefit of $(89), $34 and $27, respectively)	166	-40	-61
Benefit plan amortization (net of tax expense of $(2), $(4) and $(4), respectively)	4	5	7
Total other comprehensive income	40	71	108
Total comprehensive income	$2,732	$498	$768

CONSOLIDATED_STATEMENTS_OF_COM1

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME, TAX (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Kinder Morgan, Inc., Tax [Abstract]	'	'	'
Change in fair value of derivatives utilized for hedging purposes	$6	($19)	($5)
Reclassification of change in fair value of derivatives to net income	-2	3	-36
Foreign currency translation adjustments	22	-8	8
Benefit plan adjustments	-86	34	25
Benefit plan amortization	-2	-4	-4
Noncontrolling Interests, Tax	'	'	'
Change in fair value of derivatives utilized for hedging purposes	4	-7	-1
Reclassification of change in fair value of derivatives to net income	-1	0	-13
Foreign currency translation adjustments	9	-2	2
Benefit plan adjustments	-3	0	2
Benefit plan amortization	0	0	0
Total, Tax	'	'	'
Change in fair value of derivatives utilized for hedging purposes	10	-26	-6
Reclassification of change in fair value of derivatives to net income	-3	3	-49
Foreign currency translation adjustments	31	-10	10
Benefit plan adjustments	-89	34	27
Benefit plan amortization	($2)	($4)	($4)

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Current assets	'	'
Cash and cash equivalents	$598	$714
Accounts receivable, net	1,721	1,333
Inventories	430	374
Assets held for sale	0	298
Deferred income taxes	567	539
Other current assets	552	416
Total current assets	3,868	3,674
Property, plant and equipment, net (Note 5)	35,847	30,996
Investments	5,951	5,804
Goodwill (Note 7)	24,504	23,632
Other intangibles, net	2,438	1,171
Deferred charges and other assets	2,577	2,968
Total Assets	75,185	68,245
Current liabilities	'	'
Accounts payable	1,676	1,248
Accrued interest	565	513
Accrued contingencies	584	114
Other current liabilities	944	952
Total current liabilities	6,075	5,228
Long-term debt	'	'
Debt fair value adjustments	1,977	2,591
Total long-term debt	33,887	32,000
Deferred income taxes	4,651	4,071
Other long-term liabilities and deferred credits	2,287	2,846
Total long-term liabilities and deferred credits	40,825	38,917
Total Liabilities	46,900	44,145
Stockholders’ Equity	'	'
Preferred stock	0	0
Additional paid-in capital	14,479	14,917
Retained deficit	-1,372	-943
Accumulated other comprehensive loss	-24	-118
Total Kinder Morgan, Inc.’s stockholders’ equity	13,093	13,866
Noncontrolling interests	15,192	10,234
Total Stockholders’ Equity	28,285	24,100
Total Liabilities and Stockholders’ Equity	75,185	68,245
Class P [Member]	'	'
Stockholders’ Equity	'	'
Class P shares, $0.01 par value, 2,000,000,000 shares authorized, 1,030,677,076 and 1,035,668,596 shares, respectively, issued and outstanding	10	10
Kinder Morgan, Inc. [Member]	'	'
Current assets	'	'
Cash and cash equivalents	116	71
Property, plant and equipment, net (Note 5)	2,563	2,735
Goodwill (Note 7)	17,935	18,193
Current liabilities	'	'
Current portion of debt	725	1,153
Long-term debt	'	'
Outstanding - KMI (Note 18)	9,221	9,148
KMP and EPB [Member]	'	'
Current assets	'	'
Cash and cash equivalents	482	643
Current liabilities	'	'
Current portion of debt	1,581	1,248
Long-term debt	'	'
Outstanding - KMP and EPB (Note 18)	22,589	20,161
KMI $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock [Member] | Kinder Morgan G.P., Inc. [Member]	'	'
Stockholders’ Equity	'	'
Preferred stock	$100	$100

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
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 [Member]	'	'
Stockholders’ Equity	'	'
Common stock, par value (in dollars per share)	$0.01	$0.01
Common stock, shares authorized (in shares)	2,000,000,000	2,000,000,000
Common stock, shares issued (in shares)	'	1,035,668,596
Common stock, shares outstanding (in shares)	1,030,677,076	1,035,668,596

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

KMP and EPB [Member]

KMP and EPB [Member]

KMP and EPB [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

Other Acquisitions [Member]

Other Acquisitions [Member]

Other Acquisitions [Member]

Cash Flows From Operating Activities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net income

$2,692

$427

$660

'

'

'

'

'

'

'

'

'

'

'

'

Adjustments to reconcile net income to net cash provided by operating activities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Depreciation, depletion, and amortization

1,806

1,426

1,092

'

'

'

'

'

'

'

'

'

'

'

'

Deferred income taxes

640

47

84

'

'

'

'

'

'

'

'

'

'

'

'

Amortization of excess cost of equity investments

39

23

7

'

'

'

'

'

'

'

'

'

'

'

'

(Gain) loss from the remeasurement of net assets to fair value and the sale of discontinued operations (net of cash selling expenses), net of tax (Note 3)

-556

859

167

'

'

'

'

'

'

'

'

'

'

'

'

Gain on sale of investments in Express pipeline system (Note 3)

-224

0

0

'

'

'

'

'

'

'

'

'

'

'

'

Loss on early extinguishment of debt

0

82

0

'

'

'

'

'

'

'

'

'

'

'

'

Noncash compensation expense on settlement of EP stock awards

0

87

0

'

'

'

'

'

'

'

'

'

'

'

'

Earnings from equity investments

-327

-223

-313

'

'

'

'

'

'

'

'

'

'

'

'

Distributions from equity investments

398

381

287

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from termination of interest rate swap agreements

96

53

73

'

'

'

'

'

'

'

'

'

'

'

'

Pension contributions In excess of expense

-59

-7

0

'

'

'

'

'

'

'

'

'

'

'

'

Changes in components of working capital, net of the effects of acquisitions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accounts receivable

-131

-231

8

'

'

'

'

'

'

'

'

'

'

'

'

Inventories

-53

-92

-36

'

'

'

'

'

'

'

'

'

'

'

'

Other current assets

-24

32

-10

'

'

'

'

'

'

'

'

'

'

'

'

Accounts payable

-36

70

29

'

'

'

'

'

'

'

'

'

'

'

'

Accrued interest

42

-26

19

'

'

'

'

'

'

'

'

'

'

'

'

Accrued contingencies and other current liabilities

-100

-68

-35

'

'

'

'

'

'

'

'

'

'

'

'

Rate reparations, refunds and other litigation reserve adjustments

174

-39

171

'

'

'

'

'

'

'

'

'

'

'

'

Other, net

-313

-6

163

'

'

'

'

'

'

'

'

'

'

'

'

Net Cash Provided by Operating Activities

4,064

2,795

2,366

'

'

'

'

'

'

'

'

'

'

'

'

Cash Flows From Investing Activities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of assets and investments, net of cash acquired

'

'

'

'

'

'

'

'

'

0

-4,970

0

-292

-83

-1,179

Proceeds from Sale of Equity Method Investments

490

0

0

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from disposal of discontinued operations

0

1,791

0

'

'

'

'

'

'

'

'

'

'

'

'

Repayments from related party

11

76

31

'

'

'

'

'

'

'

'

'

'

'

'

Capital expenditures

-3,369

-2,022

-1,200

'

'

'

'

'

'

'

'

'

'

'

'

Sale or casualty of property, plant and equipment, and other net assets, net of removal costs

87

154

23

'

'

'

'

'

'

'

'

'

'

'

'

Contributions to investments

-217

-192

-371

'

'

'

'

'

'

'

'

'

'

'

'

Distributions from equity investments in excess of cumulative earnings

185

200

236

'

'

'

'

'

'

'

'

'

'

'

'

Other, net

41

-38

68

'

'

'

'

'

'

'

'

'

'

'

'

Net Cash Used in Investing Activities

-3,064

-5,084

-2,392

'

'

'

'

'

'

'

'

'

'

'

'

Cash Flows From Financing Activities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issuance of debt

'

'

'

3,267

8,218

2,070

10,314

9,930

7,502

'

'

'

'

'

'

Payment of debt

'

'

'

-3,631

-5,693

-2,399

-8,762

-9,062

-6,394

'

'

'

'

'

'

Debt issue costs

-38

-111

-76

'

'

'

'

'

'

'

'

'

'

'

'

Cash dividends/distributions (Note 10)

-1,622

-1,184

-770

'

'

'

'

'

'

'

'

'

'

'

'

Repurchases of shares and warrants

-637

-157

0

'

'

'

'

'

'

'

'

'

'

'

'

Contributions from noncontrolling interests

1,706

1,939

970

'

'

'

'

'

'

'

'

'

'

'

'

Distributions to noncontrolling interests

-1,692

-1,219

-956

'

'

'

'

'

'

'

'

'

'

'

'

Other, net

0

-77

-4

'

'

'

'

'

'

'

'

'

'

'

'

Net Cash (Used in) Provided by Financing Activities

-1,095

2,584

-57

'

'

'

'

'

'

'

'

'

'

'

'

Effect of Exchange Rate on Cash and Cash Equivalents

-21

8

-8

'

'

'

'

'

'

'

'

'

'

'

'

Net (decrease) increase in Cash and Cash Equivalents

-116

303

-91

'

'

'

'

'

'

'

'

'

'

'

'

Cash and Cash Equivalents, beginning of period

714

411

502

71

'

'

643

'

'

'

'

'

'

'

'

Cash and Cash Equivalents, end of period

598

714

411

116

71

'

482

643

'

'

'

'

'

'

'

Noncash Investing and Financing Activities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net assets and liabilities acquired by the issuance of shares and warrants

0

11,454

0

'

'

'

'

'

'

'

'

'

'

'

'

Assets acquired by the assumption or incurrence of liabilities

1,510

0

207

'

'

'

'

'

'

'

'

'

'

'

'

Assets acquired or liabilities settled by contributions from noncontrolling interests

3,733

306

24

'

'

'

'

'

'

'

'

'

'

'

'

Increase in property, plant and equipment from both accruals and contractor retainage

276

83

35

'

'

'

'

'

'

'

'

'

'

'

'

Supplemental Disclosures of Cash Flow Information

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash paid during the period for interest (net of capitalized interest)

1,652

1,349

681

'

'

'

'

'

'

'

'

'

'

'

'

Cash paid during the period for income taxes (net of refunds)

$67

$182

$277

'

'

'

'

'

'

'

'

'

'

'

'

CONSOLIDATED_STATEMENTS_OF_CAS1

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2012
Cash acquired from acquisition	$6,581

CONSOLIDATED_STATEMENT_OF_STOC

CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY (USD $)

Total

Class A B and C [Member]

KMI members [Member]

Common Stock [Member]

Common Stock [Member]

Additional Paid-in Capital [Member]

Additional Paid-in Capital [Member]

Retained Earnings [Member]

Retained Earnings [Member]

Accumulated Other Comprehensive Income (Loss) [Member]

KMI [Member]

KMI [Member]

Noncontrolling Interest [Member]

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

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

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

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

KMP, EPB and KMR [Member]

KMP, EPB and KMR [Member]

KMP, EPB and KMR [Member]

KMP, EPB and KMR [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

EP Trust I Preferred [Member]

EP Trust I Preferred [Member]

EP Trust I Preferred [Member]

In Millions

Class A B and C [Member]

Class A B and C [Member]

Class A B and C [Member]

Class A B and C [Member]

Additional Paid-in Capital [Member]

KMI [Member]

Noncontrolling Interest [Member]

Additional Paid-in Capital [Member]

KMI [Member]

Noncontrolling Interest [Member]

Common Stock [Member]

Additional Paid-in Capital [Member]

KMI [Member]

Noncontrolling Interest [Member]

KMI [Member]

Noncontrolling Interest [Member]

Additional Paid-in Capital [Member]

KMI [Member]

Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest at Dec. 31, 2010

$8,539

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stockholders' Equity Attributable to Noncontrolling Interest at Dec. 31, 2010

'

'

'

'

'

'

'

'

'

'

'

'

5,100

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stockholders' Equity Attributable to Parent at Dec. 31, 2010

'

'

3,575

0

'

0

'

0

'

-136

3,439

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class A, Class B and Class C share conversions

'

-2

'

'

'

'

'

'

-2

'

'

-2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reclassification of equity upon offering

0

'

-3,404

8

'

3,396

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization of Restricted Shares

7

'

'

'

'

7

'

'

'

'

7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Impact of subidiary equity transactions

'

'

'

'

'

'

'

'

'

'

'

'

'

-16

28

28

-44

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

A-1 and B unit amortization

4

'

4

'

'

'

'

'

'

'

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net income

594

'

71

'

'

'

'

523

'

'

594

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net Income (Loss) Attributable to Noncontrolling Interest

66

'

'

'

'

'

'

'

'

'

'

'

66

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net Income (Loss), Including Portion Attributable to Noncontrolling Interest

660

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distributions

-956

'

'

'

'

'

'

'

'

'

0

'

-956

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Contributions

994

'

'

'

'

'

'

'

'

'

0

'

994

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash distributions/dividends

-770

'

-246

'

'

'

'

-524

'

'

-770

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent

21

'

'

'

'

'

'

'

'

21

21

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Comprehensive (Income) Loss, Net of Tax, Portion Attributable to Noncontrolling Interest

87

'

'

'

'

'

'

'

'

'

'

'

87

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Comprehensive Income (Loss), Net of Tax

108

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest at Dec. 31, 2011

8,568

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stockholders' Equity Attributable to Noncontrolling Interest at Dec. 31, 2011

'

'

'

'

'

'

'

'

'

'

'

'

5,247

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stockholders' Equity Attributable to Parent at Dec. 31, 2011

'

'

0

8

'

3,431

'

-3

'

-115

3,321

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issuance of shares for EP acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3

10,598

10,601

'

'

'

'

'

'

'

Issuance of warrants for EP acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

863

'

863

863

'

'

'

'

'

'

'

Acquisition of noncontrolling interests

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,797

'

'

0

3,797

'

'

'

'

'

'

Warrants repurchased

-157

'

'

'

'

-157

'

'

'

'

-157

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

EP Trust I Preferred security conversions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

14

14

14

Class A, Class B and Class C share conversions

'

-71

'

'

-1

'

1

'

-71

'

'

-71

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization of Restricted Shares

14

'

'

'

'

14

'

'

'

'

14

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Impact of subidiary equity transactions

10,601

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-38

64

64

-102

'

'

'

'

'

'

'

'

'

'

'

Tax Impact on Stock Based Compensation

90

'

'

'

'

90

'

'

'

'

90

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net income

315

'

'

'

'

'

'

315

'

'

315

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net Income (Loss) Attributable to Noncontrolling Interest

112

'

'

'

'

'

'

'

'

'

'

'

112

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net Income (Loss), Including Portion Attributable to Noncontrolling Interest

427

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distributions

-1,219

'

'

'

'

'

'

'

'

'

0

'

-1,219

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Contributions

2,329

'

'

'

'

'

'

'

'

'

0

'

2,329

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash distributions/dividends

-1,184

'

'

'

'

'

'

-1,184

'

'

-1,184

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other

-5

'

'

'

'

-1

'

'

'

'

-1

'

-4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent

-3

'

'

'

'

'

'

'

'

-3

-3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Comprehensive (Income) Loss, Net of Tax, Portion Attributable to Noncontrolling Interest

74

'

'

'

'

'

'

'

'

'

'

'

74

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Comprehensive Income (Loss), Net of Tax

71

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest at Dec. 31, 2012

24,100

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stockholders' Equity Attributable to Noncontrolling Interest at Dec. 31, 2012

10,234

'

'

'

'

'

'

'

'

'

'

'

10,234

3,270

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stockholders' Equity Attributable to Parent at Dec. 31, 2012

13,866

'

0

10

'

14,917

'

-943

'

-118

13,866

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of noncontrolling interests

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17

0

17

'

'

'

Shares repurchased

-172

'

'

'

'

-172

'

'

'

'

-172

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Warrants repurchased

-465

'

'

'

'

-465

'

'

'

'

-465

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Warrant exercised

1

'

'

'

'

1

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

EP Trust I Preferred security conversions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3

3

3

Amortization of Restricted Shares

35

'

'

'

'

35

'

'

'

'

35

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Impact of subidiary equity transactions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-93

161

161

-254

'

'

'

'

'

'

'

'

'

'

'

Tax Impact on Stock Based Compensation

1

'

'

'

'

1

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net income

1,193

'

'

'

'

'

'

1,193

'

'

1,193

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net Income (Loss) Attributable to Noncontrolling Interest

1,499

'

'

'

'

'

'

'

'

'

'

'

1,499

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net Income (Loss), Including Portion Attributable to Noncontrolling Interest

2,692

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distributions

-1,692

'

'

'

'

'

'

'

'

'

0

'

-1,692

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Contributions

5,439

'

'

'

'

'

'

'

'

'

0

'

5,439

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash distributions/dividends

-1,622

'

'

'

'

'

'

-1,622

'

'

-1,622

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other

1

'

'

'

'

-2

'

'

'

'

-2

'

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent

94

'

'

'

'

'

'

'

'

94

94

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Comprehensive (Income) Loss, Net of Tax, Portion Attributable to Noncontrolling Interest

-54

'

'

'

'

'

'

'

'

'

'

'

-54

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Comprehensive Income (Loss), Net of Tax

40

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest at Dec. 31, 2013

28,285

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stockholders' Equity Attributable to Noncontrolling Interest at Dec. 31, 2013

15,192

'

'

'

'

'

'

'

'

'

'

'

15,192

7,642

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stockholders' Equity Attributable to Parent at Dec. 31, 2013

$13,093

'

$0

$10

'

$14,479

'

($1,372)

'

($24)

$13,093

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General_Notes

General (Notes)	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]	'
	1.  General
	Kinder Morgan, Inc. is the largest midstream and the third largest energy company in North America with a combined enterprise value, including its two publicly traded MLP subsidiaries, of approximately $110 billion and unless the context requires otherwise, references to “we,” “us,” “our,” or “KMI” are intended to mean Kinder Morgan, Inc. and its consolidated subsidiaries. We own an interest in or operate approximately 80,000 miles of pipelines and 180 terminals. Our pipelines transport natural gas, gasoline, crude oil, CO2 and other products, and our terminals store petroleum products and chemicals and handle such products as ethanol, coal, petroleum coke and steel.
	We own an approximate 10% limited partner interest and the 2% general partner interest in KMP, a leading pipeline transportation and energy storage company and one of the largest publicly-traded pipeline limited partnerships in America. KMP’s limited partner units are traded on the NYSE under the ticker symbol “KMP.”
	We also own an approximate 41% limited partner interest and the 2% general partner interest in EPB, as well as certain natural gas pipeline assets (see Notes 3 and 10). EPB’s limited partner units are traded on the NYSE under the ticker symbol “EPB.”
	Our common stock trades on the NYSE under the symbol “KMI.”
	On February 16, 2011, we completed the initial public offering of our common stock (the offering).  All of the common stock that was sold in the offering was sold by our existing investors consisting of funds advised by or affiliated with Goldman Sachs & Co., Highstar Capital LP, The Carlyle Group and Riverstone Holdings LLC.  No members of management sold shares in the offering, and we did not receive any proceeds from the offering.  During 2012, the funds advised by or affiliated with Goldman Sachs & Co., The Carlyle Group and Riverstone Holdings LLC, sold their remaining interests in KMI and representatives of these funds are no longer on our board. For additional information on the offering, see Note 10.
	KMR, is a publicly traded Delaware LLC.  KMGP, the general partner of KMP and a wholly-owned subsidiary of ours, owns all of KMR’s voting shares.  KMR, pursuant to a delegation of control agreement, has been delegated, to the fullest extent permitted under Delaware law, all of KMGP’s power and authority to manage and control the business and affairs of KMP, subject to KMGP’s right to approve certain transactions.

Summary_of_Significant_Account

Summary of Significant Accounting Policies Significant Accounting Policies (Notes)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Significant Accounting Policies [Text Block]	'
	Summary of Significant Accounting Policies
	Basis of Presentation
	Our reporting currency is U.S. dollars, and all references to dollars are U.S. dollars, except where stated otherwise. Canadian dollars are designated as C$.
	Our accompanying consolidated financial statements have been prepared under the rules and regulations of the SEC. These rules and regulations conform to the accounting principles contained in the FASB’s Accounting Standards Codification, the single source of GAAP. Under such rules and regulations, all significant intercompany items have been eliminated in consolidation. Additionally, certain amounts from prior years have been reclassified to conform to the current presentation.
	Our consolidated financial statements include our accounts and the of our majority-owned and controlled subsidiaries as well as the accounts of KMP, EPB and KMR. Investments in jointly owned operations in which we hold a 50% or less interest (other than KMP, EPB and KMR, because we have the ability to exercise significant control over their operating and financial policies) are accounted for under the equity method.
	Notwithstanding the consolidation of KMP and EPB and their respective subsidiaries into our financial statements, we are not liable for, and our assets are not available to satisfy, the obligations of KMP and EPB and/or their respective subsidiaries and vice versa, except as discussed in the following paragraph. Responsibility for payments of obligations reflected in our, KMP’s or EPB’s financial statements is a legal determination based on the entity that incurs the liability.
	Effective November 1, 2012, we sold KMP’s FTC Natural Gas Pipelines disposal group to Tallgrass Energy Partners, L.P. for approximately $1.8 billion (before selling costs), or $3.3 billion including our share of joint venture debt, to satisfy terms of a March 15, 2012 agreement with the U.S. FTC to divest certain of our assets in order to receive regulatory approval for our EP acquisition. KMP’s FTC Natural Gas Pipelines disposal group’s assets included (i) Kinder Morgan Interstate Gas Transmission natural gas pipeline system; (ii) Trailblazer natural gas pipeline system; (iii) Casper and Douglas natural gas processing operations; and (iv) 50% equity investment in the Rockies Express natural gas pipeline system. Accordingly, we (i) reclassified and excluded KMP’s FTC Natural Gas Pipelines disposal group’s results of operations from our results of continuing operations and reported the disposal group’s results of operations separately as “Income from operations of KMP’s FTC Natural Gas Pipelines disposal group and other, net of tax” within the discontinued operations section of our accompanying consolidated statements of income for all periods presented and (ii) separately reported a “Loss on sale and the remeasurement of KMP’s FTC Natural Gas Pipelines disposal group to fair value, net of tax” within the discontinued operations section of our accompanying consolidated statements of income for the years ended December 31, 2013 and 2012. In addition, we did not elect to present separately the operating, investing and financing cash flows related to the disposal group in our accompanying consolidated statements of cash flows.
	For more information about the divestiture of KMP’s FTC Natural Gas Pipelines disposal group, see Note 3.
	Use of Estimates
	Certain amounts included in or affecting our financial statements and related disclosures must be estimated, requiring us to make certain assumptions with respect to values or conditions which cannot be known with certainty at the time our financial statements are prepared. These estimates and assumptions affect the amounts we report for assets and liabilities, our revenues and expenses during the reporting period, and our disclosure of contingent assets and liabilities at the date of our financial statements. We evaluate these estimates on an ongoing basis, utilizing historical experience, consultation with experts and other methods we consider reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from our estimates. Any effects on our business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known.
	In addition, we believe that certain accounting policies are of more significance in our financial statement preparation process than others, and set out below are the principal accounting policies we apply in the preparation of our consolidated financial statements.
	Cash Equivalents and Restricted Deposits
	We define cash equivalents as all highly liquid short-term investments with original maturities of three months or less.
	Restricted cash of $75 million and $52 million as of December 31, 2013 and 2012, respectively is included in “Other current assets,” and restricted cash of $2 million as of December 31, 2013, is included in “Deferred charges and other assets.”
	Accounts Receivable
	The amounts reported as “Accounts receivable, net” on our accompanying consolidated balance sheets as of December 31, 2013 and 2012 primarily consist of amounts due from customers.
	Our policy for determining an appropriate allowance for doubtful accounts varies according to the type of business being conducted and the customers being served.  Generally, we make periodic reviews and evaluations of the appropriateness of the allowance for doubtful accounts based on a historical analysis of uncollected amounts, and we record adjustments as necessary for changed circumstances and customer-specific information.  When specific receivables are determined to be uncollectible, the reserve and receivable are relieved.
	Inventories
	Our inventories of products consist of materials and supplies, NGL, refined petroleum products and natural gas. We report these assets at the lower of weighted-average cost or market. We report materials and supplies inventories at cost, and periodically review for physical deterioration and obsolescence.
	Gas Imbalances
	We value gas imbalances due to or due from interconnecting pipelines at the lower of cost or market or index prices, per our quarterly imbalance valuation procedures. Gas imbalances represent the difference between customer nominations and actual gas receipts from, and gas deliveries to, our interconnecting pipelines and shippers under various operational balancing and shipper imbalance agreements.  Natural gas imbalances are either settled in cash or made up in-kind subject to the pipelines’ various tariff provisions. As of both December 31, 2013 and 2012, our gas imbalance receivables—including both trade and related party receivables—totaled $83 million and $18 million, respectively, and we included these amounts within “Other current assets” on our accompanying consolidated balance sheets. As of December 31, 2013 and 2012, our gas imbalance payables—consisting of only trade payables—totaled $34 million and $150 million, respectively, and we included these amounts within “Other current liabilities” on our accompanying consolidated balance sheets.
	Property, Plant and Equipment
	Capitalization, Depreciation and Depletion and Disposals
	We report property, plant and equipment at its acquisition cost.  We expense costs for maintenance and repairs in the period incurred.  As discussed below, for assets used in our oil and gas producing activities or in our unregulated bulk and liquids terminal activities, the cost of property, plant and equipment sold or retired and the related depreciation are removed from our balance sheet in the period of sale or disposition, and we record any related gains and losses from sales or retirements to income or expense accounts.  For our pipeline system assets, we generally charge the original cost of property sold or retired to accumulated depreciation and amortization, net of salvage and cost of removal.  We do not include retirement gain or loss in income except in the case of significant retirements or sales.  Gains and losses on minor operating unit sales, excluding land, are recorded to the appropriate accumulated depreciation reserve.  Generally, gains and losses for operating unit sales and land sales are booked to income or expense accounts in accordance with regulatory accounting guidelines. In those instances where we receive recovery in tariff rates related to losses on dispositions of operating units, we record a regulatory asset for the estimated recoverable amount.
	We generally compute depreciation using the straight-line method based on estimated economic lives; however, for certain depreciable assets, we employ the composite depreciation method, applying a single depreciation rate for a group of assets.  Generally, we apply composite depreciation rates to functional groups of property having similar economic characteristics.  The rates range from 0.9% to 23.0% excluding certain short-lived assets such as vehicles.  Depreciation estimates are based on various factors, including age (in the case of acquired assets), manufacturing specifications, technological advances and historical data concerning useful lives of similar assets.  Uncertainties that impact these estimates included changes in laws and regulations relating to restoration and abandonment requirements, economic conditions, and supply and demand in the area.  When assets are put into service, we make estimates with respect to useful lives (and salvage values where appropriate) that we believe are reasonable.  However, subsequent events could cause us to change our estimates, thus impacting the future calculation of depreciation and amortization expense.  Historically, adjustments to useful lives have not had a material impact on our aggregate depreciation levels from year to year.
	Our oil and gas producing activities are accounted for under the successful efforts method of accounting.  Under this method costs that are incurred to acquire leasehold and subsequent development costs are capitalized.  Costs that are associated with the drilling of successful exploration wells are capitalized if proved reserves are found.  Costs associated with the drilling of exploratory wells that do not find proved reserves, geological and geophysical costs, and costs of certain non-producing leasehold costs are expensed as incurred.  The capitalized costs of our producing oil and gas properties are depreciated and depleted by the units-of-production method.  Other miscellaneous property, plant and equipment are depreciated over the estimated useful lives of the asset.
	A gain on the sale of property, plant and equipment used in our oil and gas producing activities or in our bulk and liquids terminal activities is calculated as the difference between the cost of the asset disposed of, net of depreciation, and the sales proceeds received.  A gain on an asset disposal is recognized in income in the period that the sale is closed.  A loss on the sale of property, plant and equipment is calculated as the difference between the cost of the asset disposed of, net of depreciation, and the sales proceeds received or the market value if the asset is being held for sale.  A loss is recognized when the asset is sold or when the net cost of an asset held for sale is greater than the market value of the asset.
	We engage in enhanced recovery techniques in which CO2 is injected into certain producing oil reservoirs.  In some cases, the acquisition cost of the CO2 associated with enhanced recovery is capitalized as part of our development costs when it is injected.  The acquisition cost associated with pressure maintenance operations for reservoir management is expensed when it is injected.  When CO2 is recovered in conjunction with oil production, it is extracted and re-injected, and all of the associated costs are expensed as incurred.  Proved developed reserves are used in computing units of production rates for drilling and development costs, and total proved reserves are used for depletion of leasehold costs.  The units-of-production rate is determined by field.
	As discussed in “—Inventories” above, we own and maintain natural gas in underground storage as part of our inventory.  This component of our inventory represents the portion of gas stored in an underground storage facility generally known as working gas, and represents an estimate of the portion of gas in these facilities available for routine injection and withdrawal.  In addition to this working gas, underground gas storage reservoirs contain injected gas which is not routinely cycled but, instead, serves the function of maintaining the necessary pressure to allow efficient operation of the facility.  This gas, generally known as cushion gas, is divided into the categories of recoverable cushion gas and unrecoverable cushion gas, based on an engineering analysis of whether the gas can be economically removed from the storage facility at any point during its life.  The portion of the cushion gas that is determined to be unrecoverable is considered to be a permanent part of the facility itself (thus, part of our “Property, plant and equipment, net” balance in our accompanying consolidated balance sheets), and this unrecoverable portion is depreciated over the facility’s estimated useful life.  The portion of the cushion gas that is determined to be recoverable is also considered a component of the facility but is not depreciated because it is expected to ultimately be recovered and sold.
	Impairments
	We review long-lived assets for impairment whenever events or changes in circumstances indicate that our carrying amount of an asset may not be recoverable.  We recognize impairment losses when estimated future cash flows expected to result from our use of the asset and its eventual disposition is less than its carrying amount.
	We evaluate our oil and gas producing properties for impairment of value on a field-by-field basis or, in certain instances, by logical grouping of assets if there is significant shared infrastructure, using undiscounted future cash flows based on total proved and risk-adjusted probable and possible reserves.  For the purpose of impairment testing, adjustments for the inclusion of risk-adjusted probable and possible reserves, as well as forward curve pricing, will cause impairment calculation cash flows to differ from the amounts presented in our supplemental information on oil and gas producing activities disclosed in “Supplemental Information on Oil and Gas Producing Activities (Unaudited).”
	Oil and gas producing properties deemed to be impaired are written down to their fair value, as determined by discounted future cash flows based on total proved and risk-adjusted probable and possible reserves or, if available, comparable market values.  Unproved oil and gas properties that are individually significant are periodically assessed for impairment of value, and a loss is recognized at the time of impairment.
	Asset Retirement Obligations
	We record liabilities for obligations related to the retirement and removal of long-lived assets used in our businesses.  We record, as liabilities, the fair value of asset retirement obligations on a discounted basis when they are incurred, which is typically at the time the assets are installed or acquired.  Amounts recorded for the related assets are increased by the amount of these obligations.  Over time, the liabilities increase due to the change in their present value, and the initial capitalized costs are depreciated over the useful lives of the related assets.  The liabilities are eventually extinguished when the asset is taken out of service.
	Equity method of accounting
	We account for investments—which we do not control, but do have the ability to exercise significant influence—by the equity method of accounting. Under this method, our equity investments are carried originally at our acquisition cost, increased by our proportionate share of the investee’s net income and by contributions made, and decreased by our proportionate share of the investee’s net losses and by distributions received.
	Goodwill
	Goodwill represents the excess of the cost of an acquisition price over the fair value of the acquired net assets, and such amounts are reported separately on our consolidated balance sheets.  As of December 31, 2013 and 2012 our total goodwill was $24,504 million and $23,632 million, respectively.  Goodwill is not amortized, but instead is tested for impairment annually or on an interim basis if events or circumstances indicate that the fair value of the asset has decreased below its carrying value. We perform our goodwill impairment test on May 31 of each year.  There were no impairment charges resulting from our May 31, 2013, 2012 or 2011 impairment testing, and no event indicating an impairment has occurred subsequent to May 31, 2013.
	If a significant portion of one of our business segments is disposed of (that also constitutes a business), we would allocate goodwill based on the relative fair values of the portion of the segment being disposed of and the portion of the segment remaining.
	Revenue Recognition Policies
	We recognize revenues as services are rendered or goods are delivered and, if applicable, title has passed.  We recognize natural gas sales revenues and NGL sales revenue when the natural gas or NGL is sold to a purchaser at a fixed or determinable price, delivery has occurred and title has transferred, and collectability of the revenue is reasonably assured. Our sales and purchases of natural gas and NGL are primarily accounted for on a gross basis as natural gas sales or product sales, as applicable, and cost of sales.
	In addition to storing and transporting a significant portion of the natural gas volumes we purchase and resell, we provide various types of natural gas storage and transportation services for third-party customers.  Under these contracts, the natural gas remains the property of these customers at all times. In many cases, generally described as firm service, the customer pays a two-part rate that includes (i) a fixed fee reserving the right to transport or store natural gas in our facilities and (ii) a per-unit rate for volumes actually transported or injected into/withdrawn from storage.  The fixed-fee component of the overall rate is recognized as revenue in the period the service is provided.  The per-unit charge is recognized as revenue when the volumes are delivered to the customers’ agreed upon delivery point, or when the volumes are injected into/withdrawn from our storage facilities.
	In other cases, generally described as interruptible service, there is no fixed fee associated with the services because the customer accepts the possibility that service may be interrupted at our discretion in order to serve customers who have purchased firm service.  In the case of interruptible service, revenue is recognized in the same manner utilized for the per-unit rate for volumes actually transported under firm service agreements.
	We provide crude oil and refined petroleum products transportation and storage services to customers.  Revenues are recorded when products are delivered and services have been provided, and adjusted according to terms prescribed by the toll settlements with shippers and approved by regulatory authorities.
	We recognize bulk terminal transfer service revenues based on volumes loaded and unloaded.  We recognize liquids terminal tank rental revenue ratably over the contract period. We recognize liquids terminal throughput revenue based on volumes received and volumes delivered.  We recognize transmix processing revenues based on volumes processed or sold, and if applicable, when title has passed.  We recognize energy-related product sales revenues based on delivered quantities of product.
	Revenues from the sale of crude oil, NGL, CO2 and natural gas production within the CO2—KMP business segment are recorded using the entitlement method.  Under the entitlement method, revenue is recorded when title passes based on our net interest.  We record our entitled share of revenues based on entitled volumes and contracted sales prices. Since there is a ready market for oil and gas production, we sell the majority of our products soon after production at various locations, at which time title and risk of loss pass to the buyer.
	Environmental Matters
	We expense or capitalize, as appropriate, environmental expenditures that relate to current operations.  We expense expenditures that relate to an existing condition caused by past operations, which do not contribute to current or future revenue generation.  We generally do not discount environmental liabilities to a net present value, and we record environmental liabilities when environmental assessments and/or remedial efforts are probable and we can reasonably estimate the costs.  Generally, our recording of these accruals coincides with our completion of a feasibility study or our commitment to a formal plan of action.  We recognize receivables for anticipated associated insurance recoveries when such recoveries are deemed to be probable. We record at fair value, where appropriate, environmental liabilities assumed in a business combination.
	We routinely conduct reviews of potential environmental issues and claims that could impact our assets or operations.  These reviews assist us in identifying environmental issues and estimating the costs and timing of remediation efforts.  We also routinely adjust our environmental liabilities to reflect changes in previous estimates.  In making environmental liability estimations, we consider the material effect of environmental compliance, pending legal actions against us, and potential third-party liability claims.  Often, as the remediation evaluation and effort progresses, additional information is obtained, requiring revisions to estimated costs.  These revisions are reflected in our income in the period in which they are reasonably determinable.
	Pensions and Other Postretirement Benefits
	We recognize the difference between the fair value of plan assets and the plan’s benefit obligation of our consolidated subsidiaries’ pension and other postretirement benefit plans as either assets or liabilities on our balance sheet. We record deferred plan costs and income—unrecognized losses and gains, unrecognized prior service costs and credits, and any remaining unamortized transition obligations—in accumulated other comprehensive income or as a regulatory asset or liability for certain of our regulated operations, until they are amortized to be recognized as a component of benefit expense.
	Noncontrolling Interests
	Noncontrolling interests represents the outstanding ownership interests in our consolidated subsidiaries that are not owned by us.  In our accompanying consolidated income statements, the noncontrolling interest in the net income (or loss) of our consolidated subsidiaries is shown as an allocation of our consolidated net income and is presented separately as “Net income attributable to noncontrolling interests.”  In our accompanying consolidated balance sheets, noncontrolling interests represents the ownership interests in our consolidated subsidiaries’ net assets held by parties other than us.  It is presented separately as “Noncontrolling interests” within “Stockholders’ Equity.”
	Income Taxes
	Income tax expense is recorded based on an estimate of the effective tax rate in effect or to be in effect during the relevant periods.  Deferred income tax assets and liabilities are recognized for temporary differences between the basis of assets and liabilities for financial reporting and tax purposes.  Changes in tax legislation are included in the relevant computations in the period in which such changes are effective.  Deferred tax assets are reduced by a valuation allowance for the amount of any tax benefit we do not expect to be realized.
	In determining the deferred income tax asset and liability balances attributable to us, we have applied an accounting policy that looks through its investments including its investment in KMP and EPB.  The application of this policy resulted in no deferred income taxes being provided on the difference between the book and tax basis on the non-tax-deductible goodwill portion of our investment in KMP and EPB.
	Foreign Currency Transactions and Translation
	Foreign currency transaction gains or losses result from a change in exchange rates between (i) the functional currency, for example the Canadian dollar for a Canadian subsidiary and (ii) the currency in which a foreign currency transaction is denominated, for example the U.S. dollar for a Canadian subsidiary.  In our accompanying consolidated statements of income, gains and losses from our foreign currency transactions are included within “Other Income (Expense)—Other, net.”
	Foreign currency translation is the process of expressing, in U.S. dollars, amounts recorded in a local functional currency other than U.S. dollars, for example the Canadian dollar for a Canadian subsidiary.  We translate the assets and liabilities of each of our consolidated foreign subsidiaries that have a local functional currency to U.S. dollars at year-end exchange rates.  Income and expense items are translated at weighted-average rates of exchange prevailing during the year and stockholders’ equity accounts are translated by using historical exchange rates.  The cumulative translation adjustments balance is reported as a component of “Accumulated other comprehensive loss.”
	Comprehensive Income
	For each of the years ended December 31, 2013, 2012 and 2011, the difference between our net income and our comprehensive income resulted from (i) unrealized gains or losses on derivative contracts accounted for as cash flow hedges; (ii) foreign currency translation adjustments; and (iii) unrealized gains or losses related to changes in pension and other postretirement benefit plan liabilities. For more information on our risk management activities, see Note 13.
	Risk Management Activities
We utilize energy commodity derivative contracts for the purpose of mitigating our risk resulting from fluctuations in the market price of natural gas, NGL and crude oil.  In addition, we enter into interest rate swap agreements for the purpose of hedging the interest rate risk associated with our debt obligations. We measure our derivative contracts at fair value and we report them on our balance sheet as either an asset or liability.  If the derivative transaction qualifies for and is designated as a normal purchase and sale, it is exempted from fair value accounting and is accounted for using traditional accrual accounting.
Furthermore, changes in our derivative contracts’ fair values are recognized currently in earnings unless hedge accounting is applied.  If a derivative contract meets specific accounting criteria, the contract’s gains and losses are allowed to offset related results on the hedged item in our income statement, and we may formally designate the derivative contract as a hedge and document and assess the effectiveness of the contract associated with the transaction that receives hedge accounting.  Only designated qualifying items that are effectively offset by changes in fair value or cash flows during the term of the hedge are eligible to use the special accounting for hedging.
Our derivative contracts that hedge our energy commodity price risks involve our normal business activities, which include the purchase and sale of natural gas, NGL and crude oil, and we may designate these derivative contracts as cash flow hedges—derivative contracts that hedge exposure to variable cash flows of forecasted transactions—and the effective portion of these derivative contracts’ gain or loss is initially reported as a component of other comprehensive income (outside earnings) and subsequently reclassified into earnings when the forecasted transactions affect earnings.  The ineffective portion of the gain or loss is reported in earnings immediately.
Regulatory Assets and Liabilities
Regulatory assets and liabilities represent probable future revenues or expenses associated with certain charges and credits that will be recovered from or refunded to customers through the ratemaking process.  We included the amounts of our regulatory assets and liabilities within “Other current assets,” “Deferred charges and other assets,” “Other current liabilities” and “Other long-term liabilities and deferred credits,” respectively, in our accompanying consolidated balance sheets. As of December 31, 2013, the recovery period for these regulatory assets was approximately one year to forty-two years.
The following table summarizes our regulatory asset and liability balances as of December 31, 2013 and 2012 (in millions):
	December 31,
	2013			2012
Current regulatory assets	$	91		$	62
Non-current regulatory assets	446			402
Total regulatory assets(a)	$	537		$	464
Current regulatory liabilities	$	135		$	7
Non-current regulatory liabilities	397			113
Total regulatory liabilities(b)	$	532		$	120
_______
(a)	Includes an $88 million increase since December 31, 2012 (net of related amortization of $5 million) associated with TGP’s sale of certain natural gas facilities located offshore in the Gulf of Mexico and onshore in the state of Louisiana.
(b)	During the second quarter of 2013, we began applying regulatory accounting to the Trans Mountain pipeline systems due to a newly negotiated long-term tolling agreement approved by the system’s regulator that went into effect in April 2013. The primary impact of applying regulatory accounting was the reclassification of approximately $362 million of current and long-term deferred credits to regulatory liabilities. KMP expects this regulatory liability to be refunded to rate-payers over approximately the next four years. As of December 31, 2013, $113 million remains classified as a current regulatory liability.
On July 26, 2012, TGP filed an application with the FERC seeking authority to abandon by sale certain natural gas facilities located offshore in the Gulf of Mexico and onshore in the state of Louisiana, as well as a related offer of settlement that addressed the proposed rate and accounting treatment associated with the sale. The offer of settlement provided for a rate adjustment to TGP’s maximum tariff rates upon the transfer of the assets and established a regulatory asset for a portion of the unrecovered net book value of the facilities to be sold. Effective September 1, 2013, following the FERC’s approval of both the requested abandonment authorization and the offer of settlement, TGP sold these assets, and in 2013, TGP recognized both a $93 million increase in regulatory assets and a $36 million gain from the sale of assets.
Transfer of Net Assets Between Entities Under Common Control
We account for the transfer of net assets between entities under common control by carrying forward the net assets recognized in the balance sheets of each combining entity to the balance sheet of the combined entity, and no other assets or liabilities are recognized as a result of the combination.  Transfers of net assets between entities under common control do not affect the historical income statement or balance sheet of the combined entity.
Earnings per Share
For the year ended December 31, 2013, earnings per share was calculated using the two-class method. Earnings were allocated to Class P shares of common stock and to participating securities based on the amount of dividends paid in the current period plus an allocation of the undistributed earnings or excess distributions over earnings to the extent that each security participates in earnings or excess distributions over earnings. Our unvested restricted stock awards do not participate in excess distributions over earnings. For the year ended December 31, 2013, the following potential weighted-average Class P common shares are antidilutive and, accordingly, are excluded from the determination of diluted earnings per share; (i) 4 million related to unvested restricted stock awards; (ii) 401 million related to outstanding warrants to purchase our Class P shares; and (iii) 10 million related to convertible trust preferred securities.
The following table sets forth the allocation of net income available to shareholders for Class P shares and for participating securities for the year ended December 31, 2013 (in millions):
	Year Ended December 31, 2013
Class P	$	1,187
Participating securities(a)	6
Net Income Attributable to Kinder Morgan, Inc.	$	1,193
_______
(a)	Participating securities are unvested restricted stock awards issued to management employees that contain non-forfeitable rights to dividend equivalent payments.
On December 26, 2012, the remaining series of our Class A, Class B, and Class C shares were fully-converted and as a result, only our Class P common stock was outstanding as of December 31, 2012 (see Note 10).
For the year ended December 31, 2012 and the period February 11, 2011 through December 31, 2011, earnings per share was calculated using the two-class method.  Earnings were allocated to each class of common stock based on the amount of dividends paid in the current period for each class of stock plus an allocation of the undistributed earnings or excess distributions over earnings to the extent that each security participates in earnings or excess distributions over earnings.  For the investor retained stock, the allocation of undistributed earnings or excess distributions over earnings was in direct proportion to the maximum number of Class P shares into which it could convert.
For the Class P diluted earnings per share computations, total net income attributable to Kinder Morgan, Inc. was divided by the adjusted weighted-average shares outstanding during the period, including all dilutive potential shares.  This included the Class P shares into which the investor retained stock (collectively, our Class A, Class B and Class C common stocks) was convertible.  The number of Class P shares on a fully-converted basis was the same before and after any conversion of our investor retained stock.  Each time one Class P share was issued upon conversion of investor retained stock, the number of Class P shares went up by one, and the number of Class P shares into which the investor retained stock was convertible went down by one.  Accordingly, there was no difference between Class P basic and diluted earnings per share because the conversion of Class A, Class B, and Class C shares into Class P shares did not impact the number of Class P shares on a fully-converted basis.  Commencing with the acquisition of EP, dilutive potential shares also included the Class P shares issuable in connection with the warrants and the trust preferred securities (see Note 10).  As no securities were convertible into Class A shares, the basic and diluted earnings per share computations for Class A shares were the same. For the year ended December 31, 2012, the following potential Class P common shares were antidilutive and, accordingly, were excluded from the determination of diluted earnings per share; (i) 451 million related to outstanding warrants to purchase our Class P shares; and (ii) 11 million related to convertible trust preferred securities.
The following tables set forth the computation of basic and diluted earnings per share from continuing operations for the year ending December 31, 2012 and the period ending February 11, 2011 through December 31, 2011 (the date of our initial public offering) (in millions, except per share amounts):
	Year ended December 31, 2012
	Income from Continuing Operations Available to Shareholders
	Class P			Class A			Participating			Total
							Securities(a)
Income from continuing operations										$	1,204
Less: income from continuing operations attributable to noncontrolling interests										(696		)
Income from continuing operations attributable to KMI										508
Dividends paid in the period	$	601		$	542		$	41		(1,184		)
Excess distributions over earnings	(344		)	(331		)	(1		)	$	(676	)
Income from continuing operations attributable to shareholders	$	257		$	211		$	40		$	508
Basic earnings per share from continuing operations
Basic weighted-average number of shares outstanding	461			446			N/A
Basic earnings per common share from continuing operations(b)	$	0.56		$	0.47		N/A
Diluted earnings per share from continuing operations
Income from continuing operations attributable to shareholders and assumed conversions(c)	$	508		$	211		N/A
Diluted weighted-average number of shares	908			446			N/A
Diluted earnings per common share from continuing operations(b)	$	0.56		$	0.47		N/A
	February 11. 2011 through December 31, 2011
	Income from Continuing Operations Available to Shareholders
	Class P			Class A			Participating			Total
							Securities(a)
Income from continuing operations for the year ended December 31, 2011										$	449
Plus: loss from continuing operations attributable to noncontrolling interests for the year ended December 31, 2011										112
Income from continuing operations attributable to KMI for the year ended December 31, 2011										561
Less: income from continuing operations attributable to KMI members prior to incorporation										(67		)
Total net income from continuing operations attributable to shareholders										494
Dividends paid in the period	$	87		$	399		$	38		(524		)
Excess distributions over earnings	(5		)	(25		)	—			$	(30	)
Income from continuing operations attributable to shareholders	$	82		$	374		$	38		$	494
Basic earnings per share from continuing operations
Basic weighted-average number of shares outstanding(d)	118			589			N/A
Basic earnings per common share from continuing operations(b)	$	0.7		$	0.64		N/A
Diluted earnings per share from continuing operations
Income from continuing operations attributable to shareholders and assumed conversions(c)	$	494		$	374		N/A
Diluted weighted-average number of shares(d)	708			589			N/A
Diluted earnings per common share from continuing operations(b)	$	0.7		$	0.64		N/A
The following tables set forth the computation of basic and diluted earnings per share for the year ended December 31, 2012 and for the period February 11, 2011 through December 31, 2011 (in millions, except per share amounts):
	Year ended December 31, 2012
	Net Income Available to Shareholders
	Class P			Class A			Participating			Total
							Securities(a)
Net income attributable to KMI										$	315
Dividends paid in the period	$	601		$	542		$	41		(1,184		)
Excess distributions over earnings	(441		)	(426		)	(2		)	$	(869	)
Net income attributable to shareholders	$	160		$	116		$	39		$	315
Basic earnings per share
Basic weighted-average number of shares outstanding	461			446			N/A
Basic earnings per common share(b)	$	0.35		$	0.26		N/A
Diluted earnings per share
Net income attributable to shareholders and assumed conversions(c)	$	315		$	116		N/A
Diluted weighted-average number of shares	908			446			N/A
Diluted earnings per common share(b)	$	0.35		$	0.26		N/A
	February 11, 2011 through December 31, 2011
	Net Income Available to Shareholders
	Class P			Class A			Participating			Total
							Securities(a)
Net income attributable to KMI for the year ended December 31, 2011										$	594
Less: net income attributable to KMI members prior to incorporation										(70		)
Net income attributable to shareholders										524
Dividends paid in the period	$	87		$	399		$	38		(524		)
Excess distributions over earnings	—			—			—			$	—
Total net income attributable to shareholders	$	87		$	399		$	38		$	524
Basic earnings per share
Basic weighted-average number of shares outstanding(d)	118			589			N/A
Basic earnings per common share(b)	$	0.74		$	0.68		N/A
Diluted earnings per share
Net income attributable to shareholders and assumed conversions(c)	$	524		$	399		N/A
Diluted weighted-average number of shares(d)	708			589			N/A
Diluted earnings per common share(b)	$	0.74		$	0.68		N/A
_______
(a)	Participating securities included Class B shares, Class C shares, and unvested restricted stock awards issued to non-senior management employees that contained rights to dividend equivalents in the case of the restricted shares.  Our Class B and Class C shares were entitled to participate in our earnings, only to the extent of cash distributions made to them. As a result, no earnings in excess of dividends received were allocated to the Class B and Class C shares in our determination of basic and diluted earnings per share.
(b)	The Class A shares earnings per share as compared to the Class P shares earnings per share were reduced due to the sharing of economic benefits (including dividends) amongst the Class A, B, and C shares.  Class A, B and C shares owned by Richard Kinder, the sponsor investors, the original shareholders, and other management were referred to as “investor retained stock,” and were convertible into a fixed number of Class P shares.  In the aggregate, our investor retained stock was entitled to receive a dividend per share on a fully-converted basis equal to the dividend per share on our common stock.  The conversion of shares of investor retained stock into Class P shares did not increase our total fully-converted shares outstanding, impact the aggregate dividends we paid or the dividends we paid per share on our Class P common stock.
(c)	For the diluted earnings per share calculation, total net income attributable to each class of common stock was divided by the adjusted weighted-average shares outstanding during the period, including all dilutive potential shares.
(d)	The weighted-average shares outstanding calculation is based on the actual days in which the shares were outstanding for the period from February 11, 2011 to December 31, 2011.

Acquisitions_Notes

Acquisitions (Notes)	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	'
	Acquisitions and Divestitures
	Business Combinations and Acquisitions of Investments
	During 2013, 2012 and 2011, we and our subsidiary, KMP, completed the following significant acquisitions, and except for the acquisition of two separate equity interests in Watco Companies, LLC (noted as (2) and (6) in the table and discussion below), we accounted for these acquisitions in accordance with the “Business Combinations” Topic of the Codification.
	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 and KMP’s goodwill are both the value of the synergies created between the acquired assets and its pre-existing assets, and its expected ability to grow the business acquired by leveraging pre-existing business experience.  With the exception of KMP’s acquisitions of (i) KinderHawk and EagleHawk Field Services LLC and (ii) SouthTex Treaters (noted as (4) and (5), respectively, in the table and discussion below), we do not expect our recorded goodwill to be deductible for tax purposes.
	The following table discloses our assignment of the purchase price for each of our significant acquisitions (in millions):
				Assignment of Purchase Price
	Ref.	Date	Acquisition	Purchase				Current		Property		Deferred		Goodwill		Long-term debt			Other liabilities			Non-controlling interest			Previously held equity interest
				price				assets		plant &		charges
										equipment		& other
	KMI
	-1	12-May	EP	$	22,928			$	7,175	$	12,921	$	5,718	$	18,562	$	(13,417	)	$	(4,234	)	$	(3,797	)	$	—
	KMP
	-2	11-Jan	Watco Companies, LLC (1 of 2)	50				—		—		50		—		—			—			—			—
	-3	11-Jun	TGS Development, L.P. Terminal Acquisition	67				—		43		31		—		—			(7		)	—			—
	-4	11-Jul	KinderHawk and EagleHawk	835				36		642		140		94		(77		)	—			—			—
	-5	11-Nov	SouthTex Treaters, Inc. Natural Gas Treating Assets	152				27		9		17		126		—			(27		)	—			—
	-6	11-Dec	Watco Companies, LLC (2 of 2)	50				—		—		50		—		—			—			—			—
	-7	13-May	Copano	3,733				218		2,805		1,775		1,141		(1,252		)	(233		)	(17		)	(704		)
	-8	13-Jun	Goldsmith-Landreth Field Unit	280				—		298		—		—		—			(18		)	—			—
	(1)  EP
	Effective on May 25, 2012, we acquired all of the outstanding shares of EP for an aggregate consideration of approximately $22.9 billion (excluding assumed debt, but including payments of $87 million for share based awards expensed in the post-combination period). In total, EP shareholders received (i) $11.6 billion in cash, (ii) 330 million KMI Class P shares with a fair value of $10.6 billion (based on the $32.11 closing market price of a Class P share on May 24, 2012) and (iii) 505 million KMI warrants with a fair value of $863 million (based on a fair value of $1.71 per warrant as of May 24, 2012). The warrants have an exercise price of $40 per share and a 5-year term.
	During the second quarter of 2013, management completed its purchase accounting valuation estimates and, as a result, retrospectively adjusted the valuations of certain liabilities with a corresponding increase to goodwill as of the acquisition date. The retrospective adjustments amounted to approximately $60 million and primarily related to revisions of estimates related to certain environmental obligations, sales and use tax liabilities, and deferred income taxes.
	The asset amount assigned to “Deferred charges & other” in the table above includes $4,211 million assigned to “Investments.” The “Other liabilities” assumed and shown in the table above includes $1,463 million assigned to “Total current liabilities.” The “Noncontrolling interests” assumed in the EP acquisition represents the fair value of noncontrolling interests associated with EP’s investment in EPB and was based on the 117 million EPB common units outstanding to the public as of May 24, 2012 valued at EPB’s May 24, 2012 closing price of $32.37 per common unit.
	On May 24, 2012, EP sold its subsidiary, EP Energy LLC, which consisted of EP’s exploration and production business for $7.2 billion. Accordingly, the assets and liabilities of EP Energy LLC are not included in the purchase price allocation table above and the net sale proceeds were used to pay off the holders of EP Energy LLC’s $961 million long-term debt, and the remaining $6.2 billion (included in “Current assets” in the table above) was used to pay for a portion of the $11.6 billion cash portion of the purchase price. EP’s net operating loss carryforwards are expected to significantly offset the cash taxes associated with the sale of EP Energy LLC.
	During the year 2012, we incurred $463 million, net of legal recoveries, of pre-tax expenses associated with the EP acquisition, and EP Energy sale, including (i) $160 million in employee severance, retention and bonus costs; (ii) $87 million of accelerated EP stock based compensation allocated to the post-combination period under applicable GAAP rules; (iii) $37 million in advisory fees; (iv) $68 million for legal fees and reserves, net of legal recoveries; (v) a $108 million write-off (due to debt repayments) or amortization of capitalized financing fees associated with the EP acquisition financing; and less (vi) a $29 million benefit associated with pension income.
	Together, EP and its subsidiary EPB offered natural gas transmission services to a range of customers, including natural gas producers, marketers and end-users, as well as other natural gas transmission, distribution and electric generation companies. The pipelines group of EP and EPB were the nation’s largest interstate natural gas pipeline franchise, transporting natural gas through interstate natural gas pipelines that connect the nation’s principal supply regions to its major consuming regions (the Gulf Coast, California, the northeast, the southwest and the southeast). The pipelines business also included storage and LNG terminaling facilities. Most of the acquired assets are included in the Natural Gas Pipelines business segment.
	(2) Watco Companies, LLC (1 of 2)
	On January 3, 2011, KMP purchased 50,000 Class A preferred shares of Watco Companies, LLC for $50 million in cash in a private transaction.  In connection with its purchase of these preferred shares, the most senior equity security of Watco, KMP entered into a limited liability company agreement with Watco that provides KMP certain priority and participating cash distribution and liquidation rights.  Pursuant to the agreement, KMP receives priority, cumulative cash distributions from the preferred shares at a rate of 3.25% per quarter (13% annually), and it participates partially in additional profit distributions at a rate equal to 0.5%.  The preferred shares have no conversion features and hold no voting powers, but do provide KMP certain approval rights, including the right to appoint one of the members to Watco’s Board of Managers.  On December 28, 2011, KMP made an additional $50 million investment in Watco, as described below in “—(6) Watco Companies, LLC (2 of 2).”
	Watco Companies, LLC is the largest privately held short line railroad company in the U.S., operating 22 short line railroads on approximately 3,500 miles of leased and owned track.  KMP’s investment provided capital to Watco for further expansion of specific projects and complemented KMP’s existing terminal network.  It also provides KMP’s customers more transportation services for many of the commodities that it currently handles, and offers it the opportunity to share in additional growth opportunities through new projects.  As of December 31, 2013, KMP’s net equity investment in Watco totaled $103 million and is within “Investments” on our accompanying consolidated balance sheet.  KMP accounts for its investment under the equity method of accounting, and we include it in the Terminals—KMP business segment.
	(3) TGS Development, L.P. Terminal Acquisition
	On June 10, 2011, KMP acquired a newly constructed petroleum coke terminal located in Port Arthur, Texas from TGS Development, L.P. (TGSD) for an aggregate consideration of $74 million, consisting of $43 million in cash, $24 million in common units, and an obligation to pay additional consideration of $7 million.  In March 2012, KMP settled the $7 million liability by issuing additional common units to TGSD (KMP issued 87,162 common units and determined each unit’s value based on the $83.87 closing market price of the common units on the NYSE on the March 14, 2012 issuance date).
	All of the acquired assets are located in Port Arthur, Texas, and include long-term contracts to provide petroleum coke handling and cutting services to improve the refining of heavy crude oil at Total Petrochemicals USA Inc.’s Port Arthur refinery. The acquisition complemented KMP’s existing Gulf Coast bulk terminal facilities and expanded its pre-existing petroleum coke handling operations.  All of the acquired assets are included as part of the Terminals—KMP business segment.
	(4) KinderHawk and EagleHawk
	Effective July 1, 2011, KMP acquired from Petrohawk Energy Corporation (Petrohawk, now a subsidiary of BHP Billiton as discussed below) both the remaining 50% equity ownership interest in KinderHawk that it did not already own and a 25% equity ownership interest in EagleHawk, Petrohawk’s natural gas gathering and treating business located in the Eagle Ford shale formation in South Texas for an aggregate consideration of $912 million, consisting of $835 million in cash and assumed debt of $77 million (representing 50% of KinderHawk’s borrowings under its bank credit facility as of July 1, 2011).  KMP then repaid the outstanding $154 million of borrowings and following this repayment, KinderHawk had no outstanding debt. KMP also terminated the revolving bank credit facility at the time of such repayment. All of the acquired operations are included in the Natural Gas Pipelines business segment.
	Following this acquisition of the remaining ownership interest on July 1, 2011, KMP changed its method of accounting from the equity method to full consolidation, and due to the fact that KMP acquired a controlling financial interest in KinderHawk, KMP remeasured its previous 50% equity investment in KinderHawk to its fair value.  KMP recognized a $167 million non-cash loss as a result of this remeasurement.  The loss amount represented the excess of the carrying value of KMP’s investment ($910 million as of July 1, 2011) over its fair value ($743 million), and we reported this loss separately within the “Other Income (Expense)” section in our accompanying consolidated statement of income for the year ended December 31, 2011. Additionally, on August 25, 2011, mining and oil company BHP Billiton completed its previously announced acquisition of Petrohawk through a short-form merger under Delaware law.  The merger was closed with Petrohawk being the surviving corporation as a wholly owned subsidiary of BHP Billiton.  The acquisition did not affect the terms of KMP’s contracts with Petrohawk.
	(5) SouthTex Treaters, Inc. Asset Acquisition
	On November 30, 2011, KMP acquired a manufacturing complex and certain natural gas treating assets from SouthTex Treaters, Inc. for an aggregate consideration of $179 million, consisting of $152 million in cash and assumed liabilities of $27 million.  SouthTex Treaters, Inc. is a leading manufacturer, designer and fabricator of natural gas treating plants that are used to remove impurities (CO2 and hydrogen sulfide) from natural gas before it is delivered into gathering systems and transmission pipelines to ensure that it meets pipeline quality specifications.  The acquisition complemented and expanded KMP’s existing natural gas treating business, and all of the acquired operations are included in the Natural Gas Pipelines business segment.
	(6) Watco Companies, LLC (2 of 2)
	On December 28, 2011, KMP purchased an additional 50,000 Class A preferred shares of Watco Companies, LLC for $50 million in cash in a private transaction.  The priority and participating cash distribution and liquidation rights associated with these shares are similar to the rights associated with the 50,000 Class A preferred shares KMP acquired on January 3, 2011—KMP receives priority, cumulative cash distributions from the preferred shares at a rate of 3.25% per quarter (13% annually), and participates partially in additional profit distributions at a rate equal to 0.5%.
	(7) Copano
	Effective May 1, 2013, KMP acquired all of Copano’s outstanding units for a total purchase price of approximately $5.2 billion (including assumed debt and all other assumed liabilities). The transaction was a 100% unit for unit transaction with an exchange ratio of 0.4563 of KMP’s common units for each Copano common unit. KMP issued 43,371,210 of its common units valued at $3,733 million as consideration for the Copano acquisition (based on the $86.08 closing market price of a common unit on the NYSE on the May 1, 2013 issuance date).
	Also, due to the fact that KMP’s acquisition included the remaining 50% interest in Eagle Ford Gathering LLC that it did not already own, KMP remeasured its existing 50% equity investment in Eagle Ford to its fair value as of the acquisition date. As a result of this remeasurement, KMP recognized a $558 million non-cash gain, which represented the excess of the investment’s fair value ($704 million) over the carrying value as of May 1, 2013 ($146 million). We reported this gain separately within the “Other Income (Expense)” section in our accompanying consolidated statement of income for the year ended December 31, 2013.
	The table above reflects the adjusted preliminary purchase price allocation as of December 31, 2013. Deferred charges & other includes $1,375 million assigned to “Other intangibles, net” and $387 million assigned to “Investments.” The intangible amount represents the fair value of acquired customer contracts and agreements, and we are currently amortizing these intangible assets over an estimated remaining useful life of 25 years. The investment amount represents an aggregate of seven separate investments, each accounted for under the equity method of accounting. KMP’s evaluation of the assigned fair values is ongoing and subject to adjustment.
	Our accounting policy is to apply the look-through method of recording deferred taxes on the outside book tax basis differences in our investments without regard to non-tax deductible goodwill. As a result of the goodwill recorded by KMP for its Copano acquisition, KMI’s deferred tax liability and goodwill were increased by $260 million for the portion of its outside basis difference associated with KMP’s underlying goodwill.
	Copano provides comprehensive services to natural gas producers, including natural gas gathering, processing, treating and NGL fractionation. Copano owns an interest in or operates approximately 6,900 miles of pipelines with 2.7 Bcf/d of natural gas transportation capacity, and also owns nine natural gas processing plants with more than 1 Bcf/d of natural gas processing capacity and 315 MMcf/d of natural gas treating capacity. Its operations are located primarily in Texas, Oklahoma and Wyoming. Most of the acquired assets are included in the Natural Gas Pipelines business segment.
	(8) Goldsmith Landreth Field Unit
	On June 1, 2013, KMP acquired certain oil and gas properties, rights, and related assets in the Permian Basin of West Texas from Legado Resources LLC for an aggregate consideration of $298 million consisting of $280 million in cash and assumed liabilities of $18 million (including $12 million of long-term asset retirement obligations). The acquisition of the Goldsmith Landreth San Andres oil field unit includes more than 6,000 acres located in Ector County, Texas. The acquired oil field is in the early stages of CO2 flood development and includes a residual oil zone along with a classic San Andres waterflood. As of December 31, 2013, the field was producing approximately 1,230 Bbl/d of oil, and as part of the transaction, KMP obtained a long-term supply contract for up to 150 MMcf/d of CO2. The acquisition complemented KMP’s existing oil and gas producing assets in the Permian Basin, and we included the acquired assets as part of the CO2—KMP business segment. Our evaluation of the assigned fair values is ongoing and subject to adjustment.
	Pro Forma Information
	The following summarized unaudited pro forma consolidated income statement information for the years ended December 31, 2013 and 2012, assumes that the EP, Copano and the Goldsmith Landreth field unit acquisitions had occurred as of January 1, 2012. We prepared the following summarized unaudited pro forma financial results for comparative purposes only. The summarized unaudited pro forma financial results may not be indicative of the results that would have occurred if these acquisitions had been completed as of January 1, 2012 or the results that will be attained in the future. Amounts presented below are in millions, except for the per share amounts:
			Pro Forma
			Year Ended December 31,
			2013				2012
			(Unaudited)
	Revenues		$	14,775			$	13,035
	Income from continuing operations		2,655				866
	Income from discontinued operations, net of tax		(4		)		1,291
	Net income		2,651				2,157
	Net income attributable to noncontrolling interests		(1,486		)		(153		)
	Net income attributable to Kinder Morgan, Inc.		1,165				2,004
	Diluted earnings per common share
	Class P shares		$	1.12			$	1.93
	Class A shares						$	1.84
	Acquisition Subsequent to December 31, 2013
Effective January 17, 2014, KMP acquired American Petroleum Tankers (APT) and State Class Tankers (SCT) from affiliates of The Blackstone Group and Cerberus Capital Management for an aggregate consideration of approximately $962 million in cash (pending final true-ups for both acquired working capital balances and capital spending prior to the closing date). KMP funded this transaction with borrowings made under its commercial paper program which is supported by a short-term liquidity facility dated January 17, 2014 (see Note 8 “Debt—Credit Facilities and Restrictive Covenants—KMP—Subsequent Event”). Additionally, KMGP, as KMP’s general partner, has agreed to waive incentive distribution amounts of $13 million for 2014, $19 million for 2015 and $6 million for 2016 to facilitate the transaction.
APT and SCT are engaged in the marine transportation of crude oil, condensate and refined products in the U.S. domestic trade, commonly referred to as the Jones Act trade. APT’s primary assets consist of a fleet of five medium range Jones Act qualified product tankers, each with 330 MBbl of cargo capacity, and each operating pursuant to long-term time charters with high quality counterparties, including major integrated oil companies, major refiners and the U.S. Navy. The vessels’ time charters have an average remaining term of approximately four years, with renewal options to extend the initial terms by an average of two years. APT’s vessels are operated by Crowley Maritime Corporation.
SCT has commissioned the construction of four medium range Jones Act qualified product tankers, each with 330 MBbl of cargo capacity. The SCT vessels are scheduled to be delivered in 2015 and 2016 and are being constructed by General Dynamics’ NASSCO shipyard. KMP expects to invest approximately $214 million to complete the construction of the vessels. Upon delivery, the SCT vessels will be operated pursuant to long-term time charters with a major integrated oil company. Each of the time charters has an initial term of five years, with renewal options to extend the initial term by up to three years. The acquisition of APT and SCT complements and extends KMP’s existing crude oil and refined products transportation business, and all of the acquired assets are included in the Terminals—KMP business segment.
Drop-down of EP Assets to KMP
Aug-12
Effective August 1, 2012, KMP acquired a 100% ownership interest in TGP and an initial 50% ownership interest in EPNG from us for an aggregate consideration of approximately $6.2 billion (including a proportional share of assumed debt borrowings as of August 1, 2012). The consideration that we received from KMP consisted of (i) $3.5 billion in cash; (ii)4,667,575 of KMP’s common units (valued at $0.4 billion based on KMP’s $81.52 closing market price of the common units on the NYSE on the August 1, 2012 issuance date); and (iii) $2.3 billion in assumed debt (consisting of the combined carrying value of 100% of TGP’s debt borrowings and 50% of EPNG’s debt borrowings as of August 1, 2012, excluding any debt fair value adjustments). We used the proceeds from the drop-down transaction to (i) pay down $2.3 billion on our 3-year term loan facility; (ii) pay off and terminate our 364-day bridge facility; and (iii) pay off an $839 million senior note which matured on September 1, 2012.
Mar-13
Effective March 1, 2013, KMP acquired from us the remaining 50% ownership interest it did not already own in both EPNG and the EP midstream assets (see “—KMP Previously Held Investment in El Paso Midstream Investment Company, LLC” following) for an aggregate consideration of approximately $1.7 billion (including a proportional 50% share of assumed debt borrowings as of March 1, 2013). The consideration that we received from KMP consisted of (i) $994 million in cash (including $6 million in the second quarter of 2013 to settle the final working capital adjustment); (ii) 1,249,452 common units (valued at $108 million based on the $86.72 closing market price of KMP’s common unit on the NYSE on the March 1, 2013 issuance date); and (iii) $557 million in assumed debt (consisting of 50% of the outstanding principal amount of EPNG’s debt borrowings as of March 1, 2013, excluding any debt fair value adjustments). We used the proceeds from the March 1, 2013 drop-down transaction to (i) pay down $947 million of our senior secured term loan facility; and (ii) reduce borrowings under our credit facility.
In this report, we refer to these acquisitions of assets by KMP from us as the drop-down transactions and the combined group of assets acquired by KMP from us as the drop-down asset groups. The terms of the drop-down transactions were approved on our behalf by the independent members of our board of directors and on KMP’s behalf by the audit committees and the boards of directors of both KMGP, as KMP’s general partner, and KMR, in its capacity as the delegate of KMGP, following the receipt by our independent directors and by the audit committees of KMGP and KMR of separate fairness opinions from different independent financial advisors.
The drop-down transactions were accounted for as transfers of net assets between entities under common control. Specifically, we have retrospectively adjusted our consolidated financial statements to reflect the recognition by KMP of the acquired assets and assumed liabilities at our carrying value, including our EP purchase accounting adjustments as of May 25, 2012.
KMP Previously Held Investment in El Paso Midstream Investment Company, LLC
Effective June 1, 2012, KMP acquired from an investment vehicle affiliated with Kohlberg Kravis Roberts & Co. L.P. (together with its affiliates, referred to as KKR) a 50% ownership interest in El Paso Midstream Investment Company, LLC (EP Midstream), a joint venture that owns (i) the Altamont natural gas gathering, processing and treating assets located in the Uinta Basin in Utah and (ii) the Camino Real natural gas and oil gathering system located in the Eagle Ford shale formation in South Texas, collectively referred to in this report as the EP midstream assets. KMP acquired its initial 50% interest for an aggregate consideration of $289 million in common units (KMP issued 3,792,461 common units and determined each unit’s value based on KMP’s $76.23 closing market price of the common units on the NYSE on the June 4, 2012 issuance date).
We, through our EP acquisition, owned the remaining 50% of the EP Midstream assets, and as a result we consolidated EP Midstream in the accompanying consolidated financial statements effective June 1, 2012. The operating results of the EP midstream assets are included in the Natural Gas Pipelines business segment. No gain or loss on the previously held equity investment was recognized as the fair value of the equity investment acquired through our EP acquisition was determined to equal the $289 million purchase price paid by KMP for its 50% interest. As such, the fair value of 100% of EP Midstream was determined to be $578 million.
We measured the identifiable intangible assets acquired at fair value on the acquisition date, and as a result, we recognized $50 million in “Deferred charges and other assets,” representing the fair value of separate and identifiable relationships with existing customers.  We estimated the remaining useful life of these existing customer relationships to be approximately 10 years.  After measuring all of the identifiable tangible and intangible assets acquired and liabilities assumed at fair value on the acquisition date, we recognized $248 million of “Goodwill.”  We believe the primary item that generated the goodwill is our ability to grow the business by leveraging our pre-existing natural gas operations, and we believe that this value contributed to our acquisition price exceeding the fair value of acquired identifiable net assets and liabilities. This goodwill is not deductible for tax purposes.
Income Tax Impact of the Drop-Down of EP Assets to KMP
As discussed above, we accounted for the acquisition of EP as a business combination and for the subsequent March 2013 and August 2012 drop-down transactions as transfers of net assets between entities under common control. For income tax purposes, the March 2013 drop-down transaction was treated as a contribution and the August 2012 drop-down transaction was treated as a partial sale, and a partial contribution.
Our accounting policy is to apply the look-through method of recording deferred taxes on the outside book tax basis differences in our investments without regard to non tax deductible goodwill. As a result of the drop-down transactions, a deferred tax liability arose related to the portion of the outside basis difference associated with the underlying goodwill that was contributed to KMP by us. However, since the drop-downs were transactions between entities under common control, we recognized an offsetting deferred charge of $448 million for the August 2012 and $53 million for the March 2013 drop-down transactions. These balances will be amortized to income tax expense over the remaining useful lives of the transferred assets of approximately 25 years Similar to the impact described above, KMP’s acquisition of a 50% ownership interest in the EP Midstream joint venture, also generated the recognition of a deferred charge and corresponding deferred tax liability and is included in the amount above. For the year ended December 31, 2013 and the period subsequent to the August 2012 drop-down through December 31, 2012, total income tax expense related to the amortization of the deferred charges was approximately $20 million and $7 million, respectively.
Divestitures
KMP’s FTC Natural Gas Pipelines Disposal Group – Discontinued Operations
As described above in Note 2, following our March 2012 agreement with the FTC, we began accounting for KMP’s FTC Natural Gas Pipelines disposal group as discontinued operations (prior to KMI’s sale announcement, we included the disposal group in the Natural Gas Pipelines business segment). Effective November 1, 2012, we then sold KMP’s FTC Natural Gas Pipelines disposal group to Tallgrass Energy Partners, LP (now known as Tallgrass Development, LP) (Tallgrass), and KMP received proceeds of $1,791 million (before cash selling expenses).  In November 2012, we also paid selling expenses of $78 million (consisting of certain required tax payments to joint venture partners).
Additionally, during 2012, KMP remeasured the disposal group’s net assets to reflect its assessment of fair value as a result of the FTC mandated sale requirement, and as a result of this remeasurement of net assets to fair value and the sale of net assets, we recognized a combined $937 million loss. We reported this loss amount separately as “Loss on sale and the remeasurement of KMP’s FTC Natural Gas Pipelines disposal group to fair value, net of tax” within the discontinued operations section of our accompanying consolidated statement of income for the year ended December 31, 2012. We reported the proceeds received from the sale separately as “Proceeds from disposal of discontinued operations” within the investing section of our accompanying consolidated statement of cash flows for the year ended December 31, 2012.
In 2013, KMP and Tallgrass trued up the final consideration for the sale of KMP’s FTC Natural Gas Pipelines disposal group and based both on this true up and certain incremental selling expenses paid in 2013, we recognized an additional $4 million loss. We reported this loss amount separately as “Loss on sale and the remeasurement of KMP’s FTC Natural Gas Pipelines disposal group to fair value, net of tax” within the discontinued operations section of our accompanying consolidated statement of income for the year ended December 31, 2013, and except for this loss amount, no other financial results from the operations of KMP’s FTC Natural Gas Pipelines disposal group were recorded in 2013.
Summarized financial information for KMP’s FTC Natural Gas Pipelines disposal group is as follows (in millions):
	Year Ended December 31,
	2012(a)				2011
Operating revenues	$	227			$	322
Operating expenses	(131		)		(183		)
Depreciation and amortization	(7		)		(24		)
Other expense	(1		)		—
Earnings from equity investments	70				87
Interest income and Other, net	2				2
Income tax expense	—				(2		)
Income from operations of KMP’s FTC Natural Gas Pipelines disposal group	$	160			$	202
_______
(a)	2012 amounts represent financial information for the ten month period ended October 31, 2012. We sold KMP’s FTC Natural Gas Pipelines disposal group effective November 1, 2012.
Express Pipeline System
Effective March 14, 2013, KMP sold both its one-third equity ownership interest in the Express pipeline system and its subordinated debenture investment in Express to Spectra Energy Corp. KMP received net cash proceeds of $402 million (after paying both a final working capital settlement and certain transaction related selling expenses), and we reported the net cash proceeds received from the sale separately as “Proceeds from sales of assets and investments” within the investing section of our accompanying consolidated statement of cash flows. For the year ended December 31, 2013, we recognized a combined $224 million pre-tax gain with respect to this sale, and we reported this gain amount separately as “Gain on sale of investments in Express pipeline system” on our accompanying consolidated statement of income. We also recorded an income tax expense of $84 million related to this gain on sale, and we included this expense within “Income Tax Expense.”
As of the date of sale, KMP’s equity investment in Express totaled $67 million and its note receivable due from Express totaled $110 million. Prior to KMP’s sale, we (i) accounted for KMP’s equity investment under the equity method of accounting; (ii) accounted for KMP’s debt investment under the historical amortized cost method of accounting; and (iii) included the financial results of the Express pipeline system within the Kinder Morgan Canada—KMP business segment.  As of December 31, 2012, KMP’s equity and debt investments in Express totaled $65 million and $114 million, respectively, and we included the combined $179 million amount within “Assets held for sale” on our accompanying consolidated balance sheet.
BOSTCO
Effective December 1, 2012, TransMontaigne exercised its previously announced option to acquire up to 50% of KMP’s Class A member interest in BOSTCO, KMP’s previously announced oil terminal joint venture located on the Houston Ship Channel. On this date, TransMontaigne acquired a 42.5% Class A member interest in BOSTCO from KMP for an aggregate consideration of $79 million, and following this acquisition, KMP now owns a 55% Class A member interest in BOSTCO (KMP sold a 2.5% Class A member interest in BOSTCO to a third party on January 1, 2012 for an aggregate consideration of $1 million). Because KMP retained a controlling financial interest in BOSTCO, we continued to account for KMP’s investment under the full consolidation method and we accounted for this change in KMP’s ownership interest as an equity transaction.
TGP’s Sale of Production Area Facilities
On September 1, 2013, TGP sold certain natural gas facilities located offshore in the Gulf of Mexico and onshore in the state of Louisiana for an aggregate consideration of $32 million in cash. TGP’s net assets sold in this transaction (including assets identified as “held for sale”) totaled $89 million, and as a result of the sale, TGP recognized both a $93 million increase in regulatory assets pursuant to a FERC order, and a $36 million gain from the sale of assets. We included the cash proceeds received from the sale in 2013 within “Sale or casualty of property, plant and equipment, investments and other net assets, net of removal costs” within the investing section of our accompanying consolidated statement of cash flows for the year ended December 31, 2013, and we included the gain amount within “Other Income (Expense)” on our accompanying consolidated statement of income for the year ended December 31, 2013.
BBPP Holdings Ltda
As of December 31, 2012, we owned a 2% interest in Gas Transboliviano S.A., and a 33 1/3% interest in BBPP Holdings Ltda which we acquired as a part of the May 25, 2012 EP acquisition. BBPP Holdings Ltda owned a 29% interest in Transportadora Brasileira Gasoduto Bolivia-Brasil S.A. which, together with Gas Transboliviano S.A., owned the Bolivia to Brazil Pipeline. On January 18, 2013, we completed the sale of our equity interests in the Bolivia to Brazil Pipeline for $88 million. As of December 31, 2012, our $88 million equity interests in the Bolivia to Brazil Pipeline was included within “Assets held for sale” on our accompanying consolidated balance sheet.

Income_Taxes_Notes

Income Taxes (Notes)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	Income Taxes
	The components of “Income from Continuing Operations Before Income Taxes” are as follows (in millions):
		Year Ended December 31,
		2013			2012				2011
	U.S.	$	3,107		$	1,246			$	731
	Foreign	331			97				79
	Total Income from Continuing Operations Before Income Taxes	$	3,438		$	1,343			$	810
	Components of the income tax provision applicable to continuing operations for federal, foreign and state taxes are as follows (in millions):
		Year Ended December 31,
		2013			2012				2011
	Current tax expense
	Federal	$	57		$	48			$	241
	State	36			34				33
	Foreign	9			10				3
	Total	102			92				277
	Deferred tax expense
	Federal	612			49				64
	State	—			4				(1		)
	Foreign	28			(6		)		21
	Total	640			47				84
	Total tax provision	$	742		$	139			$	361
	The difference between the statutory federal income tax rate and our effective income tax rate is summarized as follows (in millions, except percentages):
		Year Ended December 31,
		2013						2012						2011
	Federal income tax	$	1,203		35	%		$	470			35	%	$	284		35	%
	Increase (decrease) as a result of:
	State deferred tax rate change	(21		)	(0.6	)%		20				1.5	%	(1		)	(0.1	)%
	Taxes on foreign earnings	112			3.3	%		(6		)		(0.5	)%	24			3	%
	Net effects of consolidating KMP’s and EPB’s U.S. income tax provision	(488		)	(14.2	)%		(288		)		(21.5	)%	34			4.2	%
	State income tax, net of federal benefit	45			1.3	%		21				1.6	%	26			3.2	%
	Dividend received deduction	(54		)	(1.6	)%		(32		)		(2.4	)%	(10		)	(1.2	)%
	Adjustments to uncertain tax positions	(87		)	(2.5	)%		(72		)		(5.3	)%	(9		)	(1.1	)%
	Acquisition costs	—			—	%		18				1.3	%	—			—	%
	Other	32			0.9	%		8				0.6	%	13			1.6	%
	Total	$	742		21.6	%		$	139			10.3	%	$	361		44.6	%
	Deferred tax assets and liabilities result from the following (in millions):
		December 31,
		2013			2012
	Deferred tax assets
	Employee benefits	$	238		$	360
	Book accruals	136			91
	Net operating loss, capital loss, tax credits carryforwards (net of valuation allowance)	578			1,017
	Derivative instruments	33			84
	Interest rate and currency swaps	35			37
	Debt fair value adjustment	112			155
	Other	43			86
	Total deferred tax assets	1,175			1,830
	Deferred tax liabilities
	Property, plant and equipment	351			328
	Investments	4,888			5,008
	Book accruals	10			22
	Other	10			4
	Total deferred tax liabilities	5,259			5,362
	Net deferred tax liabilities	$	4,084		$	3,532
	Current deferred tax asset	$	(567	)	$	(539	)
	Non-current deferred tax liability	4,651			4,071
	Net deferred tax liabilities	$	4,084		$	3,532
	Deferred Tax Assets and Valuation Allowances: As a result of our EP acquisition, we have deferred tax assets of $354 million related to net operating loss carryovers; alternative minimum and foreign tax credits of $308 million; and valuation allowances related to deferred tax assets of $95 million at December 31, 2013. In 2013, we also recorded an $11 million deferred tax asset related to the capital loss from our sale of the Pakistan power plant. No valuation allowance has been recorded as we fully expect to utilize this capital loss. As of December 31, 2012, the deferred tax asset related to net operating loss carryovers was $823 million, alternative minimum, general business, and foreign tax credits were $298 million, and valuation allowances related to the deferred tax assets were $104 million.
	Expiration Periods for Deferred Tax Assets: As of December 31, 2013, we have U.S. federal net operating loss carryforwards of $613 million, which will expire from 2017 - 2031; state losses of $1.4 billion which will expire from 2014 - 2032; and foreign losses of $191 million, of which approximately $140 million carries over indefinitely and $51 million expires from 2028 - 2032. We also have $297 million of federal alternative minimum tax credits which do not expire; and approximately $11 million of foreign tax credits, the majority of which will expire from 2015 - 2023. Use of our U.S. federal carryforwards is subject to the limitations provided under Sections 382 and 383 of the Internal Revenue Code as well as the separate return limitation rules of Internal Revenue Service regulations.
	Unrecognized Tax Benefits: We recognize the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained on examination by the taxing authorities, based not only on the technical merits of the tax position based on tax law, but also the past administrative practices and precedents of the taxing authority.  The tax benefits recognized in the financial statements from such a position are measured based on the largest benefit that has a greater than 50% likelihood of being realized upon ultimate resolution.
	A reconciliation of our gross unrecognized tax benefit excluding interest and penalties is as follows (in millions):
		Year Ended December 31,
		2013			2012				2011
Balance at beginning of period	$	269		$	57			$	53
Uncertain tax positions of EP	4			289				—
Subtotal	273			346				53
Additions based on current year tax positions	11			11				11
Additions based on prior year tax positions	26			1				2
Reductions based on settlements with taxing authority	(86		)	(55		)		—
Reductions due to lapse in statute of limitations	(15		)	(34		)		(9		)
Balance at end of period	$	209		$	269			$	57
Our continuing practice is to recognize interest and/or penalties related to income tax matters in income tax expense, and as of December 31, 2013, we had $29 million of accrued interest and $2 million in accrued penalties.  As of December 31, 2012, we had $28 million of accrued interest and $2 million in accrued penalties.  As of December 31, 2011, we had $5 million of accrued interest and $1 million of accrued penalties.  All of the $209 million of unrecognized tax benefits, if recognized, would affect our effective tax rate in future periods.  In addition, we believe it is reasonably possible that our liability for unrecognized tax benefits will decrease by approximately $2 million during the next year to approximately $207 million.
We are subject to taxation, and have tax years open to examination for the periods 2008-2013 in the U.S., 1999-2013 in various states and 2004-2013 in various foreign jurisdictions.
Schedule of Income before Income Tax, Domestic and Foreign [Table Text Block]	'
	The components of “Income from Continuing Operations Before Income Taxes” are as follows (in millions):
		Year Ended December 31,
		2013			2012				2011
	U.S.	$	3,107		$	1,246			$	731
	Foreign	331			97				79
	Total Income from Continuing Operations Before Income Taxes	$	3,438		$	1,343			$	810

Property_Plant_and_Equipment_N

Property, Plant and Equipment (Notes)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment Disclosure [Text Block]	'
	Property, Plant and Equipment
	Classes and Depreciation
	As of December 31, 2013 and 2012, our property, plant and equipment consisted of the following (in millions):
		December 31,
		2013			2012
	Natural gas, liquids, crude oil and CO2 pipelines	$	17,399		$	14,649
	Natural gas, liquids, CO2, and terminals station equipment	17,960			15,309
	Natural gas, liquids (including linefill), and transmix processing	259			358
	Other	3,656			3,319
	Accumulated depreciation, depletion and amortization	(6,757		)	(5,278		)
		32,517			28,357
	Land and land right-of-way	1,158			1,143
	Construction work in process	2,172			1,496
	Property, plant and equipment, net	$	35,847		$	30,996
	As of December 31, 2013 and 2012, we included regulated property, plant and equipment amounts of $14,957 million and $14,937 million, respectively, within “Property, plant and equipment, net” on our accompanying consolidated balance sheets. These regulated amounts constituted 42% and 48%, respectively, of our total property, plant and equipment amounts at each reporting date. Depreciation, depletion, and amortization expense charged against property, plant and equipment was $1,663 million, $1,324 million, and $1,022 million, for the year ended December 31, 2013, 2012, and 2011, respectively.
	Asset Retirement Obligations
	As of December 31, 2013 and 2012, we recognized asset retirement obligations in the aggregate amount of $204 million and $175 million, respectively.  The majority of our asset retirement obligations are associated with the CO2—KMP business segment, where KMP is required to plug and abandon oil and gas wells that have been removed from service and to remove its surface wellhead equipment and compressors.  We included $25 million and $31 million of asset retirement obligations as of December 31, 2013 and 2012, respectively, within “Other current liabilities” in our accompanying consolidated balance sheets.  The remaining amounts are included within “Other long-term liabilities and deferred credits” at each reporting date.
	We have various other obligations throughout our businesses to remove facilities and equipment on rights-of-way and other leased facilities.  We currently cannot reasonably estimate the fair value of these obligations because the associated assets have indeterminate lives.  These assets include pipelines, certain processing plants and distribution facilities, and certain bulk and liquids terminal facilities.  An asset retirement obligation, if any, will be recognized once sufficient information is available to reasonably estimate the fair value of the obligation.

Investments_Investments_Notes

Investments Investments (Notes)	12 Months Ended
	Dec. 31, 2013
Investments [Abstract]	'
Equity Method Investments and Joint Ventures Disclosure [Text Block]	'
	Investments
	Our investments primarily consist of equity investments where we hold significant influence over investee actions and which we account for under the equity method of accounting. As of December 31, 2013 and 2012 our investments consisted of the following (in millions):
		December 31,
		2013			2012
	Citrus Corporation	$	1,875		$	1,966
	Ruby Pipeline Holding Company, L.L.C.	1,153			1,185
	Midcontinent Express Pipeline LLC	602			633
	Gulf LNG Holdings Group, LLC	578			596
	Plantation Pipe Line Company	307			313
	EagleHawk	272			208
	Red Cedar Gathering Company	176			172
	Fort Union Gas Gathering L.L.C.	161			—
	Double Eagle Pipeline LLC	144			—
	Fayetteville Express Pipeline LLC	144			159
	Parkway Pipeline LLC	131			58
	Watco Companies, LLC	103			103
	Cortez Pipeline Company	12			11
	Eagle Ford				151
	NGPL Holdco LLC	—			68
	All others	285			173
	Total equity investments	5,943			5,796
	Bond investments	8			8
	Total investments	$	5,951		$	5,804
	The overall change in the carrying amount of our equity investments, including those of KMP, since December 31, 2012, related primarily to the increases and decreases associated with KMP’s May 1, 2013 Copano acquisition. As part of this acquisition, KMP acquired an approximate 37% equity ownership interest in Fort Union Gas Gathering L.L.C., a 50% equity ownership interest in Double Eagle Pipeline LLC and the remaining 50% equity ownership interest in Eagle Ford that KMP did not already own (KMP exchanged its status as an owner of an equity investment in Eagle Ford for a full controlling financial interest, and KMP began accounting for its investment under the full consolidation method).
	As shown in the table above, our remaining significant equity investments, including those of KMP (excluding the three investments described above), as of December 31, 2013 consisted of the following:
	•	Citrus Corporation—We operate and own a 50% interest in Citrus Corporation, the sole owner of Florida Gas Transmission Company, L.L.C. (Florida Gas). Florida Gas transports natural gas to cogeneration facilities, electric utilities, independent power producers, municipal generators, and local distribution companies through a 5,300-mile natural gas pipeline. The remaining 50% interest is owned by Energy Transfer Partners L.P.;
	•	Ruby Pipeline Holding Company, L.L.C.—We operate and own a 50% interest in Ruby Pipeline Holding Company, L.L.C., the sole owner of Ruby Pipeline natural gas transmission system. The remaining 50% interest is owned by Global Infrastructure Partners as convertible preferred interests;
	•	Midcontinent Express Pipeline LLC—KMP operates and owns a 50% interest in MEP, the sole owner of the Midcontinent Express natural gas pipeline system.  The remaining 50% ownership interest is owned by subsidiaries of Regency Energy Partners L.P.;
	•	Gulf LNG Holdings Group, LLC—We operate and own a 50% interest in Gulf LNG Holdings Group, LLC, the owner of a LNG receiving, storage and regasification terminal near Pascagoula, Mississippi, as well as pipeline facilities to deliver vaporized natural gas into third party pipelines for delivery into various markets around the country. The remaining 50% ownership interests are wholly and partially owned by the subsidiaries of GE Financial Services;
	•	Plantation—KMP operates and owns a 51.17% interest in Plantation, the sole owner of the Plantation refined petroleum products pipeline system.  A subsidiary of Exxon Mobil Corporation owns the remaining interest.  Each investor has an equal number of directors on Plantation’s board of directors, and board approval is required for certain corporate actions that are considered participating rights; therefore, KMP does not control Plantation, and it accounts for its investment under the equity method;
	•	BHP Billiton Petroleum (Eagle Ford Gathering) LLC, f/k/a EagleHawk Field Services LLC and referred to in this report as EagleHawk—KMP owns a 25% interest in EagleHawk, the sole owner of a natural gas gathering system serving the producers of the Eagle Ford shale formation. A subsidiary of BHP Billiton operates EagleHawk and owns the remaining 75% ownership interest;
	•	Red Cedar Gathering Company—KMP owns a 49% interest in the Red Cedar, the sole owner of the Red Cedar natural gas gathering, compression and treating system.  The remaining 51% interest is owned by the Southern Ute Indian Tribe;
	•	Fayetteville Express Pipeline LLC —KMP owns a 50% interest in Fayetteville Express Pipeline LLC, the sole owner of the Fayetteville Express natural gas pipeline system.  Energy Transfer Partners, L.P. owns the remaining 50% interest and serves as operator of Fayetteville Express Pipeline LLC;
	•	Parkway Pipeline LLC —KMP operates and owns a 50% interest in Parkway, the sole owner of the Parkway Pipeline refined petroleum products pipeline system. Valero Energy Corp. owns the remaining 50% interest;
	•	Watco Companies, LLC—KMP holds a preferred equity investment in Watco Companies, LLC, the largest privately held short line railroad company in the U.S.  KMP owns 100,000 Class A preferred shares and pursuant to the terms of its investment, it receives priority, cumulative cash distributions from the preferred shares at a rate of 3.25% per quarter, and participates partially in additional profit distributions at a rate equal to 0.5%.  The preferred shares have no conversion features and hold no voting powers, but do provide KMP certain approval rights, including the right to appoint one of the members to Watco’s Board of Managers;
	•	Cortez Pipeline Company—KMP operates and owns a 50% interest in the Cortez Pipeline Company, the sole owner of the Cortez carbon dioxide pipeline system.  A subsidiary of Exxon Mobil Corporation owns a 37% interest and Cortez Vickers Pipeline Company owns the remaining 13% interest; and
	•	NGPL Holdco LLC— KMI operates and owns a 20% interest in NGPL Holdco LLC, the owner of NGPL and certain affiliates, collectively referred to in this report as NGPL, a major interstate natural gas pipeline and storage system.
	During 2012 and 2013, continued deteriorating natural gas market conditions characterized by excess gas supply, low commodity prices, reduced basis spreads and low volatility have negatively impacted NGPL’s operating results and its cash flows. We also determined that these market conditions would likely not improve in the near future. Therefore, these events caused us to evaluate the carrying value of our investment utilizing market conditions and have resulted in us recording impairments on our investment in NGPL Holdco LLC in 2012 and 2013. We recognized $200 million of pre-tax, non-cash impairment charges in 2012, and in 2013, we recognized $65 million of pre-tax, non-cash impairment charges writing down our remaining investment to its estimated fair value of zero.
	Both 2013 and 2012 non-cash impairment charges are included in the caption “Earnings from equity investments” in our accompanying consolidated statements of income.
	Our earnings (losses) from equity investments were as follows (in millions):
		Year Ended December 31,
		2013			2012			2011
	Citrus Corporation(a)	$	84		$	53		$	—
	Fayetteville Express Pipeline LLC	55			55			24
	Gulf LNG Holdings Group, LLC(a)	47			22			—
	Midcontinent Express Pipeline LLC	40			42			43
	Plantation Pipe Line Company	35			32			28
	Red Cedar Gathering Company	31			32			32
	Cortez Pipeline Company	24			25			24
	Eagle Ford(b)	14			34			11
	Watco Companies, LLC	13			13			6
	Fort Union Gas Gathering L.L.C.	11			—			—
	EagleHawk	9			11			3
	Parkway Pipeline LLC	1			—			—
	Double Eagle Pipeline LLC	1			—			—
	KinderHawk(c)	—			—			22
	Ruby Pipeline Holding Company, L.L.C.(a)	(6		)	(5		)	—
	NGPL Holdco LLC(d)	(66		)	(198		)	19
	All others	34			37			14
	Total	$	327		$	153		$	226
	Amortization of excess costs	$	(39	)	$	(23	)	$	(7	)
	_______
	(a)	2012 amounts are for the period from May 25, 2012 through December 31, 2012.
(b)	Effective May 1, 2013, KMP acquired the remaining 50% equity ownership interest in Eagle Ford that KMP did not already own and KMP changed its method of accounting from the equity method to full consolidation.
(c)	Effective July 1, 2011, KMP acquired the remaining 50% equity ownership interest in KinderHawk that KMP did not already own and KMP changed its method of accounting from the equity method to full consolidation.
(d)	2013 and 2012 amounts include non-cash investment impairment charges, which we recorded in the amount of $65 million and $200 million (pre-tax), respectively, as discussed above.
Summarized combined financial information for our significant equity investments (listed or described above) is reported below (in millions; amounts represent 100% of investee financial information):
	Year Ended December 31,
Income Statement	2013			2012			2011
Revenues	$	3,615		$	3,681		$	3,145
Costs and expenses	2,803			3,194			3,287
Net income (loss)	$	812		$	487		$	(142	)
	December 31,
Balance Sheet	2013			2012
Current assets	$	950		$	917
Non-current assets	20,782			21,308
Current liabilities	1,451			1,538
Non-current liabilities	11,351			11,401
Partners’/owners’ equity	8,930			9,286

Goodwill_and_Other_Intangibles

Goodwill and Other Intangibles (Notes)	12 Months Ended
	Dec. 31, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Goodwill and Intangible Assets Disclosure [Text Block]	'
	Goodwill and Other Intangibles
	Goodwill and Excess Investment Cost
	We record the excess of the cost of an acquisition price over the fair value of acquired net assets as an asset on our balance sheet. This amount is referred to and reported separately as “Goodwill” in our accompanying consolidated balance sheets. Goodwill is not subject to amortization but must be tested for impairment at least annually. This test requires us to assign goodwill to an appropriate reporting unit and to determine if the implied fair value of the reporting unit’s goodwill is less than its carrying amount.
	We evaluate goodwill for impairment on May 31 of each year. For this purpose, we have seven reporting units as follows: (i) Products Pipelines (excluding associated terminals); (ii) Products Pipelines Terminals (evaluated separately from Products Pipelines for goodwill purposes); (iii) Natural Gas Pipelines Regulated; (iv) Natural Gas Pipelines Non-Regulated; (v) CO2; (vi) Terminals; and (vii) Kinder Morgan Canada.  During the quarter ended June 30, 2013, we created the Natural Gas Pipelines Non-Regulated reporting unit to include the non-regulated businesses KMP acquired from Copano on May 1, 2013 as well as other non-regulated businesses that were historically part of the former Natural Gas Pipelines reporting unit (now the Natural Gas Pipelines Regulated reporting unit). We then allocated goodwill between these two reporting units based on the relative fair values of the reporting units.
	There were no impairment charges resulting from our May 31, 2013 impairment testing, and no event indicating an impairment has occurred subsequent to that date. We determined the fair value of each reporting unit as of May 31, 2013 based on a market approach utilizing an average dividend/distribution yield of comparable companies. The value of each reporting unit was determined on a stand-alone basis from the perspective of a market participant and represented the price estimated to be received in a sale of the unit as a whole in an orderly transaction between market participants at the measurement date.
	Changes in the gross amounts of our goodwill and accumulated impairment losses for each of the years ended December 31, 2013 and 2012 are summarized as follows (in millions):
		Natural Gas Pipelines			CO2–KMP		Products Pipelines-KMP			Terminals–			Kinder			Total
										KMP			Morgan
													Canada–
													KMP
	Historical Goodwill	$	3,723		$	1,528	$	2,129		$	1,484		$	621		$	9,485
	Accumulated impairment losses	(2,090		)	—		(1,267		)	(677		)	(377		)	(4,411		)
	Balance as of December 31, 2011	1,633			1,528		862			807			244			5,074
	Acquisitions(a)	18,803			—		—			—			—			18,803
	Disposals(b)	(250		)	—		—			—			—			(250		)
	Currency translation adjustments	—			—		—			—			5			5
	Balance as of December 31, 2012	20,186			1,528		862			807			249			23,632
	Acquisitions(c)	888			—		—			—			—			888
	Currency translation adjustments	—			—		—			—			(16		)	(16		)
	Balance as of December 31, 2013	$	21,074		$	1,528	$	862		$	807		$	233		$	24,504
	_______
	(a)	2012 acquisition amount consists of the EP and EP Midstream acquisitions as discussed in Note 3.
	(b)	2012 disposal amount relates to the sale of KMP’s FTC Natural Gas Pipelines disposal group as discussed in Note 3. Since the FTC Natural Gas Pipelines disposal group represented a significant portion of our Natural Gas Pipelines business segment, we allocated the goodwill of the segment based on the relative fair value of the portion being disposed of and the portion of the segment remaining.
	(c)	2013 acquisition amount consists of $881 million relating to KMP’s May 1, 2013 Copano acquisition as discussed in Note 3, and $7 million relating to other EP acquisition assets.
	For more information on our accounting for goodwill, see Note 2.
	With regard to our equity investments in unconsolidated affiliates, in almost all cases, either (i) the price we paid to acquire our share of the net assets of such equity investees or (ii) the revaluation of our share of the net assets of any retained noncontrolling equity investment (from the sale of a portion of our ownership interest in a consolidated subsidiary, thereby losing our controlling financial interest in the subsidiary) differed from the underlying carrying value of such net assets.  This differential consists of two pieces.  First, an amount related to the difference between the investee’s recognized net assets at book value and at current fair values (representing the appreciated value in plant and other net assets), and secondly, to any premium in excess of fair value (referred to as equity method goodwill) we paid to acquire the investment.  We include both amounts within “Investments” on our accompanying consolidated balance sheets.
	The first differential, representing the excess of the fair market value of our investees’ plant and other net assets over its underlying book value at either the date of acquisition or the date of the loss of control totaled $809 million and $714 million as of December 31, 2013 and 2012, respectively. In almost all instances, this differential, relating to the discrepancy between our share of the investee’s recognized net assets at book values and at current fair values, represents our share of undervalued depreciable assets, and since those assets (other than land) are subject to depreciation, we amortize this portion of our investment cost against our share of investee earnings.  As of December 31, 2013, this excess investment cost is being amortized over a weighted average life of approximately fifteen years.
	The second differential, representing total unamortized excess cost over underlying fair value of net assets acquired (equity method goodwill) totaled $138 million as of both December 31, 2013 and 2012. This differential is not subject to amortization but rather to impairment testing.  Accordingly, in addition to our annual impairment test of goodwill, we periodically reevaluate the amount at which we carry the excess of cost over fair value of net assets accounted for under the equity method, as well as the amortization period for such assets, to determine whether current events or circumstances warrant adjustments to our carrying value and/or revised estimates of useful lives.  Our impairment test considers whether the fair value of the equity investment as a whole, not the underlying net assets, has declined and whether that decline is other than temporary.  As of December 31, 2013, we believed no such impairment had occurred and no reduction in estimated useful lives was warranted.
	Other Intangibles
	Excluding goodwill, our other intangible assets include customer contracts, relationships and agreements, lease value, and technology-based assets.  These intangible assets have definite lives, are subject to amortization, and are reported separately as “Other intangibles, net” in our accompanying consolidated balance sheets. As of December 31, 2013 and 2012, these intangible assets totaled $2,438 million and $1,171 million, respectively, and primarily consisted of customer contracts, relationships and agreements associated with the Natural Gas Pipelines and Terminals-KMP business segments.
	Primarily, these contracts, relationships and agreements relate to the gathering of natural gas, and the handling and storage of petroleum, chemical, and dry-bulk materials, including oil, gasoline and other refined petroleum products, coal, petroleum coke, fertilizer, steel and ores.  We determined the values of these intangible assets by first, estimating the revenues derived from a customer contract or relationship (offset by the cost and expenses of supporting assets to fulfill the contract), and second, discounting the revenues at a risk adjusted discount rate.
	We amortize the costs of our intangible assets to expense in a systematic and rational manner over their estimated useful lives.  The life of each intangible asset is based either on the life of the corresponding customer contract or agreement or, in the case of a customer relationship intangible (the life of which was determined by an analysis of all available data on that business relationship), the length of time used in the discounted cash flow analysis to determine the value of the customer relationship.  Among the factors we weigh, depending on the nature of the asset, are the effect of obsolescence, new technology, and competition.
	For each of the years ended December 31, 2013, 2012 and 2011, the amortization expense on our intangibles totaled $125 million, $86 million and $65 million, respectively.  Our estimated amortization expense for our intangible assets for each of the next five fiscal years (2014 – 2018) is approximately $141 million, $136 million, $134 million, $132 million, and $130 million respectively.  As of December 31, 2013, the weighted average amortization period for our intangible assets was approximately twenty years.

Debt_Notes

Debt (Notes)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Debt Disclosure [Text Block]	'
	Debt
	We classify our debt based on the contractual maturity dates of the underlying debt instruments.  We defer costs associated with debt issuance over the applicable term. These costs are then amortized as interest expense in our accompanying consolidated statements of income using the effective interest rate method. The following table provides detail on the principal amount of our outstanding debt balances as of December 31, 2013 and 2012. The table amounts exclude all debt fair value adjustments, including debt discounts and premiums (in millions):
		December 31,
		2013				2012
	KMI
	Senior term loan facility, variable rate, due May 24, 2015	$	1,528			$	2,714
	Senior notes and debentures, 5.00% through 7.45%, due 2015 through 2098(a)	1,815				315
	Credit facility due December 31, 2014(b)	175				1,035
	Subsidiary borrowings (as obligor)
	K N Capital Trust I and III, deferrable interest debentures issued by subsidiary trusts, 7.63% and 8.56%, due 2027 and 2028(c)	27				27
	Kinder Morgan Finance Company, LLC, senior notes, 5.70% through 6.40%, due 2016 through 2036(a)(d)	1,636				1,636
	El Paso, senior notes, 6.50% through 12.00%, due 2013 through 2037(a)	3,830				3,860
	EPC Building, LLC, promissory note, 3.967%, due 2013 through 2035(e)	461				217
	Colorado Interstate Gas Services Company, 7.76% Totem note payable, due 2018	1				1
	Other credit facilities due December 20, 2013, March 20 and June 20, 2014	193				210
	EP preferred securities, 4.75%, due March 31, 2028(f)	280				286
	KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock(g)	100				100
	Total debt – KMI	10,046				10,401
	Less: Current portion of debt – KMI	(725		)		(1,153		)
	Total long-term debt – KMI(h)	$	9,321			$	9,248
	KMP and EPB
	KMP
	Senior notes, 2.65% through 9.00%, due 2013 through 2043(a)	$	15,600			$	13,350
	Commercial paper borrowings(i)	979				621
	Credit facility due May 1, 2018(j)	—				—
	KMP subsidiary borrowings (as obligor)
	TGP senior notes, 7.00% through 8.375%, due 2016 through 2037(k)	1,790				1,790
	EPNG senior notes, 5.95% through 8.625%, due 2017 through 2032(l)	1,115				1,115
	Copano senior notes, 7.125% due April 1, 2021(m)	332				—
	Other miscellaneous subsidiary debt	98				186
	Total debt – KMP	19,914				17,062
	Less: Current portion of debt – KMP(n)	(1,504		)		(1,155		)
	Total long-term debt – KMP(h)	18,410				15,907
	EPB
	EPPOC
	Senior notes, 4.10% through 8.00%, due 2013 through 2042(o)	2,260				2,348
	Credit facility due May 27, 2016(p)	—				—
	EPB subsidiary borrowings (as obligor)
	Colorado Interstate Gas Company, L.L.C. (CIG), senior notes, 5.95% through 6.85%, due 2015 through 2037(q)	475				475
	SLNG senior notes, 9.50% through 9.75%, due 2014 through 2016(a)(r)	135				135
	SNG notes, 4.40% through 8.00%, due 2017 through 2032(s)	1,211				1,211
	Other financing obligations(t)	175				178
	Total debt – EPB	4,256				4,347
	Less: Current portion of debt – EPB	(77		)		(93		)
	Total long-term debt – EPB(h)	4,179				4,254
	Total long-term debt – KMP and EPB	$	22,589			$	20,161
	_______
	(a)	Notes provide for the redemption at any time at a price equal to 100% of the principal amount of the notes plus accrued interest to the redemption date plus a make whole premium.
	(b)	As of December 31, 2013 and 2012, the weighted average interest rates on KMI’s credit facility borrowings were 2.67% and 2.72%, respectively.
	(c)	KMI’s business trusts, K N Capital Trust I and K N Capital Trust III, are obligated for $13 million of 8.56% Capital Trust Securities maturing on April 15, 2027 and $14 million of 7.63% Capital Trust Securities maturing on April 15, 2028, respectively, which it guarantees.  The 2028 securities are redeemable in whole or in part, at KMI’s option at any time, at redemption prices as defined in the associated prospectus.  The 2027 securities are redeemable in whole or in part at KMI’s option and at any time in certain limited circumstances upon the occurrence of certain events and at prices all defined in the associated prospectus supplements.  Upon redemption by KMI or at maturity of the Junior Subordinated Deferrable Interest Debentures, the proceeds must be used to make redemptions of the Capital Trust Securities on a pro rata basis.
	(d)	Each series of these notes is fully and unconditionally guaranteed by KMI on a senior secured basis as to principal, interest and any additional amounts required to be paid as a result of any withholding or deduction for Canadian taxes.
	(e)	EPC Building, LLC, as the landlord, leases the property to KMI as a tenant.
	(f)	Capital Trust I (Trust I), is a 100%-owned business trust that as of December 31, 2013, had $5.6 million of 4.75% trust convertible preferred securities outstanding (referred to as the EP Trust I Preferred Securities). Trust I exists for the sole purpose of issuing preferred securities and investing the proceeds in 4.75% convertible subordinated debentures, which are due 2028. Trust I’s sole source of income is interest earned on these debentures. This interest income is used to pay distributions on the preferred securities. EP provides a full and unconditional guarantee of the EP Trust I Preferred Securities. There are no significant restrictions on EP’s ability to obtain funds from its subsidiaries by distribution, dividend or loan. The EP Trust I Preferred Securities are non-voting (except in limited circumstances), pay quarterly distributions at an annual rate of 4.75%, carry a liquidation value of $50 per security plus accrued and unpaid distributions and are convertible at any time prior to the close of business on March 31, 2028, at the option of the holder, into the following mixed consideration: (i) 0.7197 of a share of KMI Class P common stock; (ii) $25.18 in cash without interest; and (iii) 1.100 warrants to purchase a share of KMI Class P common stock. We have the right to redeem these Trust I Preferred Securities at any time. Because of the substantive conversion rights of the securities into the mixed consideration, we bifurcated the fair value of the EP Trust I Preferred Securities into debt and equity components and as of December 31, 2013, the outstanding balance of $280 million (of which $141 million is classified as current) was bifurcated between debt ($247 million) and equity ($33 million). During the years ended December 31, 2013 and 2012, 107,618 and 781,633 EP Trust I Preferred Securities had been converted into (i) 77,442 and 562,521 shares of KMI Class P common stock; (ii) approximately $3 million and $20 million in cash; and (iii) 118,377 and 859,796 in warrants, respectively.
	(g)	As of December 31, 2013, KMGP had outstanding 100,000 shares of its $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock due 2057.  Until August 18, 2012, dividends accumulated, commencing on the issue date, at a fixed rate of 8.33% per annum and were payable quarterly in arrears, when and if declared by KMGP’s board of directors, on February 18, May 18, August 18 and November 18 of each year, beginning November 18, 2007. After August 18, 2012, dividends on the preferred stock accumulate at a floating rate of the 3-month LIBOR plus 3.8975% and are payable quarterly in arrears, when and if declared by KMGP’s board of directors, on February 18, May 18, August 18 and November 18 of each year, beginning November 18, 2012.  The preferred stock has approval rights over a commencement of or filing of voluntary bankruptcy by KMP or its SFPP or Calnev subsidiaries. (see “—KMGP Preferred Shares” below).
	(h)	Excludes debt fair value adjustments. As of December 31, 2013 and December 31, 2012, our total “Debt fair value adjustments” increased our combined debt balances by $1,977 million and $2,591 million, respectively. In addition to all unamortized debt discount/premium amounts and purchase accounting on our debt balances, our debt fair value adjustments also include (i) amounts associated with the offsetting entry for hedged debt; and (ii) any unamortized portion of proceeds received from the early termination of interest rate swap agreements. For further information about our debt fair value adjustments, see Note 13.
	(i)	In May 2013, in association with the increase of capacity negotiated for KMP’s senior unsecured revolving bank credit facility (see “—Credit Facilities and Restrictive Covenants—KMP” below), KMP increased its commercial paper program by $500 million to provide for the issuance of up to $2.7 billion. As of December 31, 2013 and December 31, 2012, the average interest rates on KMP’s outstanding commercial paper borrowings were 0.28% and 0.45%, respectively. The borrowings under KMP’s commercial paper program were used principally to finance the acquisitions and capital expansions it made during 2013 and 2012.
	(j)	See “Credit Facilities and Restrictive Covenants—KMP” below.
	(k)	Consists of six separate series of fixed-rate unsecured senior notes that KMP assumed as part of the August 2012 drop-down transaction.
	(l)	Consists of four separate series of fixed-rate unsecured senior notes that KMP assumed as part of the August 2012 and March 2013 drop-down transactions.
	(m)	Consists of a single series of fixed-rate unsecured senior notes that KMP guaranteed as part of its May 1, 2013 Copano acquisition. The notes mature on April 1, 2021, and interest on the notes is payable semiannually on April 1 and October 1 of each year. For further information about these notes, see “—KMP’s Copano Debt” below.
	(n)	Includes commercial paper borrowings.
	(o)	EPB’s only operating asset is its investment in EPPOC, and EPPOC’s only operating assets are its investments in Wyoming Interstate Company, L.L.C. (WIC), CIG, SLNG, Elba Express, SNG, ELC and Cheyenne Plains Gas Pipeline Company, L.L.C. (CPG), (collectively, the non-guarantor operating companies). EPB and EPPOC’s independent assets and operations, other than those related to these investments and EPPOC’s debt are less than 3% of the total assets and operations of EPB, and thus substantially all of the operations and assets exist within these non-guarantor operating companies. Furthermore, there are no significant restrictions on EPPOC or EPB’s ability to access the net assets or cash flows related to its controlling interests in the operating companies either through dividend or loan. The restrictive covenants under these debt obligations are no more restrictive than the restrictive covenants under EPB’s credit facility.
	(p)	LIBOR plus 1.75%.
(q)	CIG is subject to a number of restrictions and covenants under its debt obligation. The most restrictive of these include limitations on the incurrence of liens and limitations on sale-leaseback transactions.
(r)	The SLNG senior notes impose certain limitations on the ability of SLNG to, among other things, incur additional indebtedness, make certain restricted payments, enter into transactions with affiliates, and merge or consolidate with any other person, sell, assign, transfer, lease, convey or otherwise dispose of all or substantially all of its assets. SLNG is required to comply with certain financial covenants, including a leverage ratio of no more than 5.0 to 1.0 and an interest coverage ratio of no less than 2.0 to 1.0. The SLNG senior notes are subject to a change of control prepayment offer in the event of a ratings downgrade within a 120-day period from and including the date on which a change of control with respect to SLNG occurs (as defined in the note purchase agreement). If a sufficient number of the rating agencies downgrade the ratings of the SLNG notes below investment grade within the 120-day period from and including the date of any such change of control, then SLNG is required to offer to prepay the entire unpaid principal amount of the notes held by each holder at 101% of the principal amount of such SLNG notes (without any make-whole amount or other penalty), together with interest accrued thereon to the date for such prepayment.
(s)	Under its indentures, SNG is subject to a number of restrictions and covenants. The most restrictive of these include limitations on the incurrence of liens. SNIC is a wholly owned finance subsidiary of SNG and is the co-issuer of certain of SNG's outstanding debt securities. SNIC has no material assets, operations, revenues or cash flows other than those related to its service as a co-issuer of the debt securities. Accordingly, it has no ability to service obligations on the debt securities.
(t)	In conjunction with the construction of the Totem Gas Storage facility (Totem) and the High Plains pipeline (High Plains), CIG's joint venture partner in WYCO funded 50% of the construction costs. EPB reflected the payments made by their joint venture partner as other long-term liabilities on the balance sheet during construction and upon project completion, the advances were converted into a financing obligation to WYCO. Upon placing these projects in service, EPB transferred its title in the projects to WYCO and leased the assets back. Although EPB transferred the title in these projects to WYCO, the transfer did not qualify for sale leaseback accounting because of EPB’s continuing involvement through its equity investment in WYCO. As such, the costs of the facilities remain on our balance sheets and the advanced payments received from EPB’s 50% joint venture partner were converted into a financing obligation due to WYCO. As of December 31, 2013, the principal amounts of the Totem and High Plains financing obligations were $75 million and $94 million, respectively, which will be paid in monthly installments through 2039, and extended for the term of related firm service agreements until 2060 and 2043, respectively. The interest rate on these obligations is 15.5%, payable on a monthly basis.
Credit Facilities and Restrictive Covenants
KMI
On February 10, 2012, KMI entered into the following agreements which were effective with the May 25, 2012 acquisition of EP: (i) an amendment to its existing $1 billion revolving credit facility to, among other things, permit the EP acquisition, to fund, in part, the transactions and related costs and expenses, and to provide for ongoing working capital and for other general corporate purposes; (ii) an incremental joinder agreement which provides for $750 million in additional commitments under the existing revolving credit facility; and (iii) an acquisition debt facilities credit agreement (Acquisition Credit Facility) containing a 364-day bridge facility and a $5 billion 3-year term loan facility, the proceeds of which were used to finance a portion of the cash consideration and related fees and expenses paid in connection with the EP acquisition.
The amended and restated credit facility provides that the $1.75 billion revolver bears interest, at KMI’s option, at either (i) the adjusted LIBOR plus an applicable margin per annum varying from 2.50% per annum to 4.25% per annum depending on the publicly announced debt ratings for senior secured non-credit enhanced long-term indebtedness for borrowed money of KMI or (ii) an alternate base rate plus an applicable margin varying from 1.50% per annum to 3.25% per annum depending on debt ratings of KMI. In August 2012, we repaid the remaining outstanding balance of the 364-day bridge facility and terminated the facility. In November 2012, the terms of KMI’s $1.75 billion senior secured revolving credit facility were amended to decrease the fixed spread component of our floating interest rate by 100 basis points and to extend the maturity of the revolver to December 31, 2014. As of December 31, 2013, KMI was in compliance with all required financial covenants (described following).
KMI’s credit facility included the following restrictive covenants as of December 31, 2013:
•	total debt divided by earnings before interest, income taxes, depreciation and amortization may not exceed 6.00: 1.00;
•	certain limitations on indebtedness, including payments and amendments;
•	certain limitations on entering into mergers, consolidations, sales of assets and investments;
•	limitations on granting liens; and
•	prohibitions on making any dividend to shareholders if an event of default exists or would exist upon making such dividend.
The Acquisition Credit Facility provides that:
•	the term loans under the term loan facility bears interest, at KMI’s option, at either (i) adjusted LIBOR plus an applicable margin varying from 3.00% per annum to 4.75% per annum depending on certain debt ratings of KMI or (ii) an alternate base rate plus an applicable margin varying from 2.00% per annum to 3.75% per annum depending on certain debt ratings of KMI.
As of December 31, 2013, we had $175 million outstanding under KMI’s $1.75 billion credit facility and $80 million in letters of credit. Our availability under this facility as of December 31, 2013 was $1,495 million.
KMP
On May 1, 2013, KMP replaced its previous $2.2 billion, senior unsecured revolving credit facility that was due July 1, 2016, with a new $2.7 billion five-year senior unsecured revolving credit facility expiring May 1, 2018. Borrowings under the credit facility can be used for general partnership purposes and as a backup for KMP’s commercial paper program, and borrowings under the commercial paper program reduce the borrowings allowed under KMP’s credit facility. KMP had no borrowings under the credit facility as of December 31, 2013, and there were no borrowings under its previous credit facility as of December 31, 2012. KMP’s new credit facility’s financial covenants are substantially similar to those in the previous facility, and as of December 31, 2013, KMP was in compliance with all required financial covenants (described following). KMP’s credit facility provides that both the margin KMP will pay with respect to borrowings and the facility fee KMP will pay on the total commitment, will vary based on its senior debt credit rating. Interest on the credit facility accrues at KMP’s option at a floating rate equal to either:
•	the administrative agent’s base rate, plus a margin, which varies depending upon the credit rating of KMP’s long-term senior unsecured debt (the administrative agent’s base rate is a rate equal to the greatest of (i) the Federal Funds Rate, plus 0.5%; (ii) the Prime Rate; or (iii) LIBOR for a one -month eurodollar loan, plus 1%); or
•	LIBOR for a one -month eurodollar loan, plus a margin, which varies depending upon the credit rating of KMP’s long-term senior unsecured debt.
As of December 31, 2013, KMP had $979 million of commercial paper borrowings outstanding under its $2.7 billion credit facility and $203 million in letters of credit. KMP’s availability under its facility as of December 31, 2013 was $1,518 million.
KMP’s credit facility included the following restrictive covenants as of December 31, 2013:
•	total debt divided by earnings before interest, income taxes, depreciation and amortization for the preceding four quarters may not exceed:
•	5.5, in the case of any such period ended on the last day of (i) a fiscal quarter in which KMP makes any Specified Acquisition (as defined in the credit facility) or (ii) the first or second fiscal quarter next succeeding such a fiscal quarter; or
•	5.0, in the case of any such period ended on the last day of any other fiscal quarter;
•	certain limitations on entering into mergers, consolidations and sales of assets;
•	limitations on granting liens; and
•	prohibitions on making any distribution to holders of units if an event of default exists or would exist upon making such distribution.
In addition to normal repayment covenants, under the terms of KMP’s credit facility, the occurrence at any time of any of the following would constitute an event of default: (i) KMP’s failure to make required payments of any item of indebtedness or any payment in respect of any hedging agreement, provided that the aggregate outstanding principal amount for all such indebtedness or payment obligations in respect of all hedging agreements is equal to or exceeds $75 million; (ii) KMP’s general partner’s failure to make required payments of any item of indebtedness, provided that the aggregate outstanding principal amount for all such indebtedness is equal to or exceeds $75 million; (iii) adverse judgments rendered against KMP for the payment of money in an aggregate amount in excess of $75 million, if this same amount remains undischarged for a period of thirty consecutive days during which execution shall not be effectively stayed; and (iv) voluntary or involuntary commencements of any proceedings or petitions seeking KMP’s liquidation, reorganization or any other similar relief under any federal, state or foreign bankruptcy, insolvency, receivership or similar law.
KMP’s credit facility does not contain a material adverse change clause coupled with a lockbox provision; however, the facility does provide that the margin KMP will pay with respect to borrowings, and the facility fee that it will pay on the total commitment, will vary based on its senior debt credit rating.  None of KMP’s debt is subject to payment acceleration as a result of any change to its credit ratings.
EPB
In May 2011, EPPOC and WIC entered into an unsecured five-year credit facility with an initial aggregate borrowing capacity of $1 billion, expandable to $1.5 billion for certain expansion projects and acquisitions. EPPOC is a wholly owned subsidiary of EPB. In May 2012, EPB borrowed from the revolving credit facility to fund the acquisition of CPG and the remaining interest in CIG. On May 24, 2012, Standard & Poor’s Rating Service raised EPB’s credit rating, triggering a pricing level change. EPB’s interest rate for borrowings under the credit facility has decreased from the LIBOR plus 2% to LIBOR plus 1.75% and the commitment fee paid for unutilized commitments decreased from 0.4% to 0.3% and these rates remained effective at December 31, 2013. As of December 31, 2013, EPB had no outstanding balance under its revolving credit facility. EPB’s remaining availability under this facility was $1 billion. Borrowings under the credit facility are guaranteed by EPB.
EPB’s credit facility included the following restrictive covenants as of December 31, 2013:
•	EPB and WIC’s consolidated total debt divided by earnings before interest, income taxes, depreciation and amortization as of the end of each quarter may not exceed:
•	5.0 to 1.0 for any trailing four consecutive quarter period; and
•	5.5 to 1.0 for any such four quarter period during the three full fiscal quarters subsequent to the consummation of specified permitted acquisitions having a value greater than $25 million;
•	certain limitations on entering into mergers, consolidations and sales of assets;
•	limitations on granting liens; and
•	prohibitions on making any distribution to holders of units if an event of default exists or would exist upon making such distribution.
EPB also has additional flexibility to the covenants for growth projects. In case of a capital construction or expansion project in excess of $20 million, pro forma adjustments to consolidated earnings before interest, income taxes, depreciation and amortization, approved by the lenders, may be made based on the percentage of capital costs expended and projected cash flows for the project. Such adjustments shall be limited to 25% of actual consolidated earnings before interest, income taxes, depreciation and amortization.
The credit facility contains certain customary events of default that affect EPB, the borrowers and EPB’s other restricted subsidiaries, including, without limitation, (i) nonpayment of principal when due or nonpayment of interest or other amounts within five business days when due; (ii) bankruptcy or insolvency with respect to EBP, its general partner, the borrowers or any of EPB’s other restricted subsidiaries; (iii) judgment defaults against EPB, its general partner, the borrowers or any of EPB’s other restricted subsidiaries in excess of $50 million; or (iv) the failure of El Paso to directly or indirectly own a majority of the voting equity of EPB’s general partner and a failure by EPB to directly or indirectly own 100% of the equity of EPPOC.
KMP’s Copano Debt
As of the May 1, 2013 Copano acquisition date, KMP assumed the following outstanding Copano debt amounts (i) $404 million of outstanding borrowings under Copano’s revolving credit facility due June 10, 2016; (ii) $249 million aggregate principal amount of Copano’s 7.75% unsecured senior notes due June 1, 2018; and (iii) $510 million aggregate principal amount of Copano’s 7.125% unsecured senior notes due April 1, 2021. Immediately following the acquisition, KMP repaid the outstanding $404 million of borrowings under Copano’s revolving credit facility, and terminated the credit facility at the time of such repayment. On June 1, 2013, KMP paid $259 million (based on a price of 103.875% of the principal amount) to fully redeem and retire the 7.75% series of senior notes in accordance with the terms and conditions of the indenture governing the notes. As part of its May 1, 2013 purchase price allocation, KMP valued the 7.75% senior notes equal to the $259 million redemption value and accordingly, no gain or loss was recorded from this debt retirement. KMP utilized borrowings under its commercial paper program for both of these debt retirements.
On September 4, 2013, KMP paid $191 million to complete the partial redemption and retirement of $178 million (35%) of the total $510 million outstanding principal amount of Copano’s 7.125% senior notes, (excluding a $6 million payment for accrued and unpaid interest on the redeemed notes as of September 4, 2013). As part of its May 1, 2013 purchase price allocation, KMP valued the repaid portion of the 7.125% senior notes equal to the $191 million redemption value and accordingly, KMP recorded no gain or loss from this debt retirement. As of December 31, 2013, an aggregate principal amount of $332 million of 7.125% senior notes remained outstanding.
Debt Issuances and Repayments
Apart from the changes in KMP’s Copano debt discussed above, following are significant long-term debt issuances and repayments made during 2013 and 2012:
		2013		2012
KMI
Issuances		$750 million 5.00% notes due 2021		$12,178 million of EP debt assumed as of the May 25, 2012 acquisition date
		$750 million 5.625% notes due 2023		$5,000 million senior term loan facility due 2015
		$251 million EPC Building, LLC 3.967% promissory notes(a)		$217 million EPC Building, LLC 3.967% promissory notes(a)
Repayments		$1,186 million senior term loan facility due 2015		$839 million 6.50% notes due 2012
				$2,286 million senior term loan facility due 2015
KMP
Issuances		$600 million 3.50% notes due 2023		$1,000 million 3.95% notes due 2022
		$700 million 5.00% notes due 2043		$625 million of 3.45% notes due 2023
		$800 million 2.65% notes due 2019		$625 million of 5.00% notes due 2042
		$650 million 4.15% notes due 2024
Repayments		$500 million 5.00% notes due 2013		$450 million of 7.125% notes due 2012
				$500 million of 5.85% notes due 2012
EPB (through EPPOC)
Issuances				$475 million 4.70% notes due 2042
Repayments		$88 million 8.00% notes due 2013
_______
(a)	In December 2012, our subsidiary, EPC Building, LLC had issued $468 million of 3.967% amortizing promissory notes with payments due 2013 through 2035, of which $217 million was issued to third parties and the remaining $251 million was held by KMI until they were sold to third parties in April of 2013. Proceeds from the issuance of the notes were used to reduce KMI’s credit facility borrowings.
KMGP Preferred Shares
The following table provides information about KMGP’s distributions on 100,000 shares of its Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock:
		Year Ended December 31,
		2013				2012
Per share cash distribution declared for the period(a)		$	42.101			$	63.236
Per share cash distribution paid in the period		$	42.169			$	73.423
_______
(a)	On January 15, 2014, KMGP declared a distribution for the three months ended December 31, 2013, of $10.570 per share, which was paid on February 18, 2014 to shareholders of record as of January 31, 2014.
Maturities of Debt
The scheduled maturities of the outstanding debt balances, excluding debt fair value adjustments as of December 31, 2013, are summarized as follows (in millions):
Year	KMI				KMP			EPB
2014	$	725			$	1,504		$	77
2015	1,788				300			756
2016	928				750			69
2017	798				1,255			505
2018	1,322				1,000			5
Thereafter	4,485				15,105			2,844
Total	$	10,046			$	19,914		$	4,256
Interest Rates, Interest Rate Swaps and Contingent Debt
The weighted average interest rate on all of our borrowings was 5.08% during 2013 and 4.92% during 2012. Information on our interest rate swaps is contained in Note 13. For information about our contingent debt agreements, see Note 12.
Subsequent Events
On January 17, 2014, KMP entered into a short-term unsecured liquidity facility. This liquidity facility provides for borrowings up to $1.0 billion with a term of six months. The covenants of this facility are substantially similar to the covenants of KMP’s existing senior credit facility that is due May 1, 2018. In conjunction with the establishment of KMP’s liquidity facility, KMP increased its commercial paper program to provide for the issuance of up to $3.7 billion (up from $2.7 billion). KMP’s liquidity facility supports its commercial paper program and borrowings under its commercial paper program reduce the borrowings allowed under KMP’s liquidity facility. As of the date of this report, KMP has no borrowings under its liquidity facility.
On February 19, 2014, KMP priced in a public offering $750 million of 3.50% senior notes due March 1, 2021 and $750 million of 5.50% senior notes due March 1, 2044.

Sharebased_Compensation_and_Em

Share-based Compensation and Employee Benefits (Notes)	12 Months Ended
	Dec. 31, 2013
Share-based Compensation [Abstract]	'
Share based compensation and pension and other postretirement benefits disclosure [Text Block]	'
	Share-based Compensation and Employee Benefits
	Share-based Compensation
	Kinder Morgan, Inc.
	We completed an initial public offering in February 2011 as discussed further in Note 10 “Stockholders’ Equity—Kinder Morgan, Inc.—Initial Public Offering.”  As a result of our initial public offering, our outstanding Class B units and Class A-1 units were converted to Class B shares and Class C shares, respectively. As of December 26, 2012, all class B and C shares had converted into Class P shares.
	Class P Shares
	Stock Compensation Plan for Non-Employee Directors
	In connection with our initial public offering, we adopted the Stock Compensation Plan for Non-Employee Directors, in which our independent directors will participate.  None of the 11 directors nominated by Richard D. Kinder or the Sponsor Investors participate in the plan. The plan recognizes that the compensation paid to each non-employee director is fixed by our board, generally annually, and that the compensation is payable in cash.  Pursuant to the plan, in lieu of receiving some or all of the cash compensation, each non-employee director who was not nominated by Richard D. Kinder or one of the Sponsor Investors, referred to as “eligible directors,” may elect to receive shares of Class P common stock.  Each election will be generally at or around the first board meeting in January of each calendar year and will be effective for the entire calendar year.  An eligible director may make a new election each calendar year.  The total number of shares of Class P common stock authorized under the plan is 250,000.  During 2013, 2012 and 2011, we made restricted Class P common stock grants to our non-employee directors of 5,710, 5,520 and 1,570, respectively. These grants were valued at time of issuance at $210,000, $185,000 and $45,000, respectively. All of the restricted stock grants made to non-employee directors vest during a six-month period.
	Restricted Stock and Long-term Incentive Retention Award Plan
	Upon our initial public offering, our restricted stock compensation program replaced our Long-term Incentive Retention Award Plan. Our restricted stock compensation program is available to employees eligible under the former Long-term Incentive Retention Award Plan, discussed below.  The following table sets forth a summary of activity and related balances of our restricted stock excluding that issued to non-employee directors (in millions, except share amounts):
		Year Ended							Year Ended							February 11, 2011 Through
		December 31, 2013							December 31, 2012							December 31, 2011
		Shares			Weighted Average				Shares			Weighted Average				Shares			Weighted Average
					Grant Date							Grant Date							Grant Date
					Fair Value							Fair Value							Fair Value
	Outstanding at beginning of period	2,154,022			$	69			1,163,090			$	33			—			$	—
	Granted	4,563,495			181				1,463,388			51				980,851			28
	Shares issued in exchange for cash awards	—			—				—			—				213,040			6
	Vested	(83,444	)		(3		)		(102,033	)		(3		)		—			—
	Forfeited	(251,188	)		(8		)		(370,423	)		(12		)		(30,801	)		(1		)
	Outstanding at end of period	6,382,885			$	239			2,154,022			$	69			1,163,090			$	33
	Intrinsic value of restricted stock vested during the period				$	3						$	4						$	—
	Restricted stock grants made to employees have vesting periods ranging from 2 years with variable vesting dates to 7 years. Following is a summary of the future vesting of our outstanding restricted stock grants:
	Year		Vesting of Restricted Shares
	2014		449,043
	2015		741,959
	2016		1,339,735
	2017		470,049
	2018		1,172,468
	2019		1,531,087
	2020		603,072
	2021		20,126
	2023		55,346
	Total Outstanding		6,382,885
	The related expense less estimated forfeitures is recognized ratably over the vesting period of the restricted stock grants.  Upon vesting, the grants will be paid in our Class P common shares.
	During 2013, 2012 and 2011, we recorded $35 million, $14 million and $4 million, respectively, in expense related to restricted stock grants.  In addition, in conjunction with the exchange for restricted shares discussed above, we recorded an increase to additional paid-in capital in the amount of $2 million in 2011.  At December 31, 2013 and 2012, unrecognized restricted stock compensation expense, less estimated forfeitures, was approximately $177 million and $49 million, respectively.
	From 2006 until our initial public offering, we elected not to make any restricted stock awards as a result of a 2007 going private transaction.  To ensure that certain key employees who had previously received restricted stock and restricted stock unit awards continued under a long-term retention and incentive program, the Company implemented the Long-term Incentive Retention Award plan.  The plan provided cash awards approved by the compensation committees of the Company which were granted in July of each year to recommended key employees.  Senior management was not eligible for these awards.  These grants required the employee to sign a grant agreement.  The grants vested 100% after the third year anniversary of the grant provided the employee remained with the Company.  The remaining grants outstanding were made in July of 2010.  During the years ended December 31,2013, 2012, and 2011, we expensed $2 million, $7 million and $13 million, respectively, related to these grants.
	Awards of Participation Interests in a 2007 Going Private Transaction
	In connection with our 2007 going private transaction, members of management were awarded Kinder Morgan Holdco LLC Class A-1 and Class B units. In accordance with generally accepted accounting principles, we were required to recognize compensation expense in connection with the Class A-1 and Class B units over the expected life of such units; however, we did not have any obligation, nor did we pay any amounts related to these compensation expenses as all expenses were borne by the Investors, and since we were not responsible for paying these expenses, we recognized the amounts allocated to us as both an expense on our income statement and a contribution to “Stockholders Equity” on our balance sheet. The awards and terms of the Class B units granted to members of management were determined after extensive negotiations between management and the Sponsor Investors with respect to which management agreed to forego any long-term executive compensation at least until the Sponsor Investors sell their interests in us or convert their Class A shares into Class P shares. The Class B units were converted into Class B shares, and the class A-1 units were converted into Class C shares in connection with our initial public offering. The aggregate amount of our Class P common stock into which the Class A shares, Class B shares and Class C shares could convert was fixed. The conversion of Class B shares into Class P shares reduced the number of Class P shares into which the Class A shares and Class C shares could convert. Therefore, we view the Class B shares, along with the Class A shares and Class C shares, as participation interests in a going private transaction, rather than as awards of stock-based compensation. As of December 26, 2012, all class B and C shares had converted into Class P shares.
	Kinder Morgan Energy Partners, L.P.
	On January 18, 2005, KMR’s compensation committee established the Kinder Morgan Energy Partners, L.P. Common Unit Compensation Plan for Non-Employee Directors. The plan is administered by KMR’s compensation committee and KMR’s board has sole discretion to terminate the plan at any time. The primary purpose of this plan is to promote KMP’s interests and the interests of its unitholders by aligning the compensation of the non-employee members of the board of directors of KMR with KMP unitholders’ interests. Further, since KMR’s success is dependent on its operation and management of KMP’s business and its resulting performance, the plan is expected to align the compensation of the non-employee members of the board with the interests of KMR’s shareholders.
	The Kinder Morgan Energy Partners, L.P. Common Unit Compensation Plan for Non-Employee Directors recognizes that the compensation to be paid to each non-employee director is fixed by the KMR board, generally annually, and that the compensation is payable in cash.  Pursuant to the plan, in lieu of receiving cash compensation, each non-employee director may elect to receive common units.  Each election is made generally at or around the first board meeting in January of each calendar year and is effective for the entire calendar year. A non-employee director may make a new election each calendar year.  The total number of common units authorized under this compensation plan is 100,000.  All common units issued under this plan are subject to forfeiture restrictions that expire six months from the date of issuance.  A total of 2,450 common units were issued to non-employee directors in 2011 as a result of their elections to receive common units in lieu of cash compensation.
	Pension and Other Postretirement Benefit Plans
	Overview of Retirement Benefit Plans
	Savings Plan
	We maintain a defined contribution plan covering eligible U.S. employees. We contribute 5% of eligible compensation for most of the plan participants. Certain plan participants’ contributions and Company contributions are based on collective bargaining agreements. In connection with the EP acquisition, we assumed EP’s defined contribution savings plan which was merged into our savings plan during 2012. In connection with KMP’s Copano acquisition, we assumed Copano’s defined contribution savings plan which was merged into our savings plan during 2013. The total amount charged to expense for our savings plan was approximately $40 million, $32 million, and $24 million for the years ended December 31, 2013, 2012, and 2011, respectively.
	Pension Plans
	Our pension plan is a defined benefit plan that covers substantially all of our U.S. employees and provides benefits under a cash balance formula. A participant in the cash balance plan accrues benefits through contribution credits based on a combination of age and years of service times eligible compensation. Interest is also credited to the participant’s plan account. A participant becomes fully vested in the plan after three years, and may take a lump sum distribution upon termination of employment or retirement. Certain collectively bargained and grandfathered employees continue to accrue benefits through a career pay formula.
	In connection with the EP acquisition, we assumed EP’s defined benefit pension plans including a cash balance plan and a supplemental executive retirement plan (“SERP”). These plans had combined benefit obligations of $2,407 million and assets of $1,949 million as of the May 25, 2012 acquisition date. We merged the EP cash balance plan into our cash balance plan on December 31, 2012. We terminated the EP SERP and partially settled the plan’s benefit obligation during 2012. The $28 million SERP obligation that remained as of December 31, 2012 was settled in February 2013.
	Other Postretirement Benefit Plans
	We and certain of our U.S. subsidiaries provide other postretirement benefits (“OPEB”), including medical benefits for closed groups of retired employees and certain grandfathered employees and their dependents, and limited postretirement life insurance benefits for retired employees. Medical benefits for these closed groups of retirees may be subject to deductibles, co-payment provisions, dollar caps and other limitations on the amount of employer costs, and we reserve the right to change these benefits. Effective January 1, 2014, the plan was amended to provide a fixed subsidy to post-age 65 Medicare eligible participants to purchase coverage through a retiree Medicare exchange.
	In connection with the EP acquisition, we assumed EP’s OPEB plans including retiree medical and life insurance benefits. These plans had aggregate benefit obligations of $606 million and assets of $273 million as of the May 25, 2012 acquisition date.
	Additionally, KMP’s subsidiary SFPP has incurred certain liabilities for postretirement benefits to certain current and former employees, their covered dependents, and their beneficiaries. However, the net periodic benefit costs, contributions and liability amounts associated with the SFPP postretirement benefit plan are not material to our consolidated income statements or balance sheets.
	Benefit Obligation, Plan Assets and Funded Status. The following table provides information about our pension and OPEB plans as of and for each of the years ended December 31, 2013 and 2012, and includes information regarding the EP Pension and OPEB plans since the May 25, 2012 acquisition date (in millions):
		Pension Benefits								OPEB
		2013				2012				2013				2012
	Change in benefit obligation:
	Benefit obligation at beginning of period	$	2,792			$	343			$	720			$	91
	Service cost	25				18				—				—
	Interest cost	92				67				23				18
	Actuarial (gain) loss	(132		)		178				(38		)		40
	Benefits paid	(239		)		(58		)		(54		)		(37		)
	Participant contributions	—				—				11				7
	Medicare Part D subsidy receipts	—				—				6				1
Business combination(a)	—				2,407				—				606
Plan amendments	25				(17		)		(37		)		(5		)
Curtailments, settlements and special termination benefits(b)	—				(146		)		—				(1		)
Benefit obligation at end of period	2,563				2,792				631				720
Change in plan assets:
Fair value of plan assets at beginning of period	2,240				258				341				55
Actual return on plan assets	254				203				40				24
Employer contributions	78				32				42				19
Participant contributions	—				—				11				7
Benefits paid	(239		)		(58		)		(54		)		(37		)
Business combination(a)	—				1,949				—				273
Settlements(b)	—				(144		)		—				—
Fair value of plan assets at end of period	2,333				2,240				380				341
Funded status - net liability at December 31,	$	(230	)		$	(552	)		$	(251	)		$	(379	)
_______
(a) Reflects the acquisition date amount of benefit plan obligations and assets assumed from El Paso.
(b) Reflects the settlement of benefit obligations associated with certain participants in the acquired El Paso plans as a result of the sale of EP Energy, a reduction in force and termination of the SERP.
Components of Funded Status. The following table details the amounts recognized in our balance sheet at December 31, 2013 and 2012 related to our pension and OPEB plans (in millions):
	Pension Benefits								OPEB
	2013				2012				2013				2012
Non-current benefit asset	$	—			$	—			$	224			$	135
Current benefit liability	—				(28		)		(32		)		(33		)
Non-current benefit liability	(230		)		(524		)		(443		)		(481		)
Funded status - net liability at December 31,	$	(230	)		$	(552	)		$	(251	)		$	(379	)
Components of Accumulated Other Comprehensive Income (Loss). The following table details the amounts of pre-tax accumulated other comprehensive income (loss) at December 31, 2013 and 2012 related to our pension and OPEB plans which are included on our accompanying consolidated balance sheets, including the portion attributable to our noncontrolling interests, (in millions):
	Pension Benefits								OPEB
	2013				2012				2013				2012
Unrecognized net actuarial loss	$	(10	)		$	(218	)		$	(17	)		$	(70	)
Unrecognized prior service (cost) credit	(5		)		20				21				4
Accumulated other comprehensive (loss) income	$	(15	)		$	(198	)		$	4			$	(66	)
We anticipate that less than $1 million of pre-tax accumulated other comprehensive loss will be recognized as part of our net periodic benefit cost in 2014, including approximately $1 million of unrecognized net actuarial loss and approximately $1 million of unrecognized prior service credit.
Our accumulated benefit obligation for our defined benefit pension plans was $2,516 million and $2,773 million at December 31, 2013 and 2012, respectively.
Our accumulated postretirement benefit obligation for our OPEB plans, whose accumulated postretirement benefit obligations exceeded the fair value of plan assets, was $534 million and $569 million at December 31, 2013 and 2012, respectively. The fair value of these plans’ assets was approximately $60 million and $55 million at December 31, 2013 and 2012, respectively.
Plan Assets. The investment policies and strategies for the assets of each of the pension and OPEB plans are established by the Fiduciary Committee (the “Committee), which is responsible for investment decisions and management oversight of each plan. The stated philosophy of the Committee is to manage these assets in a manner consistent with the purpose for which the plans were established and the time frame over which the plans’ obligations need to be met. The objectives of the investment management program are to (1) meet or exceed plan actuarial earnings assumptions over the long term and (2) provide a reasonable return on assets within established risk tolerance guidelines and liquidity needs of the plans with the goal of paying benefit and expense obligations when due. In seeking to meet these objectives, the Committee recognizes that prudent investing requires taking reasonable risks in order to raise the likelihood of achieving the targeted investment returns. In order to reduce portfolio risk and volatility, the Committee has adopted a strategy of using multiple asset classes.
As of December 31, 2013, the target asset allocations in effect for the pension plan were 50%, equity, 45% fixed income and 5% company securities.  As of December 31, 2013, the target asset allocations in effect for the retiree medical and retiree life insurance plans were 70% equity and 30% fixed income.
Below are the details of our pension and OPEB plan assets classified by level and a description of the valuation methodologies used for assets measured at fair value.
•	Level 1 assets’ fair values are based on quoted market prices for the instruments in actively traded markets. Included in this level are dollar-denominated money market funds, common and preferred stock, exchange traded mutual funds and limited partnerships. These investments are valued at the closing price reported on the active market on which the individual securities are traded.
•	Level 2 assets’ fair values are primarily based on pricing data representative of quoted prices for similar assets in active markets (or identical assets in less active markets). Included in this level are money market funds, common/collective trust funds, mutual funds, limited partnerships, trusts, fixed income and other securities. Money market funds are valued at amortized cost, which approximates fair value. The common/collective trust funds’, mutual funds’, limited partnerships’ and trusts’ fair values are based on the net asset value as reported by the issuer, which is determined based on the fair value of the underlying securities as of the valuation date. The fixed income securities’ fair values are primarily based on an evaluated price which is based on a compilation of primarily observable market information or a broker quote in a non-active market.
•	Level 3 assets’ fair values are calculated using valuation techniques that require inputs that are both significant to the fair value measurement and are unobservable, or are similar to Level 2 assets and are also subject to certain restrictions associated with the timing of redemption which extend beyond 90 days as of December 31. Included in this level are insurance contracts, mutual funds with significant redemption restrictions, limited partnerships and private equity. Insurance contracts are valued at contract value, which approximates fair value. The mutual funds’ fair values are primarily based on the net asset value as reported by the issuer, which is determined based on the fair value of the underlying securities as of the valuation date. The limited partnerships’ and private equity investments’ fair values are primarily based on the securities’ value as reported by the issuer, which may be determined utilizing discounted present value.
Listed below are the fair values of our pension and OPEB plans’ assets that are recorded at fair value classified in each level at December 31, 2013 and 2012 (in millions):
	Pension Assets
	2013																2012
	Level 1				Level 2				Level 3				Total				Level 1				Level 2				Level 3		Total
Money market funds	$	—			$	—			$	—			$	—			$	1			$	6			$	—	$	7
Common/collective trusts(a)	—				940				—				940				—				765				—		765
Insurance contracts	—				—				15				15				—				—				14		14
Mutual funds(b)	92				134				—				226				—				266				40		306
Common and preferred stocks(c)	498				—				—				498				812				—				—		812
Corporate bonds	—				220				—				220				—				111				—		111
U.S. government securities	—				120				—				120				—				99				—		99
Asset backed securities	—				29				—				29				—				25				—		25
Limited partnerships	—				—				28				28				—				—				24		24
Equity trusts	—				235				—				235				—				53				—		53
Private equity	—				—				9				9				—				—				9		9
Other	—				13				—				13				—				15				—		15
Total asset fair value(c)	$	590			$	1,691			$	52			$	2,333			$	813			$	1,340			$	87	$	2,240
_______
(a)	For 2013, this category includes common/collective trust funds which are invested in approximately 36% fixed income, 62% equity and 2% short term securities. For 2012, this category includes common/collective trusts funds which are invested in approximately 59% fixed income, 36% equity and 5% short term securities.
(b)	For 2013, this category includes mutual funds which are invested in approximately 60% fixed income and 40% equity. For 2012, this category includes mutual funds which are invested in approximately 28% fixed income, 72% equity and other investments.
(c)	Plan assets include $229 million and $133 million of KMI Class P common stock for 2013 and 2012, respectively.
	OPEB Assets
	2013																2012
	Level 1				Level 2				Level 3				Total				Level 1				Level 2				Level 3		Total
Money market funds	$	—			$	—			$	—			$	—			$	11			$	1			$	—	$	12
Domestic equity securities	13				—				—				13				—				—				—		—
Common/collective trusts(a)	—				85				—				85				—				277				—		277
Limited partnerships	92				72				—				164				—				—				—		—
Insurance contracts	—				—				46				46				—				—				44		44
Mutual funds	72				—				—				72				—				8				—		8
Total asset fair value	$	177			$	157			$	46			$	380			$	11			$	286			$	44	$	341
_______
(a)	For 2013, this category includes common/collective trust funds which are invested in approximately 70% equity and 30% fixed income securities. For 2012, this category includes common/collective trust funds which are invested in approximately 65% equity and 35% fixed income securities.
The following tables present the changes in our pension and OPEB plans’ assets included in Level 3 for the years ended December 31, 2013 and 2012, including the EP Pension and OPEB plans since the May 25, 2012 acquisition date (in millions):
	Pension Assets
	Balance at Beginning of Period				Transfers In (Out)				Realized and Unrealized Gains (Losses), net				Purchases (Sales), net				Balance at End of Period
2013
Insurance contracts	$	14			$	—			$	—			$	1			$	15
Mutual funds	40				—				—				(40		)		—
Limited partnerships	24				—				3				1				28
Private equity	9				—				1				(1		)		9
Total	$	87			$	—			$	4			$	(39	)		$	52
2012
Insurance contracts	$	14			$	—			$	—			$	—			$	14
Mutual funds	—				38				2				—				40
Limited partnerships	4				16				—				4				24
Private equity	9				—				—				—				9
Total	$	27			$	54			$	2			$	4			$	87
	OPEB Assets
	Balance at Beginning of Period				Transfers In (Out)				Realized and Unrealized Gains (Losses), net				Purchases (Sales), net				Balance at End of Period
2013
Insurance contracts	$	44			$	—			$	—			$	2			$	46
Total	$	44			$	—			$	—			$	2			$	46
2012
Insurance contracts	$	42			$	—			$	7			$	(5	)		$	44
Total	$	42			$	—			$	7			$	(5	)		$	44
Changes in the underlying value of Level 3 assets due to the effect of changes of fair value were immaterial for the years ended December 31, 2013 and 2012.
Expected Payment of Future Benefits and Employer Contributions. As of December 31, 2013, we expect to make the following benefit payments under our plans (in millions):
Fiscal year		Pension Benefits				OPEB(a)
2014		$	191			$	52
2015		192				51
2016		195				50
2017		195				49
2018		194				48
2019-2023		964				223
_______
(a)	Includes a reduction of approximately $3 million in each of the years 2014 - 2018 and approximately $13 million in aggregate for 2019 - 2023 for an expected subsidy related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003.
In January 2014, we contributed $50 million to our pension plan. We expect to contribute approximately $32 million to our OPEB plan in 2014.
Actuarial Assumptions and Sensitivity Analysis. Benefit obligations and net benefit cost are based on actuarial estimates and assumptions. The following table details the weighted-average actuarial assumptions used in determining our benefit obligation and net benefit costs of our pension and OPEB plans for 2013, 2012 and 2011:
		Pension Benefits									OPEB
		2013			2012			2011			2013			2012			2011
Assumptions related to benefit obligations:
Discount rate		4.45	%		3.4	%		4.5	%		4.34	%		3.34	%		4.25	%
Rate of compensation increase		3.5	%		3	%		3.5	%		n/a			n/a			n/a
Assumptions related to benefit costs:
Discount rate(a)		3.4	%		4.22	%		5.5	%		3.62	%		4.11	%		5	%
Expected return on plan assets(b)(c)		8	%		8.44	%		8.9	%		7.35	%		8.21	%		8.9	%
Rate of compensation increase		3	%		3.5	%		3.5	%		n/a			n/a			n/a
_______
(a)	The discount rate related to pension benefit cost was 4.50% for the period from January 1, 2012 to May 24, 2012, and 4.03% for the period from May 25, 2012 to December 31, 2012 (the period subsequent to the EP acquisition). The discount rate related to other postretirement benefit cost was 3.34% for the period from January 1, 2013 to July 31, 2013 (the period prior to an OPEB plan amendment that resulted in a remeasurement) and 4.00% for the period from August 1, 2013 to December 31, 2013, and 4.25% for the period from January 1, 2012 to May 24, 2012 and 4.01% for the period from May 25, 2012 to December 31, 2012.
(b)	The expected return on plan assets related to pension cost was 8.90% for the period from January 1, 2012 to May 24, 2012, and 8.11% for the period from May 25, 2012 to December 31, 2012 (the period subsequent to the EP acquisition). The expected return on plan assets related to other postretirement benefit cost was 8.90% for the period from January 1, 2012 to May 24, 2012, and 7.72% for the period from May 25, 2012 to December 31, 2012.
(c)	The expected return on plan assets listed in the table above is a pre-tax rate of return based on our targeted portfolio of investments. For the assumed EP OPEB plans, we utilize an after-tax expected return on plan assets to determine our benefit costs, which is based on unrelated business income taxes at a rate of 24% and 22% for 2013 and 2012, respectively.
The expected long-term rates of return on plan assets were determined by combining a review of the historical returns realized within the portfolio, the investment strategy included in the plans’ investment policy, and capital market projections for the asset classes in which the portfolio is invested and the target weightings of each asset class.
Actuarial estimates for our OPEB plans assumed a weighted-average annual rate of increase in the per capita cost of covered health care benefits of 6.57%, gradually decreasing to 5.00% by the year 2019. Assumed health care cost trends have a significant effect on the amounts reported for OPEB plans. A one-percentage point change in assumed health care cost trends would have the following effects as of December 31, 2013 and 2012 (in millions):
		2013				2012
One-percentage point increase:
Aggregate of service cost and interest cost		$	2			$	1
Accumulated postretirement benefit obligation		45				52
One-percentage point decrease:
Aggregate of service cost and interest cost		$	(1	)		$	(1	)
Accumulated postretirement benefit obligation		(39		)		(45		)
Components of Net Benefit Cost and Other Amounts Recognized in Other Comprehensive Income. For each of the years ended December 31, the components of net benefit cost and other amounts (including amounts associated with the EP Pension and OPEB plans since the May 25, 2012 acquisition date) recognized in pre-tax other comprehensive income related to our pension and OPEB plans are as follows (in millions):
		Pension Benefits												OPEB
		2013				2012				2011				2013				2012				2011
Components of net benefit cost:
Service cost		$	25			$	18			$	13			$	—			$	—			$	—
Interest cost		92				67				17				23				18				4
Expected return on assets		(175		)		(110		)		(22		)		(22		)		(15		)		(5		)
Amortization of prior service (credit) cost		—				(1		)		(1		)		(1		)		(1		)		—
Amortization of net actuarial loss		—				10				7				3				4				4
Curtailment and settlement gain		(3		)		(2		)		—				—				(1		)		—
Net benefit (credit) cost		(61		)		(18		)		14				3				5				3
Other changes in plan assets and benefit obligations recognized in other comprehensive (income) loss:
Net (gain) loss arising during period		(211		)		85				46				(50		)		25				13
Prior service cost (credit) arising during period		25				(17		)		(6		)		(18		)		(4		)		—
Amortization or settlement recognition of net actuarial gain (loss)		3				(10		)		(7		)		(3		)		(5		)		(4		)
Amortization of prior service credit		—				1				1				1				1				—
Total recognized in total other comprehensive income loss		(183		)		59				34				(70		)		17				9
Total recognized in net benefit (credit) cost and other comprehensive (income) loss		$	(244	)		$	41			$	48			$	(67	)		$	22			$	12
Other Plans
Plans Associated with Foreign Operations
Two of KMP’s subsidiaries, Kinder Morgan Canada Inc. and Trans Mountain Pipeline Inc. (as general partner of Trans Mountain Pipeline L.P.) are sponsors of pension plans for eligible Trans Mountain pipeline system employees.  The plans include registered defined benefit pension plans, supplemental unfunded arrangements (which provide pension benefits in excess of statutory limits) and defined contributory plans.  These subsidiaries of KMP also provide postretirement benefits other than pensions for retired employees. KMP’s combined net periodic benefit costs for these Trans Mountain pension and other postretirement benefit plans for each of the years ended December 31, 2013, 2012 and 2011 were $11 million, $11 million and $7 million, respectively, recognized ratably over each year.  As of December 31, 2013, KMP estimates its overall net periodic pension and other postretirement benefit costs for these plans for the year 2014 will be approximately $11 million, although this estimate could change if there is a significant event, such as a plan amendment or a plan curtailment, which would require a remeasurement of liabilities.  Furthermore, KMP expects to contribute approximately $10 million to these benefit plans in 2014.
Multiemployer Plans
As a result of acquiring several terminal operations, primarily KMP’s acquisition of Kinder Morgan Bulk Terminals, Inc. effective July 1, 1998, KMP participates in several multi-employer pension plans for the benefit of employees who are union members.  KMP does not administer these plans and contributes to them in accordance with the provisions of negotiated labor contracts.  Other benefits include a self-insured health and welfare insurance plan and an employee health plan where employees may contribute for their dependents’ health care costs.  Amounts charged to expense for these plans were approximately $11 million, $11 million and $12 million for the years ended December 31, 2013, 2012 and 2011, respectively. KMP considers its overall multi-employer pension plan liability exposure to be minimal in relation to the value of its total consolidated assets and net income.

Stockholders_Equity_Notes

Stockholders' Equity (Notes)	12 Months Ended
	Dec. 31, 2013
Stockholders' Equity Note [Abstract]	'
Shareholders' Equity	'
	Stockholders’ Equity
	Kinder Morgan, Inc. – Equity Interests
	Common Equity
	On May 23, 2012, we announced that our board of directors had approved a warrant repurchase program, authorizing us to repurchase in the aggregate up to $250 million of warrants, which repurchase was completed as of May 2013. In the second quarter of 2013, we repurchased an additional $38 million in warrants, which was approved by our board of directors separate and apart from the publicly announced repurchase program. On July 17, 2013, we announced that our board of directors had authorized an additional $350 million share and warrant repurchase program, which repurchase was completed as of December 2013. On October 16, 2013, we announced that our board of directors had approved an additional share and warrant repurchase program authorizing us to repurchase in the aggregate up to $250 million of additional shares or warrants. During December 2013, we repurchased $172 million of our Class P shares. During the years ended December 31, 2013 and 2012, we paid a total of $465 million and $157 million, respectively, for the repurchase of warrants. As of December 31, 2013, $156 million of the October 2013 $250 million repurchase program had been utilized.
	The following table sets forth the changes in our outstanding shares during the years ended December 31, 2013 and 2012 and during 2011 since becoming public (see “—Initial Public Offering” following):
		Class P			Class A			Class B			Class C
	Balance at February 16, 2011	109,786,590			597,213,410			100,000,000			2,462,927
	Shares converted	61,241,023			(61,241,023	)		(5,867,404	)		(144,669	)
	Shares canceled	(108,043	)		—			—			—
	Restricted shares vested	1,570			—			—			—
	Balance at December 31, 2011	170,921,140			535,972,387			94,132,596			2,318,258
	Shares issued for EP acquisition (see Note 3)	330,154,610			—			—			—
	Shares issued with conversions of EP Trust I Preferred securities	562,521			—			—			—
	Shares converted	535,972,387			(535,972,387	)		(94,132,596	)		(2,318,258	)
	Shares canceled	(2,049,615	)		—			—			—
	Restricted shares vested	107,553			—			—			—
	Balance at December 31, 2012	1,035,668,596			—			—			—
	Shares issued for EP acquisition(a)	53
	Shares repurchased and canceled	(5,175,055	)
	Shares issued with conversions of EP Trust I Preferred securities	77,442
	Shares issued for exercised warrants	16,886
	Restricted shares vested	89,154
	Balance at December 31, 2013	1,030,677,076
	_______
	(a) Represents Class P shares issued upon the settlement of an EP dissenter. The settlement of the dissenter’s 128 EP shares was determined based on the same conversion of EP shares into cash, KMI Class P shares and KMI warrants that was received by other EP shareholders at the time of the acquisition.
	Share Repurchases Subsequent to December 31, 2013
	Subsequent to December 31, 2013, we paid $94 million to repurchase approximately 3 million of our Class P shares effectively completing the October 16, 2013 share and warrant repurchase program.
	Initial Public Offering
	On February 10, 2011, we converted from a Delaware LLC named Kinder Morgan Holdco LLC to a Delaware corporation named Kinder Morgan, Inc. and our outstanding units were converted into classes of our capital stock.  These transactions are referred to herein as the “Conversion Transaction.”  On February 16, 2011, we completed the initial public offering of our Class P common stock, which is sometimes referred to herein as our “common stock.” All of the common stock that was sold in the offering was sold by our existing investors consisting of funds advised by or affiliated with Goldman Sachs & Co., Highstar Capital LP, The Carlyle Group and Riverstone Holdings LLC, referred to herein as the “Sponsor Investors.” No members of management sold shares in the offering, and we did not receive any proceeds from the offering.
	Upon the completion of our initial public offering of Class P common stock we were owned by the public, and by individuals and entities that were the owners of Kinder Morgan Holdco LLC, which are referred to collectively in this report as the “Investors.”  The Investors were Richard D. Kinder, our Chairman and Chief Executive Officer; the Sponsor Investors; Fayez Sarofim, one of our directors, and investment entities affiliated with him, and an investment entity affiliated with Michael C. Morgan, another of our directors, and William V. Morgan, one of our founders, whom we refer to collectively as the “Original Stockholders”; and a number of other members of our management, who are referred to collectively as “Other Management.”
	The Investors owned all of our outstanding Class A shares, Class B shares and Class C shares, which are sometimes referred to in this report as the “investor retained stock.”  Our Class A shares represented the total capital contributed by the Investors (and a notional amount of capital allocated to the contribution of the holders of the Class C shares) at the time of a 2007 going private transaction. The Class B shares and Class C shares represented incentive compensation that were held by members of our management, including Mr. Kinder only in the case of the Class B shares.
	During the year ended December 31, 2012, certain of the Sponsor Investors (the Selling Stockholders) completed underwritten public offerings (the Offerings) of an aggregate of 198,996,921 shares of our Class P common stock (including 8,700,000 shares that were the subject of an underwriters’ option to purchase additional shares). Neither we nor our management sold any shares of common stock in the Offerings, and we did not receive any of the proceeds from the Offerings of shares by the Selling Stockholders. As a result of these offerings, the Sponsor Investors advised by or affiliated with Goldman Sachs & Co., The Carlyle Group, and Riverstone Holdings LLC no longer own any of our shares, and representatives of these Sponsor Investors are no longer on our board.
	On December 26, 2012, the remaining series of the Class A, Class B and Class C shares held by the Investors automatically converted into shares of Class P common stock upon the election of the holders of at least two-thirds of the shares of each such series of Class A common stock and the holders of at least two-thirds of the shares of each such series of Class B common stock. Subsequent to these conversions, all our Class A, Class B and Class C shares were fully converted and as a result, only our Class P common stock was outstanding as of December 31, 2012. Additionally, as Class A, Class B and Class C shares converted, certain holders of Class P shares were paid out in cash and their Class P shares were immediately canceled. During the years ended December 31, 2012 and 2011, approximately 2 million and less than 1 million, respectively, Class P shares were canceled resulting in payments totaling approximately $71 million and $2 million, respectively, to the holders of those shares.
	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:
		Year Ended December 31,
		2013				2012				2011(a)
	Per common share cash dividend declared for the period	$	1.6			$	1.4			$	1.05
	Per common share cash dividend paid in the period	$	1.56			$	1.34			$	0.74
	_______
	(a) Represents dividends subsequent to the initial public offering.
	On February 11, 2011, our board of directors declared and paid a distribution to our then existing investors of $246 million with respect to the period for which we were not public.  This consisted of $205 million for the fourth quarter of 2010 and $105 million for the first 46 days of 2011, representing the portion of the first quarter of 2011 that we were not public, less a one-time adjustment of $64 million in available earnings and profits reserved for the after tax cost of special cash bonuses (and premium pay) in an aggregate amount of approximately $100 million that was paid in May of 2011 to certain of our non-senior management employees.  No holders of our Class B shares or Class C shares received such bonuses.
	Dividends Subsequent to December 31, 2013
	On January 15, 2014, our board of directors declared a cash dividend of $0.41 per share for the quarterly period ended December 31, 2013. This dividend was paid on February 18, 2014 to shareholders of record as of January 31, 2014. Since this dividend was declared after the end of the quarter, no amount is shown in our accompanying December 31, 2013 consolidated balance sheet as a dividend payable.
	Warrants
	Each of our warrants entitles the holder to purchase one share of our common stock for an exercise price of $40 per share, payable in cash or by cashless exercise, at any time until May 25, 2017. The table below sets forth the changes in our outstanding warrants during 2013 and 2012.
		Warrants
		2013			2012
	Beginning balance	439,809,442			—
	Warrants issued in EP acquisition(a)	81			504,598,883
	Warrants issued with conversions of EP Trust I Preferred securities(b)	118,377			859,796
	Warrants exercised	(21,208	)		—
	Warrants repurchased and canceled	(91,973,585	)		(65,649,237	)
	Ending balance	347,933,107			439,809,442
	_______
	(a)	See Note 3. 2013 amount represents warrants issued upon the settlement of an EP dissenter. The settlement of the dissenter’s 128 EP shares was determined based on the same conversion of EP shares into cash, KMI Class P shares and KMI warrants that was received by other EP shareholders at the time of the acquisition.
	(b)	See Note 8.
	Noncontrolling Interests
	The caption “Noncontrolling interests” in our accompanying consolidated balance sheets consists of interests that we do not own in the following subsidiaries (in millions):
		December 31,
		2013				2012
	KMP	$	7,642			$	3,270
	EPB	4,122				4,111
KMR	3,142				2,716
Other	286				137
	$	15,192			$	10,234
At December 31, 2013, we owned, directly, and indirectly in the form of i-units corresponding to the number of shares of KMR we owned, approximately 43 million limited partner units of KMP.  These units, which consist of 22 million common units, 5 million Class B units and 16 million i-units, represent approximately 9.8% of the total outstanding limited partner interests of KMP.  In addition, we indirectly own all the common equity of the general partner of KMP, which holds an effective 2% interest in KMP and its operating partnerships.  Together, at December 31, 2013, our limited partner and general partner interests represented approximately 11.6% of KMP’s total equity interests and represented an approximate 50% economic interest in KMP.  This difference results from the existence of incentive distribution rights (IDRs) held by KMGP, the general partner of KMP.
As of December 31, 2013, we owned approximately 90 million limited partner units of EPB, representing approximately 41% of the total equity interests of EPB. In addition, we are the sole owner of the general partner of EPB, which holds an effective 2% interest in EPB, including all of EPB’s IDRs.
At December 31, 2013, we owned approximately 16 million KMR shares representing approximately 13.0% of KMR’s outstanding shares.
Contributions
Contributions from our noncontrolling interests consist primarily of equity issuances by KMP, EPB and KMR. As of December 31, 2013, each of these subsidiaries has an equity distribution agreement in place which allows the subsidiary to sell its equity interests from time to time through a designated sales agent. The terms of each agreement are substantially similar. Sales of the subsidiary’s equity interests will be made by means of ordinary brokers’ transactions on the NYSE at market prices, in block transactions or as otherwise agreed between the subsidiary equity issuer and its sales agent. The subsidiary equity issuer may also sell its equity interests to its sales agent as principal for the sales agent’s own account at a price agreed upon at the time of the sale.  Any sale of the subsidiary’s equity interests to the sales agent as principal would be pursuant to the terms of a separate agreement between the subsidiary equity issuer and its sales agent. The equity distribution agreement provides the subsidiary with the right, but not the obligation to offer and sell its equity units or shares, at prices to be determined by market conditions. The subsidiary retains at all times complete control over the amount and the timing of sales under its respective equity distribution agreement, and it will designate the maximum number of equity units or shares to be sold through its sales agent, on a daily basis or otherwise as the subsidiary equity issuer and its sales agent agree.
The table below shows significant issuances to the public of common units or shares, the net proceeds from the issuances and the use of the proceeds during the years ended December 31, 2013 and 2012 by KMP, EPB and KMR (dollars in millions and shares in thousands).
	Issuances		Common units/shares			Net proceeds				Use of proceeds
			(in thousands)			(in millions)
KMP
Issued under Equity Distribution Agreement(a)
	2013		10,814			$	900			Reduced borrowings under KMP’s commercial paper program
	2012		6,933			$	560			Reduced borrowings under KMP’s commercial paper program
Other issuances
	Feb-13		4,600			$	385			Issued to pay a portion of the purchase price for the March 2013 drop-down transaction
	May-13		43,371			$	—		(b)	Issued to Copano unitholders as KMP’s purchase price for Copano
	Jun-12		3,792			$	—		(c)	Issued as KMP's purchase price for the 50% equity ownership interest in EP midstream assets it acquired from KKR
	December 2012(d)		4,485			$	349			Reduced borrowings under KMP's commercial paper program
EPB
Issued under Equity Distribution Agreement(e)
	2013		2,038			$	85		(f)	General partnership purposes
Other issuances
	September 2012(d)		8,165			$	272		(g)	Repayment of CPG debt, certain EPB short-term debt and general partnership purposes
KMR
Issued under Equity Distribution Agreement(h)
	2013		2,640			$	210			Purchased additional KMP i-units; KMP then used proceeds to reduce borrowings under its commercial paper program
	Sep-12		10,120			$	727			Purchased additional KMP i-units; KMP then used proceeds for a portion of the purchase price of the August 2012 drop-down transaction
_______
(a)	On June 3, 2013, KMP entered into a fourth amended and restated equity distribution agreement with UBS Securities LLC (UBS) which increased the aggregate offering price of KMP’s common units to up to $2.175 billion (up from $1.9 billion), and on August 7, 2013, KMP entered into a second and separate equity distribution agreement with UBS. The terms of this new equity distribution agreement are substantially similar to those in KMP’s previous agreement, and it allows KMP to offer and sell from time to time additional KMP common units having an aggregate offering price of up to $1.9 billion through UBS, as sales agent. On February 27, 2012, KMP entered into a third amended and restated equity distribution agreement with UBS which increased the aggregate offering price of its common units to up to $1.9 billion (up from $1.2 billion).
(b)	KMP valued these units at $3,733 million based on the $86.08 closing market price of a KMP common unit on the NYSE on May 1, 2013.
(c)	See Note 3.
(d)	Includes the underwriters’ exercise of the overallotment option.
(e)	On March 7, 2013, EPB entered into an equity distribution agreement with Global Markets, Inc. (Citigroup). Pursuant to the provisions of EPB’s equity distribution agreement, EPB may sell from time to time through Citigroup, as its sales agent, EPB’s common units representing limited partner interests having an aggregate offering price of up to $500 million.
(f)	Represents proceeds received from noncontrolling interests and excludes our $2 million contribution as the owner of EPB’s general partner.
(g)	Represents proceeds received from noncontrolling interests and excludes our $7 million contribution as the owner of EPB’s general partner.
(h)	On May 4, 2012, KMR entered into an equity distribution agreement with Credit Suisse Securities (USA) LLC (Credit Suisse). Pursuant to the provisions of KMR’s equity distribution agreement, it may sell from time to time through Credit Suisse, as its sales agent, KMR shares having an aggregate offering price of up to $500 million.
The above equity issuances by KMP, EPB and KMR during the years ended December 31, 2013 and 2012 had the associated effects of increasing our (i) noncontrolling interests by $5,059 million and $2,112 million, respectively; (ii) accumulated deferred income taxes by $93 million and $38 million, respectively; and (iii) additional paid-in capital by $161 million and $64 million, respectively.
Contributions Subsequent to December 31, 2013
Shares and units issued subsequent to December 31, 2013 include (i) 76,100 of KMR’s shares; and (ii) 198,110 of KMP’s common units both of which were issued in early January for the settlement of sales made on or before December 31, 2013 pursuant to KMR and KMP’s respective equity distribution agreements. KMR and KMP received net proceeds of $16 million and $6 million, respectively, for the issuance of these shares and common units and the combined proceeds were used to reduce borrowings under KMP’s commercial paper program.
On February 19, 2014, KMP priced in a public offering, 7,935,000 of its common units (including the exercise of the underwriters’ overallotment option) at a price of $78.32 per unit, less commissions and underwriting expenses.
Distributions
The following table provides information about distributions from our noncontrolling interests (in millions except per unit and i-unit distribution amounts):
	Year Ended December 31,
	2013				2012				2011
KMP
Per unit cash distribution declared for the period	$	5.33			$	4.98			$	4.61
Per unit cash distribution paid in the period	$	5.26			$	4.85			$	4.58
Cash distributions paid in the period to the public	$	1,372			$	1,081			$	955
EPB(a)
Per unit cash distribution declared for the period	$	2.55			$	1.74			n/a
Per unit cash distribution paid in the period	$	2.51			$	1.13			n/a
Cash distributions paid in the period to the public	$	318			$	137			n/a
KMR(b)
Share distributions paid in the period to the public	6,588,477				5,586,579				5,659,507
_______
(a)	Represents distribution information since the May 2012 EP acquisition.
(b)	KMR’s distributions are paid in the form of additional shares or fractions thereof calculated by dividing the KMP cash distribution per common unit by the average of the market closing prices of a KMR share determined for a ten-trading day period ending on the trading day immediately prior to the ex-dividend date for the shares.  Represents share distributions made in the period to noncontrolling interests and excludes 976,723, 902,367 and 941,895 of shares distributed in 2013, 2012 and 2011, respectively, on KMR shares we directly and indirectly own. On February 14, 2014, KMR paid a share distribution of 0.017841 shares per outstanding share (2,237,258 total shares) to shareholders of record as of January 31, 2014, based on the $1.36 per common unit distribution declared by KMP, of which 1,952,970 shares were distributed to the public.
KMP Distributions
KMP’s partnership agreement requires that it distribute 100% of “Available Cash,” as defined in its partnership agreement, to its partners within 45 days following the end of each calendar quarter.  Available Cash consists generally of all of KMP’s cash receipts, including cash received by its operating partnerships and net reductions in reserves, less cash disbursements and net additions to reserves and amounts payable to its noncontrolling interests.
KMR, as the delegate of KMGP, of which we indirectly own all of the outstanding common equity, and the general partner of KMP, is granted discretion, subject to the approval of KMGP in certain cases, to establish, maintain and adjust reserves for the proper conduct of KMP’s business, which might include reserves for matters such as future operating expenses, debt service, sustaining capital expenditures and rate refunds, and for distributions for the next four quarters.  These reserves are not restricted by magnitude, but only by type of future cash requirements with which they can be associated.  When KMR determines KMP’s quarterly distributions, it considers current and expected reserve needs along with current and expected cash flows to identify the appropriate sustainable distribution level.
Pursuant to KMP’s partnership agreement, distributions to its unitholders are characterized either as distributions of cash from operations or as distributions of cash from interim capital transactions.  This distinction affects the distributions to owners of common units, Class B units and i-units relative to the distributions retained by KMGP as KMP’s general partner.
Cash from Operations.  Cash from operations generally refers to KMP’s cash balance on the date it commenced operations, plus all cash generated by the operation of its business, after deducting related cash expenditures (including capital expenditures other than expansion capital expenditures), net additions to or reductions in reserves, debt service and various other items.
Cash from Interim Capital Transactions.  Cash from interim capital transactions will generally result only from distributions that are funded from borrowings, sales of debt and equity securities and sales or other dispositions of assets for cash, other than inventory, accounts receivable and other current assets and assets disposed of in the ordinary course of business.
Rule for Characterizing Distributions.  Generally, all available cash distributed by KMP from any source will be treated as distributions of cash from operations until the sum of all available cash distributed equals the cumulative amount of cash from operations actually generated from the date KMP commenced operations through the end of the calendar quarter prior to that distribution.  Any distribution of available cash which, when added to the sum of all prior distributions, is in excess of the cumulative amount of cash from operations, will be considered a distribution of cash from interim capital transactions until the initial common unit price is fully recovered as described below under “—Allocation of Distributions from Interim Capital Transactions.”  For purposes of calculating the sum of all distributions of available cash, the total equivalent cash amount of all distributions of i-units to KMR, as the holder of all i-units, will be treated as distributions of available cash, even though the distributions to KMR are made in additional i-units rather than cash and KMP retains this cash and uses it in its business.  To date, all of KMP’s available cash distributions, other than a $177 million distribution of cash from interim capital transactions in 2010, have been treated as distributions of cash from operations.
Allocation of Distributions from Operations.  Cash from operations for each quarter will be distributed effectively as follows:
			Marginal percentage interest in distribution
	Total quarterly distribution per unit target amount		Unitholders		General partner
First target distribution	$0.15		98%		2%
Second target distribution	above $0.15125 up to $0.17875		85%		15%
Third target distribution	above $0.17875 up to $0.23375		75%		25%
Thereafter	above $0.23375		50%		50%
Allocation of Distributions from Interim Capital Transactions.  Any distribution by KMP of available cash that would constitute cash from interim capital transactions would be distributed effectively as follows:
•	98% to all owners of common units and Class B units pro rata in cash and to the holder of i-units in equivalent i-units; and
•	2% to KMGP, as KMP’s general partner, until KMP has distributed cash from this source in respect of a common unit outstanding since KMP’s original public offering in an aggregate amount per unit equal to the initial common unit price of $5.75, as adjusted for splits.
As cash from interim capital transactions is distributed, it would be treated as if it were a repayment of the initial public offering price of the common units.  To reflect that repayment, the first three distribution target levels of cash from operations (described above) would be adjusted downward proportionately by multiplying each distribution target level amount by a fraction, the numerator of which is the unrecovered initial common unit price immediately after giving effect to that distribution and the denominator of which is the unrecovered initial common unit price immediately prior to giving effect to that distribution.  When the initial common unit price is fully recovered, then each of the first three distribution target levels will have been reduced to zero and thereafter, all distributions of available cash from all sources will be treated as if they were cash from operations and available cash will be distributed 50% to all classes of units pro rata (with the distribution to i-units being made instead in the form of i-units), and 50% to KMGP as KMP’s general partner.  With respect to the portion of our distribution of available cash for 2010 that was from interim capital transactions, KMGP, as KMP’s general partner, waived this resetting of the distribution target levels.
Distributions paid by KMP to KMGP during 2013 were reduced by a waived incentive amount of $50 million related to common units issued to finance KMP’s May 2013 Copano acquisition. Beginning with KMP’s distribution payments for the quarterly period ended June 30, 2013, and ending with its distribution payments for the quarterly period ended March 31, 2038, KMGP, as KMP’s general partner, agreed not to take certain incentive distributions related to KMP’s acquisition of Copano. For more information about KMP’s May 2013 Copano acquisition, see Note 3. In addition, distributions paid by KMP to KMGP during 2013, 2012 and 2011 were reduced by waived incentive amounts equal to $11 million, $27 million and $28 million, respectively, related to common units issued to finance a portion of KMP’s May 2010 and July 2011 KinderHawk acquisitions.  Beginning with KMP’s distribution payments for the quarterly period ended June 30, 2010, and ending with its distribution payments for the quarterly period ended March 31, 2013, KMGP, as KMP’s general partner, has agreed not to take certain incentive distributions related to KMP’s acquisition of KinderHawk.  For more information about KMP’s July 2011 KinderHawk acquisition, see Note 3.
EPB Distributions
Incentive Distribution Rights. El Paso Pipeline GP Company, L.L.C., as the general partner of EPB and the holder of EPB’s IDRs, has the right under EPB’s partnership agreement to elect to relinquish the right to receive incentive distribution payments based on the initial cash target distribution levels and (upon satisfaction of certain conditions) to reset, at higher levels, the minimum quarterly distribution amount and cash target distribution levels upon which the incentive distribution payments to El Paso Pipeline GP Company, L.L.C., as EPB’s general partner, would be set. In connection with this election, El Paso Pipeline GP Company, L.L.C. , as EPB’s general partner, would be entitled to receive a number of newly issued Class B common units and general partner units based on a predetermined formula. Although the conditions have been met to entitle El Paso Pipeline GP Company, L.L.C. to elect to reset the minimum quarterly distribution amount and the target distribution levels, no such election has been made.
El Paso Pipeline GP Company, L.L.C. currently holds all of EPB’s IDRs, but may transfer these rights separately from its general partner interest, subject to restrictions in EPB’s partnership agreement.
Income Allocation and Declared Distributions. For the purposes of maintaining partner capital accounts, EPB’s partnership agreement specifies that items of income and loss shall be allocated among the partners in accordance with their percentage interests. Normal allocations according to percentage interests are made, however, only after giving effect to any priority income allocations in an amount equal to the incentive distributions that are allocated 100% to El Paso Pipeline GP Company, L.L.C., as the holder of EPB’s IDRs. Incentive distributions are generally defined as all cash distributions paid to El Paso Pipeline GP Company, L.L.C., as EPB’s general partner, that are in excess of 2% of the aggregate value of cash distributions made to all partners.
EPB’s partnership agreement requires that it distribute all of its available cash from operating surplus each quarter. EPB determines the allocation of incentive distributions to El Paso Pipeline GP Company, L.L.C., as EPB’s general partner, by the amount quarterly distributions to unitholders exceed certain specified target levels, according to the provisions of EPB’s partnership agreement summarized in the table below. The percentage interests set forth below for El Paso Pipeline GP Company, L.L.C., as EPB’s general partner, include its 2% general partner interest and assume El Paso Pipeline GP Company, L.L.C. has contributed any additional capital necessary to maintain its 2% general partner interest and has not transferred its IDRs.
			Marginal percentage interest in distributions
	Total quarterly distribution per unit target amount		Unitholders		General partner
Minimum quarterly distribution	$0.29		98%		2%
First target distribution	above $0.2875 up to $0.33063		98%		2%
Second target distribution	above $0.33063 up to $0.35938		85%		15%
Third target distribution	above $0.35938 up to $0.43125		75%		25%
Thereafter	above $0.43125		50%		50%
Distributions Subsequent to December 31, 2013
On January 15, 2014, KMP declared a cash distribution of $1.36 per unit for the quarterly period ended December 31, 2013. The distribution was paid on February 14, 2014 to KMP’s unitholders of record as of January 31, 2014, of which $445 million was paid to the public holders (represented in noncontrolling interests). Related to this February 14, 2014 distribution, KMGP, waived an incentive distribution amount equal to $25 million to support KMP’s May 2013 Copano acquisition.
On January 15, 2014, EPB declared a cash distribution of $0.65 per unit for the quarterly period ended December 31, 2013. The distribution was paid on February 14, 2014 to EPB’s unitholders of record as of January 31, 2014.

Related_Party_Transactions_Not

Related Party Transactions (Notes)	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	Affiliated Balances
	The following table summarizes our balance sheet affiliate balances (in millions):
		Year Ended December 31,
		2013		2012
	Balance sheet location
	Accounts receivable, net	$	19	$	25
	Assets held for sale(a)	—		114
	Other current assets	3		14
	Deferred charges and other assets	47		48
		$	69	$	201
	Current portion of debt – KMP and EPB(b)	$	6	$	5
	Accounts payable	9		11
	Long-term debt - Outstanding - KMP and EPB(b)	169		173
		$	184	$	189
	_______
	(a)	2012 amount related to KMP’s equity investment in the Express pipeline system (see Note 2).
	(b)	EPB has financing obligations payable to WYCO.
	Notes Receivable
	Plantation
	KMP and ExxonMobil have a term loan agreement covering a note receivable due from Plantation. KMP owns a 51.17% equity interest in Plantation and KMP’s proportionate share of the outstanding principal amount of the note receivable was $48 million as of December 31, 2013 and $49 million as of December 31, 2012. The note bears interest at the rate of 4.25% per annum and provides for semiannual payments of principal and interest on December 31 and June 30 each year, with a final principal payment of $45 million (for KMP’s portion of the note) due on July 20, 2016. We included $1 million of the note receivable balance within “Other current assets” on our accompanying consolidated balance sheets as of both December 31, 2013 and December 31, 2012, and we included the remaining outstanding balance within “Deferred charges and other assets.”
	Express US Holdings LP
	As discussed in Note 3 “Acquisitions and Divestitures—Divestitures—Express Pipeline System,” KMP sold both its 33 1/3% equity ownership interest in the Express pipeline system and a subordinated debenture investment in Express to Spectra Energy Corp. effective March 14, 2013. KMP’s long-term debt investment consisted of a C$114 million debt security issued by Express US Holdings LP (the obligor), the partnership that maintained ownership of the U.S. portion of the Express pipeline system. The debenture was denominated in Canadian dollars, bore interest at a rate of 12.0% per annum, and was due in full on January 9, 2023. As of December 31, 2012 the outstanding note receivable balance, representing the translated amount included in our consolidated financial statements in U.S. dollars, was $114 million. Since KMP had entered into a definitive agreement to sell its debt investment in Express as of this date, we included this note balance within “Assets held for sale” on our accompanying consolidated balance sheet as of that date.
	Gulf LNG Holdings Group, LLC
	In conjunction with the acquisition of EP, KMI acquired a long-term note receivable, bearing interest at 12% per annum, that was due from Gulf LNG Holdings Group, LLC, a 50% equity investee, with a remaining principal amount of $85 million. Subsequent to the EP acquisition and through the end of 2012, we received payments on this note totaling $75 million. We received payments for the remaining note balance of $10 million during the first quarter of 2013. The balance of $10 million at December 31, 2012 was included in our accompanying consolidated balance sheet within “Other current assets.”
	Subsequent Event
	On February 4, 2014, KMP entered into a loan agreement with Midcontinent Express Pipeline LLC, KMP’s 50%-owned equity investee. The loan agreement allows KMP, at their sole option, to make loans from time to time to Midcontinent Express to fund its working capital needs and for other limited liability company purposes. Each individual loan must be in an amount not less than $2 million, and the aggregate loan balance outstanding must not exceed $40 million. All loans mature on February 3, 2015, however, the loan agreement includes renewal provisions for one or more additional one-year terms if approved by both parties. Borrowings under the loan agreement bear interest at a rate per annum equal to LIBOR plus 1.5875%, and all borrowings can be prepaid before maturity without penalty or premium. As of the date of this report, there was no amount outstanding pursuant to this loan agreement.

Commitments_and_Contingent_Lia

Commitments and Contingent Liabilities (Notes)	3 Months Ended
	Mar. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies Disclosure [Text Block]	'
	Commitments and Contingent Liabilities
	Leases
	The table below depicts future gross minimum rental commitments under our operating leases as of December 31, 2013 (in millions):
	Year	Commitment
	2014	$	70
	2015	59
	2016	50
	2017	39
	2018	37
	Thereafter	177
	Total minimum payments	$	432
	The remaining terms on our operating leases, including probable elections to exercise renewal options, range from one to forty. Total lease and rental expenses were $126 million, $94 million and $146 million for each of the years ended December 31, 2013, 2012 and 2011, respectively. The increase in our lease and rental expenses in 2011 compared to 2013 and 2012 was driven by a $70 million increase in expense in 2011 associated with adjustments to KMP’s Pacific operations’ rights-of-way liabilities. The amount of capital leases included within “Property, plant and equipment, net” in our accompanying consolidated balance sheets as of December 31, 2013 and 2012 are not material to our consolidated balance sheets.
	Commitments
	Capital Contributions for Elba Island Liquefaction Project
	In January 2013, SLC, a subsidiary of EPB, and Shell US Gas and Power, LLC (Shell G&P), a subsidiary of Royal Dutch Shell plc (Shell), formed ELC, EPB’s equity method investment, to develop and own a natural gas liquefaction plant at SLNG’s existing Elba Island LNG terminal. In connection with the formation of ELC, SLC and Shell G&P entered into a LLC agreement in which SLC owns 51% of ELC and Shell G&P owns the remaining membership interest. Under the terms of the LLC agreement, SLC and Shell G&P are both obligated to make certain capital contributions in proportion to their membership interests in ELC to fund the construction of the liquefaction facilities. EPB’s investment at the terminal in Phase I, including both the liquefaction facilities and SLNG ancillary facilities, is estimated to be approximately$800 million . Phase I of the project requires no additional Department of Energy (DOE) approval.
	Contingent Debt
	KMP’s contingent debt disclosures pertain to certain types of guarantees or indemnifications KMP has made and cover certain types of guarantees included within debt agreements, even if the likelihood of requiring KMP’s performance under such guarantee is remote. As of December 31, 2013 and 2012, KMP’s contingent debt obligations, as well as KMP’s obligations with respect to related letters of credit, totaled $74 million and $86 million, respectively. This amount is primarily related to the debt obligations of KMP’s 50%-owned investee, Cortez Pipeline Company (KMP is severally liable for its percentage ownership share (50%) of the Cortez Pipeline Company debt).
	Contingent Lease Liabilities
	KMP has agreed to guarantee certain lease payments from 2014 through 2035 made by us to EPC Building, LLC, a wholly owned subsidiary of KMI, related to our principal executive offices located at 1001 Louisiana Street in Houston, Texas. KMP would be required to perform under this guarantee only if we were unable to perform. During the term of this lease, the payments KMP guarantees increase from $27 million in 2014 to $38 million in 2035.
	KMI Guarantee of KMP and EPB Debt
	In conjunction with KMP’s acquisition of certain natural gas pipelines from us, we agreed to indemnify KMP with respect to approximately $5.9 billion of its debt. This indemnification primarily includes $5.2 billion associated with KMP’s August 2012 purchase of TGP and the purchase of EPNG and EP Midstream assets through both the August 2012 and the March 2013 drop-down transactions. In conjunction with our EP acquisition, we have agreed to indemnify EPB with respect to $470 million of its debt. We would be obligated to perform under these indemnities only if KMP’s or EPB’s assets, as applicable, were unable to satisfy its obligations.
	Guarantees and Indemnifications
	We are involved in joint ventures and other ownership arrangements that sometimes require financial and performance guarantees. In a financial guarantee, we are obligated to make payments if the guaranteed party fails to make payments under, or violates the terms of, the financial arrangement. In a performance guarantee, we provide assurance that the guaranteed party will execute on the terms of the contract. If they do not, we are required to perform on their behalf. We also periodically provide indemnification arrangements related to assets or businesses we have sold. These arrangements include, but are not limited to, indemnifications for income taxes, the resolution of existing disputes and environmental matters.
	Our potential exposure under guarantee and indemnification agreements can range from a specified to an unlimited dollar amount, depending on the nature of the claim and the particular transaction. While many of these agreements may specify a maximum potential exposure, or a specified duration to the indemnification obligation, there are circumstances where the amount and duration are unlimited. Those arrangements with a specified dollar amount have a maximum stated value of approximately $814 million, which primarily represents indemnification agreements that we assumed in the EP acquisition associated with EP’s prior discontinued and foreign operations. We are unable to estimate a maximum exposure for our guarantee and indemnification agreements that do not provide for limits on the amount of future payments due to the uncertainty of these exposures.
	For additional information regarding our, KMP’s and EPB’s debt facilities see Note 8.

Risk_Management_Notes

Risk Management (Notes)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Risk Management	'
	Risk Management
	Certain of our business activities expose us to risks associated with unfavorable changes in the market price of natural gas, NGL and crude oil.  We also have exposure to interest rate risk as a result of the issuance of our debt obligations.  Pursuant to our management’s approved risk management policy, we use derivative contracts to hedge or reduce our exposure to certain of these risks.
	As part of the EP acquisition, we acquired power forward and swap contracts. We have entered into offsetting positions that eliminate the price risks associated with our power contracts. As part of the May 1, 2013 Copano acquisition, KMP acquired derivative contracts related to natural gas, NGL and crude oil. None of these derivatives are designated as accounting hedges.
	Energy Commodity Price Risk Management
	As of December 31, 2013, KMP and KMI had entered into the following outstanding commodity forward contracts to hedge their forecasted energy commodity purchases and sales:
		Net open position long/(short)
	Derivatives designated as hedging contracts
	Crude oil fixed price	(22.6	)	MMBbl
	Natural gas fixed price	(19.8	)	Bcf
	Natural gas basis	(18.9	)	Bcf
	Derivatives not designated as hedging contracts
	Crude oil fixed price	(0.9	)	MMBbl
	Natural gas fixed price	(17.3	)	Bcf
	Natural gas basis	(8.2	)	Bcf
	NGL fixed price	(1.1	)	MMBbl
	As of December 31, 2013, the maximum length of time over which we have hedged our exposure to the variability in future cash flows associated with energy commodity price risk is through December 2017.
	Interest Rate Risk Management
	As of December 31, 2013, KMI and KMP had a combined notional principal amount of $725 million and $4,675 million, respectively, of fixed-to-variable interest rate swap agreements, effectively converting the interest expense associated with certain series of senior notes from fixed rates to variable rates based on an interest rate of LIBOR plus a spread.  All of KMI and KMP ‘s swap agreements have termination dates that correspond to the maturity dates of the related series of senior notes and, as of December 31, 2013, the maximum length of time over which we have hedged a portion of our exposure to the variability in the value of this debt due to interest rate risk is through March 15, 2035.
	In June 2013, KMP terminated three of their existing fixed-to-variable interest rate swap agreements in separate transactions. These swap agreements had a combined notional principal amount of $975 million, and received combined proceeds of $96 million from the early termination of these swap agreements. In August 2013, KMP entered into six separate fixed-to-variable interest rate swap agreements having a combined notional principal amount of $500 million. Four of these agreements effectively convert a portion of the interest expense associated with KMP’s 2.65% senior notes due February 1, 2019 from a fixed rate to a variable rate based on an interest rate of LIBOR plus a spread and the remaining two agreements effectively convert a portion of the interest expense associated with KMP’s 4.15% senior notes due February 1, 2024, from a fixed rate to a variable rate based on an interest rate of LIBOR plus a spread. In December 2013, three separate fixed-to-variable interest rate swap agreements having a combined notional amount of $375 million associated with KMP’s 5.00% senior notes terminated upon the maturing of the associated notes.
	As of December 31, 2012, KMI and KMP each had a combined notional principal amount of $725 million and $5,525 million, respectively, of fixed-to-variable interest rate swap agreements.
	Fair Value of Derivative Contracts
	The following table summarizes the fair values of our derivative contracts included on our accompanying consolidated balance sheets as of December 31, 2013 and 2012 (in millions):
	Fair Value of Derivative Contracts
				Asset derivatives								Liability derivatives
				December 31,								December 31,
				2013				2012				2013				2012
		Balance sheet location		Fair value								Fair value
	Derivatives designated as hedging contracts
	Natural gas and crude derivative contracts	Other current assets/(Other current liabilities)		$	18			$	42			$	(33	)		$	(18	)
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		58				40				(30		)		(11		)
	Subtotal			76				82				(63		)		(29		)
	Interest rate swap agreements	Other current assets/(Other current liabilities)		87				9				—				—
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		172				656				(116		)		(1		)
	Subtotal			259				665				(116		)		(1		)
	Total			335				747				(179		)		(30		)
	Derivatives not designated as hedging contracts
	Natural gas, crude and NGL derivative contracts	Other current assets/(Other current liabilities)		4				4				(5		)		(3		)
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		—				—				—				(1		)
	Subtotal			4				4				(5		)		(4		)
	Power derivative contracts	Other current assets/(Other current liabilities)		7				8				(54		)		(59		)
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		11				13				(73		)		(120		)
	Subtotal			18				21				(127		)		(179		)
	Total			22				25				(132		)		(183		)
	Total derivatives			$	357			$	772			$	(311	)		$	(213	)
	Certain of our derivative contracts are subject to master netting agreements. As of December 31, 2013 and 2012, we presented the fair value of our derivative contracts on a gross basis on our accompanying consolidated balance sheets. The following tables present our derivative contracts subject to such netting agreements as of the dates indicated (in millions):
			Offsetting of Financial Assets and Derivative Assets
															Gross amounts not offset in the balance sheet
			Gross amounts of recognized assets				Gross amounts offset in the balance sheet				Amounts of assets presented in the balance sheet				Financial instruments				Cash collateral held(a)				Net amount
	As of December 31, 2013:
	Natural gas, crude and NGL derivative contracts		$	80			$	—			$	80			$	(44	)		$	—			$	36
	Power derivative contracts		$	18			$	—			$	18			$	(18	)		$	—			$	—
	Interest rate swap agreements		$	259			$	—			$	259			$	(28	)		$	—			$	231
	As of December 31, 2012:
	Natural gas, crude and NGL derivative contracts		$	86			$	—			$	86			$	(17	)		$	—			$	69
	Power derivative contracts		$	21			$	—			$	21			$	(21	)		$	—			$	—
	Interest rate swap agreements		$	665			$	—			$	665			$	—			$	—			$	665
			Offsetting of Financial Liabilities and Derivative Liabilities
															Gross amounts not offset in the balance sheet
			Gross amounts of recognized liabilities				Gross amounts offset in the balance sheet				Amounts of liabilities presented in the balance sheet				Financial instruments				Cash collateral posted(b)				Net amount
	As of December 31, 2013:
	Natural gas, crude and NGL derivative contracts		$	(68	)		$	—			$	(68	)		$	44			$	17			$	(7	)
	Power derivative contracts		$	(127	)		$	—			$	(127	)		$	18			$	—			$	(109	)
	Interest rate swap agreements		$	(116	)		$	—			$	(116	)		$	28			$	—			$	(88	)
As of December 31, 2012:
Natural gas, crude and NGL derivative contracts		$	(33	)		$	—			$	(33	)		$	17			$	5			$	(11	)
Power derivative contracts		$	(179	)		$	—			$	(179	)		$	21			$	—			$	(158	)
Interest rate swap agreements		$	(1	)		$	—			$	(1	)		$	—			$	—			$	(1	)
_______
(a)	Cash margin deposits held by KMP associated with its energy commodity contract positions and OTC swap agreements and reported within “Other current liabilities” in our accompanying consolidated balance sheets.
(b)	$17 million and $5 million of cash margin deposits posted by KMP at December 31, 2013 and December 31, 2012, respectively, associated with energy commodity contract positions and OTC swap agreements and reported within “Other current assets” in our accompanying consolidated balance sheets.
Debt Fair Value Adjustments
The offsetting entry to adjust the carrying value of the debt securities whose fair value was being hedged is included within “Debt fair value adjustments” on our accompanying consolidated balance sheets. Our “Debt fair value adjustments” also include all unamortized debt discount/premium amounts, purchase accounting on our debt balances, and any unamortized portion of proceeds received from the early termination of interest rate swap agreements.  As of December 31, 2013 and 2012, these fair value adjustments to our debt balances included (i) $1,379 million and $1,470 million, respectively, associated with fair value adjustments to our debt previously recorded in purchase accounting; (ii) $143 million and $664 million, respectively, associated with the offsetting entry for hedged debt; (iii) $517 million and $490 million respectively, associated with unamortized premium from the termination of interest rate swap agreements; and offset by (iv) $62 million and $33 million, respectively, associated with unamortized debt discount amounts. As of December 31, 2013, the weighted-average amortization period of the unamortized premium from the termination of the interest rate swaps was approximately 16 years.
Effect of Derivative Contracts on the Income Statement
The following two tables summarize the impact of our derivative contracts on our accompanying consolidated statements of income for each of the years ended December 31, 2013, 2012 and 2011 (in millions):
Derivatives in fair value hedging relationships		Location of gain/(loss)recognized in income on derivatives		Amount of gain/(loss)recognized in income on derivatives and related hedged item(a)
				Year Ended December 31,
				2013				2012				2011
Interest rate swap agreements		Interest expense		$	(425	)		$	55			$	545
Total				$	(425	)		$	55			$	545
Fixed rate debt		Interest expense		$	425			$	(55	)		$	(545	)
Total				$	425			$	(55	)		$	(545	)
_______
(a) Amounts reflect the change in the fair value of interest rate swap agreements and the change in the fair value of the associated fixed rate debt, which exactly offset each other as a result of no hedge ineffectiveness.
Derivatives in cash flow hedging relationships		Amount of gain/(loss) recognized in OCI on derivative (effective portion)(a)												Location of gain/(loss) reclassified from Accumulated OCI into income (effective portion)		Amount of gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b)											Location of gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	Amount of gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)
		Year Ended														Year Ended												Year Ended
		December 31,														December 31,												December 31,
		2013				2012				2011						2013				2012				2011				2013		2012			2011
Energy commodity derivative contracts		$	(45	)		$	87			$	13			Revenues—Natural gas sales		$	—			$	4			$	2		Revenues—Natural gas sales	$	—	$	—		$	—
														Revenues—Product sales and other		(13		)		(15		)		(193		)	Revenues—Product sales and other	3		(11		)	5
														Costs of sales		—				17				7			Costs of sales	—		—			—
Interest rate swap agreements		7				(5		)		—				Interest expense		2				2				—			Interest expense	—		—			—
Total		$	(38	)		$	82			$	13			Total		$	(11	)		$	8			$	(184	)	Total	$	3	$	(11	)	$	5
_______
(a)	We expect to reclassify an approximate $1 million loss associated with energy commodity price risk management activities and included in our accumulated other comprehensive loss and noncontrolling interest balances as of December 31, 2013 into earnings during the next twelve months (when the associated forecasted sales and purchases are also expected to occur), however, actual amounts reclassified into earnings could vary materially as a result of changes in market prices.
(b)	Amounts reclassified were the result of the hedged forecasted transactions actually affecting earnings (i.e., when the forecasted sales and purchases actually occurred).
For the years ended December 31, 2013 and 2012, we recognized losses of $10 million and $4 million, respectively, in income and included these amounts within “Revenues-Product sales and other” from derivative contracts not designated as accounting hedges. For the year ended December 31, 2011, such amounts were not significant.
Credit Risks
We and our subsidiary, KMP, have counterparty credit risk as a result of our use of financial derivative contracts.  Our counterparties consist primarily of financial institutions, major energy companies, natural gas and electric utilities and local distribution companies.  This concentration of counterparties may impact our overall exposure to credit risk, either positively or negatively, in that the counterparties may be similarly affected by changes in economic, regulatory or other conditions.
We maintain credit policies with regard to our counterparties that we believe minimize our overall credit risk.  These policies include (i) an evaluation of potential counterparties’ financial condition (including credit ratings); (ii) collateral requirements under certain circumstances; and (iii) the use of standardized agreements which allow for netting of positive and negative exposure associated with a single counterparty.  Based on our policies, exposure, credit and other reserves, our management does not anticipate a material adverse effect on our financial position, results of operations, or cash flows as a result of counterparty performance.
Our OTC swaps and options are entered into with counterparties outside central trading organizations such as futures, options or stock exchanges.  These contracts are with a number of parties, all of which have investment grade credit ratings.  While we enter into derivative transactions with investment grade counterparties and actively monitor their ratings, it is nevertheless possible that from time to time losses will result from counterparty credit risk in the future.
In conjunction with the purchase of exchange-traded derivative contracts or when the market value of our derivative contracts with specific counterparties exceeds established limits, we are required to provide collateral to our counterparties, which may include posting letters of credit or placing cash in margin accounts.  As of both December 31, 2013 and 2012, KMP had no outstanding letters of credit supporting its hedging of energy commodity price risks associated with the sale of natural gas, NGL and crude oil. As of December 31, 2013 and 2012, KMI had $167 million and $300 million, respectively, of outstanding letters of credit supporting its commodity price risks associated with the sale of natural gas and power.
KMP and KMI also have agreements with certain counterparties to their derivative contracts that contain provisions requiring the posting of additional collateral upon a decrease in their credit rating.  As of December 31, 2013, we estimate that if KMP’s credit rating was downgraded one notch, KMP would be required to post no additional collateral to its counterparties. If KMP was downgraded two notches (that is below investment grade), KMP would be required to post $8 million of additional collateral. As of December 31, 2013, we estimate that if KMI’s credit rating was downgraded one or two notches, KMI would be required to post no additional collateral to its counterparties.
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income
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” for the year ended December 31, 2013 are summarized as follows (in millions):
	Net unrealized				Foreign				Pension and				Total
	gains/(losses)				currency				other				Accumulated other
	on cash flow				translation				postretirement				comprehensive
	hedge derivatives				adjustments				liability adjustments				income/(loss)
Balance as of December 31, 2012	$	7			$	51			$	(176	)		$	(118	)
Other comprehensive (loss) income before reclassifications	(14		)		(49		)		151				88
Amounts reclassified from accumulated other comprehensive income	4				—				2				6
Net current-period other comprehensive (loss) income	(10		)		(49		)		153				94
Balance as of December 31, 2013	$	(3	)		$	2			$	(23	)		$	(24	)

Fair_Value_Notes

Fair Value (Notes)	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value	'
	Fair Value
	The fair values of our financial instruments are separated into three broad levels (Levels 1, 2 and 3) based on our assessment of the availability of observable market data and the significance of non-observable data used to determine fair value. Each fair value measurement must be assigned to a level corresponding to the lowest level input that is significant to the fair value measurement in its entirety.
	The three broad levels of inputs defined by the fair value hierarchy are as follows:
	•	Level 1 Inputs—quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity has the ability to access at the measurement date;
	•	Level 2 Inputs—inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. If the asset or liability has a specified (contractual) term, a Level 2 input must be observable for substantially the full term of the asset or liability; and
	•	Level 3 Inputs—unobservable inputs for the asset or liability. These unobservable inputs reflect the entity’s own assumptions about the assumptions that market participants would use in pricing the asset or liability, and are developed based on the best information available in the circumstances (which might include the reporting entity’s own data).
	Fair Value of Derivative Contracts
	The following two tables summarize the fair value measurements of our (i) energy commodity derivative contracts and (ii) interest rate swap agreements as of December 31, 2013 and 2012, based on the three levels established by the Codification. The fair value measurements in the tables below do not include cash margin deposits made by us, which are reported within “Other current assets” in our accompanying consolidated balance sheets (in millions).
		Asset fair value measurements using
		Total			Quoted prices in			Significant other			Significant
					active markets			observable			unobservable
					for identical			inputs			inputs
					assets			(Level 2)			(Level 3)
					(Level 1)
	As of December 31, 2013
	Energy commodity derivative contracts(a)	$	98		$	4		$	46		$	48
	Interest rate swap agreements	$	259		$	—		$	259		$	—
	As of December 31, 2012
	Energy commodity derivative contracts(a)	$	107		$	3		$	76		$	28
	Interest rate swap agreements	$	665		$	—		$	665		$	—
		Liability fair value measurements using
		Total			Quoted			Significant			Significant
					prices in			other			unobservable
					active			observable			inputs
					markets			inputs			(Level 3)
					for identical			(Level 2)
					liabilities
					(Level 1)
	As of December 31, 2013
	Energy commodity derivative contracts(a)	$	(195	)	$	(6	)	$	(31	)	$	(158	)
	Interest rate swap agreements	$	(116	)	$	—		$	(116	)	$	—
	As of December 31, 2012
	Energy commodity derivative contracts(a)	$	(212	)	$	(3	)	$	(26	)	$	(183	)
	Interest rate swap agreements	$	(1	)	$	—		$	(1	)	$	—
	_______
	(a)	Level 1 consists primarily of NYMEX natural gas futures.  Level 2 consists primarily of OTC WTI swaps and OTC natural gas swaps that are settled on NYMEX.  Level 3 consists primarily of WTI options, NGL options and power derivative contracts.
	The table below provides a summary of changes in the fair value of our Level 3 energy commodity derivative contracts for each of the years ended December 31, 2013 and 2012 (in millions):
	Significant unobservable inputs (Level 3)
		Year Ended December 31,
		2013			2012
	Derivatives-net asset (liability)
	Beginning of period	$	(155	)	$	7
	Total gains or (losses)
	Included in earnings	(5		)	(4		)
	Included in other comprehensive income	(1		)	(1		)
	Purchases (a)	17			(194		)
	Settlements	34			37
	End of period	$	(110	)	$	(155	)
	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	$	(8	)	$	(2	)
	_______
	(a)	2012 purchases include a net liability of $197 million of Level 3 energy commodity derivative contracts associated with the EP acquisition. 2013 purchases include a net asset of $18 million of Level 3 energy commodity derivative contracts assumed in conjunction with KMP’s May 1, 2013 Copano acquisition.
	As of December 31, 2013, our Level 3 derivative assets and liabilities consisted primarily of WTI options, NGL options and power derivative contracts, where a significant portion of fair value is calculated from underlying market data that is not readily observable. The derived values use industry standard methodologies that may consider the historical relationships among various commodities, modeled market prices, time value, volatility factors and other relevant economic measures. The use of these inputs results in management’s best estimate of fair value.
	The significant unobservable inputs used in the fair value measurement of our power-related derivatives are illiquid pricing points. As the delivery points in our power contracts are in an illiquid market and not actively traded, we adjust the Pennsylvania-New Jersey-Maryland (PJM) forward curves by the difference between the 12-month rolling average of actual settled prices at delivery points in the PJM East region. As of December 31, 2012, the adjusted prices over the contract term ranged from $28.50 per MW/h to $57.32 per MW/h. However, we have entered into offsetting positions that eliminate the price risks associated with our PJM power contracts. Significant increases (decreases) in these inputs in isolation would result in a significantly lower (higher) fair value measurement.
	Fair Value of Financial Instruments
	The estimated fair value of our outstanding debt balance (both short-term and long-term and including debt fair value adjustments), is disclosed below (in millions):
		December 31, 2013						December 31, 2012
		Carrying			Estimated			Carrying			Estimated
		value			fair value			value			fair value
	Total debt	$	36,193		$	36,248		$	34,401		$	36,720
	We used Level 2 input values to measure the estimated fair value of our outstanding debt balance as of both December 31, 2013 and 2012.

Reportable_Segments_Notes

Reportable Segments (Notes)	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Reportable Segments	'
	Reportable Segments
	We divide our operations into the following reportable business segments.  These segments and their principal sources of revenues are as follows:
	•	Natural Gas Pipelines—the sale, transport, processing, treating, fractionation, storage and gathering of natural gas and NGL;
	•	CO2—KMP—the production, sale and transportation of crude oil from fields in the Permian Basin of West Texas and the production, transportation and marketing of CO2 used as a flooding medium for recovering crude oil from mature oil fields;
	•	Products Pipelines—KMP— the transportation and terminaling of refined petroleum products (including gasoline, diesel fuel and jet fuel) NGL, crude and condensate, and bio-fuels;
	•	Terminals—KMP—the transloading and storing of refined petroleum products and dry and liquid bulk products, including coal, petroleum coke, cement, alumina, salt and other bulk chemicals;
	•	Kinder Morgan Canada—KMP—the transportation of crude oil and refined products from Alberta, Canada to marketing terminals and refineries in British Columbia and the state of Washington. As further described in Note 3, Kinder Morgan Canada divested its interest in the Express pipeline system effective March 14, 2013; and
	•	Other—primarily includes several physical natural gas contracts with power plants associated with EP’s legacy trading activities. These contracts obligate EP to sell natural gas to these plants and have various expiration dates ranging from 2012 to 2028.
	We evaluate performance principally based on each segment’s EBDA (including amortization of excess cost of equity investments), which excludes general and administrative expenses, third-party debt costs and interest expense, unallocable interest income, and unallocable income tax expense.  Our reportable segments are strategic business units that offer different products and services, and they are structured based on how our chief operating decision makers organize their operations for optimal performance and resource allocation.  Each segment is managed separately because each segment involves different products and marketing strategies.
	Because KMP’s and EPB’s partnership agreements require them to distribute 100% of their available cash to their partners on a quarterly basis (available cash consists primarily of all cash receipts, less cash disbursements and changes in reserves), we consider each period’s earnings before all non-cash DD&A expenses to be an important measure of business segment performance for our segments that are also segments.  We account for intersegment sales at market prices, while we account for asset transfers at either market value or, in some instances, book value.
	During 2013, 2012 and 2011, we did not have revenues from any single external customer that exceeded 10% of our consolidated revenues.
	Financial information by segment follows (in millions):
		Year Ended December 31,
		2013			2012			2011
	Revenues
	Natural Gas Pipelines(a)
	Revenues from external customers	$	8,613		$	5,230		$	3,943
	Intersegment revenues	4			—			—
	CO2—KMP	1,857			1,677			1,434
	Products Pipelines—KMP	1,853			1,370			914
	Terminals—KMP
	Revenues from external customers	1,408			1,356			1,314
	Intersegment revenues	2			3			1
	Kinder Morgan Canada—KMP	302			311			302
	Other	1			(6		)	—
	Total segment revenues	14,040			9,941			7,908
	Other revenues(b)	36			35			36
	Less: Total intersegment revenues	(6		)	(3		)	(1		)
	Total consolidated revenues	$	14,070		$	9,973		$	7,943
		Year Ended December 31,
		2013			2012			2011
	Operating expenses(c)
	Natural Gas Pipelines(a)	$	5,235		$	3,111		$	3,370
	CO2—KMP	439			381			342
	Products Pipelines—KMP	1,295			759			500
	Terminals—KMP	657			685			634
	Kinder Morgan Canada—KMP	110			103			97
	Other	30			5			—
	Total segment operating expenses	7,766			5,044			4,943
	Other operating expenses	—			4			1
	Less: Total intersegment operating expenses	(6		)	(3		)	(1		)
	Total consolidated operating expenses	$	7,760		$	5,045		$	4,943
		Year Ended December 31,
		2013			2012			2011
	Other expense (income)
	Natural Gas Pipelines(a)	$	(24	)	$	14		$	1
	CO2—KMP	—			(7		)	—
	Products Pipelines—KMP	6			(5		)	(8		)
	Terminals—KMP	(74		)	(14		)	1
	Other	(7		)	(1		)	—
	Total consolidated other expense (income)	$	(99	)	$	(13	)	$	(6	)
		Year Ended December 31,
		2013			2012			2011
	DD&A
	Natural Gas Pipelines(a)	$	797		$	478		$	163
	CO2—KMP	533			494			492
	Products Pipelines—KMP	155			143			131
	Terminals—KMP	247			236			226
	Kinder Morgan Canada—KMP	54			56			56
	Other	20			12			—
	Total consolidated DD&A	$	1,806		$	1,419		$	1,068
		Year Ended December 31,
		2013			2012			2011
Earnings (loss) from equity investments
Natural Gas Pipelines(a)(d)	$	232		$	52		$	158
CO2—KMP	24			25			24
Products Pipelines—KMP	45			39			34
Terminals—KMP	22			21			11
Kinder Morgan Canada—KMP	4			5			(2		)
Other	—			11			1
Total consolidated equity earnings (loss)	$	327		$	153		$	226
	Year Ended December 31,
	2013			2012			2011
Amortization of excess cost of equity investments
Natural Gas Pipelines(a)	$	32		$	17		$	1
CO2—KMP	2			2			2
Products Pipelines—KMP	5			4			4
Total consolidated amortization of excess cost of equity investments	$	39		$	23		$	7
	Year Ended December 31,
	2013			2012			2011
Interest income
Natural Gas Pipelines	$	—		$	18		$	—
CO2—KMP	—			—			1
Products Pipelines—KMP	2			2			3
Kinder Morgan Canada—KMP	3			14			14
Other	8			3			—
Total segment interest income	13			37			18
Unallocated interest income	2			(9		)	3
Total consolidated interest income	$	15		$	28		$	21
	Year Ended December 31,
	2013			2012			2011
Other, net-income (expense)
Natural Gas Pipelines(e)	$	578		$	4		$	(164	)
CO2—KMP	—			(1		)	4
Products Pipelines—KMP	1			9			5
Terminals—KMP	1			2			6
Kinder Morgan Canada—KMP(f)	246			3			—
Other	9			2			(1		)
Total consolidated other, net-income (expense)	$	835		$	19		$	(150	)
	Year Ended December 31,
	2013			2012			2011
Income tax benefit (expense)
Natural Gas Pipelines	$	(9	)	$	(5	)	$	(3	)
CO2—KMP	(7		)	(5		)	(4		)
Products Pipelines—KMP	2			2			(3		)
Terminals—KMP	(14		)	(3		)	5
Kinder Morgan Canada—KMP(g)	(105		)	(1		)	(15		)
Total segment income tax expense	(133		)	(12		)	(20		)
Unallocated income tax expense	(609		)	(127		)	(341		)
Total consolidated income tax expense	$	(742	)	$	(139	)	$	(361	)
	Year Ended December 31,
	2013			2012			2011
Segment EBDA(h)
Natural Gas Pipelines(a)	$	4,207		$	2,174		$	563
CO2—KMP	1,435			1,322			1,117
Products Pipelines—KMP	602			668			461
Terminals—KMP	836			708			702
Kinder Morgan Canada—KMP	340			229			202
Other	(5		)	7			—
Total segment EBDA	7,415			5,108			3,045
Total segment DD&A	(1,806		)	(1,419		)	(1,068		)
Total segment amortization of excess cost of equity investments	(39		)	(23		)	(7		)
Other revenues	36			35			36
General and administrative expenses(i)	(613		)	(929		)	(515		)
Interest expense, net of unallocable interest income(j)	(1,688		)	(1,441		)	(701		)
Unallocable income tax expense	(609		)	(127		)	(341		)
(Loss) income from discontinued operations, net of tax(k)	(4		)	(777		)	211
Total consolidated net income	$	2,692		$	427		$	660
	Year Ended December 31,
	2013			2012			2011
Capital expenditures
Natural Gas Pipelines(a)	$	1,085		$	499		$	153
CO2—KMP	667			453			432
Products Pipelines—KMP	416			307			254
Terminals—KMP	1,108			707			332
Kinder Morgan Canada—KMP	77			16			28
Other	16			40			1
Total consolidated capital expenditures	$	3,369		$	2,022		$	1,200
	2013			2012
Investments at December 31
Natural Gas Pipelines	$	5,130		$	5,193
CO2—KMP	12			11
Products Pipelines—KMP	611			400
Terminals—KMP	196			179
Kinder Morgan Canada—KMP	1			1
Other	1			20
Total consolidated investments	$	5,951		$	5,804
	2013			2012
Assets at December 31
Natural Gas Pipelines(a)	$	52,357		$	46,600
CO2—KMP	4,708			4,148
Products Pipelines—KMP	6,648			6,089
Terminals—KMP	6,888			5,931
Kinder Morgan Canada—KMP	1,677			1,724
Other	568			601
Total segment assets	72,846			65,093
Corporate assets(l)	2,339			2,854
Assets held for sale(m)	—			298
Total consolidated assets	$	75,185		$	68,245
_______
(a)	The changes in the 2012 amount versus the 2011 amount include the effects of the acquisition of EP and for 2013 versus 2012 only, KMP’s acquisition of Copano. See Note 3.
(b)	Primarily represents a reimbursement of general and administrative costs for services we perform for NGPL Holdco LLC.
(c)	Includes natural gas purchases and other costs of sales, operations and maintenance expenses, and taxes, other than income taxes.
(d)	2013 and 2012 amounts include impairment charges of $65 million and $200 million, respectively, to reduce the carrying value of our investment in NGPL Holdco LLC (see Note 6).
(e)	2013 amount includes a $558 million gain from the remeasurement of our previously held 50% equity interest in Eagle Ford to fair value (discussed further in Note 3). 2011 amount includes a $167 million loss from the remeasurement of KMP’s previously held 50% equity interest in KinderHawk to fair value (see Note 3).
(f)	2013 amount includes a $224 million gain from the sale of our equity and debt investments in the Express pipeline system (discussed further in Note 3).
(g)	2013 amount includes an $84 million increase in expense related to the pre-tax gain amount described in footnote (f).
(h)	Includes revenues, earnings from equity investments, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other expense (income).
(i)	2012 amount includes $352 million of pretax expense associated with the EP acquisition and EP Energy sale.
(j)	Includes (i) interest expense and (ii) miscellaneous other income and expenses not allocated to business segments. 2012 amount includes $108 million of expense for capitalized financing fees associated with the EP acquisition financing that were written-off (due to debt repayments) or amortized.
(k)	Represents amounts from KMP’s FTC Natural Gas Pipelines disposal group and other, net of tax (see Note 3).
(l)	Includes cash and cash equivalents, margin and restricted deposits, unallocable interest receivable, prepaid assets and deferred charges, risk management assets related to debt fair value adjustments and miscellaneous corporate assets (such as information technology and telecommunications equipment) not allocated to individual segments.
(m)	Primarily represents amounts attributable to KMP’s Express pipelines system and our ownership interest in Bolivia to Brazil Pipeline.
We do not attribute interest and debt expense to any of our reportable business segments.  For each of the years ended December 31, 2013, 2012 and 2011, we reported total consolidated interest expense of $1,690 million, $1,427 million, and $703 million, respectively.
Following is geographic information regarding the revenues and long-lived assets of our business segments (in millions):
	Year Ended December 31,
	2013			2012			2011
Revenues from external customers
U.S.	$	13,656		$	9,488		$	7,513
Canada	398			407			411
Mexico and other(a)	16			78			19
Total consolidated revenues from external customers	$	14,070		$	9,973		$	7,943
	2013			2012			2011
Long-lived assets at December 31(b)
U.S.	$	42,080		$	37,651		$	20,848
Canada	2,214			2,035			1,863
Mexico and other(a)	81			82			84
Total consolidated long-lived assets	$	44,375		$	39,768		$	22,795
_______
(a)	Includes operations in Mexico and until August 31, 2011, the Netherlands.
(b)	Long-lived assets exclude goodwill and other intangibles, net

Litigation_Environmental_and_O

Litigation, Environmental and Other Contingencies (Notes)	3 Months Ended	12 Months Ended
	Mar. 31, 2013	Dec. 31, 2013
Loss Contingency, Information about Litigation Matters [Abstract]	'	'
Litigation, Environmental and Other Contingencies	'	'
	Litigation, Environmental and Other Contingencies	Litigation, Environmental and Other Contingencies
	We and our subsidiaries are parties to various legal, regulatory and other matters arising from the day-to-day operations of our businesses that may result in claims against the Company. Although no assurance can be given, we believe, based on our experiences to date and taking into account established reserves, that the ultimate resolution of such items will not have a material adverse impact on our business, financial position, results of operations or dividends to our shareholders. We believe we have meritorious defenses to the matters to which we are a party and intend to vigorously defend the Company. When we determine a loss is probable of occurring and is reasonably estimable, we accrue an undiscounted liability for such contingencies based on our best estimate using information available at that time. If the estimated loss is a range of potential outcomes and there is no better estimate within the range, we accrue the amount at the low end of the range. We disclose contingencies where an adverse outcome may be material, or in the judgment of management, we conclude the matter should otherwise be disclosed.	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	Federal Energy Regulatory Commission Proceedings
	The tariffs and rates charged by SFPP and EPNG are subject to a number of ongoing proceedings at the FERC. A substantial portion of our legal reserves relate to these FERC cases and the CPUC cases described below them.	The tariffs and rates charged by SFPP and EPNG are subject to a number of ongoing proceedings at the FERC. A substantial portion of our legal reserves relate to these FERC cases and the CPUC cases described below them.
	SFPP	SFPP
	The tariffs and rates charged by SFPP are subject to a number of ongoing proceedings at the FERC, including the complaints and protests of various shippers. In general, these complaints and protests allege the rates and tariffs charged by SFPP are not just and reasonable under the Interstate Commerce Act (ICA). If the shippers are successful in proving their claims, they are entitled to seek reparations (which may reach back up to two years prior to the filing of their complaints) or refunds of any excess rates paid, and SFPP may be required to reduce its rates going forward. These proceedings tend to be protracted, with decisions of the FERC often appealed to the federal courts. The issues involved in these proceedings include, among others, whether indexed rate increases are justified, and the appropriate level of return and income tax allowance KMP may include in its rates. With respect to all of the SFPP proceedings at the FERC, we estimate that the shippers are seeking approximately $20 million in annual rate reductions and approximately $100 million in refunds. However, applying the principles of several recent FERC decisions in SFPP cases, as applicable, to pending cases would result in substantially lower rate reductions and refunds than those sought by the shippers. We do not expect refunds in these cases to have an impact on KMP’s distributions to its limited partners or our dividends to our shareholders.	The tariffs and rates charged by SFPP are subject to a number of ongoing proceedings at the FERC, including the complaints and protests of various shippers. In general, these complaints and protests allege the rates and tariffs charged by SFPP are not just and reasonable under the Interstate Commerce Act (ICA). If the shippers are successful in proving their claims, they are entitled to seek reparations (which may reach back up to two years prior to the filing of their complaints) or refunds of any excess rates paid, and SFPP may be required to reduce its rates going forward. These proceedings tend to be protracted, with decisions of the FERC often appealed to the federal courts. The issues involved in these proceedings include, among others, whether indexed rate increases are justified, and the appropriate level of return and income tax allowance KMP may include in its rates. With respect to all of the SFPP proceedings at the FERC, we estimate that the shippers are seeking approximately $20 million in annual rate reductions and approximately $100 million in refunds. However, applying the principles of several recent FERC decisions in SFPP cases, as applicable, to pending cases would result in substantially lower rate reductions and refunds than those sought by the shippers. We do not expect refunds in these cases to have an impact on KMP’s distributions to its limited partners or our dividends to our shareholders.
	EPNG	EPNG
	The tariffs and rates charged by EPNG are subject to two ongoing FERC proceedings (the “2008 rate case” and the “2010 rate case”). With respect to the 2008 rate case, the FERC issued its decision (Opinion 517) in May 2012. EPNG implemented certain aspects of that decision and believes it has an appropriate reserve related to the findings in Opinion 517. EPNG has sought rehearing on Opinion 517. With respect to the 2010 rate case, the FERC issued its decision (Opinion 528) on October 17, 2013. The FERC ordered EPNG to file within 60 days of issuance of Opinion 528 revised pro forma recalculated rates consistent with the terms of Opinion 528. The FERC has ordered additional proceedings concerning one of the issues in Opinion 528. EPNG has filed for rehearing on certain issues in Opinion 528. We have evaluated all recent decisions and believe our reserve is appropriate.	The tariffs and rates charged by EPNG are subject to two ongoing FERC proceedings (the “2008 rate case” and the “2010 rate case”). With respect to the 2008 rate case, the FERC issued its decision (Opinion 517) in May 2012. EPNG implemented certain aspects of that decision and believes it has an appropriate reserve related to the findings in Opinion 517. EPNG has sought rehearing on Opinion 517. With respect to the 2010 rate case, the FERC issued its decision (Opinion 528) on October 17, 2013. The FERC ordered EPNG to file within 60 days of issuance of Opinion 528 revised pro forma recalculated rates consistent with the terms of Opinion 528. The FERC has ordered additional proceedings concerning one of the issues in Opinion 528. EPNG has filed for rehearing on certain issues in Opinion 528. We have evaluated all recent decisions and believe our reserve is appropriate.
	California Public Utilities Commission Proceedings	California Public Utilities Commission Proceedings
	KMP has previously reported ratemaking and complaint proceedings against SFPP pending with the CPUC. The ratemaking and complaint cases generally involve challenges to rates charged by SFPP for intrastate transportation of refined petroleum products through its pipeline system in the state of California and request prospective rate adjustments and refunds with respect to tariffed and previously untariffed charges for certain pipeline transportation and related services. These matters have generally been consolidated and assigned to two administrative law judges.	KMP has previously reported ratemaking and complaint proceedings against SFPP pending with the CPUC. The ratemaking and complaint cases generally involve challenges to rates charged by SFPP for intrastate transportation of refined petroleum products through its pipeline system in the state of California and request prospective rate adjustments and refunds with respect to tariffed and previously untariffed charges for certain pipeline transportation and related services. These matters have generally been consolidated and assigned to two administrative law judges.
	On May 26, 2011, the CPUC issued a decision in several intrastate rate cases involving SFPP and a number of its shippers, (the “Long” cases). The decision includes determinations on issues, such as SFPP’s entitlement to an income tax allowance, allocation of environmental expenses, and refund liability, which KMP believes are contrary both to CPUC policy and precedent and to established federal regulatory policies for pipelines. On March 8, 2012, the CPUC issued another decision related to the Long cases. This decision largely reflected the determinations made on May 26, 2011, including the denial of an income tax allowance for SFPP. The CPUC’s order denied SFPP’s request for rehearing of the CPUC’s income tax allowance treatment, while granting requested rehearing of various, other issues relating to SFPP’s refund liability and staying the payment of refunds until resolution of the outstanding issues on rehearing. On March 23, 2012, SFPP filed a petition for writ of review in the California Court of Appeals, seeking a court order vacating the CPUC’s determination that SFPP is not entitled to recover an income tax allowance in its intrastate rates. The Court denied SFPP’s petition, and on October 16, 2013, the California Supreme Court declined SFPP’s request for further review. SFPP is currently assessing the precise impact of the now final state rulings denying SFPP an income tax allowance and is awaiting CPUC decisions that will determine the impact related to the denial of an income tax allowance.	On May 26, 2011, the CPUC issued a decision in several intrastate rate cases involving SFPP and a number of its shippers, (the “Long” cases). The decision includes determinations on issues, such as SFPP’s entitlement to an income tax allowance, allocation of environmental expenses, and refund liability, which KMP believes are contrary both to CPUC policy and precedent and to established federal regulatory policies for pipelines. On March 8, 2012, the CPUC issued another decision related to the Long cases. This decision largely reflected the determinations made on May 26, 2011, including the denial of an income tax allowance for SFPP. The CPUC’s order denied SFPP’s request for rehearing of the CPUC’s income tax allowance treatment, while granting requested rehearing of various, other issues relating to SFPP’s refund liability and staying the payment of refunds until resolution of the outstanding issues on rehearing. On March 23, 2012, SFPP filed a petition for writ of review in the California Court of Appeals, seeking a court order vacating the CPUC’s determination that SFPP is not entitled to recover an income tax allowance in its intrastate rates. The Court denied SFPP’s petition, and on October 16, 2013, the California Supreme Court declined SFPP’s request for further review. SFPP is currently assessing the precise impact of the now final state rulings denying SFPP an income tax allowance and is awaiting CPUC decisions that will determine the impact related to the denial of an income tax allowance.
	On April 6, 2011, in proceedings unrelated to the above-referenced CPUC dockets, a CPUC administrative law judge issued a proposed decision (Bemesderfer case) substantially reducing SFPP’s authorized cost of service and ordering SFPP to pay refunds from May 24, 2007 to the present of revenues collected in excess of the authorized cost of service. The proposed decision was subsequently withdrawn, and the presiding administrative law judge is expected to reissue a proposed decision at some indeterminate time in the future.	On April 6, 2011, in proceedings unrelated to the above-referenced CPUC dockets, a CPUC administrative law judge issued a proposed decision (Bemesderfer case) substantially reducing SFPP’s authorized cost of service and ordering SFPP to pay refunds from May 24, 2007 to the present of revenues collected in excess of the authorized cost of service. The proposed decision was subsequently withdrawn, and the presiding administrative law judge is expected to reissue a proposed decision at some indeterminate time in the future.
	On January 30, 2012, SFPP filed an application reducing its intrastate rates by approximately 7%. This matter remains pending before the CPUC, with a decision expected in the second quarter of 2014.	On January 30, 2012, SFPP filed an application reducing its intrastate rates by approximately 7%. This matter remains pending before the CPUC, with a decision expected in the second quarter of 2014.
	On July 19, 2013, Calnev filed an application with the CPUC requesting a 36% increase in its intrastate rates. A decision from the CPUC approving the request rate increase was issued on November 14, 2013.	On July 19, 2013, Calnev filed an application with the CPUC requesting a 36% increase in its intrastate rates. A decision from the CPUC approving the request rate increase was issued on November 14, 2013.
	On November 27, 2013, the CPUC issued its Order to Show Cause directing SFPP to demonstrate whether or not the CPUC should require immediate refund payments associated with various pending SFPP rate matters. Subsequently, the CPUC issued an order directing SFPP and its shippers to engage in mandatory settlement discussions. If the matter is not settled, a decision addressing, if not resolving, all pending SFPP rate matters at the CPUC is anticipated in the second quarter of 2014.	On November 27, 2013, the CPUC issued its Order to Show Cause directing SFPP to demonstrate whether or not the CPUC should require immediate refund payments associated with various pending SFPP rate matters. Subsequently, the CPUC issued an order directing SFPP and its shippers to engage in mandatory settlement discussions. If the matter is not settled, a decision addressing, if not resolving, all pending SFPP rate matters at the CPUC is anticipated in the second quarter of 2014.
	Based on KMP’s review of these CPUC proceedings and the shipper comments thereon, it estimates that the shippers are requesting approximately $400 million in reparation payments and approximately $30 million in annual rate reductions. The actual amount of reparations will be determined through further proceedings at the CPUC.  As of December 31, 2013, we believe our legal reserve, including an adjustment of the reserve made in the second quarter of 2013 related in part to this matter, is adequate such that the resolution of pending CPUC matters will not have a material adverse impact on KMP’s business, financial position or results of operations. Furthermore, we do not expect any reparations that KMP would pay in this matter to impact the per unit cash distributions it expects to pay to its limited partners for 2014.	Based on KMP’s review of these CPUC proceedings and the shipper comments thereon, it estimates that the shippers are requesting approximately $400 million in reparation payments and approximately $30 million in annual rate reductions. The actual amount of reparations will be determined through further proceedings at the CPUC.  As of December 31, 2013, we believe our legal reserve, including an adjustment of the reserve made in the second quarter of 2013 related in part to this matter, is adequate such that the resolution of pending CPUC matters will not have a material adverse impact on KMP’s business, financial position or results of operations. Furthermore, we do not expect any reparations that KMP would pay in this matter to impact the per unit cash distributions it expects to pay to its limited partners for 2014.
	Copano Shareholders’ Litigation	Copano Shareholders’ Litigation
	Three putative class action lawsuits were filed in connection with KMP’s merger with Copano: (i) Schultes v. Copano Energy, L.L.C., et al. (Case No. 06966), in the District Court of Harris County, Texas, which is referred to as the Texas State Action; (ii) Bruen v. Copano Energy, L.L.C., et al. (Case No. 4:13-CV-00540) in the U.S. District Court for the Southern District of Texas, which is referred to as the Texas Federal Action; and (iii) In re Copano Energy, L.L.C. Shareholder Litigation, Case No. 8284-VCN in the Court of Chancery of the State of Delaware, which is referred to as the Delaware Action, which reflects the consolidation of three actions originally filed in the Court of Chancery. The Texas State Action, the Texas Federal Action and the Delaware Action are collectively referred to as the “Actions.”	Three putative class action lawsuits were filed in connection with KMP’s merger with Copano: (i) Schultes v. Copano Energy, L.L.C., et al. (Case No. 06966), in the District Court of Harris County, Texas, which is referred to as the Texas State Action; (ii) Bruen v. Copano Energy, L.L.C., et al. (Case No. 4:13-CV-00540) in the U.S. District Court for the Southern District of Texas, which is referred to as the Texas Federal Action; and (iii) In re Copano Energy, L.L.C. Shareholder Litigation, Case No. 8284-VCN in the Court of Chancery of the State of Delaware, which is referred to as the Delaware Action, which reflects the consolidation of three actions originally filed in the Court of Chancery. The Texas State Action, the Texas Federal Action and the Delaware Action are collectively referred to as the “Actions.”
	The Actions name Copano, R. Bruce Northcutt, William L. Thacker, James G. Crump, Ernie L. Danner, T. William Porter, Scott A. Griffiths, Michael L. Johnson, Michael G. MacDougall, Kinder Morgan G.P., Inc., KMEP and Javelina Merger Sub LLC as defendants. The Actions were purportedly brought on behalf of a putative class seeking to enjoin the merger and allege, among other things, that the members of Copano’s board of directors breached their fiduciary duties by agreeing to sell Copano for inadequate and unfair consideration and pursuant to an inadequate and unfair process, and that Copano, KMEP, Kinder Morgan G.P., Inc. and Javelina Merger Sub LLC aided and abetted such alleged breaches. In addition, the plaintiffs in each of the Texas State Action and the Delaware Action alleged that the Copano directors breached their duty of candor to unitholders by failing to provide the unitholders with all material information regarding the merger and/or made misstatements in the preliminary proxy statement. The plaintiffs in the Texas Federal Action also asserted a claim under the federal securities laws alleging that the preliminary proxy statement omits and/or misrepresents material information in connection with the merger.	The Actions name Copano, R. Bruce Northcutt, William L. Thacker, James G. Crump, Ernie L. Danner, T. William Porter, Scott A. Griffiths, Michael L. Johnson, Michael G. MacDougall, Kinder Morgan G.P., Inc., KMEP and Javelina Merger Sub LLC as defendants. The Actions were purportedly brought on behalf of a putative class seeking to enjoin the merger and allege, among other things, that the members of Copano’s board of directors breached their fiduciary duties by agreeing to sell Copano for inadequate and unfair consideration and pursuant to an inadequate and unfair process, and that Copano, KMEP, Kinder Morgan G.P., Inc. and Javelina Merger Sub LLC aided and abetted such alleged breaches. In addition, the plaintiffs in each of the Texas State Action and the Delaware Action alleged that the Copano directors breached their duty of candor to unitholders by failing to provide the unitholders with all material information regarding the merger and/or made misstatements in the preliminary proxy statement. The plaintiffs in the Texas Federal Action also asserted a claim under the federal securities laws alleging that the preliminary proxy statement omits and/or misrepresents material information in connection with the merger.
	On April 21, 2013, the parties in all the Actions executed a Memorandum of Understanding pursuant to which Copano agreed to make certain additional disclosures concerning the merger in a Form 8-K, which Copano filed on April 22, 2013, and the plaintiffs agreed to enter into a stipulation of settlement providing for full settlement and dismissal with prejudice of each of the Actions. The parties then prepared and filed a Stipulation of Settlement with the Delaware Chancery Court, and on June 28, 2013, Copano announced that we had reached an agreement with the plaintiffs to settle all claims asserted against all defendants. The settlement does not require the defendants to pay any monetary consideration to the proposed settlement class. Following notice to the putative class, the Delaware Chancery Court held a settlement hearing and issued a final order approving the settlement on September 9, 2013. The order, among other things, dismissed the Delaware Action with prejudice and provided for a release in favor of all of the defendants for any and all claims by any of the putative class members arising out of the merger. The order also awarded plaintiffs’ counsel in the Delaware action $450,000 for their fees and expenses, to be paid by defendants. The plaintiff in the Texas Federal Action dismissed his case on May 13, 2013 and intervened in the Texas State Action on August 12, 2013 for the sole purpose of advancing a joint motion and petition for attorneys’ fees and expenses. On October 11, 2013, the court in the Texas State Action entered an order and final judgment denying plaintiffs’ joint motion for fees and expenses.	On April 21, 2013, the parties in all the Actions executed a Memorandum of Understanding pursuant to which Copano agreed to make certain additional disclosures concerning the merger in a Form 8-K, which Copano filed on April 22, 2013, and the plaintiffs agreed to enter into a stipulation of settlement providing for full settlement and dismissal with prejudice of each of the Actions. The parties then prepared and filed a Stipulation of Settlement with the Delaware Chancery Court, and on June 28, 2013, Copano announced that we had reached an agreement with the plaintiffs to settle all claims asserted against all defendants. The settlement does not require the defendants to pay any monetary consideration to the proposed settlement class. Following notice to the putative class, the Delaware Chancery Court held a settlement hearing and issued a final order approving the settlement on September 9, 2013. The order, among other things, dismissed the Delaware Action with prejudice and provided for a release in favor of all of the defendants for any and all claims by any of the putative class members arising out of the merger. The order also awarded plaintiffs’ counsel in the Delaware action $450,000 for their fees and expenses, to be paid by defendants. The plaintiff in the Texas Federal Action dismissed his case on May 13, 2013 and intervened in the Texas State Action on August 12, 2013 for the sole purpose of advancing a joint motion and petition for attorneys’ fees and expenses. On October 11, 2013, the court in the Texas State Action entered an order and final judgment denying plaintiffs’ joint motion for fees and expenses.
	Other Commercial Matters	Other Commercial Matters
	Union Pacific Railroad Company Easements	Union Pacific Railroad Company Easements
	SFPP and Union Pacific Railroad Company (UPRR) are engaged in a proceeding to determine the extent, if any, to which the rent payable by SFPP for the use of pipeline easements on rights-of-way held by UPRR should be adjusted pursuant to existing contractual arrangements for the ten-year period beginning January 1, 2004 (Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al., Superior Court of the State of California for the County of Los Angeles, filed July 28, 2004). In September 2011, the judge determined that the annual rent payable as of January 1, 2004 was, $15 million subject to annual consumer price index increases. SFPP has appealed the judge’s determination, but if that determination is upheld, SFPP would owe approximately $90 million in back rent. Accordingly, KMP increased its rights-of-way liability to cover this potential liability for back rent. In addition, the judge determined that UPRR is entitled to an estimated $20 million for interest on the outstanding back rent liability. KMP believes the award of interest is without merit and are pursuing our appellate rights. By notice dated October 25, 2013, UPRR demanded the payment of $22.25 million in rent for the first year of the next ten-year period beginning January 1, 2014. SFPP rejected the demand and the parties are pursuing the dispute resolution procedure in their contract to determine the rental adjustment, if any, for such period.	SFPP and Union Pacific Railroad Company (UPRR) are engaged in a proceeding to determine the extent, if any, to which the rent payable by SFPP for the use of pipeline easements on rights-of-way held by UPRR should be adjusted pursuant to existing contractual arrangements for the ten-year period beginning January 1, 2004 (Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al., Superior Court of the State of California for the County of Los Angeles, filed July 28, 2004). In September 2011, the judge determined that the annual rent payable as of January 1, 2004 was, $15 million subject to annual consumer price index increases. SFPP has appealed the judge’s determination, but if that determination is upheld, SFPP would owe approximately $90 million in back rent. Accordingly, KMP increased its rights-of-way liability to cover this potential liability for back rent. In addition, the judge determined that UPRR is entitled to an estimated $20 million for interest on the outstanding back rent liability. KMP believes the award of interest is without merit and are pursuing our appellate rights. By notice dated October 25, 2013, UPRR demanded the payment of $22.25 million in rent for the first year of the next ten-year period beginning January 1, 2014. SFPP rejected the demand and the parties are pursuing the dispute resolution procedure in their contract to determine the rental adjustment, if any, for such period.
	SFPP and UPRR are also engaged in multiple disputes over the circumstances under which SFPP must pay for a relocation of its pipeline within the UPRR right-of-way and the safety standards that govern relocations. In July 2006, a trial before a judge regarding the circumstances under which SFPP must pay for relocations concluded, and the judge determined that SFPP must pay for any relocations resulting from any legitimate business purpose of the UPRR. SFPP appealed this decision, and in December 2008, the appellate court affirmed the decision. In addition, UPRR contends that SFPP must comply with the more expensive American Railway Engineering and Maintenance-of-Way Association (AREMA) standards in determining when relocations are necessary and in completing relocations. Each party is seeking declaratory relief with respect to its positions regarding the application of these standards with respect to relocations. A trial occurred in the fourth quarter of 2011, with a verdict having been reached that SFPP was obligated to comply with AREMA standards in connection with a railroad project in Beaumont Hills, California. A judgment has not been entered on the verdict and SFPP is continuing to evaluate its post-trial and appellate options.	SFPP and UPRR are also engaged in multiple disputes over the circumstances under which SFPP must pay for a relocation of its pipeline within the UPRR right-of-way and the safety standards that govern relocations. In July 2006, a trial before a judge regarding the circumstances under which SFPP must pay for relocations concluded, and the judge determined that SFPP must pay for any relocations resulting from any legitimate business purpose of the UPRR. SFPP appealed this decision, and in December 2008, the appellate court affirmed the decision. In addition, UPRR contends that SFPP must comply with the more expensive American Railway Engineering and Maintenance-of-Way Association (AREMA) standards in determining when relocations are necessary and in completing relocations. Each party is seeking declaratory relief with respect to its positions regarding the application of these standards with respect to relocations. A trial occurred in the fourth quarter of 2011, with a verdict having been reached that SFPP was obligated to comply with AREMA standards in connection with a railroad project in Beaumont Hills, California. A judgment has not been entered on the verdict and SFPP is continuing to evaluate its post-trial and appellate options.
	Since SFPP does not know UPRR’s plans for projects or other activities that would cause pipeline relocations, it is difficult to quantify the effects of the outcome of these cases on SFPP. Even if SFPP is successful in advancing its positions, significant relocations for which SFPP must nonetheless bear the expense (i.e., for railroad purposes, with the standards in the federal Pipeline Safety Act applying) would have an adverse effect on our financial position, our results of operations, our cash flows, and our distributions to our limited partners. These effects would be even greater in the event SFPP is unsuccessful in one or more of these litigations.	Since SFPP does not know UPRR’s plans for projects or other activities that would cause pipeline relocations, it is difficult to quantify the effects of the outcome of these cases on SFPP. Even if SFPP is successful in advancing its positions, significant relocations for which SFPP must nonetheless bear the expense (i.e., for railroad purposes, with the standards in the federal Pipeline Safety Act applying) would have an adverse effect on our financial position, our results of operations, our cash flows, and our distributions to our limited partners. These effects would be even greater in the event SFPP is unsuccessful in one or more of these litigations.
	Severstal Sparrows Point Crane Collapse	Severstal Sparrows Point Crane Collapse
	On June 4, 2008, a bridge crane owned by Severstal and located in Sparrows Point, Maryland collapsed while being operated by our subsidiary Kinder Morgan Bulk Terminals, Inc. (KMBT). According to KMP’s investigation, the collapse was caused by unexpected, sudden and extreme winds. On June 24, 2009, Severstal filed suit against KMBT in the U.S. District Court for the District of Maryland, Case No. 09CV1668-WMN. Severstal and its successor in interest, RG Steel, allege that KMBT was contractually obligated to replace the collapsed crane and that its employees were negligent in failing to properly secure the crane prior to the collapse. RG Steel seeks to recover in excess of $30 million for the alleged value of the crane and lost profits. KMBT denies each of RG Steel’s allegations. A bench trial occurred in November 2013 and we are awaiting the court’s decision.	On June 4, 2008, a bridge crane owned by Severstal and located in Sparrows Point, Maryland collapsed while being operated by our subsidiary Kinder Morgan Bulk Terminals, Inc. (KMBT). According to KMP’s investigation, the collapse was caused by unexpected, sudden and extreme winds. On June 24, 2009, Severstal filed suit against KMBT in the U.S. District Court for the District of Maryland, Case No. 09CV1668-WMN. Severstal and its successor in interest, RG Steel, allege that KMBT was contractually obligated to replace the collapsed crane and that its employees were negligent in failing to properly secure the crane prior to the collapse. RG Steel seeks to recover in excess of $30 million for the alleged value of the crane and lost profits. KMBT denies each of RG Steel’s allegations. A bench trial occurred in November 2013 and we are awaiting the court’s decision.
	Plains Gas Solutions, LLC v. Tennessee Gas Pipeline Company, L.L.C. et al	Plains Gas Solutions, LLC v. Tennessee Gas Pipeline Company, L.L.C. et al
	On October 16, 2013, Plains Gas Solutions, LLC (Plains) filed a petition in the 151st Judicial District Court for Harris County, Texas (Case No. 62528) against TGP, Kinetica Partners, LLC and two other Kinetica entities. The suit arises from the sale by TGP of the Cameron System in Louisiana to Kinetica Partners, LLC on September 1, 2013. Plains alleges that defendants breached a straddle agreement requiring that gas on the Cameron System be committed to Plains’ Grand Chenier gas-processing facility, that requisite daily volume reports were not provided, that TGP improperly assigned its obligations under the straddle agreement to Kinetica, and that defendants interfered with Plains’ contracts with producers. The petition alleges damages of at least $100 million. Under the Amended and Restated Purchase and Sale Agreement with Kinetica, Kinetica has agreed to indemnify TGP in connection with the gas commitment and reporting claims. We intend to vigorously defend the suit.	On October 16, 2013, Plains Gas Solutions, LLC (Plains) filed a petition in the 151st Judicial District Court for Harris County, Texas (Case No. 62528) against TGP, Kinetica Partners, LLC and two other Kinetica entities. The suit arises from the sale by TGP of the Cameron System in Louisiana to Kinetica Partners, LLC on September 1, 2013. Plains alleges that defendants breached a straddle agreement requiring that gas on the Cameron System be committed to Plains’ Grand Chenier gas-processing facility, that requisite daily volume reports were not provided, that TGP improperly assigned its obligations under the straddle agreement to Kinetica, and that defendants interfered with Plains’ contracts with producers. The petition alleges damages of at least $100 million. Under the Amended and Restated Purchase and Sale Agreement with Kinetica, Kinetica has agreed to indemnify TGP in connection with the gas commitment and reporting claims. We intend to vigorously defend the suit.
	Brinckerhoff v. El Paso Pipeline GP Company, LLC., et al.	Brinckerhoff v. El Paso Pipeline GP Company, LLC., et al.
	In December 2011 (Brinckerhoff I), March 2012, (Brinckerhoff II) and May 2013 (Brinckerhoff III) derivative lawsuits were filed in Delaware Chancery Court against EP, El Paso Pipeline GP Company, L.L.C., the general partner of EPB, and the directors of the general partner. EPB was named in these lawsuits as a “Nominal Defendant.” The lawsuits arise from the March 2010, November 2010 and May 2012 drop-down transactions involving EPB’s purchase of SLNG, Elba Express, CPG and interests in SNG and CIG. The lawsuits allege various conflicts of interest and that the consideration paid by EPB was excessive. Defendants’ motion to dismiss in Brinckerhoff I was denied in part. Brinckerhoff I and II have been consolidated into one proceeding. The parties’ motions for summary judgment filed by Plaintiff and Defendants are pending. A motion to dismiss has been filed in Brinckerhoff III. Defendants continue to believe that these actions are without merit and intend to defend against them vigorously.	In December 2011 (Brinckerhoff I), March 2012, (Brinckerhoff II) and May 2013 (Brinckerhoff III) derivative lawsuits were filed in Delaware Chancery Court against EP, El Paso Pipeline GP Company, L.L.C., the general partner of EPB, and the directors of the general partner. EPB was named in these lawsuits as a “Nominal Defendant.” The lawsuits arise from the March 2010, November 2010 and May 2012 drop-down transactions involving EPB’s purchase of SLNG, Elba Express, CPG and interests in SNG and CIG. The lawsuits allege various conflicts of interest and that the consideration paid by EPB was excessive. Defendants’ motion to dismiss in Brinckerhoff I was denied in part. Brinckerhoff I and II have been consolidated into one proceeding. The parties’ motions for summary judgment filed by Plaintiff and Defendants are pending. A motion to dismiss has been filed in Brinckerhoff III. Defendants continue to believe that these actions are without merit and intend to defend against them vigorously.
	Allen v. El Paso Pipeline GP Company, L.L.C., et al.	Allen v. El Paso Pipeline GP Company, L.L.C., et al.
	In May 2012, a unitholder of EPB filed a purported class action in Delaware Chancery Court, alleging both derivative and non derivative claims, against EPB, and EPB’s general partner and its board. EPB was named in the lawsuit as both a “Class Defendant” and a “Derivative Nominal Defendant.” The complaint alleges a breach of the duty of good faith and fair dealing in connection with the March 2011 sale to EPB of a 25% ownership interest in SNG. Defendants’ motion to dismiss was denied, and Defendants’ motion for summary judgment is pending. Defendants continue to believe this action is without merit, and intend to defend against it vigorously.	In May 2012, a unitholder of EPB filed a purported class action in Delaware Chancery Court, alleging both derivative and non derivative claims, against EPB, and EPB’s general partner and its board. EPB was named in the lawsuit as both a “Class Defendant” and a “Derivative Nominal Defendant.” The complaint alleges a breach of the duty of good faith and fair dealing in connection with the March 2011 sale to EPB of a 25% ownership interest in SNG. Defendants’ motion to dismiss was denied, and Defendants’ motion for summary judgment is pending. Defendants continue to believe this action is without merit, and intend to defend against it vigorously.
	Price Reporting Litigation	Price Reporting Litigation
	Beginning in 2003, several lawsuits were filed against El Paso Marketing L.P. (EPM) alleging that EP, EPM and other energy companies conspired to manipulate the price of natural gas by providing false price information to industry trade publications that published gas indices. Several of the cases have been settled or dismissed. The remaining cases, which were pending in Nevada federal court, were dismissed, but the dismissal was reversed by the 9th Circuit Court of Appeals. A petition for certiorari is pending before the U.S. Supreme Court. 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.	Beginning in 2003, several lawsuits were filed against El Paso Marketing L.P. (EPM) alleging that EP, EPM and other energy companies conspired to manipulate the price of natural gas by providing false price information to industry trade publications that published gas indices. Several of the cases have been settled or dismissed. The remaining cases, which were pending in Nevada federal court, were dismissed, but the dismissal was reversed by the 9th Circuit Court of Appeals. A petition for certiorari is pending before the U.S. Supreme Court. Although damages in excess of $140 million have been alleged in total against all defendants in one of the remaining lawsuits where a damage number is provided, there remains significant uncertainty regarding the validity of the causes of action, the damages asserted and the level of damages, if any, that may be allocated to us. Therefore, our costs and legal exposure related to the remaining outstanding lawsuits and claims are not currently determinable.
	Pipeline Integrity and Releases	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.	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	General
	As of December 31, 2013 and 2012, our total reserve for legal matters was $624 million and $425 million, respectively. The reserve primarily relates to various claims from regulatory proceedings arising from KMP’s products pipeline and natural gas pipeline transportation rates. The overall change in the reserve from December 31, 2012 was primarily due to increases in expense in 2013 associated with adjustments to interstate and California intrastate transportation rate case liabilities.	As of December 31, 2013 and 2012, our total reserve for legal matters was $624 million and $425 million, respectively. The reserve primarily relates to various claims from regulatory proceedings arising from KMP’s products pipeline and natural gas pipeline transportation rates. The overall change in the reserve from December 31, 2012 was primarily due to increases in expense in 2013 associated with adjustments to interstate and California intrastate transportation rate case liabilities.
	Other	Other
	Slotoroff v. Kinder Morgan, Inc., Kinder Morgan G.P., Inc., et al.	Slotoroff v. Kinder Morgan, Inc., Kinder Morgan G.P., Inc., et al.
	On February 5, 2014, a putative class action and derivative complaint was filed in the Court of Chancery in the State of Delaware (Case No. 9318) against defendants Kinder Morgan, Inc., Kinder Morgan G.P., Inc. and nominal defendant Kinder Morgan Energy Partners, L.P. The suit was filed by a purported unitholder of KMP and seeks to assert claims both individually and on behalf of a putative class consisting of all public holders of KMP units during the period of February 5, 2011 through the date of the filing of the suit. The suit alleges direct and derivative causes of action for breach of the Partnership Agreement, breach of the duty of good faith and fair dealing, aiding and abetting, and tortious interference. Among other things, the suit alleges that defendants made a bad faith allocation of capital expenditures to expansion capital expenditures rather than maintenance capital expenditures for the alleged purpose of “artificially” inflating KMP’s distributions and growth rate. The suit seeks disgorgement of any distributions to KMGP, KMI and any related entities, beyond amounts that would have been distributed in accordance with a “good faith” allocation of KMP’s maintenance capital expenses, together with other unspecified monetary damages including punitive damages and attorney fees. Defendants believe that this suit is without merit and intend to defend it vigorously.	On February 5, 2014, a putative class action and derivative complaint was filed in the Court of Chancery in the State of Delaware (Case No. 9318) against defendants Kinder Morgan, Inc., Kinder Morgan G.P., Inc. and nominal defendant Kinder Morgan Energy Partners, L.P. The suit was filed by a purported unitholder of KMP and seeks to assert claims both individually and on behalf of a putative class consisting of all public holders of KMP units during the period of February 5, 2011 through the date of the filing of the suit. The suit alleges direct and derivative causes of action for breach of the Partnership Agreement, breach of the duty of good faith and fair dealing, aiding and abetting, and tortious interference. Among other things, the suit alleges that defendants made a bad faith allocation of capital expenditures to expansion capital expenditures rather than maintenance capital expenditures for the alleged purpose of “artificially” inflating KMP’s distributions and growth rate. The suit seeks disgorgement of any distributions to KMGP, KMI and any related entities, beyond amounts that would have been distributed in accordance with a “good faith” allocation of KMP’s maintenance capital expenses, together with other unspecified monetary damages including punitive damages and attorney fees. Defendants believe that this suit is without merit and intend to defend it vigorously.
	Environmental 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 CO2 field and oil field operations, and there can be no assurance that we will not incur significant costs and liabilities. Moreover, it is possible that other developments, such as increasingly stringent environmental laws, regulations and enforcement policies under the terms of authority of those laws, and claims for damages to property or persons resulting from our operations, could result in substantial costs and liabilities to us.	We 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 CO2 field and oil field operations, and there can be no assurance that we will not incur significant costs and liabilities. Moreover, it is possible that other developments, such as increasingly stringent environmental laws, regulations and enforcement policies under the terms of authority of those laws, and claims for damages to property or persons resulting from our operations, could result in substantial costs and liabilities to us.
	We are currently involved in several governmental proceedings involving alleged violations of environmental and safety regulations. As we receive notices of non-compliance, we attempt to negotiate and settle such matters where appropriate. We do not believe that these alleged violations will have a material adverse effect on our business, financial position, results of operations or dividends to our shareholders.	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.	We are also currently involved in several governmental proceedings involving groundwater and soil remediation efforts under administrative orders or related state remediation programs. We have established a reserve to address the costs associated with the cleanup.
	In addition, we are involved with and have been identified as a potentially responsible party in several federal and state superfund sites. Environmental reserves have been established for those sites where our contribution is probable and reasonably estimable. In addition, we are from time to time involved in civil proceedings relating to damages alleged to have occurred as a result of accidental leaks or spills of refined petroleum products, NGL, natural gas and CO2.	In addition, we are involved with and have been identified as a potentially responsible party in several federal and state superfund sites. Environmental reserves have been established for those sites where our contribution is probable and reasonably estimable. In addition, we are from time to time involved in civil proceedings relating to damages alleged to have occurred as a result of accidental leaks or spills of refined petroleum products, NGL, natural gas and CO2.
	Colorado Oil and Gas Conservation Commission Inspections	Colorado Oil and Gas Conservation Commission Inspections
	In Fall 2012, the Colorado Oil and Gas Conservation Commission, referred to as COGCC, performed inspections at multiple well sites in Southwestern Colorado owned by KMCO2 and some of these inspections resulted in alleged violations of COGCC’s rules. KMCO2 took immediate steps to correct the alleged deficiencies and has engaged COGCC and other agencies in its efforts to maintain compliance. In June 2013, the parties settled the matter through an Administrative Order on Consent under which KMCO2 agreed to pay $220,000 of which up to $80,000 may be paid toward a public project. The agreed public project, has been completed and this matter is concluded.	In Fall 2012, the Colorado Oil and Gas Conservation Commission, referred to as COGCC, performed inspections at multiple well sites in Southwestern Colorado owned by KMCO2 and some of these inspections resulted in alleged violations of COGCC’s rules. KMCO2 took immediate steps to correct the alleged deficiencies and has engaged COGCC and other agencies in its efforts to maintain compliance. In June 2013, the parties settled the matter through an Administrative Order on Consent under which KMCO2 agreed to pay $220,000 of which up to $80,000 may be paid toward a public project. The agreed public project, has been completed and this matter is concluded.
	New Jersey Department of Environmental Protection v. Occidental Chemical Corporation, et al. (Defendants), Maxus Energy Corp. and Tierra Solutions, Inc. (Third Party Plaintiffs) v. 3M Company et al., Superior Court of New Jersey, Law Division - Essex County, Docket No. L-9868-05	New Jersey Department of Environmental Protection v. Occidental Chemical Corporation, et al. (Defendants), Maxus Energy Corp. and Tierra Solutions, Inc. (Third Party Plaintiffs) v. 3M Company et al., Superior Court of New Jersey, Law Division - Essex County, Docket No. L-9868-05
	The New Jersey Department of Environmental Protection (NJDEP) sued Occidental Chemical and others under the New Jersey Spill Act for contamination in the Newark Bay Complex including numerous waterways and rivers. In 2009, Occidental et al. asserted claims for contribution against approximately 300 third party defendants. NJDEP claimed damages related to 40 years of discharges of TCDD (a form of dioxin), DDT and “other hazardous substances.” GATX Terminals Corporation (n/k/a Kinder Morgan Liquids Terminals LLC) (KMLT) was named as a third party defendant because of the noted hazardous substances language and because the Carteret, New Jersey facility (a former GATX Terminals facility) is located on the Arthur Kill River, one of the waterways included in the litigation. KMLT, as part of a joint defense group, entered a settlement agreement (Consent Judgment) with the NJDEP whereby the settling parties for a prescribed payment, obtained a contribution bar against first party defendants Occidental, Maxus and Tierra in addition to a release of claims. The Consent Judgment was published in the New Jersey Register for a 60-day comment period and no significant comments were received. Additionally, the NJDEP reached a settlement agreement with Maxus and Tierra. Occidental is not part of the settlement. On December 12, 2013, the court approved the settlements between NJDEP and the third-party defendants and between NJDEP and the Maxus Tierra parties. Pursuant to the Consent Judgment, KMLT submitted its settlement payment by the January 27, 2014 deadline and is awaiting a court order formally dismissing KMLT from the litigation.	The New Jersey Department of Environmental Protection (NJDEP) sued Occidental Chemical and others under the New Jersey Spill Act for contamination in the Newark Bay Complex including numerous waterways and rivers. In 2009, Occidental et al. asserted claims for contribution against approximately 300 third party defendants. NJDEP claimed damages related to 40 years of discharges of TCDD (a form of dioxin), DDT and “other hazardous substances.” GATX Terminals Corporation (n/k/a Kinder Morgan Liquids Terminals LLC) (KMLT) was named as a third party defendant because of the noted hazardous substances language and because the Carteret, New Jersey facility (a former GATX Terminals facility) is located on the Arthur Kill River, one of the waterways included in the litigation. KMLT, as part of a joint defense group, entered a settlement agreement (Consent Judgment) with the NJDEP whereby the settling parties for a prescribed payment, obtained a contribution bar against first party defendants Occidental, Maxus and Tierra in addition to a release of claims. The Consent Judgment was published in the New Jersey Register for a 60-day comment period and no significant comments were received. Additionally, the NJDEP reached a settlement agreement with Maxus and Tierra. Occidental is not part of the settlement. On December 12, 2013, the court approved the settlements between NJDEP and the third-party defendants and between NJDEP and the Maxus Tierra parties. Pursuant to the Consent Judgment, KMLT submitted its settlement payment by the January 27, 2014 deadline and is awaiting a court order formally dismissing KMLT from the litigation.
	Portland Harbor Superfund Site, Willamette River, Portland, Oregon	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 leading to the proposed remedy for cleanup of the Portland Harbor site. Once the EPA determines the cleanup remedy from the remedial investigations and feasibility studies conducted during the last decade at the site, it will issue a Record of Decision. Currently, KMLT and 90 other parties are involved in an allocation process to determine each party’s respective share of the cleanup costs. This is a non-judicial allocation process. KMP is participating in the allocation process on behalf of both KMLT and KMBT. Each entity has two facilities located in Portland Harbor. KMP expects the allocation to conclude in 2014 and the EPA to issue its Record of Decision in 2015. It is anticipated that the cleanup activities will begin within one year of the issuance of the Record of Decision.	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 leading to the proposed remedy for cleanup of the Portland Harbor site. Once the EPA determines the cleanup remedy from the remedial investigations and feasibility studies conducted during the last decade at the site, it will issue a Record of Decision. Currently, KMLT and 90 other parties are involved in an allocation process to determine each party’s respective share of the cleanup costs. This is a non-judicial allocation process. KMP is participating in the allocation process on behalf of both KMLT and KMBT. Each entity has two facilities located in Portland Harbor. KMP expects the allocation to conclude in 2014 and the EPA to issue its Record of Decision in 2015. It is anticipated that the cleanup activities will begin within one year of the issuance of the Record of Decision.
	Roosevelt Irrigation District v. Kinder Morgan G.P., Inc., Kinder Morgan Energy Partners, L.P. , U.S. District Court, Arizona	Roosevelt Irrigation District v. Kinder Morgan G.P., Inc., Kinder Morgan Energy Partners, L.P. , U.S. District Court, Arizona
	This is a CERCLA case brought by a water purveyor whose wells have allegedly been contaminated due to the presence of a number of contaminants. The First Amended Complaint sought $175 million in damages against approximately 70 defendants. On August 6, 2013 plaintiffs filed its Second Amended Complaint (SAC) seeking monetary damages in unspecified amounts and reducing the number of defendants to 26 including KMEP and SFPP. The claims now presented in the SAC against KMEP and SFPP are related to alleged releases from a specific parcel within the SFPP Phoenix Terminal and the alleged impact of such releases on water wells owned by the plaintiffs and located in the vicinity of the Terminal. On October 24, 2013, we moved to dismiss the SAC.	This is a CERCLA case brought by a water purveyor whose wells have allegedly been contaminated due to the presence of a number of contaminants. The First Amended Complaint sought $175 million in damages against approximately 70 defendants. On August 6, 2013 plaintiffs filed its Second Amended Complaint (SAC) seeking monetary damages in unspecified amounts and reducing the number of defendants to 26 including KMEP and SFPP. The claims now presented in the SAC against KMEP and SFPP are related to alleged releases from a specific parcel within the SFPP Phoenix Terminal and the alleged impact of such releases on water wells owned by the plaintiffs and located in the vicinity of the Terminal. On October 24, 2013, we moved to dismiss the SAC.
	The City of Los Angeles v. Kinder Morgan Liquids Terminals, LLC, Shell Oil Company, Equilon Enterprises LLC; California Superior Court, County of Los Angeles, Case No. NC041463	The City of Los Angeles v. Kinder Morgan Liquids Terminals, LLC, Shell Oil Company, Equilon Enterprises LLC; California Superior Court, County of Los Angeles, Case No. NC041463
	KMLT was a defendant in a lawsuit filed in 2005 alleging claims for environmental cleanup costs at the former Los Angeles Marine Terminal in the Port of Los Angeles. On April 9, 2013, KMLT and the Port of Los Angeles entered into a Settlement and Release Agreement the terms of which provide for the dismissal of the litigation by the Port and KMLT’s agreement to pay 60% of the Port’s costs to remediate the former terminal site up to a $15 million cap. Further, according to terms of the Settlement and Release, KMP received a 5-year lease extension that allows KMLT to continue fuel loading and offloading operations at another KMLT Port of Los Angeles terminal property. The Court approved the parties’ Good Faith Settlement motion in the Superior Court and dismissed the case.	KMLT was a defendant in a lawsuit filed in 2005 alleging claims for environmental cleanup costs at the former Los Angeles Marine Terminal in the Port of Los Angeles. On April 9, 2013, KMLT and the Port of Los Angeles entered into a Settlement and Release Agreement the terms of which provide for the dismissal of the litigation by the Port and KMLT’s agreement to pay 60% of the Port’s costs to remediate the former terminal site up to a $15 million cap. Further, according to terms of the Settlement and Release, KMP received a 5-year lease extension that allows KMLT to continue fuel loading and offloading operations at another KMLT Port of Los Angeles terminal property. The Court approved the parties’ Good Faith Settlement motion in the Superior Court and dismissed the case.
	The City of Los Angeles, KMLT, Chevron and Phillips 66 remain named on a Cleanup and Abatement Order from the California Regional Water Quality Control Board as parties responsible for the cleanup of the former Los Angeles Marine Terminal. The private parties have all settled with the City of Los Angeles and agreed to pay a percentage of the City’s costs to perform the required cleanup at the site.We anticipate that cleanup activities by the Port will begin within the first quarter of 2014.	The City of Los Angeles, KMLT, Chevron and Phillips 66 remain named on a Cleanup and Abatement Order from the California Regional Water Quality Control Board as parties responsible for the cleanup of the former Los Angeles Marine Terminal. The private parties have all settled with the City of Los Angeles and agreed to pay a percentage of the City’s costs to perform the required cleanup at the site.We anticipate that cleanup activities by the Port will begin within the first quarter of 2014.
	Exxon Mobil Corporation v. GATX Corporation, Kinder Morgan Liquids Terminals, LLC and ST Services, Inc.	Exxon Mobil Corporation v. GATX Corporation, Kinder Morgan Liquids Terminals, LLC and ST Services, Inc.
	On April 23, 2003, ExxonMobil filed a complaint in the Superior Court of New Jersey, Gloucester County. The lawsuit relates to environmental remediation obligations at a Paulsboro, New Jersey liquids terminal owned by ExxonMobil from the mid-1950s through November 1989, by GATX Terminals Corporation from 1989 through September 2000, and later owned by Support Terminals and Pacific Atlantic Terminals, LLC. The terminal is now owned by Plains Products, which is also a party to the lawsuit.	On April 23, 2003, ExxonMobil filed a complaint in the Superior Court of New Jersey, Gloucester County. The lawsuit relates to environmental remediation obligations at a Paulsboro, New Jersey liquids terminal owned by ExxonMobil from the mid-1950s through November 1989, by GATX Terminals Corporation from 1989 through September 2000, and later owned by Support Terminals and Pacific Atlantic Terminals, LLC. The terminal is now owned by Plains Products, which is also a party to the lawsuit.
	On June 25, 2007, the NJDEP, the Commissioner of the New Jersey Department of Environmental Protection and the Administrator of the New Jersey Spill Compensation Fund, referred to collectively as the plaintiffs, filed a complaint against ExxonMobil and KMLT, formerly known as GATX Terminals Corporation, alleging natural resource damages related to historic contamination at the Paulsboro terminal. The complaint was filed in Gloucester County, New Jersey. Both ExxonMobil and KMLT filed third party complaints against Support Terminals/Plains. The court consolidated the two cases.	On June 25, 2007, the NJDEP, the Commissioner of the New Jersey Department of Environmental Protection and the Administrator of the New Jersey Spill Compensation Fund, referred to collectively as the plaintiffs, filed a complaint against ExxonMobil and KMLT, formerly known as GATX Terminals Corporation, alleging natural resource damages related to historic contamination at the Paulsboro terminal. The complaint was filed in Gloucester County, New Jersey. Both ExxonMobil and KMLT filed third party complaints against Support Terminals/Plains. The court consolidated the two cases.
	In mid 2011, KMLT and Plains Products entered into a settlement agreement and subsequent Consent Judgment with the NJDEP which resolved the state’s alleged natural resource damages claim. The natural resource damage settlement includes a monetary award of $1 million and a series of remediation and restoration activities at the terminal site. KMLT and Plains Products have joint responsibility for this settlement. Simultaneously, KMLT and Plains Products entered into an agreement that settled each party’s relative share of responsibility (50/50) to the NJDEP under the Consent Judgment noted above. The Consent Judgment is now entered with the Court and the settlement is final. According to the agreement, Plains will conduct remediation activities at the site and KMLT will provide oversight and 50% of the costs. We anticipate remediation activities to begin by second quarter 2014.	In mid 2011, KMLT and Plains Products entered into a settlement agreement and subsequent Consent Judgment with the NJDEP which resolved the state’s alleged natural resource damages claim. The natural resource damage settlement includes a monetary award of $1 million and a series of remediation and restoration activities at the terminal site. KMLT and Plains Products have joint responsibility for this settlement. Simultaneously, KMLT and Plains Products entered into an agreement that settled each party’s relative share of responsibility (50/50) to the NJDEP under the Consent Judgment noted above. The Consent Judgment is now entered with the Court and the settlement is final. According to the agreement, Plains will conduct remediation activities at the site and KMLT will provide oversight and 50% of the costs. We anticipate remediation activities to begin by second quarter 2014.
	The settlement with the state did not resolve the original complaint brought by ExxonMobil. On or around, April 10, 2013, KMLT, Plains and ExxonMobil settled the original Exxon complaint for past remediation costs for $750,000 to be split 50/50 between KMLT and Plains. All parties have now executed the agreement and the litigation is settled and dismissed.	The settlement with the state did not resolve the original complaint brought by ExxonMobil. On or around, April 10, 2013, KMLT, Plains and ExxonMobil settled the original Exxon complaint for past remediation costs for $750,000 to be split 50/50 between KMLT and Plains. All parties have now executed the agreement and the litigation is settled and dismissed.
Mission Valley Terminal Lawsuit	Mission Valley Terminal Lawsuit
In August 2007, the City of San Diego, on its own behalf and purporting to act on behalf of the People of the State of California, filed a lawsuit against KMP and several affiliates seeking injunctive relief and unspecified damages allegedly resulting from hydrocarbon and methyl tertiary butyl ether (MTBE) impacted soils and groundwater beneath the City’s stadium property in San Diego arising from historic operations at the Mission Valley terminal facility. The case was filed in the Superior Court of California, San Diego County, case number 37-2007-00073033-CU-OR-CTL. On September 26, 2007, KMP removed the case to the U.S. District Court, Southern District of California, case number 07CV1883WCAB. The City disclosed in discovery that it is seeking approximately $170 million in damages for alleged lost value/lost profit from the redevelopment of the City’s property and alleged lost use of the water resources underlying the property. Later, in 2010, the City amended its initial disclosures to add claims for restoration of the site as well as a number of other claims that increased their claim for damages to approximately $365 million.	In August 2007, the City of San Diego, on its own behalf and purporting to act on behalf of the People of the State of California, filed a lawsuit against KMP and several affiliates seeking injunctive relief and unspecified damages allegedly resulting from hydrocarbon and methyl tertiary butyl ether (MTBE) impacted soils and groundwater beneath the City’s stadium property in San Diego arising from historic operations at the Mission Valley terminal facility. The case was filed in the Superior Court of California, San Diego County, case number 37-2007-00073033-CU-OR-CTL. On September 26, 2007, KMP removed the case to the U.S. District Court, Southern District of California, case number 07CV1883WCAB. The City disclosed in discovery that it is seeking approximately $170 million in damages for alleged lost value/lost profit from the redevelopment of the City’s property and alleged lost use of the water resources underlying the property. Later, in 2010, the City amended its initial disclosures to add claims for restoration of the site as well as a number of other claims that increased their claim for damages to approximately $365 million.
On November 29, 2012, the Court issued a Notice of Tentative Rulings on the parties’ summary adjudication motions. The Court tentatively granted our partial motions for summary judgment on the City’s claims for water and real estate damages and the State’s claims for violations of California Business and Professions Code § 17200, tentatively denied the City’s motion for summary judgment on its claims of liability for nuisance and trespass, and tentatively granted our cross motion for summary judgment on such claims. On January 25, 2013, the Court issued its final order reaffirming in all respects its tentative rulings and rendered judgment in favor of all defendants on all claims asserted by the City.	On November 29, 2012, the Court issued a Notice of Tentative Rulings on the parties’ summary adjudication motions. The Court tentatively granted our partial motions for summary judgment on the City’s claims for water and real estate damages and the State’s claims for violations of California Business and Professions Code § 17200, tentatively denied the City’s motion for summary judgment on its claims of liability for nuisance and trespass, and tentatively granted our cross motion for summary judgment on such claims. On January 25, 2013, the Court issued its final order reaffirming in all respects its tentative rulings and rendered judgment in favor of all defendants on all claims asserted by the City.
On February 20, 2013, the City of San Diego filed a notice of appeal of this case to the U.S. Court of Appeals for the Ninth Circuit. The appeal is currently pending.	On February 20, 2013, the City of San Diego filed a notice of appeal of this case to the U.S. Court of Appeals for the Ninth Circuit. The appeal is currently pending.
This site has been, and currently is, under the regulatory oversight and order of the California Regional Water Quality Control Board. SFPP continues to conduct an extensive remediation effort at the City’s stadium property site.	This site has been, and currently is, under the regulatory oversight and order of the California Regional Water Quality Control Board. SFPP continues to conduct an extensive remediation effort at the City’s stadium property site.
On May 7, 2013, the City of San Diego filed a writ of mandamus to the California Superior Court seeking an order from the Court setting aside the California Regional Water Quality Control Board’s (RWQCB) approval of KMP’s permit request to increase the discharge of water from KMP’s groundwater treatment system to the City of San Diego’s municipal storm sewer system. KMEP is coordinating with the RWQCB to oppose the City’s writ.	On May 7, 2013, the City of San Diego filed a writ of mandamus to the California Superior Court seeking an order from the Court setting aside the California Regional Water Quality Control Board’s (RWQCB) approval of KMP’s permit request to increase the discharge of water from KMP’s groundwater treatment system to the City of San Diego’s municipal storm sewer system. KMEP is coordinating with the RWQCB to oppose the City’s writ.
Uranium Mines in Vicinity of Cameron, Arizona	Uranium Mines in Vicinity of Cameron, Arizona
In the 1950s and 1960s, Rare Metals Inc., an historical subsidiary of EPNG, operated approximately twenty uranium mines in the vicinity of Cameron, Arizona, many of which are located on the Navajo Indian Reservation. The mining activities were in response to numerous incentives provided to industry by the U.S. to locate and produce domestic sources of uranium to support the Cold War-era nuclear weapons program. In May 2012, EPNG received a general notice letter from the EPA notifying EPNG of the EPA’s investigation of certain sites and its determination that the EPA considers EPNG to be a potentially responsible party within the meaning of CERCLA. In August 2013, EPNG and the EPA entered into an Administrative Order on Consent and Scope of Work pursuant to which EPNG will conduct a radiological assessment of the surface of the mines. We are also seeking contribution from the applicable federal government agencies toward the cost of environmental activities associated with the mines, given their pervasive control over all aspects of the nuclear weapons program.	In the 1950s and 1960s, Rare Metals Inc., an historical subsidiary of EPNG, operated approximately twenty uranium mines in the vicinity of Cameron, Arizona, many of which are located on the Navajo Indian Reservation. The mining activities were in response to numerous incentives provided to industry by the U.S. to locate and produce domestic sources of uranium to support the Cold War-era nuclear weapons program. In May 2012, EPNG received a general notice letter from the EPA notifying EPNG of the EPA’s investigation of certain sites and its determination that the EPA considers EPNG to be a potentially responsible party within the meaning of CERCLA. In August 2013, EPNG and the EPA entered into an Administrative Order on Consent and Scope of Work pursuant to which EPNG will conduct a radiological assessment of the surface of the mines. We are also seeking contribution from the applicable federal government agencies toward the cost of environmental activities associated with the mines, given their pervasive control over all aspects of the nuclear weapons program.
PHMSA Inspection of Carteret Terminal, Carteret, NJ	PHMSA Inspection of Carteret Terminal, Carteret, NJ
On April 4, 2013, the PHMSA, Office of Pipeline Safety issued a Notice of Probable Violation, Proposed Civil Penalty and Proposed Compliance Order (NOPV) arising from an inspection at the KMLT, Carteret, New Jersey location on March 15, 2011 following a release and fire that occurred during maintenance activity on March 14, 2011. On July 17, 2013, KMLT entered into a Consent Agreement and Order with the PHMSA, pursuant to which KMLT paid a penalty of $63,100 and is required to complete ongoing pipeline integrity testing and other corrective measures by May, 2015.	On April 4, 2013, the PHMSA, Office of Pipeline Safety issued a Notice of Probable Violation, Proposed Civil Penalty and Proposed Compliance Order (NOPV) arising from an inspection at the KMLT, Carteret, New Jersey location on March 15, 2011 following a release and fire that occurred during maintenance activity on March 14, 2011. On July 17, 2013, KMLT entered into a Consent Agreement and Order with the PHMSA, pursuant to which KMLT paid a penalty of $63,100 and is required to complete ongoing pipeline integrity testing and other corrective measures by May, 2015.
Southeast Louisiana Flood Protection Litigation	Southeast Louisiana Flood Protection Litigation
On July 24, 2013, the Board of Commissioners of the Southeast Louisiana Flood Protection Authority - East (Flood Protection Authority) filed a petition for damages and injunctive relief in state district court for Orleans Parish, Louisiana (Case No. 13-6911) against TGP, SNG and approximately one hundred other energy companies, alleging that defendants’ drilling, dredging, pipeline and industrial operations since the 1930’s have caused direct land loss and increased erosion and submergence resulting in alleged increased storm surge risk, increased flood protection costs and unspecified damages to the plaintiff. The Flood Protection Authority asserts claims for negligence, strict liability, public nuisance, private nuisance, and breach of contract. Among other relief, the petition seeks unspecified monetary damages, attorney fees, interest, and injunctive relief in the form of abatement and restoration of the alleged coastal land loss including but not limited to backfilling and re-vegetation of canals, wetlands and reef creation, land bridge construction, hydrologic restoration, shoreline protection, structural protection, and bank stabilization. On August 13, 2013, the suit was removed to the U.S. District Court for the Eastern District of Louisiana. On September 10, 2013, the Flood Protection Authority filed a motion to remand the case to the state district court for Orleans Parish. On December 18, 2013, a hearing was conducted on the remand motion and it remains under consideration by the court.	On July 24, 2013, the Board of Commissioners of the Southeast Louisiana Flood Protection Authority - East (Flood Protection Authority) filed a petition for damages and injunctive relief in state district court for Orleans Parish, Louisiana (Case No. 13-6911) against TGP, SNG and approximately one hundred other energy companies, alleging that defendants’ drilling, dredging, pipeline and industrial operations since the 1930’s have caused direct land loss and increased erosion and submergence resulting in alleged increased storm surge risk, increased flood protection costs and unspecified damages to the plaintiff. The Flood Protection Authority asserts claims for negligence, strict liability, public nuisance, private nuisance, and breach of contract. Among other relief, the petition seeks unspecified monetary damages, attorney fees, interest, and injunctive relief in the form of abatement and restoration of the alleged coastal land loss including but not limited to backfilling and re-vegetation of canals, wetlands and reef creation, land bridge construction, hydrologic restoration, shoreline protection, structural protection, and bank stabilization. On August 13, 2013, the suit was removed to the U.S. District Court for the Eastern District of Louisiana. On September 10, 2013, the Flood Protection Authority filed a motion to remand the case to the state district court for Orleans Parish. On December 18, 2013, a hearing was conducted on the remand motion and it remains under consideration by the court.
Plaquemines Parish Louisiana Coastal Zone Litigation	Plaquemines Parish Louisiana Coastal Zone Litigation
On November 8, 2013, the Parish of Plaquemines, Louisiana filed a petition for damages in the state district court for Plaquemines Parish, Louisiana (Docket No. 60-999) against TGP and 17 other energy companies, alleging that defendants’ oil and gas exploration, production and transportation operations in the Bastian Bay, Buras, Empire and Fort Jackson oil and gas fields of Plaquemines Parish caused substantial damage to the coastal waters and nearby lands (Coastal Zone) within the Parish, including the erosion of marshes and the discharge of oil waste and other pollutants which detrimentally affected the quality of state waters and plant and animal life, in violation of the State and Local Coastal Resources Management Act of 1978 (Coastal Zone Management Act). As a result of such alleged violations of the Coastal Zone Management Act, Plaquemines Parish seeks, among other relief, unspecified monetary relief, attorney fees, interest, and payment of costs necessary to restore the allegedly affected Coastal Zone to its original condition, including costs to clear, vegetate and detoxify the Coastal Zone. On December 18, 2013, defendants removed the case to the U.S. District Court for the Eastern District of Louisiana. On January 14, 2014, the plaintiff filed a motion to remand the case to state court and such motion remains pending.	On November 8, 2013, the Parish of Plaquemines, Louisiana filed a petition for damages in the state district court for Plaquemines Parish, Louisiana (Docket No. 60-999) against TGP and 17 other energy companies, alleging that defendants’ oil and gas exploration, production and transportation operations in the Bastian Bay, Buras, Empire and Fort Jackson oil and gas fields of Plaquemines Parish caused substantial damage to the coastal waters and nearby lands (Coastal Zone) within the Parish, including the erosion of marshes and the discharge of oil waste and other pollutants which detrimentally affected the quality of state waters and plant and animal life, in violation of the State and Local Coastal Resources Management Act of 1978 (Coastal Zone Management Act). As a result of such alleged violations of the Coastal Zone Management Act, Plaquemines Parish seeks, among other relief, unspecified monetary relief, attorney fees, interest, and payment of costs necessary to restore the allegedly affected Coastal Zone to its original condition, including costs to clear, vegetate and detoxify the Coastal Zone. On December 18, 2013, defendants removed the case to the U.S. District Court for the Eastern District of Louisiana. On January 14, 2014, the plaintiff filed a motion to remand the case to state court and such motion remains pending.
Pennsylvania Department of Environmental Protection Notice of Alleged Violations	Pennsylvania Department of Environmental Protection Notice of Alleged Violations
The Pennsylvania Department of Environmental Protection (PADEP) has notified TGP of alleged violations of certain conditions to the construction permits issued to TGP for the construction of TGP’s 300 Line Project in 2011. The alleged violations arise from field inspections performed during construction by county conservation districts, as delegates of the PADEP, and generally involve the alleged failure by TGP to implement and maintain best practices to achieve sufficient erosion and sediment controls, stabilization of the right of way, and prevention of potential discharge of sediment into the waters of the commonwealth during construction and before placing the line into service. To resolve such alleged violations, the PADEP initially proposed a collective penalty of approximately $1.5 million. TGP and the PADEP are seeking to reach a mutually agreeable resolution of the alleged notices of violations, including an agreed penalty amount.	The Pennsylvania Department of Environmental Protection (PADEP) has notified TGP of alleged violations of certain conditions to the construction permits issued to TGP for the construction of TGP’s 300 Line Project in 2011. The alleged violations arise from field inspections performed during construction by county conservation districts, as delegates of the PADEP, and generally involve the alleged failure by TGP to implement and maintain best practices to achieve sufficient erosion and sediment controls, stabilization of the right of way, and prevention of potential discharge of sediment into the waters of the commonwealth during construction and before placing the line into service. To resolve such alleged violations, the PADEP initially proposed a collective penalty of approximately $1.5 million. TGP and the PADEP are seeking to reach a mutually agreeable resolution of the alleged notices of violations, including an agreed penalty amount.
General	General
Although it is not possible to predict the ultimate outcomes, we believe that the resolution of the environmental matters set forth in this note, and other matters to which we and our subsidiaries are a party, will not have a material adverse effect on our business, financial position, results of operations or cash flows. As of December 31, 2013 and 2012, we have accrued a total reserve for environmental liabilities in the amount of $378 million and $421 million, respectively, of which $208 million and $253 million, respectively, are associated with KMI (excluding KMP and EPB) and primarily relate to legacy sites acquired in the May 25, 2012 EP acquisition. In addition, as of December 31, 2013 and December 31, 2012, we have recorded a receivable of $14 million and $22 million, respectively, for expected cost recoveries that have been deemed probable.	Although it is not possible to predict the ultimate outcomes, we believe that the resolution of the environmental matters set forth in this note, and other matters to which we and our subsidiaries are a party, will not have a material adverse effect on our business, financial position, results of operations or cash flows. As of December 31, 2013 and 2012, we have accrued a total reserve for environmental liabilities in the amount of $378 million and $421 million, respectively, of which $208 million and $253 million, respectively, are associated with KMI (excluding KMP and EPB) and primarily relate to legacy sites acquired in the May 25, 2012 EP acquisition. In addition, as of December 31, 2013 and December 31, 2012, we have recorded a receivable of $14 million and $22 million, respectively, for expected cost recoveries that have been deemed probable.

Reconciliation_of_Significant_

Reconciliation of Significant Asset and Liabilities Balances (Notes)	12 Months Ended
	Dec. 31, 2013
Balance Sheet Related Disclosures [Abstract]	'
Reconciliation of Significant Asset Balances	'
	Reconciliation of Significant Asset and Liability Balances
	The following is a reconciliation between KMP’s and EPB’s significant asset balances as reported in KMP’s and EPB’s Annual Report on Form 10-K as of December 31, 2013 and 2012 and our consolidated asset balances as shown on our accompanying consolidated balance sheets (in millions):
		December 31,
		2013		2012
	Cash and cash equivalents - KMI(a)	$	116	$	71
	Cash and cash equivalents - KMP	404		529
	Cash and cash equivalents - EPB	78		114
	Cash and cash equivalents	$	598	$	714
	Property, plant and equipment, net–KMI(a)	$	2,563	$	2,735
	Property, plant and equipment, net–KMP	27,405		22,330
	Property, plant and equipment, net–EPB	5,879		5,931
	Property, plant and equipment, net	$	35,847	$	30,996
	Goodwill–KMI(a)	$	17,935	$	18,193
	Goodwill–KMP	6,547		5,417
	Goodwill–EPB	22		22
	Goodwill	$	24,504	$	23,632
	Current portion of debt–KMI(a)	$	725	$	1,153
	Current portion of debt–KMP	1,504		1,155
	Current portion of debt–EPB	77		93
	Current portion of debt	$	2,306	$	2,401
	Long-term debt outstanding–KMI(a)	$	9,221	$	9,148
	Long-term debt outstanding–KMP	18,410		15,907
	Long-term debt outstanding–EPB(b)	4,179		4,254
	Long-term debt outstanding	$	31,810	$	29,309
	_______
	(a)	Includes assets and liabilities of KMI’s consolidated subsidiaries, excluding KMP and EPB.
	(b)	Excludes debt fair value adjustments.  Decrease to long-term debt for debt fair value adjustments totaled $8 million as of both December 31, 2013 and 2012.

Guarantee_of_Securities_of_Sub

Guarantee of Securities of Subsidiaries (Notes)	12 Months Ended
	Dec. 31, 2013
Guarantee of Securities of Subsidiaries [Abstract]	'
Guarantees [Text Block]	'
	Guarantee of Securities of Subsidiaries
	KMI had guaranteed the payment of the outstanding senior notes issued by El Paso LLC (formerly known as El Paso Corporation) as a result of the EP acquisition. These notes were also guaranteed by El Paso Holdco LLC (“El Paso Holdco”), El Paso LLC’s direct parent. El Paso Issuing Corporation (“Finance Corp”), a direct subsidiary of El Paso LLC, is the co-issuer of these notes. The aggregate principal amount of these series of El Paso LLC senior notes are referred to as the “Guaranteed Notes”. On October 3, 2013, El Paso LLC transferred substantially all of its assets to El Paso Holdco pursuant to an internal restructuring transaction. In connection with such internal restructuring, El Paso Holdco succeeded El Paso LLC as issuer with respect to the Guaranteed Notes, and El Paso LLC ceased to be an obligor with respect to the Guaranteed Notes. Prior to the internal restructuring, El Paso Holdco had been presented as the “Guarantor Subsidiary” and is now presented as one of the “Subsidiary Issuers.” KMI continues to guarantee the payment of the Guaranteed Notes. Finance Corp’s obligations as a co-issuer and primary obligor continue to be joint and several with the obligations of El Paso Holdco as issuer. As of both December 31, 2013, and 2012, approximately $3.8 billion and $3.9 billion, respectively, of these guaranteed notes are outstanding. Subject to the limitations set forth in the applicable supplemental indentures, the guarantee of KMI is full and unconditional and joint and several, and guarantee the Guaranteed Notes through their respective maturity dates, the latest of which is in 2037. Finance Corp has no subsidiaries and no independent assets or operations. A significant amount of KMI’s income and cash flow are generated by its subsidiaries. As a result, the funds necessary to meet KMI’s debt service and/or guarantee obligations are provided in large part by distributions or advances from its subsidiaries. Included among the non-guarantor subsidiaries are KMP, KMR and EPB, along with KMGP, the general partner of KMP and El Paso Pipeline GP Company, L.L.C., the general partner of EPB. In the following condensed consolidating financial information, KMI is “Parent Guarantor,” and El Paso Holdco and Finance Corp are the “Subsidiary Issuers.” Both of the Subsidiary Issuers are 100% owned by KMI.
	The condensed consolidating financial information for all periods presented below reflect the internal restructuring transaction described above.
	Condensed Consolidating Balance Sheets as of December 31, 2013
	(In Millions)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	ASSETS
	Cash and cash equivalents	$	83		$	—		$	515		$	—		$	598
	All other current assets	945			38			2,763			(476		)	3,270
	Property, plant and equipment, net	10			—			35,837			—			35,847
	Investments	—			—			5,951			—			5,951
	Investments in subsidiaries	20,336			6,651			—			(26,987		)	—
	Goodwill	—			8,062			16,442			—			24,504
	Notes receivable from affiliates	—			—			1,993			(1,993		)	—
	Deferred charges and all other assets	227			841			4,759			(812		)	5,015
	Total assets	$	21,601		$	15,592		$	68,260		$	(30,268	)	$	75,185
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Liabilities
	Current portion of debt	$	175		$	400		$	1,731		$	—		$	2,306
	All other current liabilities	228			135			3,882			(476		)	3,769
	Long-term debt	3,371			3,999			26,517			—			33,887
	Notes payable to affiliates	1,993			—			—			(1,993		)	—
	Deferred income taxes	2,426			—			3,037			(812		)	4,651
	All other long-term liabilities	315			69			1,903			—			2,287
	Total liabilities	8,508			4,603			37,070			(3,281		)	46,900
	Stockholders’ equity
	Total KMI equity	13,093			10,989			15,596			(26,585		)	13,093
	Noncontrolling interests	—			—			15,594			(402		)	15,192
	Total stockholders’ equity	13,093			10,989			31,190			(26,987		)	28,285
	Total liabilities and stockholders’ equity	$	21,601		$	15,592		$	68,260		$	(30,268	)	$	75,185
	Condensed Consolidating Balance Sheets as of December 31, 2012
	(In Millions)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	ASSETS
	Cash and cash equivalents	$	3		$	45		$	666		$	—		$	714
	All other current assets	813			51			9,322			(7,226		)	2,960
	Property, plant and equipment, net	8			—			30,988			—			30,996
	Investments	—			19			5,785			—			5,804
	Investments in subsidiaries	20,053			13,501			—			(33,554		)	—
	Goodwill	—			8,059			15,573			—			23,632
	Notes receivable from affiliates	1,555			—			2,095			(3,650		)	—
	Deferred charges and all other assets	202			879			3,914			(856		)	4,139
	Total assets	$	22,634		$	22,554		$	68,343		$	(45,286	)	$	68,245
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Liabilities
	Current portion of debt	$	1,035		$	115		$	1,251		$	—		$	2,401
	All other current liabilities	196			7,024			2,833			(7,226		)	2,827
	Long-term debt	3,068			4,378			24,554			—			32,000
	Notes payable to affiliates	1,764			331			1,555			(3,650		)	—
	Deferred income taxes	2,095			—			2,832			(856		)	4,071
	All other long-term liabilities	610			169			2,067			—			2,846
	Total liabilities	8,768			12,017			35,092			(11,732		)	44,145
	Stockholders’ equity
	Total KMI equity	13,866			10,537			22,858			(33,395		)	13,866
	Noncontrolling interests	—			—			10,393			(159		)	10,234
	Total stockholders’ equity	13,866			10,537			33,251			(33,554		)	24,100
	Total liabilities and stockholders’ equity	$	22,634		$	22,554		$	68,343		$	(45,286	)	$	68,245
	Condensed Consolidating Statements of Income for the Year Ended December 31, 2013
	(In Millions)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Revenues	$	36		$	—		$	14,066		$	(32	)	$	14,070
	Costs, expenses and other
	Costs of sales	—			—			5,253			—			5,253
Depreciation, depletion and amortization	1			—			1,805			—			1,806
Other operating expenses	20			(3		)	3,036			(32		)	3,021
Total costs, expenses and other	21			(3		)	10,094			(32		)	10,080
Operating income	15			3			3,972			—			3,990
Other income (expense)
Earnings from equity investments	1,386			553			327			(1,939		)	327
Interest, net	(262		)	(305		)	(1,108		)	—			(1,675		)
Amortization of excess cost of equity investments and other, net	—			—			796			—			796
Income from continuing operations before income taxes	1,139			251			3,987			(1,939		)	3,438
Income tax benefit (expense)	54			89			(885		)	—			(742		)
Income from continuing operations	1,193			340			3,102			(1,939		)	2,696
Loss from discontinued operations, net of tax	—			—			(4		)	—			(4		)
Net income	1,193			340			3,098			(1,939		)	2,692
Net income attributable to noncontrolling interests	—			—			(1,595		)	96			(1,499		)
Net income attributable to controlling interests	$	1,193		$	340		$	1,503		$	(1,843	)	$	1,193
Condensed Consolidating Statements of Income for the Year Ended December 31, 2012
(In Millions)
	Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Revenues	$	35		$	—		$	9,938		$	—		$	9,973
Costs, expenses and other
Costs of sales	—			—			3,057			—			3,057
Depreciation, depletion and amortization	—			—			1,419			—			1,419
Other operating expenses	232			62			2,610			—			2,904
Total costs, expenses and other	232			62			7,086			—			7,380
Operating (loss) income	(197		)	(62		)	2,852			—			2,593
Other income (expense)
Earnings from equity investments	123			276			153			(399		)	153
Interest, net	(381		)	(265		)	(753		)	—			(1,399		)
Amortization of excess cost of equity investments and other, net	(1		)	—			(3		)	—			(4		)
(Loss) income from continuing operations before income taxes	(456		)	(51		)	2,249			(399		)	1,343
Income tax benefit (expense)	771			(380		)	(530		)	—			(139		)
													—
Income (loss) from continuing operations	315			(431		)	1,719			(399		)	1,204
Loss from discontinued operations, net of tax	—			—			(777		)	—			(777		)
Net income (loss)	315			(431		)	942			(399		)	427
Net income attributable to noncontrolling interests	—			—			(109		)	(3		)	(112		)
Net income (loss) attributable to controlling interests	$	315		$	(431	)	$	833		$	(402	)	$	315
Condensed Consolidating Statements of Income for the Year Ended December 31, 2011
(In Millions)
	Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Revenues	$	36		$	—		$	7,907		$	—		$	7,943
Costs, expenses and other
Costs of sales	—			—			3,278			—			3,278
Depreciation, depletion and amortization	—			—			1,068			—			1,068
Other operating expenses	42			—			2,132			—			2,174
Total costs, expenses and other	42			—			6,478			—			6,520
Operating (loss) income	(6		)	—			1,429			—			1,423
Other income (expense)
Earnings from equity investments	712			—			226			(712		)	226
Interest, net	(187		)	—			(495		)	—			(682		)
Amortization of excess cost of equity investments and other, net	(1		)	—			(156		)	—			(157		)
Income from continuing operations before income taxes	518			—			1,004			(712		)	810
Income tax benefit (expense)	68			—			(429		)	—			(361		)
Income from continuing operations	586			—			575			(712		)	449
Income from discontinued operations, net of tax	8			—			203			—			211
Net income	594			—			778			(712		)	660
Net income attributable to noncontrolling interests	—			—			(71		)	5			(66		)
Net income attributable to controlling interests	$	594		$	—		$	707		$	(707	)	$	594
Condensed Consolidating Statements of Comprehensive Income for the Year Ended December 31, 2013
(In Millions)
	Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Net Income	$	1,193		$	340		$	3,098		$	(1,939	)	$	2,692
Other comprehensive income (loss), net of tax
Change in fair value of derivatives utilized for hedging purposes	(14		)	7			(38		)	7			(38		)
Reclassification of change in fair value of derivatives to net income	4			(2		)	11			(2		)	11
Foreign currency translation adjustments	(49		)	—			(102		)	48			(103		)
Adjustments to pension and other postretirement benefit plan liabilities	153			16			50			(49		)	170
Total other comprehensive income (loss)	94			21			(79		)	4			40
Comprehensive income	1,287			361			3,019			(1,935		)	2,732
Comprehensive income attributable to noncontrolling interests	—			—			(1,445		)	—			(1,445		)
Comprehensive income attributable to controlling interests	$	1,287		$	361		$	1,574		$	(1,935	)	$	1,287
Condensed Consolidating Statements of Comprehensive Income for the Year Ended December 31, 2012
(In Millions)
	Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Net Income (loss)	$	315		$	(431	)	$	942		$	(399	)	$	427
Other comprehensive income (loss), net of tax
Change in fair value of derivatives utilized for hedging purposes	32			(5		)	86			(31		)	82
Reclassification of change in fair value of derivatives to net income	(5		)	(2		)	(8		)	7			(8		)
Foreign currency translation adjustments	14			—			33			(15		)	32
Adjustments to pension and other postretirement benefit plan liabilities	(44		)	(14		)	(4		)	27			(35		)
Total other comprehensive (loss) income	(3		)	(21		)	107			(12		)	71
Comprehensive income (loss)	312			(452		)	1,049			(411		)	498
Comprehensive income attributable to noncontrolling interests	—			—			(186		)	—			(186		)
Comprehensive income (loss) attributable to controlling interests	$	312		$	(452	)	$	863		$	(411	)	$	312
Condensed Consolidating Statements of Comprehensive Income for the Year Ended December 31, 2011
(In Millions)
	Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Net income	$	594		$	—		$	778		$	(712	)	$	660
Other comprehensive income (loss), net of tax
Change in fair value of derivatives utilized for hedging purposes	6			—			11			(4		)	13
Reclassification of change in fair value of derivatives to net income	67			—			176			(59		)	184
Foreign currency translation adjustments	(14		)	—			(31		)	10			(35		)
Adjustments to pension and other postretirement benefit plan liabilities	(38		)	—			(23		)	7			(54		)
Total other comprehensive income	21			—			133			(46		)	108
Comprehensive income	615			—			911			(758		)	768
Comprehensive income attributable to noncontrolling interests	—			—			(153		)	—			(153		)
Comprehensive income attributable to controlling interests	$	615		$	—		$	758		$	(758	)	$	615
Condensed Consolidating Statements of Cash Flows for the Year Ended December 31, 2013
(In Millions)
	Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Net cash provided by operating activities	$	1,693		$	91		$	4,506		$	(2,226	)	$	4,064
Cash flows from investing activities
Capital expenditures	(6		)	—			(3,363		)	—			(3,369		)
Proceeds from sale of investments	—			—			490			—			490
Acquisitions of assets and investments	—			—			(292		)	—			(292		)
Repayments from related party	—			—			11			—			11
Funding to affiliates	(376		)	(597		)	(623		)	1,596			—
Drop down assets to KMP	994			—			(994		)	—			—
Contribution to investments	(6		)	—			(217		)	6			(217		)
Investments in KMP and EPB	(65		)	(3		)	—			68			—
Distributions from equity investments in excess of cumulative earnings	18			23			183			(39		)	185
Other, net	—			—			128			—			128
Net cash provided by (used in) investing activities	559			(577		)	(4,677		)	1,631			(3,064		)
Cash flows from financing activities
Issuance of debt	2,895			133			10,553			—			13,581
Payment of debt	(3,444		)	(180		)	(8,769		)	—			(12,393		)
Funding from affiliates	651			488			457			(1,596		)	—
Debt issuance costs	(15		)	—			(23		)	—			(38		)
Cash dividends	(1,622		)	—			—			—			(1,622		)
Repurchases of shares and warrants	(637		)	—			—			—			(637		)
Distributions to parent	—			—			(2,253		)	2,253			—
Contributions from noncontrolling interests	—			—			1,762			(56		)	1,706
Distributions to noncontrolling interests	—			—			(1,692		)	—			(1,692		)
Other, net	—			—			6			(6		)	—
Net cash (used in) provided by financing activities	(2,172		)	441			41			595			(1,095		)
Effect of exchange rate changes on cash and cash equivalents	—			—			(21		)	—			(21		)
Net increase (decrease) in cash and cash equivalents	80			(45		)	(151		)	—			(116		)
Cash and cash equivalents, beginning of period	3			45			666			—			714
Cash and cash equivalents, end of period	$	83		$	—		$	515		$	—		$	598
Condensed Consolidating Statements of Cash Flows for the Year Ended December 31, 2012
(In Millions)
	Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Net cash provided by (used in) operating activities	$	1,014		$	(369	)	$	3,757		$	(1,607	)	$	2,795
Cash flows from investing activities
Capital expenditures	(5		)	—			(2,017		)	—			(2,022		)
Proceeds from disposal of discontinued operations	—			—			1,791			—			1,791
Acquisitions of assets and investments	—			—			(83		)	—			(83		)
Repayments from related party	—			—			76			—			76
Funding to affiliates	(701		)	(968		)	(1,280		)	2,949			—
Acquisition of EP	(5,212		)	—			242			—			(4,970		)
Drop down assets to KMP	3,485			—			(3,485		)	—			—
Contributions to investments	(15		)	—			(177		)	—			(192		)
Investments in KMP and EPB	(85		)	(9		)	—			94			—
Distributions from equity investments in excess of cumulative earnings	16			—			188			(4		)	200
Other, net	—			1			115			—			116
Net cash used in investing activities	(2,517		)	(976		)	(4,630		)	3,039			(5,084		)
Cash flows from financing activities
Issuance of debt	7,889			112			10,147			—			18,148
Payment of debt	(5,418		)	(274		)	(9,063		)	—			(14,755		)
Funding from affiliates	539			1,552			858			(2,949		)	—
Debt issuance costs	(91		)	—			(20		)	—			(111		)
Cash dividends	(1,184		)	—			—			—			(1,184		)
Repurchases of warrants	(157		)	—			—			—			(157		)
Distributions to parents	—			—			(1,597		)	1,597			—
Contributions from noncontrolling interests	—			—			2,012			(73		)	1,939
Distributions to noncontrolling interests	—			—			(1,219		)	—			(1,219		)
Other, net	(74		)	—			4			(7		)	(77		)
Net cash provided by financing activities	1,504			1,390			1,122			(1,432		)	2,584
Effect of exchange rate changes on cash and cash equivalents	—			—			8			—			8
Net increase in cash and cash equivalents	1			45			257			—			303
Cash and cash equivalents, beginning of period	2			—			409			—			411
Cash and cash equivalents, end of period	$	3		$	45		$	666		$	—		$	714
Condensed Consolidating Statements of Cash Flows for the Year Ended December 31, 2011
(In Millions)
	Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Net cash provided by operating activities	$	957		$	—		$	2,766		$	(1,357	)	$	2,366
Cash flows from investing activities
Capital expenditures	(1		)	—			(1,199		)	—			(1,200		)
Acquisitions of assets and investments	—			—			(1,179		)	—			(1,179		)
Repayments from related party	—			—			31			—			31
Funding to affiliates	(852		)	—			(1		)	853			—
Contributions to investments	(92		)	—			(371		)	92			(371		)
Distributions from equity investments in excess of cumulative earnings	22			—			214			—			236
Other, net	—			—			91			—			91
Net cash used in investing activities	(923		)	—			(2,414		)	945			(2,392		)
Cash flows from financing activities
Issuance of debt	2,070			—			7,502			—			9,572
Payment of debt	(1,649		)	—			(7,144		)	—			(8,793		)
Funding from affiliates	1			—			852			(853		)	—
Debt issuance costs	(57		)	—			(19		)	—			(76		)
Cash dividends/distributions	(770		)	—			—			—			(770		)
Distributions to parents	—			—			(1,275		)	1,275			—
Contributions from noncontrolling interests	—			—			980			(10		)	970
Distributions to noncontrolling interests	—			—			(956		)	—			(956		)
Other, net	—			—			(4		)	—			(4		)
Net cash used in financing activities	(405		)	—			(64		)	412			(57		)
Effect of exchange rate changes on cash and cash equivalents	—			—			(8		)	—			(8		)
Net (decrease) increase in cash and cash equivalents	(371		)	—			280			—			(91		)
Cash and cash equivalents, beginning of period	373			—			129			—			502
Cash and cash equivalents, end of period	$	2		$	—		$	409		$	—		$	411

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Income Tax Uncertainties, Policy [Policy Text Block]	'
	We recognize the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained on examination by the taxing authorities, based not only on the technical merits of the tax position based on tax law, but also the past administrative practices and precedents of the taxing authority.  The tax benefits recognized in the financial statements from such a position are measured based on the largest benefit that has a greater than 50% likelihood of being realized upon ultimate resolution.
Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block]	'
	Impairments
	We review long-lived assets for impairment whenever events or changes in circumstances indicate that our carrying amount of an asset may not be recoverable.  We recognize impairment losses when estimated future cash flows expected to result from our use of the asset and its eventual disposition is less than its carrying amount.
	We evaluate our oil and gas producing properties for impairment of value on a field-by-field basis or, in certain instances, by logical grouping of assets if there is significant shared infrastructure, using undiscounted future cash flows based on total proved and risk-adjusted probable and possible reserves.  For the purpose of impairment testing, adjustments for the inclusion of risk-adjusted probable and possible reserves, as well as forward curve pricing, will cause impairment calculation cash flows to differ from the amounts presented in our supplemental information on oil and gas producing activities disclosed in “Supplemental Information on Oil and Gas Producing Activities (Unaudited).”
	Oil and gas producing properties deemed to be impaired are written down to their fair value, as determined by discounted future cash flows based on total proved and risk-adjusted probable and possible reserves or, if available, comparable market values.  Unproved oil and gas properties that are individually significant are periodically assessed for impairment of value, and a loss is recognized at the time of impairment.
Basis of Accounting, Policy [Policy Text Block]	'
	Basis of Presentation
	Our reporting currency is U.S. dollars, and all references to dollars are U.S. dollars, except where stated otherwise. Canadian dollars are designated as C$.
	Our accompanying consolidated financial statements have been prepared under the rules and regulations of the SEC. These rules and regulations conform to the accounting principles contained in the FASB’s Accounting Standards Codification, the single source of GAAP. Under such rules and regulations, all significant intercompany items have been eliminated in consolidation. Additionally, certain amounts from prior years have been reclassified to conform to the current presentation.
	Our consolidated financial statements include our accounts and the of our majority-owned and controlled subsidiaries as well as the accounts of KMP, EPB and KMR. Investments in jointly owned operations in which we hold a 50% or less interest (other than KMP, EPB and KMR, because we have the ability to exercise significant control over their operating and financial policies) are accounted for under the equity method.
	Notwithstanding the consolidation of KMP and EPB and their respective subsidiaries into our financial statements, we are not liable for, and our assets are not available to satisfy, the obligations of KMP and EPB and/or their respective subsidiaries and vice versa, except as discussed in the following paragraph. Responsibility for payments of obligations reflected in our, KMP’s or EPB’s financial statements is a legal determination based on the entity that incurs the liability.
	Effective November 1, 2012, we sold KMP’s FTC Natural Gas Pipelines disposal group to Tallgrass Energy Partners, L.P. for approximately $1.8 billion (before selling costs), or $3.3 billion including our share of joint venture debt, to satisfy terms of a March 15, 2012 agreement with the U.S. FTC to divest certain of our assets in order to receive regulatory approval for our EP acquisition. KMP’s FTC Natural Gas Pipelines disposal group’s assets included (i) Kinder Morgan Interstate Gas Transmission natural gas pipeline system; (ii) Trailblazer natural gas pipeline system; (iii) Casper and Douglas natural gas processing operations; and (iv) 50% equity investment in the Rockies Express natural gas pipeline system. Accordingly, we (i) reclassified and excluded KMP’s FTC Natural Gas Pipelines disposal group’s results of operations from our results of continuing operations and reported the disposal group’s results of operations separately as “Income from operations of KMP’s FTC Natural Gas Pipelines disposal group and other, net of tax” within the discontinued operations section of our accompanying consolidated statements of income for all periods presented and (ii) separately reported a “Loss on sale and the remeasurement of KMP’s FTC Natural Gas Pipelines disposal group to fair value, net of tax” within the discontinued operations section of our accompanying consolidated statements of income for the years ended December 31, 2013 and 2012. In addition, we did not elect to present separately the operating, investing and financing cash flows related to the disposal group in our accompanying consolidated statements of cash flows.
	For more information about the divestiture of KMP’s FTC Natural Gas Pipelines disposal group, see Note 3.
Use of Estimates, Policy [Policy Text Block]	'
	Use of Estimates
	Certain amounts included in or affecting our financial statements and related disclosures must be estimated, requiring us to make certain assumptions with respect to values or conditions which cannot be known with certainty at the time our financial statements are prepared. These estimates and assumptions affect the amounts we report for assets and liabilities, our revenues and expenses during the reporting period, and our disclosure of contingent assets and liabilities at the date of our financial statements. We evaluate these estimates on an ongoing basis, utilizing historical experience, consultation with experts and other methods we consider reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from our estimates. Any effects on our business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known.
	In addition, we believe that certain accounting policies are of more significance in our financial statement preparation process than others, and set out below are the principal accounting policies we apply in the preparation of our consolidated financial statements.
Cash and Cash Equivalents, Restricted Cash and Cash Equivalents, Policy [Policy Text Block]	'
	Cash Equivalents and Restricted Deposits
	We define cash equivalents as all highly liquid short-term investments with original maturities of three months or less.
	Restricted cash of $75 million and $52 million as of December 31, 2013 and 2012, respectively is included in “Other current assets,” and restricted cash of $2 million as of December 31, 2013, is included in “Deferred charges and other assets.”
Receivables, Policy [Policy Text Block]	'
	Accounts Receivable
	The amounts reported as “Accounts receivable, net” on our accompanying consolidated balance sheets as of December 31, 2013 and 2012 primarily consist of amounts due from customers.
	Our policy for determining an appropriate allowance for doubtful accounts varies according to the type of business being conducted and the customers being served.  Generally, we make periodic reviews and evaluations of the appropriateness of the allowance for doubtful accounts based on a historical analysis of uncollected amounts, and we record adjustments as necessary for changed circumstances and customer-specific information.  When specific receivables are determined to be uncollectible, the reserve and receivable are relieved.
Inventory, Policy [Policy Text Block]	'
	Inventories
	Our inventories of products consist of materials and supplies, NGL, refined petroleum products and natural gas. We report these assets at the lower of weighted-average cost or market. We report materials and supplies inventories at cost, and periodically review for physical deterioration and obsolescence.
Gas Balancing Arrangements, Policy [Policy Text Block]	'
	Gas Imbalances
	We value gas imbalances due to or due from interconnecting pipelines at the lower of cost or market or index prices, per our quarterly imbalance valuation procedures. Gas imbalances represent the difference between customer nominations and actual gas receipts from, and gas deliveries to, our interconnecting pipelines and shippers under various operational balancing and shipper imbalance agreements.  Natural gas imbalances are either settled in cash or made up in-kind subject to the pipelines’ various tariff provisions. As of both December 31, 2013 and 2012, our gas imbalance receivables—including both trade and related party receivables—totaled $83 million and $18 million, respectively, and we included these amounts within “Other current assets” on our accompanying consolidated balance sheets. As of December 31, 2013 and 2012, our gas imbalance payables—consisting of only trade payables—totaled $34 million and $150 million, respectively, and we included these amounts within “Other current liabilities” on our accompanying consolidated balance sheets.
Property, Plant and Equipment, Policy [Policy Text Block]	'
	Property, Plant and Equipment
	Capitalization, Depreciation and Depletion and Disposals
	We report property, plant and equipment at its acquisition cost.  We expense costs for maintenance and repairs in the period incurred.  As discussed below, for assets used in our oil and gas producing activities or in our unregulated bulk and liquids terminal activities, the cost of property, plant and equipment sold or retired and the related depreciation are removed from our balance sheet in the period of sale or disposition, and we record any related gains and losses from sales or retirements to income or expense accounts.  For our pipeline system assets, we generally charge the original cost of property sold or retired to accumulated depreciation and amortization, net of salvage and cost of removal.  We do not include retirement gain or loss in income except in the case of significant retirements or sales.  Gains and losses on minor operating unit sales, excluding land, are recorded to the appropriate accumulated depreciation reserve.  Generally, gains and losses for operating unit sales and land sales are booked to income or expense accounts in accordance with regulatory accounting guidelines. In those instances where we receive recovery in tariff rates related to losses on dispositions of operating units, we record a regulatory asset for the estimated recoverable amount.
	We generally compute depreciation using the straight-line method based on estimated economic lives; however, for certain depreciable assets, we employ the composite depreciation method, applying a single depreciation rate for a group of assets.  Generally, we apply composite depreciation rates to functional groups of property having similar economic characteristics.  The rates range from 0.9% to 23.0% excluding certain short-lived assets such as vehicles.  Depreciation estimates are based on various factors, including age (in the case of acquired assets), manufacturing specifications, technological advances and historical data concerning useful lives of similar assets.  Uncertainties that impact these estimates included changes in laws and regulations relating to restoration and abandonment requirements, economic conditions, and supply and demand in the area.  When assets are put into service, we make estimates with respect to useful lives (and salvage values where appropriate) that we believe are reasonable.  However, subsequent events could cause us to change our estimates, thus impacting the future calculation of depreciation and amortization expense.  Historically, adjustments to useful lives have not had a material impact on our aggregate depreciation levels from year to year.
	Our oil and gas producing activities are accounted for under the successful efforts method of accounting.  Under this method costs that are incurred to acquire leasehold and subsequent development costs are capitalized.  Costs that are associated with the drilling of successful exploration wells are capitalized if proved reserves are found.  Costs associated with the drilling of exploratory wells that do not find proved reserves, geological and geophysical costs, and costs of certain non-producing leasehold costs are expensed as incurred.  The capitalized costs of our producing oil and gas properties are depreciated and depleted by the units-of-production method.  Other miscellaneous property, plant and equipment are depreciated over the estimated useful lives of the asset.
	A gain on the sale of property, plant and equipment used in our oil and gas producing activities or in our bulk and liquids terminal activities is calculated as the difference between the cost of the asset disposed of, net of depreciation, and the sales proceeds received.  A gain on an asset disposal is recognized in income in the period that the sale is closed.  A loss on the sale of property, plant and equipment is calculated as the difference between the cost of the asset disposed of, net of depreciation, and the sales proceeds received or the market value if the asset is being held for sale.  A loss is recognized when the asset is sold or when the net cost of an asset held for sale is greater than the market value of the asset.
	We engage in enhanced recovery techniques in which CO2 is injected into certain producing oil reservoirs.  In some cases, the acquisition cost of the CO2 associated with enhanced recovery is capitalized as part of our development costs when it is injected.  The acquisition cost associated with pressure maintenance operations for reservoir management is expensed when it is injected.  When CO2 is recovered in conjunction with oil production, it is extracted and re-injected, and all of the associated costs are expensed as incurred.  Proved developed reserves are used in computing units of production rates for drilling and development costs, and total proved reserves are used for depletion of leasehold costs.  The units-of-production rate is determined by field.
	As discussed in “—Inventories” above, we own and maintain natural gas in underground storage as part of our inventory.  This component of our inventory represents the portion of gas stored in an underground storage facility generally known as working gas, and represents an estimate of the portion of gas in these facilities available for routine injection and withdrawal.  In addition to this working gas, underground gas storage reservoirs contain injected gas which is not routinely cycled but, instead, serves the function of maintaining the necessary pressure to allow efficient operation of the facility.  This gas, generally known as cushion gas, is divided into the categories of recoverable cushion gas and unrecoverable cushion gas, based on an engineering analysis of whether the gas can be economically removed from the storage facility at any point during its life.  The portion of the cushion gas that is determined to be unrecoverable is considered to be a permanent part of the facility itself (thus, part of our “Property, plant and equipment, net” balance in our accompanying consolidated balance sheets), and this unrecoverable portion is depreciated over the facility’s estimated useful life.  The portion of the cushion gas that is determined to be recoverable is also considered a component of the facility but is not depreciated because it is expected to ultimately be recovered and sold.
Asset Retirement Obligations, Policy [Policy Text Block]	'
	Asset Retirement Obligations
	We record liabilities for obligations related to the retirement and removal of long-lived assets used in our businesses.  We record, as liabilities, the fair value of asset retirement obligations on a discounted basis when they are incurred, which is typically at the time the assets are installed or acquired.  Amounts recorded for the related assets are increased by the amount of these obligations.  Over time, the liabilities increase due to the change in their present value, and the initial capitalized costs are depreciated over the useful lives of the related assets.  The liabilities are eventually extinguished when the asset is taken out of service.
Equity Method Investments, Policy [Policy Text Block]	'
	Equity method of accounting
	We account for investments—which we do not control, but do have the ability to exercise significant influence—by the equity method of accounting. Under this method, our equity investments are carried originally at our acquisition cost, increased by our proportionate share of the investee’s net income and by contributions made, and decreased by our proportionate share of the investee’s net losses and by distributions received.
Goodwill and Intangible Assets, Goodwill, Policy [Policy Text Block]	'
	Goodwill
	Goodwill represents the excess of the cost of an acquisition price over the fair value of the acquired net assets, and such amounts are reported separately on our consolidated balance sheets.  As of December 31, 2013 and 2012 our total goodwill was $24,504 million and $23,632 million, respectively.  Goodwill is not amortized, but instead is tested for impairment annually or on an interim basis if events or circumstances indicate that the fair value of the asset has decreased below its carrying value. We perform our goodwill impairment test on May 31 of each year.  There were no impairment charges resulting from our May 31, 2013, 2012 or 2011 impairment testing, and no event indicating an impairment has occurred subsequent to May 31, 2013.
	If a significant portion of one of our business segments is disposed of (that also constitutes a business), we would allocate goodwill based on the relative fair values of the portion of the segment being disposed of and the portion of the segment remaining.
Revenue Recognition, Policy [Policy Text Block]	'
	Revenue Recognition Policies
	We recognize revenues as services are rendered or goods are delivered and, if applicable, title has passed.  We recognize natural gas sales revenues and NGL sales revenue when the natural gas or NGL is sold to a purchaser at a fixed or determinable price, delivery has occurred and title has transferred, and collectability of the revenue is reasonably assured. Our sales and purchases of natural gas and NGL are primarily accounted for on a gross basis as natural gas sales or product sales, as applicable, and cost of sales.
	In addition to storing and transporting a significant portion of the natural gas volumes we purchase and resell, we provide various types of natural gas storage and transportation services for third-party customers.  Under these contracts, the natural gas remains the property of these customers at all times. In many cases, generally described as firm service, the customer pays a two-part rate that includes (i) a fixed fee reserving the right to transport or store natural gas in our facilities and (ii) a per-unit rate for volumes actually transported or injected into/withdrawn from storage.  The fixed-fee component of the overall rate is recognized as revenue in the period the service is provided.  The per-unit charge is recognized as revenue when the volumes are delivered to the customers’ agreed upon delivery point, or when the volumes are injected into/withdrawn from our storage facilities.
	In other cases, generally described as interruptible service, there is no fixed fee associated with the services because the customer accepts the possibility that service may be interrupted at our discretion in order to serve customers who have purchased firm service.  In the case of interruptible service, revenue is recognized in the same manner utilized for the per-unit rate for volumes actually transported under firm service agreements.
	We provide crude oil and refined petroleum products transportation and storage services to customers.  Revenues are recorded when products are delivered and services have been provided, and adjusted according to terms prescribed by the toll settlements with shippers and approved by regulatory authorities.
	We recognize bulk terminal transfer service revenues based on volumes loaded and unloaded.  We recognize liquids terminal tank rental revenue ratably over the contract period. We recognize liquids terminal throughput revenue based on volumes received and volumes delivered.  We recognize transmix processing revenues based on volumes processed or sold, and if applicable, when title has passed.  We recognize energy-related product sales revenues based on delivered quantities of product.
	Revenues from the sale of crude oil, NGL, CO2 and natural gas production within the CO2—KMP business segment are recorded using the entitlement method.  Under the entitlement method, revenue is recorded when title passes based on our net interest.  We record our entitled share of revenues based on entitled volumes and contracted sales prices. Since there is a ready market for oil and gas production, we sell the majority of our products soon after production at various locations, at which time title and risk of loss pass to the buyer.
Regulatory Environmental Costs, Policy [Policy Text Block]	'
	Environmental Matters
	We expense or capitalize, as appropriate, environmental expenditures that relate to current operations.  We expense expenditures that relate to an existing condition caused by past operations, which do not contribute to current or future revenue generation.  We generally do not discount environmental liabilities to a net present value, and we record environmental liabilities when environmental assessments and/or remedial efforts are probable and we can reasonably estimate the costs.  Generally, our recording of these accruals coincides with our completion of a feasibility study or our commitment to a formal plan of action.  We recognize receivables for anticipated associated insurance recoveries when such recoveries are deemed to be probable. We record at fair value, where appropriate, environmental liabilities assumed in a business combination.
	We routinely conduct reviews of potential environmental issues and claims that could impact our assets or operations.  These reviews assist us in identifying environmental issues and estimating the costs and timing of remediation efforts.  We also routinely adjust our environmental liabilities to reflect changes in previous estimates.  In making environmental liability estimations, we consider the material effect of environmental compliance, pending legal actions against us, and potential third-party liability claims.  Often, as the remediation evaluation and effort progresses, additional information is obtained, requiring revisions to estimated costs.  These revisions are reflected in our income in the period in which they are reasonably determinable.
Pension and Other Postretirement Plans, Policy [Policy Text Block]	'
	ensions and Other Postretirement Benefits
	We recognize the difference between the fair value of plan assets and the plan’s benefit obligation of our consolidated subsidiaries’ pension and other postretirement benefit plans as either assets or liabilities on our balance sheet. We record deferred plan costs and income—unrecognized losses and gains, unrecognized prior service costs and credits, and any remaining unamortized transition obligations—in accumulated other comprehensive income or as a regulatory asset or liability for certain of our regulated operations, until they are amortized to be recognized as a component of benefit expense.
Consolidation, Subsidiaries or Other Investments, Consolidated Entities, Policy [Policy Text Block]	'
	Noncontrolling Interests
	Noncontrolling interests represents the outstanding ownership interests in our consolidated subsidiaries that are not owned by us.  In our accompanying consolidated income statements, the noncontrolling interest in the net income (or loss) of our consolidated subsidiaries is shown as an allocation of our consolidated net income and is presented separately as “Net income attributable to noncontrolling interests.”  In our accompanying consolidated balance sheets, noncontrolling interests represents the ownership interests in our consolidated subsidiaries’ net assets held by parties other than us.  It is presented separately as “Noncontrolling interests” within “Stockholders’ Equity.”
Income Tax, Policy [Policy Text Block]	'
	Income Taxes
	Income tax expense is recorded based on an estimate of the effective tax rate in effect or to be in effect during the relevant periods.  Deferred income tax assets and liabilities are recognized for temporary differences between the basis of assets and liabilities for financial reporting and tax purposes.  Changes in tax legislation are included in the relevant computations in the period in which such changes are effective.  Deferred tax assets are reduced by a valuation allowance for the amount of any tax benefit we do not expect to be realized.
	In determining the deferred income tax asset and liability balances attributable to us, we have applied an accounting policy that looks through its investments including its investment in KMP and EPB.  The application of this policy resulted in no deferred income taxes being provided on the difference between the book and tax basis on the non-tax-deductible goodwill portion of our investment in KMP and EPB.
Foreign Currency Transactions and Translations Policy [Policy Text Block]	'
	Foreign Currency Transactions and Translation
	Foreign currency transaction gains or losses result from a change in exchange rates between (i) the functional currency, for example the Canadian dollar for a Canadian subsidiary and (ii) the currency in which a foreign currency transaction is denominated, for example the U.S. dollar for a Canadian subsidiary.  In our accompanying consolidated statements of income, gains and losses from our foreign currency transactions are included within “Other Income (Expense)—Other, net.”
	Foreign currency translation is the process of expressing, in U.S. dollars, amounts recorded in a local functional currency other than U.S. dollars, for example the Canadian dollar for a Canadian subsidiary.  We translate the assets and liabilities of each of our consolidated foreign subsidiaries that have a local functional currency to U.S. dollars at year-end exchange rates.  Income and expense items are translated at weighted-average rates of exchange prevailing during the year and stockholders’ equity accounts are translated by using historical exchange rates.  The cumulative translation adjustments balance is reported as a component of “Accumulated other comprehensive loss.”
Comprehensive Income, Policy [Policy Text Block]	'
	Comprehensive Income
	For each of the years ended December 31, 2013, 2012 and 2011, the difference between our net income and our comprehensive income resulted from (i) unrealized gains or losses on derivative contracts accounted for as cash flow hedges; (ii) foreign currency translation adjustments; and (iii) unrealized gains or losses related to changes in pension and other postretirement benefit plan liabilities. For more information on our risk management activities, see Note 13.
Derivatives, Policy [Policy Text Block]	'
	Risk Management Activities
	We utilize energy commodity derivative contracts for the purpose of mitigating our risk resulting from fluctuations in the market price of natural gas, NGL and crude oil.  In addition, we enter into interest rate swap agreements for the purpose of hedging the interest rate risk associated with our debt obligations. We measure our derivative contracts at fair value and we report them on our balance sheet as either an asset or liability.  If the derivative transaction qualifies for and is designated as a normal purchase and sale, it is exempted from fair value accounting and is accounted for using traditional accrual accounting.
	Furthermore, changes in our derivative contracts’ fair values are recognized currently in earnings unless hedge accounting is applied.  If a derivative contract meets specific accounting criteria, the contract’s gains and losses are allowed to offset related results on the hedged item in our income statement, and we may formally designate the derivative contract as a hedge and document and assess the effectiveness of the contract associated with the transaction that receives hedge accounting.  Only designated qualifying items that are effectively offset by changes in fair value or cash flows during the term of the hedge are eligible to use the special accounting for hedging.
	Our derivative contracts that hedge our energy commodity price risks involve our normal business activities, which include the purchase and sale of natural gas, NGL and crude oil, and we may designate these derivative contracts as cash flow hedges—derivative contracts that hedge exposure to variable cash flows of forecasted transactions—and the effective portion of these derivative contracts’ gain or loss is initially reported as a component of other comprehensive income (outside earnings) and subsequently reclassified into earnings when the forecasted transactions affect earnings.  The ineffective portion of the gain or loss is reported in earnings immediately.
Public Utilities, Policy [Policy Text Block]	'
	Regulatory Assets and Liabilities
	Regulatory assets and liabilities represent probable future revenues or expenses associated with certain charges and credits that will be recovered from or refunded to customers through the ratemaking process.  We included the amounts of our regulatory assets and liabilities within “Other current assets,” “Deferred charges and other assets,” “Other current liabilities” and “Other long-term liabilities and deferred credits,” respectively, in our accompanying consolidated balance sheets. As of December 31, 2013, the recovery period for these regulatory assets was approximately one year to forty-two years
Transfer of net assets between entities under common control [Policy Text Block]	'
	Transfer of Net Assets Between Entities Under Common Control
	We account for the transfer of net assets between entities under common control by carrying forward the net assets recognized in the balance sheets of each combining entity to the balance sheet of the combined entity, and no other assets or liabilities are recognized as a result of the combination.  Transfers of net assets between entities under common control do not affect the historical income statement or balance sheet of the combined entity.
Earnings Per Share, Policy [Policy Text Block]	'
	Earnings per Share
	For the year ended December 31, 2013, earnings per share was calculated using the two-class method. Earnings were allocated to Class P shares of common stock and to participating securities based on the amount of dividends paid in the current period plus an allocation of the undistributed earnings or excess distributions over earnings to the extent that each security participates in earnings or excess distributions over earnings. Our unvested restricted stock awards do not participate in excess distributions over earnings. For the year ended December 31, 2013, the following potential weighted-average Class P common shares are antidilutive and, accordingly, are excluded from the determination of diluted earnings per share; (i) 4 million related to unvested restricted stock awards; (ii) 401 million related to outstanding warrants to purchase our Class P shares; and (iii) 10 million related to convertible trust preferred securities.
	The following table sets forth the allocation of net income available to shareholders for Class P shares and for participating securities for the year ended December 31, 2013 (in millions):
		Year Ended December 31, 2013
	Class P	$	1,187
	Participating securities(a)	6
	Net Income Attributable to Kinder Morgan, Inc.	$	1,193
	_______
	(a)	Participating securities are unvested restricted stock awards issued to management employees that contain non-forfeitable rights to dividend equivalent payments.
	On December 26, 2012, the remaining series of our Class A, Class B, and Class C shares were fully-converted and as a result, only our Class P common stock was outstanding as of December 31, 2012 (see Note 10).
	For the year ended December 31, 2012 and the period February 11, 2011 through December 31, 2011, earnings per share was calculated using the two-class method.  Earnings were allocated to each class of common stock based on the amount of dividends paid in the current period for each class of stock plus an allocation of the undistributed earnings or excess distributions over earnings to the extent that each security participates in earnings or excess distributions over earnings.  For the investor retained stock, the allocation of undistributed earnings or excess distributions over earnings was in direct proportion to the maximum number of Class P shares into which it could convert.
	For the Class P diluted earnings per share computations, total net income attributable to Kinder Morgan, Inc. was divided by the adjusted weighted-average shares outstanding during the period, including all dilutive potential shares.  This included the Class P shares into which the investor retained stock (collectively, our Class A, Class B and Class C common stocks) was convertible.  The number of Class P shares on a fully-converted basis was the same before and after any conversion of our investor retained stock.  Each time one Class P share was issued upon conversion of investor retained stock, the number of Class P shares went up by one, and the number of Class P shares into which the investor retained stock was convertible went down by one.  Accordingly, there was no difference between Class P basic and diluted earnings per share because the conversion of Class A, Class B, and Class C shares into Class P shares did not impact the number of Class P shares on a fully-converted basis.  Commencing with the acquisition of EP, dilutive potential shares also included the Class P shares issuable in connection with the warrants and the trust preferred securities (see Note 10).  As no securities were convertible into Class A shares, the basic and diluted earnings per share computations for Class A shares were the same. For the year ended December 31, 2012, the following potential Class P common shares were antidilutive and, accordingly, were excluded from the determination of diluted earnings per share; (i) 451 million related to outstanding warrants to purchase our Class P shares; and (ii) 11 million related to convertible trust preferred securities.
	The following tables set forth the computation of basic and diluted earnings per share from continuing operations for the year ending December 31, 2012 and the period ending February 11, 2011 through December 31, 2011 (the date of our initial public offering) (in millions, except per share amounts):
		Year ended December 31, 2012
		Income from Continuing Operations Available to Shareholders
		Class P			Class A			Participating			Total
								Securities(a)
	Income from continuing operations										$	1,204
	Less: income from continuing operations attributable to noncontrolling interests										(696		)
	Income from continuing operations attributable to KMI										508
	Dividends paid in the period	$	601		$	542		$	41		(1,184		)
	Excess distributions over earnings	(344		)	(331		)	(1		)	$	(676	)
	Income from continuing operations attributable to shareholders	$	257		$	211		$	40		$	508
	Basic earnings per share from continuing operations
	Basic weighted-average number of shares outstanding	461			446			N/A
	Basic earnings per common share from continuing operations(b)	$	0.56		$	0.47		N/A
	Diluted earnings per share from continuing operations
	Income from continuing operations attributable to shareholders and assumed conversions(c)	$	508		$	211		N/A
	Diluted weighted-average number of shares	908			446			N/A
	Diluted earnings per common share from continuing operations(b)	$	0.56		$	0.47		N/A
		February 11. 2011 through December 31, 2011
		Income from Continuing Operations Available to Shareholders
		Class P			Class A			Participating			Total
								Securities(a)
	Income from continuing operations for the year ended December 31, 2011										$	449
	Plus: loss from continuing operations attributable to noncontrolling interests for the year ended December 31, 2011										112
	Income from continuing operations attributable to KMI for the year ended December 31, 2011										561
	Less: income from continuing operations attributable to KMI members prior to incorporation										(67		)
	Total net income from continuing operations attributable to shareholders										494
	Dividends paid in the period	$	87		$	399		$	38		(524		)
	Excess distributions over earnings	(5		)	(25		)	—			$	(30	)
	Income from continuing operations attributable to shareholders	$	82		$	374		$	38		$	494
	Basic earnings per share from continuing operations
	Basic weighted-average number of shares outstanding(d)	118			589			N/A
	Basic earnings per common share from continuing operations(b)	$	0.7		$	0.64		N/A
	Diluted earnings per share from continuing operations
	Income from continuing operations attributable to shareholders and assumed conversions(c)	$	494		$	374		N/A
	Diluted weighted-average number of shares(d)	708			589			N/A
	Diluted earnings per common share from continuing operations(b)	$	0.7		$	0.64		N/A
	The following tables set forth the computation of basic and diluted earnings per share for the year ended December 31, 2012 and for the period February 11, 2011 through December 31, 2011 (in millions, except per share amounts):
		Year ended December 31, 2012
		Net Income Available to Shareholders
		Class P			Class A			Participating			Total
								Securities(a)
	Net income attributable to KMI										$	315
	Dividends paid in the period	$	601		$	542		$	41		(1,184		)
	Excess distributions over earnings	(441		)	(426		)	(2		)	$	(869	)
	Net income attributable to shareholders	$	160		$	116		$	39		$	315
	Basic earnings per share
	Basic weighted-average number of shares outstanding	461			446			N/A
	Basic earnings per common share(b)	$	0.35		$	0.26		N/A
	Diluted earnings per share
	Net income attributable to shareholders and assumed conversions(c)	$	315		$	116		N/A
Diluted weighted-average number of shares	908			446			N/A
Diluted earnings per common share(b)	$	0.35		$	0.26		N/A
	February 11, 2011 through December 31, 2011
	Net Income Available to Shareholders
	Class P			Class A			Participating			Total
							Securities(a)
Net income attributable to KMI for the year ended December 31, 2011										$	594
Less: net income attributable to KMI members prior to incorporation										(70		)
Net income attributable to shareholders										524
Dividends paid in the period	$	87		$	399		$	38		(524		)
Excess distributions over earnings	—			—			—			$	—
Total net income attributable to shareholders	$	87		$	399		$	38		$	524
Basic earnings per share
Basic weighted-average number of shares outstanding(d)	118			589			N/A
Basic earnings per common share(b)	$	0.74		$	0.68		N/A
Diluted earnings per share
Net income attributable to shareholders and assumed conversions(c)	$	524		$	399		N/A
Diluted weighted-average number of shares(d)	708			589			N/A
Diluted earnings per common share(b)	$	0.74		$	0.68		N/A
_______
(a)	Participating securities included Class B shares, Class C shares, and unvested restricted stock awards issued to non-senior management employees that contained rights to dividend equivalents in the case of the restricted shares.  Our Class B and Class C shares were entitled to participate in our earnings, only to the extent of cash distributions made to them. As a result, no earnings in excess of dividends received were allocated to the Class B and Class C shares in our determination of basic and diluted earnings per share.
(b)	The Class A shares earnings per share as compared to the Class P shares earnings per share were reduced due to the sharing of economic benefits (including dividends) amongst the Class A, B, and C shares.  Class A, B and C shares owned by Richard Kinder, the sponsor investors, the original shareholders, and other management were referred to as “investor retained stock,” and were convertible into a fixed number of Class P shares.  In the aggregate, our investor retained stock was entitled to receive a dividend per share on a fully-converted basis equal to the dividend per share on our common stock.  The conversion of shares of investor retained stock into Class P shares did not increase our total fully-converted shares outstanding, impact the aggregate dividends we paid or the dividends we paid per share on our Class P common stock.
(c)	For the diluted earnings per share calculation, total net income attributable to each class of common stock was divided by the adjusted weighted-average shares outstanding during the period, including all dilutive potential shares.
(d)	The weighted-average shares outstanding calculation is based on the actual days in which the shares were outstanding for the period from February 11, 2011 to December 31, 2011.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Schedule of Regulatory Assets and Liabilities [Line Items]	'
Schedule of Regulatory Assets and Liabilities [Text Block]	'
	The following table summarizes our regulatory asset and liability balances as of December 31, 2013 and 2012 (in millions):
		December 31,
		2013			2012
	Current regulatory assets	$	91		$	62
	Non-current regulatory assets	446			402
	Total regulatory assets(a)	$	537		$	464
	Current regulatory liabilities	$	135		$	7
	Non-current regulatory liabilities	397			113
	Total regulatory liabilities(b)	$	532		$	120
	_______
	(a)	Includes an $88 million increase since December 31, 2012 (net of related amortization of $5 million) associated with TGP’s sale of certain natural gas facilities located offshore in the Gulf of Mexico and onshore in the state of Louisiana.
	(b)	During the second quarter of 2013, we began applying regulatory accounting to the Trans Mountain pipeline systems due to a newly negotiated long-term tolling agreement approved by the system’s regulator that went into effect in April 2013. The primary impact of applying regulatory accounting was the reclassification of approximately $362 million of current and long-term deferred credits to regulatory liabilities. KMP expects this regulatory liability to be refunded to rate-payers over approximately the next four years. As of December 31, 2013, $113 million remains classified as a current regulatory liability.
Schedule of Net Income for Shareholders and Participating Securities [Table Text Block]	'
	The following table sets forth the allocation of net income available to shareholders for Class P shares and for participating securities for the year ended December 31, 2013 (in millions):
		Year Ended December 31, 2013
	Class P	$	1,187
	Participating securities(a)	6
	Net Income Attributable to Kinder Morgan, Inc.	$	1,193
	_______
	(a)	Participating securities are unvested restricted stock awards issued to management employees that contain non-forfeitable rights to dividend equivalent payments.
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]	'
	The following tables set forth the computation of basic and diluted earnings per share from continuing operations for the year ending December 31, 2012 and the period ending February 11, 2011 through December 31, 2011 (the date of our initial public offering) (in millions, except per share amounts):
		Year ended December 31, 2012
		Income from Continuing Operations Available to Shareholders
		Class P			Class A			Participating			Total
								Securities(a)
	Income from continuing operations										$	1,204
	Less: income from continuing operations attributable to noncontrolling interests										(696		)
	Income from continuing operations attributable to KMI										508
	Dividends paid in the period	$	601		$	542		$	41		(1,184		)
	Excess distributions over earnings	(344		)	(331		)	(1		)	$	(676	)
	Income from continuing operations attributable to shareholders	$	257		$	211		$	40		$	508
	Basic earnings per share from continuing operations
	Basic weighted-average number of shares outstanding	461			446			N/A
	Basic earnings per common share from continuing operations(b)	$	0.56		$	0.47		N/A
	Diluted earnings per share from continuing operations
	Income from continuing operations attributable to shareholders and assumed conversions(c)	$	508		$	211		N/A
	Diluted weighted-average number of shares	908			446			N/A
	Diluted earnings per common share from continuing operations(b)	$	0.56		$	0.47		N/A
		February 11. 2011 through December 31, 2011
		Income from Continuing Operations Available to Shareholders
		Class P			Class A			Participating			Total
								Securities(a)
	Income from continuing operations for the year ended December 31, 2011										$	449
	Plus: loss from continuing operations attributable to noncontrolling interests for the year ended December 31, 2011										112
	Income from continuing operations attributable to KMI for the year ended December 31, 2011										561
	Less: income from continuing operations attributable to KMI members prior to incorporation										(67		)
	Total net income from continuing operations attributable to shareholders										494
	Dividends paid in the period	$	87		$	399		$	38		(524		)
	Excess distributions over earnings	(5		)	(25		)	—			$	(30	)
	Income from continuing operations attributable to shareholders	$	82		$	374		$	38		$	494
	Basic earnings per share from continuing operations
	Basic weighted-average number of shares outstanding(d)	118			589			N/A
	Basic earnings per common share from continuing operations(b)	$	0.7		$	0.64		N/A
	Diluted earnings per share from continuing operations
	Income from continuing operations attributable to shareholders and assumed conversions(c)	$	494		$	374		N/A
	Diluted weighted-average number of shares(d)	708			589			N/A
	Diluted earnings per common share from continuing operations(b)	$	0.7		$	0.64		N/A
	The following tables set forth the computation of basic and diluted earnings per share for the year ended December 31, 2012 and for the period February 11, 2011 through December 31, 2011 (in millions, except per share amounts):
		Year ended December 31, 2012
		Net Income Available to Shareholders
		Class P			Class A			Participating			Total
								Securities(a)
	Net income attributable to KMI										$	315
	Dividends paid in the period	$	601		$	542		$	41		(1,184		)
	Excess distributions over earnings	(441		)	(426		)	(2		)	$	(869	)
	Net income attributable to shareholders	$	160		$	116		$	39		$	315
	Basic earnings per share
	Basic weighted-average number of shares outstanding	461			446			N/A
	Basic earnings per common share(b)	$	0.35		$	0.26		N/A
	Diluted earnings per share
	Net income attributable to shareholders and assumed conversions(c)	$	315		$	116		N/A
	Diluted weighted-average number of shares	908			446			N/A
	Diluted earnings per common share(b)	$	0.35		$	0.26		N/A
		February 11, 2011 through December 31, 2011
		Net Income Available to Shareholders
		Class P			Class A			Participating			Total
								Securities(a)
	Net income attributable to KMI for the year ended December 31, 2011										$	594
	Less: net income attributable to KMI members prior to incorporation										(70		)
	Net income attributable to shareholders										524
	Dividends paid in the period	$	87		$	399		$	38		(524		)
	Excess distributions over earnings	—			—			—			$	—
	Total net income attributable to shareholders	$	87		$	399		$	38		$	524
Basic earnings per share
Basic weighted-average number of shares outstanding(d)	118			589			N/A
Basic earnings per common share(b)	$	0.74		$	0.68		N/A
Diluted earnings per share
Net income attributable to shareholders and assumed conversions(c)	$	524		$	399		N/A
Diluted weighted-average number of shares(d)	708			589			N/A
Diluted earnings per common share(b)	$	0.74		$	0.68		N/A
_______
(a)	Participating securities included Class B shares, Class C shares, and unvested restricted stock awards issued to non-senior management employees that contained rights to dividend equivalents in the case of the restricted shares.  Our Class B and Class C shares were entitled to participate in our earnings, only to the extent of cash distributions made to them. As a result, no earnings in excess of dividends received were allocated to the Class B and Class C shares in our determination of basic and diluted earnings per share.
(b)	The Class A shares earnings per share as compared to the Class P shares earnings per share were reduced due to the sharing of economic benefits (including dividends) amongst the Class A, B, and C shares.  Class A, B and C shares owned by Richard Kinder, the sponsor investors, the original shareholders, and other management were referred to as “investor retained stock,” and were convertible into a fixed number of Class P shares.  In the aggregate, our investor retained stock was entitled to receive a dividend per share on a fully-converted basis equal to the dividend per share on our common stock.  The conversion of shares of investor retained stock into Class P shares did not increase our total fully-converted shares outstanding, impact the aggregate dividends we paid or the dividends we paid per share on our Class P common stock.
(c)	For the diluted earnings per share calculation, total net income attributable to each class of common stock was divided by the adjusted weighted-average shares outstanding during the period, including all dilutive potential shares.
(d)	The weighted-average shares outstanding calculation is based on the actual days in which the shares were outstanding for the period from February 11, 2011 to December 31, 2011.

Acquisitions_Tables

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'
Schedule of Business Acquisitions, by Acquisition [Table Text Block]	'
				Assignment of Purchase Price
	Ref.	Date	Acquisition	Purchase				Current		Property		Deferred		Goodwill		Long-term debt			Other liabilities			Non-controlling interest			Previously held equity interest
				price				assets		plant &		charges
										equipment		& other
	KMI
	-1	12-May	EP	$	22,928			$	7,175	$	12,921	$	5,718	$	18,562	$	(13,417	)	$	(4,234	)	$	(3,797	)	$	—
	KMP
	-2	11-Jan	Watco Companies, LLC (1 of 2)	50				—		—		50		—		—			—			—			—
	-3	11-Jun	TGS Development, L.P. Terminal Acquisition	67				—		43		31		—		—			(7		)	—			—
	-4	11-Jul	KinderHawk and EagleHawk	835				36		642		140		94		(77		)	—			—			—
	-5	11-Nov	SouthTex Treaters, Inc. Natural Gas Treating Assets	152				27		9		17		126		—			(27		)	—			—
	-6	11-Dec	Watco Companies, LLC (2 of 2)	50				—		—		50		—		—			—			—			—
	-7	13-May	Copano	3,733				218		2,805		1,775		1,141		(1,252		)	(233		)	(17		)	(704		)
	-8	13-Jun	Goldsmith-Landreth Field Unit	280				—		298		—		—		—			(18		)	—			—
Business Acquisition, Pro Forma Information [Table Text Block]	'
	The following summarized unaudited pro forma consolidated income statement information for the years ended December 31, 2013 and 2012, assumes that the EP, Copano and the Goldsmith Landreth field unit acquisitions had occurred as of January 1, 2012. We prepared the following summarized unaudited pro forma financial results for comparative purposes only. The summarized unaudited pro forma financial results may not be indicative of the results that would have occurred if these acquisitions had been completed as of January 1, 2012 or the results that will be attained in the future. Amounts presented below are in millions, except for the per share amounts:
			Pro Forma
			Year Ended December 31,
			2013				2012
			(Unaudited)
	Revenues		$	14,775			$	13,035
	Income from continuing operations		2,655				866
	Income from discontinued operations, net of tax		(4		)		1,291
	Net income		2,651				2,157
	Net income attributable to noncontrolling interests		(1,486		)		(153		)
	Net income attributable to Kinder Morgan, Inc.		1,165				2,004
	Diluted earnings per common share
	Class P shares		$	1.12			$	1.93
	Class A shares						$	1.84
KMP’s FTC Natural Gas Pipelines [Member]	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	'
	Summarized financial information for KMP’s FTC Natural Gas Pipelines disposal group is as follows (in millions):
		Year Ended December 31,
		2012(a)				2011
	Operating revenues	$	227			$	322
	Operating expenses	(131		)		(183		)
	Depreciation and amortization	(7		)		(24		)
	Other expense	(1		)		—
	Earnings from equity investments	70				87
	Interest income and Other, net	2				2
	Income tax expense	—				(2		)
	Income from operations of KMP’s FTC Natural Gas Pipelines disposal group	$	160			$	202
	_______
	(a)	2012 amounts represent financial information for the ten month period ended October 31, 2012. We sold KMP’s FTC Natural Gas Pipelines disposal group effective November 1, 2012.

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Schedule of Unrecognized Tax Benefits Roll Forward [Table Text Block]	'
	A reconciliation of our gross unrecognized tax benefit excluding interest and penalties is as follows (in millions):
		Year Ended December 31,
		2013			2012				2011
	Balance at beginning of period	$	269		$	57			$	53
	Uncertain tax positions of EP	4			289				—
	Subtotal	273			346				53
	Additions based on current year tax positions	11			11				11
	Additions based on prior year tax positions	26			1				2
	Reductions based on settlements with taxing authority	(86		)	(55		)		—
	Reductions due to lapse in statute of limitations	(15		)	(34		)		(9		)
	Balance at end of period	$	209		$	269			$	57
Schedule of Income before Income Tax, Domestic and Foreign [Table Text Block]	'
	The components of “Income from Continuing Operations Before Income Taxes” are as follows (in millions):
		Year Ended December 31,
		2013			2012				2011
	U.S.	$	3,107		$	1,246			$	731
	Foreign	331			97				79
	Total Income from Continuing Operations Before Income Taxes	$	3,438		$	1,343			$	810
Schedule of Components of Income Tax Expense (Benefit)	'
	Components of the income tax provision applicable to continuing operations for federal, foreign and state taxes are as follows (in millions):
		Year Ended December 31,
		2013			2012				2011
	Current tax expense
	Federal	$	57		$	48			$	241
	State	36			34				33
	Foreign	9			10				3
	Total	102			92				277
	Deferred tax expense
	Federal	612			49				64
	State	—			4				(1		)
	Foreign	28			(6		)		21
	Total	640			47				84
	Total tax provision	$	742		$	139			$	361
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	'
	The difference between the statutory federal income tax rate and our effective income tax rate is summarized as follows (in millions, except percentages):
		Year Ended December 31,
		2013						2012						2011
	Federal income tax	$	1,203		35	%		$	470			35	%	$	284		35	%
	Increase (decrease) as a result of:
	State deferred tax rate change	(21		)	(0.6	)%		20				1.5	%	(1		)	(0.1	)%
	Taxes on foreign earnings	112			3.3	%		(6		)		(0.5	)%	24			3	%
	Net effects of consolidating KMP’s and EPB’s U.S. income tax provision	(488		)	(14.2	)%		(288		)		(21.5	)%	34			4.2	%
	State income tax, net of federal benefit	45			1.3	%		21				1.6	%	26			3.2	%
	Dividend received deduction	(54		)	(1.6	)%		(32		)		(2.4	)%	(10		)	(1.2	)%
	Adjustments to uncertain tax positions	(87		)	(2.5	)%		(72		)		(5.3	)%	(9		)	(1.1	)%
	Acquisition costs	—			—	%		18				1.3	%	—			—	%
	Other	32			0.9	%		8				0.6	%	13			1.6	%
	Total	$	742		21.6	%		$	139			10.3	%	$	361		44.6	%
Schedule of Deferred Tax Assets and Liabilities [Table Text Block]	'
	Deferred tax assets and liabilities result from the following (in millions):
		December 31,
		2013			2012
	Deferred tax assets
	Employee benefits	$	238		$	360
	Book accruals	136			91
	Net operating loss, capital loss, tax credits carryforwards (net of valuation allowance)	578			1,017
	Derivative instruments	33			84
	Interest rate and currency swaps	35			37
	Debt fair value adjustment	112			155
	Other	43			86
	Total deferred tax assets	1,175			1,830
	Deferred tax liabilities
	Property, plant and equipment	351			328
	Investments	4,888			5,008
	Book accruals	10			22
	Other	10			4
	Total deferred tax liabilities	5,259			5,362
	Net deferred tax liabilities	$	4,084		$	3,532
	Current deferred tax asset	$	(567	)	$	(539	)
	Non-current deferred tax liability	4,651			4,071
	Net deferred tax liabilities	$	4,084		$	3,532
	Deferred Tax Assets and Valuation Allowances: As a result of our EP acquisition, we have deferred tax assets of $354 million related to net operating loss carryovers; alternative minimum and foreign tax credits of $308 million; and valuation allowances related to deferred tax assets of $95 million at December 31, 2013. In 2013, we also recorded an $11 million deferred tax asset related to the capital loss from our sale of the Pakistan power plant. No valuation allowance has been recorded as we fully expect to utilize this capital loss. As of December 31, 2012, the deferred tax asset related to net operating loss carryovers was $823 million, alternative minimum, general business, and foreign tax credits were $298 million, and valuation allowances related to the deferred tax assets were $104 million.
	Expiration Periods for Deferred Tax Assets: As of December 31, 2013, we have U.S. federal net operating loss carryforwards of $613 million, which will expire from 2017 - 2031; state losses of $1.4 billion which will expire from 2014 - 2032; and foreign losses of $191 million, of which approximately $140 million carries over indefinitely and $51 million expires from 2028 - 2032. We also have $297 million of federal alternative minimum tax credits which do not expire; and approximately $11 million of foreign tax credits, the majority of which will expire from 2015 - 2023. Use of our U.S. federal carryforwards is subject to the limitations provided under Sections 382 and 383 of the Internal Revenue Code as well as the separate return limitation rules of Internal Revenue Service regulations.
	Unrecognized Tax Benefits: We recognize the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained on examination by the taxing authorities, based not only on the technical merits of the tax position based on tax law, but also the past administrative practices and precedents of the taxing authority.  The tax benefits recognized in the financial statements from such a position are measured based on the largest benefit that has a greater than 50% likelihood of being realized upon ultimate resolution.

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment [Table Text Block]	'
	As of December 31, 2013 and 2012, our property, plant and equipment consisted of the following (in millions):
		December 31,
		2013			2012
	Natural gas, liquids, crude oil and CO2 pipelines	$	17,399		$	14,649
	Natural gas, liquids, CO2, and terminals station equipment	17,960			15,309
	Natural gas, liquids (including linefill), and transmix processing	259			358
	Other	3,656			3,319
	Accumulated depreciation, depletion and amortization	(6,757		)	(5,278		)
		32,517			28,357
	Land and land right-of-way	1,158			1,143
	Construction work in process	2,172			1,496
	Property, plant and equipment, net	$	35,847		$	30,996

Investments_Tables

Investments (Tables)	12 Months Ended
	Dec. 31, 2013
Investments [Abstract]	'
Schedule of earnings from equity investments [Table Text Block]	'
	Our earnings (losses) from equity investments were as follows (in millions):
		Year Ended December 31,
		2013			2012			2011
	Citrus Corporation(a)	$	84		$	53		$	—
	Fayetteville Express Pipeline LLC	55			55			24
	Gulf LNG Holdings Group, LLC(a)	47			22			—
	Midcontinent Express Pipeline LLC	40			42			43
	Plantation Pipe Line Company	35			32			28
	Red Cedar Gathering Company	31			32			32
	Cortez Pipeline Company	24			25			24
	Eagle Ford(b)	14			34			11
	Watco Companies, LLC	13			13			6
	Fort Union Gas Gathering L.L.C.	11			—			—
	EagleHawk	9			11			3
	Parkway Pipeline LLC	1			—			—
	Double Eagle Pipeline LLC	1			—			—
	KinderHawk(c)	—			—			22
	Ruby Pipeline Holding Company, L.L.C.(a)	(6		)	(5		)	—
	NGPL Holdco LLC(d)	(66		)	(198		)	19
	All others	34			37			14
	Total	$	327		$	153		$	226
	Amortization of excess costs	$	(39	)	$	(23	)	$	(7	)
	_______
	(a)	2012 amounts are for the period from May 25, 2012 through December 31, 2012.
	(b)	Effective May 1, 2013, KMP acquired the remaining 50% equity ownership interest in Eagle Ford that KMP did not already own and KMP changed its method of accounting from the equity method to full consolidation.
	(c)	Effective July 1, 2011, KMP acquired the remaining 50% equity ownership interest in KinderHawk that KMP did not already own and KMP changed its method of accounting from the equity method to full consolidation.
	(d)	2013 and 2012 amounts include non-cash investment impairment charges, which we recorded in the amount of $65 million and $200 million (pre-tax), respectively, as discussed above.
Schedule of Equity Method Investments [Table Text Block]	'
	Our investments primarily consist of equity investments where we hold significant influence over investee actions and which we account for under the equity method of accounting. As of December 31, 2013 and 2012 our investments consisted of the following (in millions):
		December 31,
		2013			2012
	Citrus Corporation	$	1,875		$	1,966
	Ruby Pipeline Holding Company, L.L.C.	1,153			1,185
	Midcontinent Express Pipeline LLC	602			633
	Gulf LNG Holdings Group, LLC	578			596
	Plantation Pipe Line Company	307			313
	EagleHawk	272			208
	Red Cedar Gathering Company	176			172
	Fort Union Gas Gathering L.L.C.	161			—
	Double Eagle Pipeline LLC	144			—
	Fayetteville Express Pipeline LLC	144			159
	Parkway Pipeline LLC	131			58
	Watco Companies, LLC	103			103
	Cortez Pipeline Company	12			11
	Eagle Ford				151
	NGPL Holdco LLC	—			68
	All others	285			173
	Total equity investments	5,943			5,796
	Bond investments	8			8
	Total investments	$	5,951		$	5,804
Summarized financial info of significant equity investment [Table Text Block]	'
	Summarized combined financial information for our significant equity investments (listed or described above) is reported below (in millions; amounts represent 100% of investee financial information):
		Year Ended December 31,
	Income Statement	2013			2012			2011
	Revenues	$	3,615		$	3,681		$	3,145
	Costs and expenses	2,803			3,194			3,287
	Net income (loss)	$	812		$	487		$	(142	)
		December 31,
	Balance Sheet	2013			2012
	Current assets	$	950		$	917
	Non-current assets	20,782			21,308
	Current liabilities	1,451			1,538
	Non-current liabilities	11,351			11,401
	Partners’/owners’ equity	8,930			9,286

Goodwill_and_Other_Intangibles1

Goodwill and Other Intangibles (Tables)	12 Months Ended
	Dec. 31, 2013
Goodwill [Line Items]	'
Schedule of Goodwill [Table Text Block]	'
	Changes in the gross amounts of our goodwill and accumulated impairment losses for each of the years ended December 31, 2013 and 2012 are summarized as follows (in millions):
		Natural Gas Pipelines			CO2–KMP		Products Pipelines-KMP			Terminals–			Kinder			Total
										KMP			Morgan
													Canada–
													KMP
	Historical Goodwill	$	3,723		$	1,528	$	2,129		$	1,484		$	621		$	9,485
	Accumulated impairment losses	(2,090		)	—		(1,267		)	(677		)	(377		)	(4,411		)
	Balance as of December 31, 2011	1,633			1,528		862			807			244			5,074
	Acquisitions(a)	18,803			—		—			—			—			18,803
	Disposals(b)	(250		)	—		—			—			—			(250		)
	Currency translation adjustments	—			—		—			—			5			5
	Balance as of December 31, 2012	20,186			1,528		862			807			249			23,632
	Acquisitions(c)	888			—		—			—			—			888
	Currency translation adjustments	—			—		—			—			(16		)	(16		)
	Balance as of December 31, 2013	$	21,074		$	1,528	$	862		$	807		$	233		$	24,504
	_______
	(a)	2012 acquisition amount consists of the EP and EP Midstream acquisitions as discussed in Note 3.
	(b)	2012 disposal amount relates to the sale of KMP’s FTC Natural Gas Pipelines disposal group as discussed in Note 3. Since the FTC Natural Gas Pipelines disposal group represented a significant portion of our Natural Gas Pipelines business segment, we allocated the goodwill of the segment based on the relative fair value of the portion being disposed of and the portion of the segment remaining.
	(c)	2013 acquisition amount consists of $881 million relating to KMP’s May 1, 2013 Copano acquisition as discussed in Note 3, and $7 million relating to other EP acquisition assets.

Debt_Tables

Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Schedule of Long-term Debt Instruments [Table Text Block]	'
	The following table provides detail on the principal amount of our outstanding debt balances as of December 31, 2013 and 2012. The table amounts exclude all debt fair value adjustments, including debt discounts and premiums (in millions):
		December 31,
		2013				2012
	KMI
	Senior term loan facility, variable rate, due May 24, 2015	$	1,528			$	2,714
	Senior notes and debentures, 5.00% through 7.45%, due 2015 through 2098(a)	1,815				315
	Credit facility due December 31, 2014(b)	175				1,035
	Subsidiary borrowings (as obligor)
	K N Capital Trust I and III, deferrable interest debentures issued by subsidiary trusts, 7.63% and 8.56%, due 2027 and 2028(c)	27				27
	Kinder Morgan Finance Company, LLC, senior notes, 5.70% through 6.40%, due 2016 through 2036(a)(d)	1,636				1,636
	El Paso, senior notes, 6.50% through 12.00%, due 2013 through 2037(a)	3,830				3,860
	EPC Building, LLC, promissory note, 3.967%, due 2013 through 2035(e)	461				217
	Colorado Interstate Gas Services Company, 7.76% Totem note payable, due 2018	1				1
	Other credit facilities due December 20, 2013, March 20 and June 20, 2014	193				210
	EP preferred securities, 4.75%, due March 31, 2028(f)	280				286
	KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock(g)	100				100
	Total debt – KMI	10,046				10,401
	Less: Current portion of debt – KMI	(725		)		(1,153		)
	Total long-term debt – KMI(h)	$	9,321			$	9,248
	KMP and EPB
	KMP
	Senior notes, 2.65% through 9.00%, due 2013 through 2043(a)	$	15,600			$	13,350
	Commercial paper borrowings(i)	979				621
	Credit facility due May 1, 2018(j)	—				—
	KMP subsidiary borrowings (as obligor)
	TGP senior notes, 7.00% through 8.375%, due 2016 through 2037(k)	1,790				1,790
	EPNG senior notes, 5.95% through 8.625%, due 2017 through 2032(l)	1,115				1,115
	Copano senior notes, 7.125% due April 1, 2021(m)	332				—
	Other miscellaneous subsidiary debt	98				186
	Total debt – KMP	19,914				17,062
	Less: Current portion of debt – KMP(n)	(1,504		)		(1,155		)
	Total long-term debt – KMP(h)	18,410				15,907
	EPB
	EPPOC
	Senior notes, 4.10% through 8.00%, due 2013 through 2042(o)	2,260				2,348
	Credit facility due May 27, 2016(p)	—				—
	EPB subsidiary borrowings (as obligor)
	Colorado Interstate Gas Company, L.L.C. (CIG), senior notes, 5.95% through 6.85%, due 2015 through 2037(q)	475				475
	SLNG senior notes, 9.50% through 9.75%, due 2014 through 2016(a)(r)	135				135
	SNG notes, 4.40% through 8.00%, due 2017 through 2032(s)	1,211				1,211
	Other financing obligations(t)	175				178
	Total debt – EPB	4,256				4,347
	Less: Current portion of debt – EPB	(77		)		(93		)
	Total long-term debt – EPB(h)	4,179				4,254
	Total long-term debt – KMP and EPB	$	22,589			$	20,161
	_______
	(a)	Notes provide for the redemption at any time at a price equal to 100% of the principal amount of the notes plus accrued interest to the redemption date plus a make whole premium.
	(b)	As of December 31, 2013 and 2012, the weighted average interest rates on KMI’s credit facility borrowings were 2.67% and 2.72%, respectively.
	(c)	KMI’s business trusts, K N Capital Trust I and K N Capital Trust III, are obligated for $13 million of 8.56% Capital Trust Securities maturing on April 15, 2027 and $14 million of 7.63% Capital Trust Securities maturing on April 15, 2028, respectively, which it guarantees.  The 2028 securities are redeemable in whole or in part, at KMI’s option at any time, at redemption prices as defined in the associated prospectus.  The 2027 securities are redeemable in whole or in part at KMI’s option and at any time in certain limited circumstances upon the occurrence of certain events and at prices all defined in the associated prospectus supplements.  Upon redemption by KMI or at maturity of the Junior Subordinated Deferrable Interest Debentures, the proceeds must be used to make redemptions of the Capital Trust Securities on a pro rata basis.
	(d)	Each series of these notes is fully and unconditionally guaranteed by KMI on a senior secured basis as to principal, interest and any additional amounts required to be paid as a result of any withholding or deduction for Canadian taxes.
	(e)	EPC Building, LLC, as the landlord, leases the property to KMI as a tenant.
	(f)	Capital Trust I (Trust I), is a 100%-owned business trust that as of December 31, 2013, had $5.6 million of 4.75% trust convertible preferred securities outstanding (referred to as the EP Trust I Preferred Securities). Trust I exists for the sole purpose of issuing preferred securities and investing the proceeds in 4.75% convertible subordinated debentures, which are due 2028. Trust I’s sole source of income is interest earned on these debentures. This interest income is used to pay distributions on the preferred securities. EP provides a full and unconditional guarantee of the EP Trust I Preferred Securities. There are no significant restrictions on EP’s ability to obtain funds from its subsidiaries by distribution, dividend or loan. The EP Trust I Preferred Securities are non-voting (except in limited circumstances), pay quarterly distributions at an annual rate of 4.75%, carry a liquidation value of $50 per security plus accrued and unpaid distributions and are convertible at any time prior to the close of business on March 31, 2028, at the option of the holder, into the following mixed consideration: (i) 0.7197 of a share of KMI Class P common stock; (ii) $25.18 in cash without interest; and (iii) 1.100 warrants to purchase a share of KMI Class P common stock. We have the right to redeem these Trust I Preferred Securities at any time. Because of the substantive conversion rights of the securities into the mixed consideration, we bifurcated the fair value of the EP Trust I Preferred Securities into debt and equity components and as of December 31, 2013, the outstanding balance of $280 million (of which $141 million is classified as current) was bifurcated between debt ($247 million) and equity ($33 million). During the years ended December 31, 2013 and 2012, 107,618 and 781,633 EP Trust I Preferred Securities had been converted into (i) 77,442 and 562,521 shares of KMI Class P common stock; (ii) approximately $3 million and $20 million in cash; and (iii) 118,377 and 859,796 in warrants, respectively.
	(g)	As of December 31, 2013, KMGP had outstanding 100,000 shares of its $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock due 2057.  Until August 18, 2012, dividends accumulated, commencing on the issue date, at a fixed rate of 8.33% per annum and were payable quarterly in arrears, when and if declared by KMGP’s board of directors, on February 18, May 18, August 18 and November 18 of each year, beginning November 18, 2007. After August 18, 2012, dividends on the preferred stock accumulate at a floating rate of the 3-month LIBOR plus 3.8975% and are payable quarterly in arrears, when and if declared by KMGP’s board of directors, on February 18, May 18, August 18 and November 18 of each year, beginning November 18, 2012.  The preferred stock has approval rights over a commencement of or filing of voluntary bankruptcy by KMP or its SFPP or Calnev subsidiaries. (see “—KMGP Preferred Shares” below).
	(h)	Excludes debt fair value adjustments. As of December 31, 2013 and December 31, 2012, our total “Debt fair value adjustments” increased our combined debt balances by $1,977 million and $2,591 million, respectively. In addition to all unamortized debt discount/premium amounts and purchase accounting on our debt balances, our debt fair value adjustments also include (i) amounts associated with the offsetting entry for hedged debt; and (ii) any unamortized portion of proceeds received from the early termination of interest rate swap agreements. For further information about our debt fair value adjustments, see Note 13.
	(i)	In May 2013, in association with the increase of capacity negotiated for KMP’s senior unsecured revolving bank credit facility (see “—Credit Facilities and Restrictive Covenants—KMP” below), KMP increased its commercial paper program by $500 million to provide for the issuance of up to $2.7 billion. As of December 31, 2013 and December 31, 2012, the average interest rates on KMP’s outstanding commercial paper borrowings were 0.28% and 0.45%, respectively. The borrowings under KMP’s commercial paper program were used principally to finance the acquisitions and capital expansions it made during 2013 and 2012.
	(j)	See “Credit Facilities and Restrictive Covenants—KMP” below.
	(k)	Consists of six separate series of fixed-rate unsecured senior notes that KMP assumed as part of the August 2012 drop-down transaction.
	(l)	Consists of four separate series of fixed-rate unsecured senior notes that KMP assumed as part of the August 2012 and March 2013 drop-down transactions.
	(m)	Consists of a single series of fixed-rate unsecured senior notes that KMP guaranteed as part of its May 1, 2013 Copano acquisition. The notes mature on April 1, 2021, and interest on the notes is payable semiannually on April 1 and October 1 of each year. For further information about these notes, see “—KMP’s Copano Debt” below.
	(n)	Includes commercial paper borrowings.
	(o)	EPB’s only operating asset is its investment in EPPOC, and EPPOC’s only operating assets are its investments in Wyoming Interstate Company, L.L.C. (WIC), CIG, SLNG, Elba Express, SNG, ELC and Cheyenne Plains Gas Pipeline Company, L.L.C. (CPG), (collectively, the non-guarantor operating companies). EPB and EPPOC’s independent assets and operations, other than those related to these investments and EPPOC’s debt are less than 3% of the total assets and operations of EPB, and thus substantially all of the operations and assets exist within these non-guarantor operating companies. Furthermore, there are no significant restrictions on EPPOC or EPB’s ability to access the net assets or cash flows related to its controlling interests in the operating companies either through dividend or loan. The restrictive covenants under these debt obligations are no more restrictive than the restrictive covenants under EPB’s credit facility.
	(p)	LIBOR plus 1.75%.
	(q)	CIG is subject to a number of restrictions and covenants under its debt obligation. The most restrictive of these include limitations on the incurrence of liens and limitations on sale-leaseback transactions.
(r)	The SLNG senior notes impose certain limitations on the ability of SLNG to, among other things, incur additional indebtedness, make certain restricted payments, enter into transactions with affiliates, and merge or consolidate with any other person, sell, assign, transfer, lease, convey or otherwise dispose of all or substantially all of its assets. SLNG is required to comply with certain financial covenants, including a leverage ratio of no more than 5.0 to 1.0 and an interest coverage ratio of no less than 2.0 to 1.0. The SLNG senior notes are subject to a change of control prepayment offer in the event of a ratings downgrade within a 120-day period from and including the date on which a change of control with respect to SLNG occurs (as defined in the note purchase agreement). If a sufficient number of the rating agencies downgrade the ratings of the SLNG notes below investment grade within the 120-day period from and including the date of any such change of control, then SLNG is required to offer to prepay the entire unpaid principal amount of the notes held by each holder at 101% of the principal amount of such SLNG notes (without any make-whole amount or other penalty), together with interest accrued thereon to the date for such prepayment.
(s)	Under its indentures, SNG is subject to a number of restrictions and covenants. The most restrictive of these include limitations on the incurrence of liens. SNIC is a wholly owned finance subsidiary of SNG and is the co-issuer of certain of SNG's outstanding debt securities. SNIC has no material assets, operations, revenues or cash flows other than those related to its service as a co-issuer of the debt securities. Accordingly, it has no ability to service obligations on the debt securities.
(t)	In conjunction with the construction of the Totem Gas Storage facility (Totem) and the High Plains pipeline (High Plains), CIG's joint venture partner in WYCO funded 50% of the construction costs. EPB reflected the payments made by their joint venture partner as other long-term liabilities on the balance sheet during construction and upon project completion, the advances were converted into a financing obligation to WYCO. Upon placing these projects in service, EPB transferred its title in the projects to WYCO and leased the assets back. Although EPB transferred the title in these projects to WYCO, the transfer did not qualify for sale leaseback accounting because of EPB’s continuing involvement through its equity investment in WYCO. As such, the costs of the facilities remain on our balance sheets and the advanced payments received from EPB’s 50% joint venture partner were converted into a financing obligation due to WYCO. As of December 31, 2013, the principal amounts of the Totem and High Plains financing obligations were $75 million and $94 million, respectively, which will be paid in monthly installments through 2039, and extended for the term of related firm service agreements until 2060 and 2043, respectively. The interest rate on these obligations is 15.5%, payable on a monthly basis.
Schedule of Significant Long-Term Debt Issuances and Payments [Table Text Block]	'
	Apart from the changes in KMP’s Copano debt discussed above, following are significant long-term debt issuances and repayments made during 2013 and 2012:
			2013		2012
	KMI
	Issuances		$750 million 5.00% notes due 2021		$12,178 million of EP debt assumed as of the May 25, 2012 acquisition date
			$750 million 5.625% notes due 2023		$5,000 million senior term loan facility due 2015
			$251 million EPC Building, LLC 3.967% promissory notes(a)		$217 million EPC Building, LLC 3.967% promissory notes(a)
	Repayments		$1,186 million senior term loan facility due 2015		$839 million 6.50% notes due 2012
					$2,286 million senior term loan facility due 2015
	KMP
	Issuances		$600 million 3.50% notes due 2023		$1,000 million 3.95% notes due 2022
			$700 million 5.00% notes due 2043		$625 million of 3.45% notes due 2023
			$800 million 2.65% notes due 2019		$625 million of 5.00% notes due 2042
			$650 million 4.15% notes due 2024
	Repayments		$500 million 5.00% notes due 2013		$450 million of 7.125% notes due 2012
					$500 million of 5.85% notes due 2012
	EPB (through EPPOC)
	Issuances				$475 million 4.70% notes due 2042
	Repayments		$88 million 8.00% notes due 2013
	_______
	(a)	In December 2012, our subsidiary, EPC Building, LLC had issued $468 million of 3.967% amortizing promissory notes with payments due 2013 through 2035, of which $217 million was issued to third parties and the remaining $251 million was held by KMI until they were sold to third parties in April of 2013. Proceeds from the issuance of the notes were used to reduce KMI’s credit facility borrowings.
Schedule of preferred share distributions [Table Text Block]	'
	The following table provides information about KMGP’s distributions on 100,000 shares of its Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock:
			Year Ended December 31,
			2013				2012
	Per share cash distribution declared for the period(a)		$	42.101			$	63.236
	Per share cash distribution paid in the period		$	42.169			$	73.423
	_______
	(a)	On January 15, 2014, KMGP declared a distribution for the three months ended December 31, 2013, of $10.570 per share, which was paid on February 18, 2014 to shareholders of record as of January 31, 2014.
Schedule of Maturities of Long-term Debt [Table Text Block]	'
	The scheduled maturities of the outstanding debt balances, excluding debt fair value adjustments as of December 31, 2013, are summarized as follows (in millions):
	Year	KMI				KMP			EPB
	2014	$	725			$	1,504		$	77
	2015	1,788				300			756
	2016	928				750			69
	2017	798				1,255			505
	2018	1,322				1,000			5
	Thereafter	4,485				15,105			2,844
	Total	$	10,046			$	19,914		$	4,256

Sharebased_Compensation_and_Em1

Share-based Compensation and Employee Benefits (Tables)	12 Months Ended
	Dec. 31, 2013
Share-based Compensation [Abstract]	'
Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity [Table Text Block]	'
	The following table sets forth a summary of activity and related balances of our restricted stock excluding that issued to non-employee directors (in millions, except share amounts):
		Year Ended							Year Ended							February 11, 2011 Through
		December 31, 2013							December 31, 2012							December 31, 2011
		Shares			Weighted Average				Shares			Weighted Average				Shares			Weighted Average
					Grant Date							Grant Date							Grant Date
					Fair Value							Fair Value							Fair Value
	Outstanding at beginning of period	2,154,022			$	69			1,163,090			$	33			—			$	—
	Granted	4,563,495			181				1,463,388			51				980,851			28
	Shares issued in exchange for cash awards	—			—				—			—				213,040			6
	Vested	(83,444	)		(3		)		(102,033	)		(3		)		—			—
	Forfeited	(251,188	)		(8		)		(370,423	)		(12		)		(30,801	)		(1		)
	Outstanding at end of period	6,382,885			$	239			2,154,022			$	69			1,163,090			$	33
	Intrinsic value of restricted stock vested during the period				$	3						$	4						$	—
Schedule of Share-based Compensation Arrangement by Share-based Payment Award, Restricted Stock Units, Vested and Expected to Vest [Table Text Block]	'
	Year		Vesting of Restricted Shares
	2014		449,043
	2015		741,959
	2016		1,339,735
	2017		470,049
	2018		1,172,468
	2019		1,531,087
	2020		603,072
	2021		20,126
	2023		55,346
	Total Outstanding		6,382,885
Schedule of Defined Benefit Plans Disclosures [Table Text Block]	'
	Benefit Obligation, Plan Assets and Funded Status. The following table provides information about our pension and OPEB plans as of and for each of the years ended December 31, 2013 and 2012, and includes information regarding the EP Pension and OPEB plans since the May 25, 2012 acquisition date (in millions):
		Pension Benefits								OPEB
		2013				2012				2013				2012
	Change in benefit obligation:
	Benefit obligation at beginning of period	$	2,792			$	343			$	720			$	91
	Service cost	25				18				—				—
	Interest cost	92				67				23				18
	Actuarial (gain) loss	(132		)		178				(38		)		40
	Benefits paid	(239		)		(58		)		(54		)		(37		)
	Participant contributions	—				—				11				7
	Medicare Part D subsidy receipts	—				—				6				1
	Business combination(a)	—				2,407				—				606
	Plan amendments	25				(17		)		(37		)		(5		)
	Curtailments, settlements and special termination benefits(b)	—				(146		)		—				(1		)
	Benefit obligation at end of period	2,563				2,792				631				720
	Change in plan assets:
	Fair value of plan assets at beginning of period	2,240				258				341				55
	Actual return on plan assets	254				203				40				24
	Employer contributions	78				32				42				19
	Participant contributions	—				—				11				7
	Benefits paid	(239		)		(58		)		(54		)		(37		)
	Business combination(a)	—				1,949				—				273
	Settlements(b)	—				(144		)		—				—
	Fair value of plan assets at end of period	2,333				2,240				380				341
	Funded status - net liability at December 31,	$	(230	)		$	(552	)		$	(251	)		$	(379	)
	_______
	(a) Reflects the acquisition date amount of benefit plan obligations and assets assumed from El Paso.
	(b) Reflects the settlement of benefit obligations associated with certain participants in the acquired El Paso plans as a result of the sale of EP Energy, a reduction in force and termination of the SERP.
Schedule of Net Funded Status [Table Text Block]	'
	Components of Funded Status. The following table details the amounts recognized in our balance sheet at December 31, 2013 and 2012 related to our pension and OPEB plans (in millions):
		Pension Benefits								OPEB
		2013				2012				2013				2012
	Non-current benefit asset	$	—			$	—			$	224			$	135
	Current benefit liability	—				(28		)		(32		)		(33		)
	Non-current benefit liability	(230		)		(524		)		(443		)		(481		)
	Funded status - net liability at December 31,	$	(230	)		$	(552	)		$	(251	)		$	(379	)
Schedule of Defined Benefit Plan Amounts Recognized in Other Comprehensive Income (Loss) [Table Text Block]	'
	Components of Accumulated Other Comprehensive Income (Loss). The following table details the amounts of pre-tax accumulated other comprehensive income (loss) at December 31, 2013 and 2012 related to our pension and OPEB plans which are included on our accompanying consolidated balance sheets, including the portion attributable to our noncontrolling interests, (in millions):
		Pension Benefits								OPEB
		2013				2012				2013				2012
	Unrecognized net actuarial loss	$	(10	)		$	(218	)		$	(17	)		$	(70	)
	Unrecognized prior service (cost) credit	(5		)		20				21				4
	Accumulated other comprehensive (loss) income	$	(15	)		$	(198	)		$	4			$	(66	)
Fair value of Pension and OPEB assets by level of assets [Table Text Block]	'
	Listed below are the fair values of our pension and OPEB plans’ assets that are recorded at fair value classified in each level at December 31, 2013 and 2012 (in millions):
		Pension Assets
		2013																2012
		Level 1				Level 2				Level 3				Total				Level 1				Level 2				Level 3		Total
	Money market funds	$	—			$	—			$	—			$	—			$	1			$	6			$	—	$	7
	Common/collective trusts(a)	—				940				—				940				—				765				—		765
	Insurance contracts	—				—				15				15				—				—				14		14
	Mutual funds(b)	92				134				—				226				—				266				40		306
	Common and preferred stocks(c)	498				—				—				498				812				—				—		812
	Corporate bonds	—				220				—				220				—				111				—		111
	U.S. government securities	—				120				—				120				—				99				—		99
	Asset backed securities	—				29				—				29				—				25				—		25
	Limited partnerships	—				—				28				28				—				—				24		24
	Equity trusts	—				235				—				235				—				53				—		53
	Private equity	—				—				9				9				—				—				9		9
	Other	—				13				—				13				—				15				—		15
	Total asset fair value(c)	$	590			$	1,691			$	52			$	2,333			$	813			$	1,340			$	87	$	2,240
	_______
	(a)	For 2013, this category includes common/collective trust funds which are invested in approximately 36% fixed income, 62% equity and 2% short term securities. For 2012, this category includes common/collective trusts funds which are invested in approximately 59% fixed income, 36% equity and 5% short term securities.
	(b)	For 2013, this category includes mutual funds which are invested in approximately 60% fixed income and 40% equity. For 2012, this category includes mutual funds which are invested in approximately 28% fixed income, 72% equity and other investments.
	(c)	Plan assets include $229 million and $133 million of KMI Class P common stock for 2013 and 2012, respectively.
		OPEB Assets
		2013																2012
		Level 1				Level 2				Level 3				Total				Level 1				Level 2				Level 3		Total
	Money market funds	$	—			$	—			$	—			$	—			$	11			$	1			$	—	$	12
	Domestic equity securities	13				—				—				13				—				—				—		—
	Common/collective trusts(a)	—				85				—				85				—				277				—		277
	Limited partnerships	92				72				—				164				—				—				—		—
	Insurance contracts	—				—				46				46				—				—				44		44
	Mutual funds	72				—				—				72				—				8				—		8
	Total asset fair value	$	177			$	157			$	46			$	380			$	11			$	286			$	44	$	341
	_______
	(a)	For 2013, this category includes common/collective trust funds which are invested in approximately 70% equity and 30% fixed income securities. For 2012, this category includes common/collective trust funds which are invested in approximately 65% equity and 35% fixed income securities.
Schedule of Changes in Accumulated Postemployment Benefit Obligations [Table Text Block]	'
	The following tables present the changes in our pension and OPEB plans’ assets included in Level 3 for the years ended December 31, 2013 and 2012, including the EP Pension and OPEB plans since the May 25, 2012 acquisition date (in millions):
		Pension Assets
		Balance at Beginning of Period				Transfers In (Out)				Realized and Unrealized Gains (Losses), net				Purchases (Sales), net				Balance at End of Period
	2013
	Insurance contracts	$	14			$	—			$	—			$	1			$	15
	Mutual funds	40				—				—				(40		)		—
	Limited partnerships	24				—				3				1				28
	Private equity	9				—				1				(1		)		9
	Total	$	87			$	—			$	4			$	(39	)		$	52
	2012
	Insurance contracts	$	14			$	—			$	—			$	—			$	14
	Mutual funds	—				38				2				—				40
	Limited partnerships	4				16				—				4				24
	Private equity	9				—				—				—				9
	Total	$	27			$	54			$	2			$	4			$	87
		OPEB Assets
		Balance at Beginning of Period				Transfers In (Out)				Realized and Unrealized Gains (Losses), net				Purchases (Sales), net				Balance at End of Period
	2013
	Insurance contracts	$	44			$	—			$	—			$	2			$	46
	Total	$	44			$	—			$	—			$	2			$	46
	2012
	Insurance contracts	$	42			$	—			$	7			$	(5	)		$	44
	Total	$	42			$	—			$	7			$	(5	)		$	44
Schedule of Expected Benefit Payments [Table Text Block]	'
	Expected Payment of Future Benefits and Employer Contributions. As of December 31, 2013, we expect to make the following benefit payments under our plans (in millions):
	Fiscal year		Pension Benefits				OPEB(a)
	2014		$	191			$	52
	2015		192				51
	2016		195				50
	2017		195				49
	2018		194				48
	2019-2023		964				223
	_______
	(a)	Includes a reduction of approximately $3 million in each of the years 2014 - 2018 and approximately $13 million in aggregate for 2019 - 2023 for an expected subsidy related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003.
Schedule or Description of Weighted Average Discount Rate [Table Text Block]	'
	Actuarial Assumptions and Sensitivity Analysis. Benefit obligations and net benefit cost are based on actuarial estimates and assumptions. The following table details the weighted-average actuarial assumptions used in determining our benefit obligation and net benefit costs of our pension and OPEB plans for 2013, 2012 and 2011:
			Pension Benefits									OPEB
			2013			2012			2011			2013			2012			2011
	Assumptions related to benefit obligations:
	Discount rate		4.45	%		3.4	%		4.5	%		4.34	%		3.34	%		4.25	%
	Rate of compensation increase		3.5	%		3	%		3.5	%		n/a			n/a			n/a
	Assumptions related to benefit costs:
	Discount rate(a)		3.4	%		4.22	%		5.5	%		3.62	%		4.11	%		5	%
	Expected return on plan assets(b)(c)		8	%		8.44	%		8.9	%		7.35	%		8.21	%		8.9	%
	Rate of compensation increase		3	%		3.5	%		3.5	%		n/a			n/a			n/a
	_______
	(a)	The discount rate related to pension benefit cost was 4.50% for the period from January 1, 2012 to May 24, 2012, and 4.03% for the period from May 25, 2012 to December 31, 2012 (the period subsequent to the EP acquisition). The discount rate related to other postretirement benefit cost was 3.34% for the period from January 1, 2013 to July 31, 2013 (the period prior to an OPEB plan amendment that resulted in a remeasurement) and 4.00% for the period from August 1, 2013 to December 31, 2013, and 4.25% for the period from January 1, 2012 to May 24, 2012 and 4.01% for the period from May 25, 2012 to December 31, 2012.
	(b)	The expected return on plan assets related to pension cost was 8.90% for the period from January 1, 2012 to May 24, 2012, and 8.11% for the period from May 25, 2012 to December 31, 2012 (the period subsequent to the EP acquisition). The expected return on plan assets related to other postretirement benefit cost was 8.90% for the period from January 1, 2012 to May 24, 2012, and 7.72% for the period from May 25, 2012 to December 31, 2012.
	(c)	The expected return on plan assets listed in the table above is a pre-tax rate of return based on our targeted portfolio of investments. For the assumed EP OPEB plans, we utilize an after-tax expected return on plan assets to determine our benefit costs, which is based on unrelated business income taxes at a rate of 24% and 22% for 2013 and 2012, respectively.
Schedule of Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates [Table Text Block]	'
	Actuarial estimates for our OPEB plans assumed a weighted-average annual rate of increase in the per capita cost of covered health care benefits of 6.57%, gradually decreasing to 5.00% by the year 2019. Assumed health care cost trends have a significant effect on the amounts reported for OPEB plans. A one-percentage point change in assumed health care cost trends would have the following effects as of December 31, 2013 and 2012 (in millions):
			2013				2012
	One-percentage point increase:
	Aggregate of service cost and interest cost		$	2			$	1
	Accumulated postretirement benefit obligation		45				52
	One-percentage point decrease:
	Aggregate of service cost and interest cost		$	(1	)		$	(1	)
	Accumulated postretirement benefit obligation		(39		)		(45		)
Schedule of Net Benefit Costs [Table Text Block]	'
	Components of Net Benefit Cost and Other Amounts Recognized in Other Comprehensive Income. For each of the years ended December 31, the components of net benefit cost and other amounts (including amounts associated with the EP Pension and OPEB plans since the May 25, 2012 acquisition date) recognized in pre-tax other comprehensive income related to our pension and OPEB plans are as follows (in millions):
			Pension Benefits												OPEB
			2013				2012				2011				2013				2012				2011
	Components of net benefit cost:
	Service cost		$	25			$	18			$	13			$	—			$	—			$	—
	Interest cost		92				67				17				23				18				4
	Expected return on assets		(175		)		(110		)		(22		)		(22		)		(15		)		(5		)
	Amortization of prior service (credit) cost		—				(1		)		(1		)		(1		)		(1		)		—
	Amortization of net actuarial loss		—				10				7				3				4				4
	Curtailment and settlement gain		(3		)		(2		)		—				—				(1		)		—
	Net benefit (credit) cost		(61		)		(18		)		14				3				5				3
	Other changes in plan assets and benefit obligations recognized in other comprehensive (income) loss:
	Net (gain) loss arising during period		(211		)		85				46				(50		)		25				13
	Prior service cost (credit) arising during period		25				(17		)		(6		)		(18		)		(4		)		—
	Amortization or settlement recognition of net actuarial gain (loss)		3				(10		)		(7		)		(3		)		(5		)		(4		)
	Amortization of prior service credit		—				1				1				1				1				—
	Total recognized in total other comprehensive income loss		(183		)		59				34				(70		)		17				9
	Total recognized in net benefit (credit) cost and other comprehensive (income) loss		$	(244	)		$	41			$	48			$	(67	)		$	22			$	12

Stockholders_Equity_Tables

Stockholders Equity (Tables)	12 Months Ended
	Dec. 31, 2013
Stockholders' Equity Note [Abstract]	'
Schedule of Common Stock Outstanding Roll Forward	'
	The following table sets forth the changes in our outstanding shares during the years ended December 31, 2013 and 2012 and during 2011 since becoming public (see “—Initial Public Offering” following):
		Class P			Class A			Class B			Class C
	Balance at February 16, 2011	109,786,590			597,213,410			100,000,000			2,462,927
	Shares converted	61,241,023			(61,241,023	)		(5,867,404	)		(144,669	)
	Shares canceled	(108,043	)		—			—			—
	Restricted shares vested	1,570			—			—			—
	Balance at December 31, 2011	170,921,140			535,972,387			94,132,596			2,318,258
	Shares issued for EP acquisition (see Note 3)	330,154,610			—			—			—
	Shares issued with conversions of EP Trust I Preferred securities	562,521			—			—			—
	Shares converted	535,972,387			(535,972,387	)		(94,132,596	)		(2,318,258	)
	Shares canceled	(2,049,615	)		—			—			—
	Restricted shares vested	107,553			—			—			—
	Balance at December 31, 2012	1,035,668,596			—			—			—
	Shares issued for EP acquisition(a)	53
	Shares repurchased and canceled	(5,175,055	)
	Shares issued with conversions of EP Trust I Preferred securities	77,442
	Shares issued for exercised warrants	16,886
	Restricted shares vested	89,154
	Balance at December 31, 2013	1,030,677,076
Schedule of Dividends Payable [Table Text Block]	'
	The following table provides information about our per share dividends:
		Year Ended December 31,
		2013				2012				2011(a)
	Per common share cash dividend declared for the period	$	1.6			$	1.4			$	1.05
	Per common share cash dividend paid in the period	$	1.56			$	1.34			$	0.74
Schedule of Warrants Outstanding Roll Forward [Table Text Block]	'
	The table below sets forth the changes in our outstanding warrants during 2013 and 2012.
		Warrants
		2013			2012
	Beginning balance	439,809,442			—
	Warrants issued in EP acquisition(a)	81			504,598,883
	Warrants issued with conversions of EP Trust I Preferred securities(b)	118,377			859,796
	Warrants exercised	(21,208	)		—
	Warrants repurchased and canceled	(91,973,585	)		(65,649,237	)
	Ending balance	347,933,107			439,809,442
	_______
	(a)	See Note 3. 2013 amount represents warrants issued upon the settlement of an EP dissenter. The settlement of the dissenter’s 128 EP shares was determined based on the same conversion of EP shares into cash, KMI Class P shares and KMI warrants that was received by other EP shareholders at the time of the acquisition.
	(b)	See Note 8.
Schedule of Noncontrolling Interest [Table Text Block]	'
	The caption “Noncontrolling interests” in our accompanying consolidated balance sheets consists of interests that we do not own in the following subsidiaries (in millions):
		December 31,
		2013				2012
	KMP	$	7,642			$	3,270
	EPB	4,122				4,111
	KMR	3,142				2,716
	Other	286				137
		$	15,192			$	10,234
Schedule of noncontrolling interest contributions text block [Table Text Block]	'
	The table below shows significant issuances to the public of common units or shares, the net proceeds from the issuances and the use of the proceeds during the years ended December 31, 2013 and 2012 by KMP, EPB and KMR (dollars in millions and shares in thousands).
		Issuances		Common units/shares			Net proceeds				Use of proceeds
				(in thousands)			(in millions)
	KMP
	Issued under Equity Distribution Agreement(a)
		2013		10,814			$	900			Reduced borrowings under KMP’s commercial paper program
		2012		6,933			$	560			Reduced borrowings under KMP’s commercial paper program
	Other issuances
		Feb-13		4,600			$	385			Issued to pay a portion of the purchase price for the March 2013 drop-down transaction
		May-13		43,371			$	—		(b)	Issued to Copano unitholders as KMP’s purchase price for Copano
		Jun-12		3,792			$	—		(c)	Issued as KMP's purchase price for the 50% equity ownership interest in EP midstream assets it acquired from KKR
		December 2012(d)		4,485			$	349			Reduced borrowings under KMP's commercial paper program
	EPB
	Issued under Equity Distribution Agreement(e)
		2013		2,038			$	85		(f)	General partnership purposes
	Other issuances
		September 2012(d)		8,165			$	272		(g)	Repayment of CPG debt, certain EPB short-term debt and general partnership purposes
	KMR
	Issued under Equity Distribution Agreement(h)
		2013		2,640			$	210			Purchased additional KMP i-units; KMP then used proceeds to reduce borrowings under its commercial paper program
		Sep-12		10,120			$	727			Purchased additional KMP i-units; KMP then used proceeds for a portion of the purchase price of the August 2012 drop-down transaction
	_______
	(a)	On June 3, 2013, KMP entered into a fourth amended and restated equity distribution agreement with UBS Securities LLC (UBS) which increased the aggregate offering price of KMP’s common units to up to $2.175 billion (up from $1.9 billion), and on August 7, 2013, KMP entered into a second and separate equity distribution agreement with UBS. The terms of this new equity distribution agreement are substantially similar to those in KMP’s previous agreement, and it allows KMP to offer and sell from time to time additional KMP common units having an aggregate offering price of up to $1.9 billion through UBS, as sales agent. On February 27, 2012, KMP entered into a third amended and restated equity distribution agreement with UBS which increased the aggregate offering price of its common units to up to $1.9 billion (up from $1.2 billion).
	(b)	KMP valued these units at $3,733 million based on the $86.08 closing market price of a KMP common unit on the NYSE on May 1, 2013.
	(c)	See Note 3.
	(d)	Includes the underwriters’ exercise of the overallotment option.
	(e)	On March 7, 2013, EPB entered into an equity distribution agreement with Global Markets, Inc. (Citigroup). Pursuant to the provisions of EPB’s equity distribution agreement, EPB may sell from time to time through Citigroup, as its sales agent, EPB’s common units representing limited partner interests having an aggregate offering price of up to $500 million.
	(f)	Represents proceeds received from noncontrolling interests and excludes our $2 million contribution as the owner of EPB’s general partner.
	(g)	Represents proceeds received from noncontrolling interests and excludes our $7 million contribution as the owner of EPB’s general partner.
	(h)	On May 4, 2012, KMR entered into an equity distribution agreement with Credit Suisse Securities (USA) LLC (Credit Suisse). Pursuant to the provisions of KMR’s equity distribution agreement, it may sell from time to time through Credit Suisse, as its sales agent, KMR shares having an aggregate offering price of up to $500 million.
Schedule of Distributions by Noncontrolling Interests [Table Text Block]	'
	The following table provides information about distributions from our noncontrolling interests (in millions except per unit and i-unit distribution amounts):
		Year Ended December 31,
		2013				2012				2011
	KMP
	Per unit cash distribution declared for the period	$	5.33			$	4.98			$	4.61
	Per unit cash distribution paid in the period	$	5.26			$	4.85			$	4.58
	Cash distributions paid in the period to the public	$	1,372			$	1,081			$	955
	EPB(a)
	Per unit cash distribution declared for the period	$	2.55			$	1.74			n/a
	Per unit cash distribution paid in the period	$	2.51			$	1.13			n/a
	Cash distributions paid in the period to the public	$	318			$	137			n/a
	KMR(b)
	Share distributions paid in the period to the public	6,588,477				5,586,579				5,659,507
	_______
	(a)	Represents distribution information since the May 2012 EP acquisition.
	(b)	KMR’s distributions are paid in the form of additional shares or fractions thereof calculated by dividing the KMP cash distribution per common unit by the average of the market closing prices of a KMR share determined for a ten-trading day period ending on the trading day immediately prior to the ex-dividend date for the shares.  Represents share distributions made in the period to noncontrolling interests and excludes 976,723, 902,367 and 941,895 of shares distributed in 2013, 2012 and 2011, respectively, on KMR shares we directly and indirectly own. On February 14, 2014, KMR paid a share distribution of 0.017841 shares per outstanding share (2,237,258 total shares) to shareholders of record as of January 31, 2014, based on the $1.36 per common unit distribution declared by KMP, of which 1,952,970 shares were distributed to the public.
Distribution Waterfall Table [Table Text Block]	'
	Cash from operations for each quarter will be distributed effectively as follows:
				Marginal percentage interest in distribution
		Total quarterly distribution per unit target amount		Unitholders		General partner
	First target distribution	$0.15		98%		2%
	Second target distribution	above $0.15125 up to $0.17875		85%		15%
	Third target distribution	above $0.17875 up to $0.23375		75%		25%
	Thereafter	above $0.23375		50%		50%
	The percentage interests set forth below for El Paso Pipeline GP Company, L.L.C., as EPB’s general partner, include its 2% general partner interest and assume El Paso Pipeline GP Company, L.L.C. has contributed any additional capital necessary to maintain its 2% general partner interest and has not transferred its IDRs.
				Marginal percentage interest in distributions
		Total quarterly distribution per unit target amount		Unitholders		General partner
	Minimum quarterly distribution	$0.29		98%		2%
	First target distribution	above $0.2875 up to $0.33063		98%		2%
	Second target distribution	above $0.33063 up to $0.35938		85%		15%
	Third target distribution	above $0.35938 up to $0.43125		75%		25%
	Thereafter	above $0.43125		50%		50%

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2013
Related Party Transaction [Line Items]	'
Schedule of Related Party Transactions [Table Text Block]	'
	The following table summarizes our balance sheet affiliate balances (in millions):
		Year Ended December 31,
		2013		2012
	Balance sheet location
	Accounts receivable, net	$	19	$	25
	Assets held for sale(a)	—		114
	Other current assets	3		14
	Deferred charges and other assets	47		48
		$	69	$	201
	Current portion of debt – KMP and EPB(b)	$	6	$	5
	Accounts payable	9		11
	Long-term debt - Outstanding - KMP and EPB(b)	169		173
		$	184	$	189
	_______
	(a)	2012 amount related to KMP’s equity investment in the Express pipeline system (see Note 2).
	(b)	EPB has financing obligations payable to WYCO.

Commitments_and_Contingent_Lia1

Commitments and Contingent Liabilities (Tables)	12 Months Ended
	Dec. 31, 2013
Schedule of Future Minimum Rental Payments [Abstract]	'
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]	'
	The table below depicts future gross minimum rental commitments under our operating leases as of December 31, 2013 (in millions):
	Year	Commitment
	2014	$	70
	2015	59
	2016	50
	2017	39
	2018	37
	Thereafter	177
	Total minimum payments	$	432

Risk_Management_Tables

Risk Management (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative [Line Items]	'
Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]	'
	Changes in the components of our “Accumulated other comprehensive loss” for the year ended December 31, 2013 are summarized as follows (in millions):
		Net unrealized				Foreign				Pension and				Total
		gains/(losses)				currency				other				Accumulated other
		on cash flow				translation				postretirement				comprehensive
		hedge derivatives				adjustments				liability adjustments				income/(loss)
	Balance as of December 31, 2012	$	7			$	51			$	(176	)		$	(118	)
	Other comprehensive (loss) income before reclassifications	(14		)		(49		)		151				88
	Amounts reclassified from accumulated other comprehensive income	4				—				2				6
	Net current-period other comprehensive (loss) income	(10		)		(49		)		153				94
	Balance as of December 31, 2013	$	(3	)		$	2			$	(23	)		$	(24	)
Schedule of Derivative Instruments [Table Text Block]	'
	As of December 31, 2013, KMP and KMI had entered into the following outstanding commodity forward contracts to hedge their forecasted energy commodity purchases and sales:
		Net open position long/(short)
	Derivatives designated as hedging contracts
	Crude oil fixed price	(22.6	)	MMBbl
	Natural gas fixed price	(19.8	)	Bcf
	Natural gas basis	(18.9	)	Bcf
	Derivatives not designated as hedging contracts
	Crude oil fixed price	(0.9	)	MMBbl
	Natural gas fixed price	(17.3	)	Bcf
	Natural gas basis	(8.2	)	Bcf
	NGL fixed price	(1.1	)	MMBbl
	As of December 31, 2013, the maximum length of time over which we have hedged our exposure to the variability in future cash flows associated with energy commodity price risk is through December 2017.
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	'
	The following table summarizes the fair values of our derivative contracts included on our accompanying consolidated balance sheets as of December 31, 2013 and 2012 (in millions):
	Fair Value of Derivative Contracts
				Asset derivatives								Liability derivatives
				December 31,								December 31,
				2013				2012				2013				2012
		Balance sheet location		Fair value								Fair value
	Derivatives designated as hedging contracts
	Natural gas and crude derivative contracts	Other current assets/(Other current liabilities)		$	18			$	42			$	(33	)		$	(18	)
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		58				40				(30		)		(11		)
	Subtotal			76				82				(63		)		(29		)
	Interest rate swap agreements	Other current assets/(Other current liabilities)		87				9				—				—
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		172				656				(116		)		(1		)
	Subtotal			259				665				(116		)		(1		)
	Total			335				747				(179		)		(30		)
	Derivatives not designated as hedging contracts
	Natural gas, crude and NGL derivative contracts	Other current assets/(Other current liabilities)		4				4				(5		)		(3		)
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		—				—				—				(1		)
	Subtotal			4				4				(5		)		(4		)
	Power derivative contracts	Other current assets/(Other current liabilities)		7				8				(54		)		(59		)
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		11				13				(73		)		(120		)
	Subtotal			18				21				(127		)		(179		)
	Total			22				25				(132		)		(183		)
	Total derivatives			$	357			$	772			$	(311	)		$	(213	)
Schedule of Derivative Contracts Subject to Netting Agreements [Table Text Block]	'
	The following tables present our derivative contracts subject to such netting agreements as of the dates indicated (in millions):
			Offsetting of Financial Assets and Derivative Assets
															Gross amounts not offset in the balance sheet
			Gross amounts of recognized assets				Gross amounts offset in the balance sheet				Amounts of assets presented in the balance sheet				Financial instruments				Cash collateral held(a)				Net amount
	As of December 31, 2013:
	Natural gas, crude and NGL derivative contracts		$	80			$	—			$	80			$	(44	)		$	—			$	36
	Power derivative contracts		$	18			$	—			$	18			$	(18	)		$	—			$	—
	Interest rate swap agreements		$	259			$	—			$	259			$	(28	)		$	—			$	231
	As of December 31, 2012:
	Natural gas, crude and NGL derivative contracts		$	86			$	—			$	86			$	(17	)		$	—			$	69
	Power derivative contracts		$	21			$	—			$	21			$	(21	)		$	—			$	—
	Interest rate swap agreements		$	665			$	—			$	665			$	—			$	—			$	665
			Offsetting of Financial Liabilities and Derivative Liabilities
															Gross amounts not offset in the balance sheet
			Gross amounts of recognized liabilities				Gross amounts offset in the balance sheet				Amounts of liabilities presented in the balance sheet				Financial instruments				Cash collateral posted(b)				Net amount
	As of December 31, 2013:
	Natural gas, crude and NGL derivative contracts		$	(68	)		$	—			$	(68	)		$	44			$	17			$	(7	)
	Power derivative contracts		$	(127	)		$	—			$	(127	)		$	18			$	—			$	(109	)
	Interest rate swap agreements		$	(116	)		$	—			$	(116	)		$	28			$	—			$	(88	)
	As of December 31, 2012:
	Natural gas, crude and NGL derivative contracts		$	(33	)		$	—			$	(33	)		$	17			$	5			$	(11	)
	Power derivative contracts		$	(179	)		$	—			$	(179	)		$	21			$	—			$	(158	)
	Interest rate swap agreements		$	(1	)		$	—			$	(1	)		$	—			$	—			$	(1	)
	_______
	(a)	Cash margin deposits held by KMP associated with its energy commodity contract positions and OTC swap agreements and reported within “Other current liabilities” in our accompanying consolidated balance sheets.
	(b)	$17 million and $5 million of cash margin deposits posted by KMP at December 31, 2013 and December 31, 2012, respectively, associated with energy commodity contract positions and OTC swap agreements and reported within “Other current assets” in our accompanying consolidated balance sheets.
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance	'
	The following two tables summarize the impact of our derivative contracts on our accompanying consolidated statements of income for each of the years ended December 31, 2013, 2012 and 2011 (in millions):
	Derivatives in fair value hedging relationships		Location of gain/(loss)recognized in income on derivatives		Amount of gain/(loss)recognized in income on derivatives and related hedged item(a)
					Year Ended December 31,
					2013				2012				2011
	Interest rate swap agreements		Interest expense		$	(425	)		$	55			$	545
	Total				$	(425	)		$	55			$	545
	Fixed rate debt		Interest expense		$	425			$	(55	)		$	(545	)
	Total				$	425			$	(55	)		$	(545	)
	_______
	(a) Amounts reflect the change in the fair value of interest rate swap agreements and the change in the fair value of the associated fixed rate debt, which exactly offset each other as a result of no hedge ineffectiveness.
	Derivatives in cash flow hedging relationships		Amount of gain/(loss) recognized in OCI on derivative (effective portion)(a)												Location of gain/(loss) reclassified from Accumulated OCI into income (effective portion)		Amount of gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b)											Location of gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	Amount of gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)
			Year Ended														Year Ended												Year Ended
			December 31,														December 31,												December 31,
			2013				2012				2011						2013				2012				2011				2013		2012			2011
	Energy commodity derivative contracts		$	(45	)		$	87			$	13			Revenues—Natural gas sales		$	—			$	4			$	2		Revenues—Natural gas sales	$	—	$	—		$	—
															Revenues—Product sales and other		(13		)		(15		)		(193		)	Revenues—Product sales and other	3		(11		)	5
															Costs of sales		—				17				7			Costs of sales	—		—			—
	Interest rate swap agreements		7				(5		)		—				Interest expense		2				2				—			Interest expense	—		—			—
	Total		$	(38	)		$	82			$	13			Total		$	(11	)		$	8			$	(184	)	Total	$	3	$	(11	)	$	5
	_______
	(a)	We expect to reclassify an approximate $1 million loss associated with energy commodity price risk management activities and included in our accumulated other comprehensive loss and noncontrolling interest balances as of December 31, 2013 into earnings during the next twelve months (when the associated forecasted sales and purchases are also expected to occur), however, actual amounts reclassified into earnings could vary materially as a result of changes in market prices.
	(b)	Amounts reclassified were the result of the hedged forecasted transactions actually affecting earnings (i.e., when the forecasted sales and purchases actually occurred).

Fair_Value_Tables

Fair Value (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'
Fair Value, by Balance Sheet Grouping	'
	The estimated fair value of our outstanding debt balance (both short-term and long-term and including debt fair value adjustments), is disclosed below (in millions):
		December 31, 2013						December 31, 2012
		Carrying			Estimated			Carrying			Estimated
		value			fair value			value			fair value
	Total debt	$	36,193		$	36,248		$	34,401		$	36,720
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation	'
	The table below provides a summary of changes in the fair value of our Level 3 energy commodity derivative contracts for each of the years ended December 31, 2013 and 2012 (in millions):
	Significant unobservable inputs (Level 3)
		Year Ended December 31,
		2013			2012
	Derivatives-net asset (liability)
	Beginning of period	$	(155	)	$	7
	Total gains or (losses)
	Included in earnings	(5		)	(4		)
	Included in other comprehensive income	(1		)	(1		)
	Purchases (a)	17			(194		)
	Settlements	34			37
	End of period	$	(110	)	$	(155	)
	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	$	(8	)	$	(2	)
	_______
	(a)	2012 purchases include a net liability of $197 million of Level 3 energy commodity derivative contracts associated with the EP acquisition. 2013 purchases include a net asset of $18 million of Level 3 energy commodity derivative contracts assumed in conjunction with KMP’s May 1, 2013 Copano acquisition.
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	'
	he fair value measurements in the tables below do not include cash margin deposits made by us, which are reported within “Other current assets” in our accompanying consolidated balance sheets (in millions).
		Asset fair value measurements using
		Total			Quoted prices in			Significant other			Significant
					active markets			observable			unobservable
					for identical			inputs			inputs
					assets			(Level 2)			(Level 3)
					(Level 1)
	As of December 31, 2013
	Energy commodity derivative contracts(a)	$	98		$	4		$	46		$	48
	Interest rate swap agreements	$	259		$	—		$	259		$	—
	As of December 31, 2012
	Energy commodity derivative contracts(a)	$	107		$	3		$	76		$	28
	Interest rate swap agreements	$	665		$	—		$	665		$	—
		Liability fair value measurements using
		Total			Quoted			Significant			Significant
					prices in			other			unobservable
					active			observable			inputs
					markets			inputs			(Level 3)
					for identical			(Level 2)
					liabilities
					(Level 1)
	As of December 31, 2013
	Energy commodity derivative contracts(a)	$	(195	)	$	(6	)	$	(31	)	$	(158	)
	Interest rate swap agreements	$	(116	)	$	—		$	(116	)	$	—
	As of December 31, 2012
	Energy commodity derivative contracts(a)	$	(212	)	$	(3	)	$	(26	)	$	(183	)
	Interest rate swap agreements	$	(1	)	$	—		$	(1	)	$	—
	_______
	(a)	Level 1 consists primarily of NYMEX natural gas futures.  Level 2 consists primarily of OTC WTI swaps and OTC natural gas swaps that are settled on NYMEX.  Level 3 consists primarily of WTI options, NGL options and power derivative contracts.

Reportable_Segments_Tables

Reportable Segments (Tables)	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Schedule of Revenue from External Customers Attributed to Foreign Countries by Geographic Area [Table Text Block]	'
	Following is geographic information regarding the revenues and long-lived assets of our business segments (in millions):
		Year Ended December 31,
		2013			2012			2011
	Revenues from external customers
	U.S.	$	13,656		$	9,488		$	7,513
	Canada	398			407			411
	Mexico and other(a)	16			78			19
	Total consolidated revenues from external customers	$	14,070		$	9,973		$	7,943
		2013			2012			2011
	Long-lived assets at December 31(b)
	U.S.	$	42,080		$	37,651		$	20,848
	Canada	2,214			2,035			1,863
	Mexico and other(a)	81			82			84
	Total consolidated long-lived assets	$	44,375		$	39,768		$	22,795
	_______
	(a)	Includes operations in Mexico and until August 31, 2011, the Netherlands.
	(b)	Long-lived assets exclude goodwill and other intangibles, net.
Schedule of Segment Reporting Information, by Segment	'
	Financial information by segment follows (in millions):
		Year Ended December 31,
		2013			2012			2011
	Revenues
	Natural Gas Pipelines(a)
	Revenues from external customers	$	8,613		$	5,230		$	3,943
	Intersegment revenues	4			—			—
	CO2—KMP	1,857			1,677			1,434
	Products Pipelines—KMP	1,853			1,370			914
	Terminals—KMP
	Revenues from external customers	1,408			1,356			1,314
	Intersegment revenues	2			3			1
	Kinder Morgan Canada—KMP	302			311			302
	Other	1			(6		)	—
	Total segment revenues	14,040			9,941			7,908
	Other revenues(b)	36			35			36
	Less: Total intersegment revenues	(6		)	(3		)	(1		)
	Total consolidated revenues	$	14,070		$	9,973		$	7,943
		Year Ended December 31,
		2013			2012			2011
	Operating expenses(c)
	Natural Gas Pipelines(a)	$	5,235		$	3,111		$	3,370
	CO2—KMP	439			381			342
	Products Pipelines—KMP	1,295			759			500
	Terminals—KMP	657			685			634
	Kinder Morgan Canada—KMP	110			103			97
	Other	30			5			—
	Total segment operating expenses	7,766			5,044			4,943
	Other operating expenses	—			4			1
	Less: Total intersegment operating expenses	(6		)	(3		)	(1		)
	Total consolidated operating expenses	$	7,760		$	5,045		$	4,943
		Year Ended December 31,
		2013			2012			2011
	Other expense (income)
	Natural Gas Pipelines(a)	$	(24	)	$	14		$	1
	CO2—KMP	—			(7		)	—
	Products Pipelines—KMP	6			(5		)	(8		)
	Terminals—KMP	(74		)	(14		)	1
	Other	(7		)	(1		)	—
	Total consolidated other expense (income)	$	(99	)	$	(13	)	$	(6	)
		Year Ended December 31,
		2013			2012			2011
	DD&A
	Natural Gas Pipelines(a)	$	797		$	478		$	163
	CO2—KMP	533			494			492
	Products Pipelines—KMP	155			143			131
	Terminals—KMP	247			236			226
	Kinder Morgan Canada—KMP	54			56			56
	Other	20			12			—
	Total consolidated DD&A	$	1,806		$	1,419		$	1,068
		Year Ended December 31,
		2013			2012			2011
	Earnings (loss) from equity investments
	Natural Gas Pipelines(a)(d)	$	232		$	52		$	158
	CO2—KMP	24			25			24
	Products Pipelines—KMP	45			39			34
	Terminals—KMP	22			21			11
	Kinder Morgan Canada—KMP	4			5			(2		)
	Other	—			11			1
	Total consolidated equity earnings (loss)	$	327		$	153		$	226
		Year Ended December 31,
		2013			2012			2011
	Amortization of excess cost of equity investments
Natural Gas Pipelines(a)	$	32		$	17		$	1
CO2—KMP	2			2			2
Products Pipelines—KMP	5			4			4
Total consolidated amortization of excess cost of equity investments	$	39		$	23		$	7
	Year Ended December 31,
	2013			2012			2011
Interest income
Natural Gas Pipelines	$	—		$	18		$	—
CO2—KMP	—			—			1
Products Pipelines—KMP	2			2			3
Kinder Morgan Canada—KMP	3			14			14
Other	8			3			—
Total segment interest income	13			37			18
Unallocated interest income	2			(9		)	3
Total consolidated interest income	$	15		$	28		$	21
	Year Ended December 31,
	2013			2012			2011
Other, net-income (expense)
Natural Gas Pipelines(e)	$	578		$	4		$	(164	)
CO2—KMP	—			(1		)	4
Products Pipelines—KMP	1			9			5
Terminals—KMP	1			2			6
Kinder Morgan Canada—KMP(f)	246			3			—
Other	9			2			(1		)
Total consolidated other, net-income (expense)	$	835		$	19		$	(150	)
	Year Ended December 31,
	2013			2012			2011
Income tax benefit (expense)
Natural Gas Pipelines	$	(9	)	$	(5	)	$	(3	)
CO2—KMP	(7		)	(5		)	(4		)
Products Pipelines—KMP	2			2			(3		)
Terminals—KMP	(14		)	(3		)	5
Kinder Morgan Canada—KMP(g)	(105		)	(1		)	(15		)
Total segment income tax expense	(133		)	(12		)	(20		)
Unallocated income tax expense	(609		)	(127		)	(341		)
Total consolidated income tax expense	$	(742	)	$	(139	)	$	(361	)
	Year Ended December 31,
	2013			2012			2011
Segment EBDA(h)
Natural Gas Pipelines(a)	$	4,207		$	2,174		$	563
CO2—KMP	1,435			1,322			1,117
Products Pipelines—KMP	602			668			461
Terminals—KMP	836			708			702
Kinder Morgan Canada—KMP	340			229			202
Other	(5		)	7			—
Total segment EBDA	7,415			5,108			3,045
Total segment DD&A	(1,806		)	(1,419		)	(1,068		)
Total segment amortization of excess cost of equity investments	(39		)	(23		)	(7		)
Other revenues	36			35			36
General and administrative expenses(i)	(613		)	(929		)	(515		)
Interest expense, net of unallocable interest income(j)	(1,688		)	(1,441		)	(701		)
Unallocable income tax expense	(609		)	(127		)	(341		)
(Loss) income from discontinued operations, net of tax(k)	(4		)	(777		)	211
Total consolidated net income	$	2,692		$	427		$	660
	Year Ended December 31,
	2013			2012			2011
Capital expenditures
Natural Gas Pipelines(a)	$	1,085		$	499		$	153
CO2—KMP	667			453			432
Products Pipelines—KMP	416			307			254
Terminals—KMP	1,108			707			332
Kinder Morgan Canada—KMP	77			16			28
Other	16			40			1
Total consolidated capital expenditures	$	3,369		$	2,022		$	1,200
	2013			2012
Investments at December 31
Natural Gas Pipelines	$	5,130		$	5,193
CO2—KMP	12			11
Products Pipelines—KMP	611			400
Terminals—KMP	196			179
Kinder Morgan Canada—KMP	1			1
Other	1			20
Total consolidated investments	$	5,951		$	5,804
	2013			2012
Assets at December 31
Natural Gas Pipelines(a)	$	52,357		$	46,600
CO2—KMP	4,708			4,148
Products Pipelines—KMP	6,648			6,089
Terminals—KMP	6,888			5,931
Kinder Morgan Canada—KMP	1,677			1,724
Other	568			601
Total segment assets	72,846			65,093
Corporate assets(l)	2,339			2,854
Assets held for sale(m)	—			298
Total consolidated assets	$	75,185		$	68,245
_______
(a)	The changes in the 2012 amount versus the 2011 amount include the effects of the acquisition of EP and for 2013 versus 2012 only, KMP’s acquisition of Copano. See Note 3.
(b)	Primarily represents a reimbursement of general and administrative costs for services we perform for NGPL Holdco LLC.
(c)	Includes natural gas purchases and other costs of sales, operations and maintenance expenses, and taxes, other than income taxes.
(d)	2013 and 2012 amounts include impairment charges of $65 million and $200 million, respectively, to reduce the carrying value of our investment in NGPL Holdco LLC (see Note 6).
(e)	2013 amount includes a $558 million gain from the remeasurement of our previously held 50% equity interest in Eagle Ford to fair value (discussed further in Note 3). 2011 amount includes a $167 million loss from the remeasurement of KMP’s previously held 50% equity interest in KinderHawk to fair value (see Note 3).
(f)	2013 amount includes a $224 million gain from the sale of our equity and debt investments in the Express pipeline system (discussed further in Note 3).
(g)	2013 amount includes an $84 million increase in expense related to the pre-tax gain amount described in footnote (f).
(h)	Includes revenues, earnings from equity investments, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other expense (income).
(i)	2012 amount includes $352 million of pretax expense associated with the EP acquisition and EP Energy sale.
(j)	Includes (i) interest expense and (ii) miscellaneous other income and expenses not allocated to business segments. 2012 amount includes $108 million of expense for capitalized financing fees associated with the EP acquisition financing that were written-off (due to debt repayments) or amortized.
(k)	Represents amounts from KMP’s FTC Natural Gas Pipelines disposal group and other, net of tax (see Note 3).
(l)	Includes cash and cash equivalents, margin and restricted deposits, unallocable interest receivable, prepaid assets and deferred charges, risk management assets related to debt fair value adjustments and miscellaneous corporate assets (such as information technology and telecommunications equipment) not allocated to individual segments.
(m)	Primarily represents amounts attributable to KMP’s Express pipelines system and our ownership interest in Bolivia to Brazil Pipeline.

Reconciliation_of_Significant_1

Reconciliation of Significant Asset and Liabilities Balances (Tables)	12 Months Ended
	Dec. 31, 2013
Reconciliation of Significant Asset and Liability Balances [Line Items]	'
Reconcilliation of significant asset balances [Table Text Block]	'
	The following is a reconciliation between KMP’s and EPB’s significant asset balances as reported in KMP’s and EPB’s Annual Report on Form 10-K as of December 31, 2013 and 2012 and our consolidated asset balances as shown on our accompanying consolidated balance sheets (in millions):
		December 31,
		2013		2012
	Cash and cash equivalents - KMI(a)	$	116	$	71
	Cash and cash equivalents - KMP	404		529
	Cash and cash equivalents - EPB	78		114
	Cash and cash equivalents	$	598	$	714
	Property, plant and equipment, net–KMI(a)	$	2,563	$	2,735
	Property, plant and equipment, net–KMP	27,405		22,330
	Property, plant and equipment, net–EPB	5,879		5,931
	Property, plant and equipment, net	$	35,847	$	30,996
	Goodwill–KMI(a)	$	17,935	$	18,193
	Goodwill–KMP	6,547		5,417
	Goodwill–EPB	22		22
	Goodwill	$	24,504	$	23,632
	Current portion of debt–KMI(a)	$	725	$	1,153
	Current portion of debt–KMP	1,504		1,155
	Current portion of debt–EPB	77		93
	Current portion of debt	$	2,306	$	2,401
	Long-term debt outstanding–KMI(a)	$	9,221	$	9,148
	Long-term debt outstanding–KMP	18,410		15,907
	Long-term debt outstanding–EPB(b)	4,179		4,254
	Long-term debt outstanding	$	31,810	$	29,309
	_______
	(a)	Includes assets and liabilities of KMI’s consolidated subsidiaries, excluding KMP and EPB.
	(b)	Excludes debt fair value adjustments.  Decrease to long-term debt for debt fair value adjustments totaled $8 million as of both December 31, 2013 and 2012.

Guarantee_of_Securities_of_Sub1

Guarantee of Securities of Subsidiaries (Tables)	12 Months Ended
	Dec. 31, 2013
Guarantee of Securities of Subsidiaries [Abstract]	'
Schedule of Condensed Balance Sheet [Table Text Block]	'
	Condensed Consolidating Balance Sheets as of December 31, 2013
	(In Millions)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	ASSETS
	Cash and cash equivalents	$	83		$	—		$	515		$	—		$	598
	All other current assets	945			38			2,763			(476		)	3,270
	Property, plant and equipment, net	10			—			35,837			—			35,847
	Investments	—			—			5,951			—			5,951
	Investments in subsidiaries	20,336			6,651			—			(26,987		)	—
	Goodwill	—			8,062			16,442			—			24,504
	Notes receivable from affiliates	—			—			1,993			(1,993		)	—
	Deferred charges and all other assets	227			841			4,759			(812		)	5,015
	Total assets	$	21,601		$	15,592		$	68,260		$	(30,268	)	$	75,185
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Liabilities
	Current portion of debt	$	175		$	400		$	1,731		$	—		$	2,306
	All other current liabilities	228			135			3,882			(476		)	3,769
	Long-term debt	3,371			3,999			26,517			—			33,887
	Notes payable to affiliates	1,993			—			—			(1,993		)	—
	Deferred income taxes	2,426			—			3,037			(812		)	4,651
	All other long-term liabilities	315			69			1,903			—			2,287
	Total liabilities	8,508			4,603			37,070			(3,281		)	46,900
	Stockholders’ equity
	Total KMI equity	13,093			10,989			15,596			(26,585		)	13,093
	Noncontrolling interests	—			—			15,594			(402		)	15,192
	Total stockholders’ equity	13,093			10,989			31,190			(26,987		)	28,285
	Total liabilities and stockholders’ equity	$	21,601		$	15,592		$	68,260		$	(30,268	)	$	75,185
	Condensed Consolidating Balance Sheets as of December 31, 2012
	(In Millions)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	ASSETS
	Cash and cash equivalents	$	3		$	45		$	666		$	—		$	714
	All other current assets	813			51			9,322			(7,226		)	2,960
	Property, plant and equipment, net	8			—			30,988			—			30,996
	Investments	—			19			5,785			—			5,804
	Investments in subsidiaries	20,053			13,501			—			(33,554		)	—
	Goodwill	—			8,059			15,573			—			23,632
	Notes receivable from affiliates	1,555			—			2,095			(3,650		)	—
	Deferred charges and all other assets	202			879			3,914			(856		)	4,139
	Total assets	$	22,634		$	22,554		$	68,343		$	(45,286	)	$	68,245
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Liabilities
	Current portion of debt	$	1,035		$	115		$	1,251		$	—		$	2,401
	All other current liabilities	196			7,024			2,833			(7,226		)	2,827
	Long-term debt	3,068			4,378			24,554			—			32,000
	Notes payable to affiliates	1,764			331			1,555			(3,650		)	—
	Deferred income taxes	2,095			—			2,832			(856		)	4,071
	All other long-term liabilities	610			169			2,067			—			2,846
	Total liabilities	8,768			12,017			35,092			(11,732		)	44,145
	Stockholders’ equity
	Total KMI equity	13,866			10,537			22,858			(33,395		)	13,866
	Noncontrolling interests	—			—			10,393			(159		)	10,234
	Total stockholders’ equity	13,866			10,537			33,251			(33,554		)	24,100
	Total liabilities and stockholders’ equity	$	22,634		$	22,554		$	68,343		$	(45,286	)	$	68,245
Schedule of Condensed Income Statement [Table Text Block]	'
	Condensed Consolidating Statements of Income for the Year Ended December 31, 2013
	(In Millions)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Revenues	$	36		$	—		$	14,066		$	(32	)	$	14,070
	Costs, expenses and other
	Costs of sales	—			—			5,253			—			5,253
	Depreciation, depletion and amortization	1			—			1,805			—			1,806
	Other operating expenses	20			(3		)	3,036			(32		)	3,021
	Total costs, expenses and other	21			(3		)	10,094			(32		)	10,080
	Operating income	15			3			3,972			—			3,990
	Other income (expense)
	Earnings from equity investments	1,386			553			327			(1,939		)	327
	Interest, net	(262		)	(305		)	(1,108		)	—			(1,675		)
	Amortization of excess cost of equity investments and other, net	—			—			796			—			796
	Income from continuing operations before income taxes	1,139			251			3,987			(1,939		)	3,438
	Income tax benefit (expense)	54			89			(885		)	—			(742		)
	Income from continuing operations	1,193			340			3,102			(1,939		)	2,696
	Loss from discontinued operations, net of tax	—			—			(4		)	—			(4		)
	Net income	1,193			340			3,098			(1,939		)	2,692
	Net income attributable to noncontrolling interests	—			—			(1,595		)	96			(1,499		)
	Net income attributable to controlling interests	$	1,193		$	340		$	1,503		$	(1,843	)	$	1,193
	Condensed Consolidating Statements of Income for the Year Ended December 31, 2012
	(In Millions)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Revenues	$	35		$	—		$	9,938		$	—		$	9,973
	Costs, expenses and other
	Costs of sales	—			—			3,057			—			3,057
	Depreciation, depletion and amortization	—			—			1,419			—			1,419
	Other operating expenses	232			62			2,610			—			2,904
	Total costs, expenses and other	232			62			7,086			—			7,380
	Operating (loss) income	(197		)	(62		)	2,852			—			2,593
	Other income (expense)
	Earnings from equity investments	123			276			153			(399		)	153
	Interest, net	(381		)	(265		)	(753		)	—			(1,399		)
	Amortization of excess cost of equity investments and other, net	(1		)	—			(3		)	—			(4		)
	(Loss) income from continuing operations before income taxes	(456		)	(51		)	2,249			(399		)	1,343
	Income tax benefit (expense)	771			(380		)	(530		)	—			(139		)
														—
	Income (loss) from continuing operations	315			(431		)	1,719			(399		)	1,204
	Loss from discontinued operations, net of tax	—			—			(777		)	—			(777		)
	Net income (loss)	315			(431		)	942			(399		)	427
	Net income attributable to noncontrolling interests	—			—			(109		)	(3		)	(112		)
	Net income (loss) attributable to controlling interests	$	315		$	(431	)	$	833		$	(402	)	$	315
	Condensed Consolidating Statements of Income for the Year Ended December 31, 2011
	(In Millions)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Revenues	$	36		$	—		$	7,907		$	—		$	7,943
	Costs, expenses and other
	Costs of sales	—			—			3,278			—			3,278
	Depreciation, depletion and amortization	—			—			1,068			—			1,068
	Other operating expenses	42			—			2,132			—			2,174
	Total costs, expenses and other	42			—			6,478			—			6,520
	Operating (loss) income	(6		)	—			1,429			—			1,423
	Other income (expense)
	Earnings from equity investments	712			—			226			(712		)	226
	Interest, net	(187		)	—			(495		)	—			(682		)
	Amortization of excess cost of equity investments and other, net	(1		)	—			(156		)	—			(157		)
	Income from continuing operations before income taxes	518			—			1,004			(712		)	810
	Income tax benefit (expense)	68			—			(429		)	—			(361		)
	Income from continuing operations	586			—			575			(712		)	449
	Income from discontinued operations, net of tax	8			—			203			—			211
	Net income	594			—			778			(712		)	660
	Net income attributable to noncontrolling interests	—			—			(71		)	5			(66		)
Net income attributable to controlling interests	$	594		$	—		$	707		$	(707	)	$	594
Condensed consolidating statement of comprehensive income [Table Text Block]	'
	Condensed Consolidating Statements of Comprehensive Income for the Year Ended December 31, 2013
	(In Millions)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Net Income	$	1,193		$	340		$	3,098		$	(1,939	)	$	2,692
	Other comprehensive income (loss), net of tax
	Change in fair value of derivatives utilized for hedging purposes	(14		)	7			(38		)	7			(38		)
	Reclassification of change in fair value of derivatives to net income	4			(2		)	11			(2		)	11
	Foreign currency translation adjustments	(49		)	—			(102		)	48			(103		)
	Adjustments to pension and other postretirement benefit plan liabilities	153			16			50			(49		)	170
	Total other comprehensive income (loss)	94			21			(79		)	4			40
	Comprehensive income	1,287			361			3,019			(1,935		)	2,732
	Comprehensive income attributable to noncontrolling interests	—			—			(1,445		)	—			(1,445		)
	Comprehensive income attributable to controlling interests	$	1,287		$	361		$	1,574		$	(1,935	)	$	1,287
	Condensed Consolidating Statements of Comprehensive Income for the Year Ended December 31, 2012
	(In Millions)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Net Income (loss)	$	315		$	(431	)	$	942		$	(399	)	$	427
	Other comprehensive income (loss), net of tax
	Change in fair value of derivatives utilized for hedging purposes	32			(5		)	86			(31		)	82
	Reclassification of change in fair value of derivatives to net income	(5		)	(2		)	(8		)	7			(8		)
	Foreign currency translation adjustments	14			—			33			(15		)	32
	Adjustments to pension and other postretirement benefit plan liabilities	(44		)	(14		)	(4		)	27			(35		)
	Total other comprehensive (loss) income	(3		)	(21		)	107			(12		)	71
	Comprehensive income (loss)	312			(452		)	1,049			(411		)	498
	Comprehensive income attributable to noncontrolling interests	—			—			(186		)	—			(186		)
	Comprehensive income (loss) attributable to controlling interests	$	312		$	(452	)	$	863		$	(411	)	$	312
	Condensed Consolidating Statements of Comprehensive Income for the Year Ended December 31, 2011
	(In Millions)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Net income	$	594		$	—		$	778		$	(712	)	$	660
	Other comprehensive income (loss), net of tax
	Change in fair value of derivatives utilized for hedging purposes	6			—			11			(4		)	13
	Reclassification of change in fair value of derivatives to net income	67			—			176			(59		)	184
	Foreign currency translation adjustments	(14		)	—			(31		)	10			(35		)
	Adjustments to pension and other postretirement benefit plan liabilities	(38		)	—			(23		)	7			(54		)
	Total other comprehensive income	21			—			133			(46		)	108
	Comprehensive income	615			—			911			(758		)	768
	Comprehensive income attributable to noncontrolling interests	—			—			(153		)	—			(153		)
	Comprehensive income attributable to controlling interests	$	615		$	—		$	758		$	(758	)	$	615
Schedule of Condensed Cash Flow Statement [Table Text Block]	'
	Condensed Consolidating Statements of Cash Flows for the Year Ended December 31, 2013
	(In Millions)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Net cash provided by operating activities	$	1,693		$	91		$	4,506		$	(2,226	)	$	4,064
	Cash flows from investing activities
	Capital expenditures	(6		)	—			(3,363		)	—			(3,369		)
	Proceeds from sale of investments	—			—			490			—			490
	Acquisitions of assets and investments	—			—			(292		)	—			(292		)
	Repayments from related party	—			—			11			—			11
	Funding to affiliates	(376		)	(597		)	(623		)	1,596			—
	Drop down assets to KMP	994			—			(994		)	—			—
	Contribution to investments	(6		)	—			(217		)	6			(217		)
	Investments in KMP and EPB	(65		)	(3		)	—			68			—
	Distributions from equity investments in excess of cumulative earnings	18			23			183			(39		)	185
	Other, net	—			—			128			—			128
	Net cash provided by (used in) investing activities	559			(577		)	(4,677		)	1,631			(3,064		)
	Cash flows from financing activities
	Issuance of debt	2,895			133			10,553			—			13,581
	Payment of debt	(3,444		)	(180		)	(8,769		)	—			(12,393		)
	Funding from affiliates	651			488			457			(1,596		)	—
	Debt issuance costs	(15		)	—			(23		)	—			(38		)
	Cash dividends	(1,622		)	—			—			—			(1,622		)
	Repurchases of shares and warrants	(637		)	—			—			—			(637		)
	Distributions to parent	—			—			(2,253		)	2,253			—
	Contributions from noncontrolling interests	—			—			1,762			(56		)	1,706
	Distributions to noncontrolling interests	—			—			(1,692		)	—			(1,692		)
	Other, net	—			—			6			(6		)	—
	Net cash (used in) provided by financing activities	(2,172		)	441			41			595			(1,095		)
	Effect of exchange rate changes on cash and cash equivalents	—			—			(21		)	—			(21		)
	Net increase (decrease) in cash and cash equivalents	80			(45		)	(151		)	—			(116		)
	Cash and cash equivalents, beginning of period	3			45			666			—			714
	Cash and cash equivalents, end of period	$	83		$	—		$	515		$	—		$	598
	Condensed Consolidating Statements of Cash Flows for the Year Ended December 31, 2012
	(In Millions)
		Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
	Net cash provided by (used in) operating activities	$	1,014		$	(369	)	$	3,757		$	(1,607	)	$	2,795
	Cash flows from investing activities
	Capital expenditures	(5		)	—			(2,017		)	—			(2,022		)
	Proceeds from disposal of discontinued operations	—			—			1,791			—			1,791
	Acquisitions of assets and investments	—			—			(83		)	—			(83		)
	Repayments from related party	—			—			76			—			76
	Funding to affiliates	(701		)	(968		)	(1,280		)	2,949			—
	Acquisition of EP	(5,212		)	—			242			—			(4,970		)
	Drop down assets to KMP	3,485			—			(3,485		)	—			—
	Contributions to investments	(15		)	—			(177		)	—			(192		)
	Investments in KMP and EPB	(85		)	(9		)	—			94			—
	Distributions from equity investments in excess of cumulative earnings	16			—			188			(4		)	200
	Other, net	—			1			115			—			116
	Net cash used in investing activities	(2,517		)	(976		)	(4,630		)	3,039			(5,084		)
	Cash flows from financing activities
	Issuance of debt	7,889			112			10,147			—			18,148
	Payment of debt	(5,418		)	(274		)	(9,063		)	—			(14,755		)
	Funding from affiliates	539			1,552			858			(2,949		)	—
	Debt issuance costs	(91		)	—			(20		)	—			(111		)
	Cash dividends	(1,184		)	—			—			—			(1,184		)
	Repurchases of warrants	(157		)	—			—			—			(157		)
	Distributions to parents	—			—			(1,597		)	1,597			—
	Contributions from noncontrolling interests	—			—			2,012			(73		)	1,939
	Distributions to noncontrolling interests	—			—			(1,219		)	—			(1,219		)
	Other, net	(74		)	—			4			(7		)	(77		)
	Net cash provided by financing activities	1,504			1,390			1,122			(1,432		)	2,584
	Effect of exchange rate changes on cash and cash equivalents	—			—			8			—			8
	Net increase in cash and cash equivalents	1			45			257			—			303
Cash and cash equivalents, beginning of period	2			—			409			—			411
Cash and cash equivalents, end of period	$	3		$	45		$	666		$	—		$	714
Condensed Consolidating Statements of Cash Flows for the Year Ended December 31, 2011
(In Millions)
	Parent Guarantor			Subsidiary Issuers			Non-guarantor Subsidiaries			Eliminations			Consolidated KMI
Net cash provided by operating activities	$	957		$	—		$	2,766		$	(1,357	)	$	2,366
Cash flows from investing activities
Capital expenditures	(1		)	—			(1,199		)	—			(1,200		)
Acquisitions of assets and investments	—			—			(1,179		)	—			(1,179		)
Repayments from related party	—			—			31			—			31
Funding to affiliates	(852		)	—			(1		)	853			—
Contributions to investments	(92		)	—			(371		)	92			(371		)
Distributions from equity investments in excess of cumulative earnings	22			—			214			—			236
Other, net	—			—			91			—			91
Net cash used in investing activities	(923		)	—			(2,414		)	945			(2,392		)
Cash flows from financing activities
Issuance of debt	2,070			—			7,502			—			9,572
Payment of debt	(1,649		)	—			(7,144		)	—			(8,793		)
Funding from affiliates	1			—			852			(853		)	—
Debt issuance costs	(57		)	—			(19		)	—			(76		)
Cash dividends/distributions	(770		)	—			—			—			(770		)
Distributions to parents	—			—			(1,275		)	1,275			—
Contributions from noncontrolling interests	—			—			980			(10		)	970
Distributions to noncontrolling interests	—			—			(956		)	—			(956		)
Other, net	—			—			(4		)	—			(4		)
Net cash used in financing activities	(405		)	—			(64		)	412			(57		)
Effect of exchange rate changes on cash and cash equivalents	—			—			(8		)	—			(8		)
Net (decrease) increase in cash and cash equivalents	(371		)	—			280			—			(91		)
Cash and cash equivalents, beginning of period	373			—			129			—			502
Cash and cash equivalents, end of period	$	2		$	—		$	409		$	—		$	411

General_Details

General (Details) (USD $)	12 Months Ended
In Billions, unless otherwise specified	Dec. 31, 2013
Entity Information [Line Items]	'
Enterprise Market Value	$110
Miles Of Pipeline	80,000
Number Of Pipeline Terminals Owned Interest In And Or Operated	180
Kinder Morgan Energy Partners, L.P. [Member]	'
Entity Information [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]	'
Entity Information [Line Items]	'
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	41.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	2.00%

Summary_of_Significant_Account3

Summary of Significant Accounting Policies Basis of presentation (Details) (USD $)	Dec. 31, 2013	Nov. 01, 2012	Dec. 31, 2013
		Energy Transfers Partners LP [Member]	KMP’s FTC Natural Gas Pipelines [Member]
		KMP’s FTC Natural Gas Pipelines [Member]	Rockies Express Pipeline LLC [Member]
Summary of accounting policies [Line Items]	'	'	'
Equity Investment, Classify as Equity Method, Percentage	50.00%	'	'
Equity Method Investment, Ownership Percentage	'	'	50.00%
Significant Acquisitions and Disposals, Acquisition Costs or Sale Proceeds	'	$1,800,000,000	'
Business Acquisition, Transaction Costs	'	$3,300,000,000	'

Summary_of_Significant_Account4

Summary of Significant Accounting Policies Cash Equivalents and Restricted Deposits (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Other Assets [Member]	'	'
Restricted Cash and Cash Equivalents Items [Line Items]	'	'
Restricted Cash and Cash Equivalents, Current	$75	$52
Deferred charges and other assets [Member]	'	'
Restricted Cash and Cash Equivalents Items [Line Items]	'	'
Restricted Cash and Cash Equivalents, Current	$2	'

Summary_of_Significant_Account5

Summary of Significant Accounting Policies Gas Imbalances (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'	'
Gas Balancing Asset (Liability)	$83	$18
Gas Balancing Payable, Current	$34	$150

Summary_of_Significant_Account6

Summary of Significant Accounting Policies Regulatory Assets and Liabilities (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013	Sep. 03, 2013	Dec. 31, 2013	Jun. 30, 2013	Dec. 31, 2013
In Millions, unless otherwise specified			Minimum [Member]	Maximum [Member]	Federal Energy Regulatory Commission [Member]	Federal Energy Regulatory Commission [Member]	Newly Negotiated KMP Pipeline System Tolling Aggeement , Effective as of April 2013 [Member]	Newly Negotiated KMP Pipeline System Tolling Aggeement , Effective as of April 2013 [Member]
					TGP's Sale of Production Area Facilities [Member]	Oil and Gas Properties [Member]	KMP Pipeline System [Member]	KMP Pipeline System [Member]
					TGP [Member]	Natural Gas [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]
						Gulf of Mexico and Louisiana [Member]
						TGP's Sale of Production Area Facilities [Member]
Regulatory Assets and Liabilities [Line Items]	'	'	'	'	'	'	'	'
Regulatory Assets Recovery Period	'	'	'1 year	'42 years	'	'	'	'
Regulatory Assets, Current	$91	$62	'	'	'	'	'	'
Regulatory Assets, Noncurrent	446	402	'	'	'	'	'	'
Regulatory Assets	537	464	'	'	'	'	'	'
Regulatory Liability, Current	135	7	'	'	'	'	'	'
Regulatory Liability, Noncurrent	397	113	'	'	'	'	'	'
Regulatory Liabilities	532	120	'	'	'	'	'	'
Increase (Decrease) in Regulatory Assets and Liabilities	'	'	'	'	'	88	'	'
Amortization of Regulatory Asset	'	'	'	'	'	5	'	'
Regulatory Liabilities Reclassified from Long-term Deferred Credits due to Application of Regulatory Accounting	'	'	'	'	'	'	362	'
Regulatory Assets or Liabilities Recovery Period	'	'	'	'	'	'	'	'4 years
Regulatory Liabilities Reclassified from Long-term Deferred Credits due to Application of Regulatory Accounting, Current	'	'	'	'	'	'	'	113
Increase (Decrease) in Other Regulatory Assets	'	'	'	'	93	'	'	'
Gain (Loss) on Disposition of Oil and Gas and Timber Property	'	'	'	'	$36	'	'	'

Summary_of_Significant_Account7

Summary of Significant Accounting Policies Earnings per share (Details) (USD $)	11 Months Ended	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]	'	'	'	'
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	$449	$2,696	$1,204	$449
Net income attributable to KMI	594	1,193	315	594
Income (Loss) from Continuing Operations Attributable to Noncontrolling Interest	112	'	-696	'
Income attributable to KMI members prior to incorporation	-70	'	'	'
Income (Loss) from Continuing Operations Attributable to Parent	561	'	508	'
Dividends, Common Stock, Cash	'	-1,622	-1,184	-770
Income (Loss) from Continuing Operations Attributable to Parent, Prior to Incorporation	-67	'	'	'
Remaining Undistributed Earnings, Continuing Operations	-30	'	-676	'
Undistributed Earnings, Basic	0	'	-869	'
Net Income (Loss) Available to Common Stockholders, Basic	524	1,193	315	'
income (Loss) from Continuing Operations Attributable to Shareholders	494	'	508	'
Class P [Member]	'	'	'	'
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]	'	'	'	'
Dividends	87	'	601	'
Net Income (Loss) Available to Common Stockholders And Assumed Conversion	524	'	315	'
Remaining Undistributed Earnings, Continuing Operations	-5	'	-344	'
Undistributed Earnings, Basic	0	'	-441	'
Net Income (Loss) Available to Common Stockholders, Basic	87	1,187	160	'
income (Loss) from Continuing Operations Attributable to Shareholders	82	'	257	'
Basic Weighted-Average Number of Shares Outstanding	118	1,036	461	118
Income (Loss) from Continuing Operations, Per Basic Share	$0.70	'	$0.56	'
Net Income (Loss) From Continuing Operation Available to Common Stockholders And Assumed Conversion	494	'	508	'
Diluted Weighted-Average Number of Shares Outstanding	708	1,036	908	708
Income (Loss) from Continuing Operations, Per Diluted Share	$0.70	'	$0.56	'
Earnings Per Share, Diluted	$0.74	'	$0.35	'
Earnings Per Share, Basic	$0.74	'	$0.35	'
Common Class A [Member]	'	'	'	'
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]	'	'	'	'
Dividends	399	'	542	'
Net Income (Loss) Available to Common Stockholders And Assumed Conversion	399	'	116	'
Remaining Undistributed Earnings, Continuing Operations	-25	'	-331	'
Undistributed Earnings, Basic	0	'	-426	'
Net Income (Loss) Available to Common Stockholders, Basic	399	'	116	'
income (Loss) from Continuing Operations Attributable to Shareholders	374	'	211	'
Basic Weighted-Average Number of Shares Outstanding	589	'	446	589
Income (Loss) from Continuing Operations, Per Basic Share	$0.64	'	$0.47	'
Net Income (Loss) From Continuing Operation Available to Common Stockholders And Assumed Conversion	374	'	211	'
Diluted Weighted-Average Number of Shares Outstanding	589	'	446	589
Income (Loss) from Continuing Operations, Per Diluted Share	$0.64	'	$0.47	'
Earnings Per Share, Diluted	$0.68	'	$0.26	'
Earnings Per Share, Basic	$0.68	'	$0.26	'
Participating Securities [Member]	'	'	'	'
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]	'	'	'	'
Dividends	38	'	41	'
Remaining Undistributed Earnings, Continuing Operations	0	'	-1	'
Undistributed Earnings, Basic	0	'	-2	'
Net Income (Loss) Available to Common Stockholders, Basic	38	6	39	'
income (Loss) from Continuing Operations Attributable to Shareholders	38	'	40	'
Warrant [Member]	'	'	'	'
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]	'	'	'	'
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	'	401	451	'
Restricted Stock [Member]	'	'	'	'
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]	'	'	'	'
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	'	4	'	'
Convertible Preferred Stock [Member]	'	'	'	'
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]	'	'	'	'
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	'	10	11	'
Retained Earnings [Member]	'	'	'	'
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]	'	'	'	'
Net income attributable to KMI	'	1,193	315	523
Dividends, Common Stock, Cash	'	-1,622	-1,184	-524
Cash [Member] | Retained Earnings [Member]	'	'	'	'
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]	'	'	'	'
Dividends, Common Stock, Cash	'	'	'	($524)

Summary_of_Significant_Account8

Summary of Significant Accounting Policies Goodwill (Details) (USD $)	Dec. 31, 2013	31-May-13	Dec. 31, 2012	Dec. 31, 2011
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'	'	'	'
Goodwill (Note 7)	$24,504,000,000	'	$23,632,000,000	$5,074,000,000
Goodwill, Impaired, Accumulated Impairment Loss	'	$0	'	($4,411,000,000)

Summary_of_Significant_Account9

Summary of Significant Accounting Policies Property, Plant and Equipment (Details)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Line Items]	'
Composite depreciation rate, low	0.90%
Composite depreciation rate, high	23.00%

Acquisitions_Business_Combinat

Acquisitions Business Combinations and Acquisitions of Investments (Details) (USD $)

0 Months Ended

5 Months Ended

9 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

9 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

1 Months Ended

0 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

12 Months Ended

In Millions, except Share data, unless otherwise specified

Jan. 17, 2014

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

25-May-12

Dec. 31, 2012

25-May-12

Jul. 02, 2011

25-May-12

Dec. 31, 2013

Dec. 31, 2012

25-May-12

Dec. 31, 2013

31-May-13

Dec. 31, 2012

Jun. 10, 2011

Jul. 02, 2011

Nov. 30, 2011

3-May-13

Sep. 30, 2013

1-May-13

Apr. 30, 2013

1-May-13

Jun. 02, 2013

31-May-13

Dec. 28, 2011

Jan. 03, 2011

Dec. 28, 2011

Jan. 03, 2011

Jul. 02, 2011

Jul. 03, 2011

Dec. 31, 2013

1-May-13

Dec. 31, 2013

Dec. 31, 2012

1-May-13

25-May-12

Dec. 31, 2013

Mar. 31, 2012

Mar. 14, 2012

3-May-13

1-May-13

3-May-13

1-May-13

Jun. 30, 2013

25-May-12

25-May-12

25-May-12

25-May-12

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 28, 2011

Dec. 28, 2011

Jul. 02, 2011

Jul. 02, 2011

Jul. 02, 2011

Jun. 02, 2013

31-May-13

31-May-13

3-May-13

Dec. 31, 2012

El Paso Corporation [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

KinderHawk Field Services LLC [Member]

EP Energy LLC [Member]

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Warrant [Member]

Warrant [Member]

Common Unit [Member]

Common Unit [Member]

Common Units [Member]

Common Units [Member]

Common Units [Member]

Common Units [Member]

Revision of estimates to environmental obligations, sales and use tax liabilities and deferred income taxes [Member]

Investments [Member]

Current Liabilities [Member]

EP Energy LLC [Member]

EP Energy LLC [Member]

Advisory Fees [Member]

Legal fees and expenses [Member]

Pension Costs [Member]

Quarterly Rate [Member]

Annual Rate [Domain]

Petrohawk Energy Corporation [Member]

Petrohawk Energy Corporation [Member]

Petrohawk Energy Corporation [Member]

Legado Resources [Member]

Legado Resources [Member]

Legado Resources [Member]

Other Income (Expense) [Member]

Other Income (Expense) [Member]

Class P [Member]

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

bbl

TGS Development, L.P. [Member]

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

SouthTex Treaters Inc. [Member]

Copano Energy LLC [Member]

Copano Energy LLC [Member]

Copano Energy LLC [Member]

Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

Goldsmith-Landreth Field Unit [Member]

Goldsmith-Landreth Field Unit [Member]

Watco Companies LLC [Member]

Watco Companies LLC [Member]

Watco Companies LLC [Member]

Watco Companies LLC [Member]

KinderHawk Field Services LLC [Member]

KinderHawk Field Services LLC [Member]

Eagle Ford Gathering LLC [Member]

Eagle Ford Gathering LLC [Member]

Copano Energy LLC [Member]

El Paso Corporation [Member]

Kinder Morgan, Inc. [Member]

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

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

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

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

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

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

El Paso Corporation [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

Current Assets [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

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

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

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

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

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

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

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

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

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

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

acre

MMcf

MMcf

Preferred Class A [Member]

Preferred Class A [Member]

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

Copano Energy LLC [Member]

El Paso Corporation [Member]

TGS Development, L.P. [Member]

TGS Development, L.P. [Member]

Copano Energy LLC [Member]

Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

Remaining proceeds used to pay for portion of acquisition purchase price [Member]

Watco Companies LLC [Member]

Watco Companies LLC [Member]

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

KinderHawk Field Services LLC [Member]

EagleHawk Field Services LLC [Member]

Goldsmith-Landreth Field Unit [Member]

Copano Energy LLC [Member]

KinderHawk Field Services LLC [Member]

mi

El Paso Corporation [Member]

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Consideration Transferred

$962

'

'

'

'

'

$22,900

'

'

'

'

'

'

'

'

'

'

'

'

'

$5,200

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$912

'

'

'

'

'

'

'

Business Combination, Acquisition of Less than 100 Percent, Noncontrolling Interest, Fair Value

'

'

'

'

'

'

-3,797

'

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

-17

'

'

0

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

0

0

0

-704

'

'

'

'

0

'

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Consideration Transferred, Including Equity Interest in Acquiree Held Prior to Combination

'

'

'

'

'

'

22,928

'

'

'

'

'

'

'

'

'

'

67

835

152

'

'

'

3,733

'

'

280

50

50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

7,175

'

'

'

'

'

'

'

'

'

'

0

36

27

'

'

'

218

'

'

0

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment

'

'

'

'

'

'

12,921

'

'

'

'

'

'

'

'

'

'

43

642

9

'

'

'

2,805

'

'

298

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

298

'

'

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

'

'

'

'

'

'

5,718

'

'

'

'

'

'

'

'

'

'

31

140

17

'

'

'

1,775

'

'

0

50

50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,211

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Goodwill (Note 7)

'

23,632

'

24,504

23,632

5,074

18,562

'

'

'

'

22

22

'

6,547

'

5,417

0

94

126

'

'

'

1,141

'

'

0

0

0

'

'

'

'

'

'

17,935

18,193

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

-13,417

'

'

'

'

'

'

'

'

'

'

0

-77

0

'

'

'

-1,252

'

'

0

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-77

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

-4,234

'

'

'

'

'

'

'

'

'

'

-7

0

-27

'

'

'

-233

'

'

-18

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-1,463

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payments to Acquire Businesses, Gross

'

'

'

'

'

'

'

'

11,600

'

'

'

'

'

'

'

'

43

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

835

'

'

280

'

'

'

'

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

'

'

'

'

'

'

'

'

330,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

505,000,000

'

'

'

43,371,210

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Equity Interest Issued or Issuable, Value Assigned

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

863

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Consideration Transferred, Equity Interests Issued and Issuable

'

'

'

'

'

'

'

'

10,600

'

'

'

'

'

'

'

'

24

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,733

'

3,733

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Share Price

'

'

'

'

'

'

'

'

$32.11

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1.71

'

'

'

'

$86.08

'

$86.08

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class of Warrant or Right, Exercise Price of Warrants or Rights

'

'

'

'

'

'

40

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class of Warrant or Right, Term

'

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Goodwill, Purchase Accounting Adjustments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

60

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination Acquisition Of Less Than 100 Percent Noncontrolling Interest, Common Units Acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

117,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination Acquisition Of Less Than 100 Percent Noncontrolling Interest, Price of Common Units Acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

$32.37

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from disposal of discontinued operations

'

'

'

0

1,791

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,200

6,200

'

'

'

'

'

'

'

'

'

'

'

'

'

Repayments of Long-term Debt

'

2,300

839

'

'

'

'

'

'

'

961

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

154

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Acquisition Related Costs

'

'

'

'

'

'

'

463

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

37

68

-29

'

'

'

'

'

'

'

'

'

'

Write off of Deferred Debt Issuance Cost

'

'

'

'

108

'

'

108

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Integration Related Costs

'

'

'

'

'

'

'

160

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award Accelerated Compensation Cost

'

'

'

'

'

'

'

87

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity method investment, shares purchased

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50,000

50,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Significant Acquisitions and Disposals, Acquisition Costs or Sale Proceeds

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

74

'

'

'

'

'

'

'

'

'

50

50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred Stock, Dividend Rate, Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.25%

13.00%

'

'

'

'

'

'

'

'

Preferred shares, additional profit distribution rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of board members to appoint

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Consideration Transferred, Liabilities Incurred

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Assets acquired or liabilites setteled by issuances of common units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Assets acquired or liabilities settled by issuances of common units, number of common units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

87,162

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Sale of Stock, Price Per Share

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$83.87

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Percentage of Voting Interests Acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

Equity Method Investment, Ownership Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

558

-167

Equity Method Investments

'

5,796

'

5,943

5,796

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

146

'

'

'

'

'

'

'

'

'

910

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investments, Fair Value Disclosure

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

704

'

'

'

'

'

'

'

'

743

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Consideration Transferred, Equity Interests Issued and Issuable, Percent of Transaction Unit for Unit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Consideration Transferred, Equity Interests Issued and Issuable,Unit for Unit Exchange Ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.4563

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,375

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

387

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Finite-Lived Intangible Assets, Remaining Amortization Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'25 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of equity method investments acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred Tax Liabilities, Goodwill

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

260

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Miles Of Pipeline

'

'

'

80,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,900

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Natural gas transportation capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,700

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of Processing Plants

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gas Processing Capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Treating Capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

315

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$18

'

'

'

Gas and Oil Area, Total

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Barrels of Oil

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,230

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Oil and Gas Delivery Commitments and Contracts, Remaining Contractual Volume

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

150

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisitions_1_EP_Details

Acquisitions (1) EP (Details) (USD $)	0 Months Ended	12 Months Ended			0 Months Ended			3 Months Ended
In Millions, except Share data, unless otherwise specified	Jan. 17, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	25-May-12	25-May-12	25-May-12	Jun. 30, 2013
					El Paso Corporation [Member]	El Paso Corporation [Member]	Warrant [Member]	Revision of estimates to environmental obligations, sales and use tax liabilities and deferred income taxes [Member]
						Class P [Member]	El Paso Corporation [Member]	El Paso Corporation [Member]
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'
Business Combination, Consideration Transferred	$962	'	'	'	$22,900	'	'	'
Noncash compensation expense on settlement of EP stock awards	'	0	87	0	87	'	'	'
Payments to Acquire Businesses, Gross	'	'	'	'	'	11,600	'	'
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	'	'	'	'	'	330,000,000	505,000,000	'
Business Acquisition, Equity Interest Issued or Issuable, Value Assigned	'	'	'	'	'	'	863	'
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable	'	'	'	'	'	10,600	'	'
Business Acquisition, Share Price	'	'	'	'	'	$32.11	$1.71	'
Class of Warrant or Right, Exercise Price of Warrants or Rights	'	'	'	'	40	'	'	'
Class of Warrant or Right, Term	'	'	'	'	'5 years	'	'	'
Goodwill, Purchase Accounting Adjustments	'	'	'	'	'	'	'	$60

Acquisitions_2_Watco_Companies

Acquisitions (2) Watco Companies, LLC (1 of 2) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 28, 2011	Jan. 03, 2011	Dec. 28, 2011	Jan. 03, 2011	Dec. 28, 2011	Dec. 28, 2011
In Millions, except Share data, unless otherwise specified			Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Quarterly Rate [Member]	Annual Rate [Domain]
			Watco Companies LLC [Member]	Watco Companies LLC [Member]	Watco Companies LLC [Member]	Watco Companies LLC [Member]	Watco Companies LLC [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]
						Preferred Class A [Member]	Preferred Class A [Member]	Watco Companies LLC [Member]	Watco Companies LLC [Member]
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'	'
Equity method investment, shares purchased	'	'	'	'	'	50,000	50,000	'	'
Significant Acquisitions and Disposals, Acquisition Costs or Sale Proceeds	'	'	'	$50	$50	'	'	'	'
Numer of railroad lines operated	'	'	22	'	'	'	'	'	'
Miles of railroad track owned or leased	'	'	3,500	'	'	'	'	'	'
Equity Method Investments	$5,943	$5,796	$103	'	'	'	'	'	'
Preferred Stock, Dividend Rate, Percentage	'	'	'	'	'	'	'	3.25%	13.00%
Preferred shares, additional profit distribution rate	'	'	'	0.50%	'	'	'	'	'
Number of board members to appoint	'	'	'	'	1	'	'	'	'

Acquisitions_3_TGS_Development

Acquisitions (3) TGS Development, Terminal, L.P. Terminal Acquisition (Details) (Kinder Morgan Energy Partners, L.P. [Member], TGS Development, L.P. [Member], USD $)	0 Months Ended	1 Months Ended
In Millions, except Share data, unless otherwise specified	Jun. 10, 2011	Mar. 31, 2012	Mar. 14, 2012
		Common Unit [Member]	Common Unit [Member]
Business Acquisition [Line Items]	'	'	'
Significant Acquisitions and Disposals, Acquisition Costs or Sale Proceeds	$74	'	'
Payments to Acquire Businesses, Gross	43	'	'
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable	24	'	'
Business Combination, Consideration Transferred, Liabilities Incurred	7	'	'
Assets acquired or liabilites setteled by issuances of common units	'	$7	'
Assets acquired or liabilities settled by issuances of common units, number of common units	'	'	87,162
Sale of Stock, Price Per Share	'	'	$83.87

Acquisitions_4_Kinderhawk_and_

Acquisitions (4) Kinderhawk and EagleHawk (Details) (USD $)

0 Months Ended

5 Months Ended

9 Months Ended

0 Months Ended

0 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Jan. 17, 2014

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2013

Jul. 02, 2011

Jul. 02, 2011

Jul. 02, 2011

Jul. 03, 2011

Jul. 02, 2011

Jul. 02, 2011

Jul. 02, 2011

Dec. 31, 2012

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

KinderHawk Field Services LLC [Member]

KinderHawk Field Services LLC [Member]

KinderHawk Field Services LLC [Member]

Petrohawk Energy Corporation [Member]

Petrohawk Energy Corporation [Member]

Petrohawk Energy Corporation [Member]

Other Income (Expense) [Member]

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

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

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

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

KinderHawk Field Services LLC [Member]

EagleHawk Field Services LLC [Member]

KinderHawk Field Services LLC [Member]

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

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

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

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

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

KinderHawk Field Services, LLC and EagleHawk Field Services, LLC [Member]

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Percentage of Voting Interests Acquired

'

'

'

'

'

'

'

'

'

50.00%

'

'

Equity Method Investment, Ownership Percentage

'

'

'

'

'

'

'

'

'

'

25.00%

'

Business Combination, Consideration Transferred

$962

'

'

'

'

'

'

'

$912

'

'

'

Payments to Acquire Businesses, Gross

'

'

'

'

'

'

'

'

835

'

'

'

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

'

'

'

'

77

'

'

'

77

'

'

'

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

'

'

'

'

'

50.00%

'

'

'

'

'

'

Repayments of Long-term Debt

'

2,300

839

'

'

'

154

'

'

'

'

'

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

'

'

'

'

'

'

50.00%

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

-167

Equity Method Investments

'

5,796

'

5,943

'

'

'

910

'

'

'

'

Equity Method Investments, Fair Value Disclosure

'

'

'

'

'

'

$743

'

'

'

'

'

Acquisitions_5_SouthTex_Treate

Acquisitions (5) SouthTex Treaters, Inc. Asset Acquisition (Details) (Kinder Morgan Energy Partners, L.P. [Member], SouthTex Treaters Inc. [Member], USD $)	0 Months Ended
In Millions, unless otherwise specified	Nov. 30, 2011
Kinder Morgan Energy Partners, L.P. [Member] | SouthTex Treaters Inc. [Member]	'
Business Acquisition [Line Items]	'
Payments to Acquire Businesses, Net of Cash Acquired	$152
Business Combination, Consideration Transferred, Including Equity Interest in Acquiree Held Prior to Combination	$179

Acquisitions_6_Watco_Companies

Acquisitions (6) Watco Companies, LLC (2 of 2) (Details) (Watco Companies LLC [Member], Kinder Morgan Energy Partners, L.P. [Member], USD $)	0 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 28, 2011	Jan. 03, 2011
Business Acquisition [Line Items]	'	'
Significant Acquisitions and Disposals, Acquisition Costs or Sale Proceeds	$50	$50
Preferred shares, additional profit distribution rate	0.50%	'
Preferred Class A [Member]	'	'
Business Acquisition [Line Items]	'	'
Equity method investment, shares purchased	50,000	50,000
Quarterly Rate [Member]	'	'
Business Acquisition [Line Items]	'	'
Preferred Stock, Dividend Rate, Percentage	3.25%	'
Annual Rate [Domain]	'	'
Business Acquisition [Line Items]	'	'
Preferred Stock, Dividend Rate, Percentage	13.00%	'

Acquisitions_7_Copano_Details

Acquisitions (7) Copano (Details) (USD $)

0 Months Ended

0 Months Ended

9 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

In Millions, except Share data, unless otherwise specified

Jan. 17, 2014

Dec. 31, 2013

Dec. 31, 2012

3-May-13

Sep. 30, 2013

1-May-13

1-May-13

1-May-13

3-May-13

1-May-13

3-May-13

1-May-13

1-May-13

3-May-13

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

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

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

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

Kinder Morgan, Inc. [Member]

Common Units [Member]

Common Units [Member]

Common Units [Member]

Common Units [Member]

Eagle Ford Gathering LLC [Member]

Other Income (Expense) [Member]

Copano Energy LLC [Member]

Copano Energy LLC [Member]

Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

Copano Energy LLC [Member]

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

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

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

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

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

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

mi

Copano Energy LLC [Member]

Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

Copano Energy LLC [Member]

Copano Energy LLC [Member]

MMcf

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Consideration Transferred

$962

'

'

$5,200

'

'

'

'

'

'

'

'

'

'

Business Combination, Consideration Transferred, Equity Interests Issued and Issuable, Percent of Transaction Unit for Unit

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

Business Combination, Consideration Transferred, Equity Interests Issued and Issuable,Unit for Unit Exchange Ratio

'

'

'

'

'

'

'

'

'

0.4563

'

'

'

'

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

'

'

'

'

'

'

'

'

43,371,210

'

'

'

'

'

Business Combination, Consideration Transferred, Equity Interests Issued and Issuable

'

'

'

'

'

'

'

'

3,733

'

3,733

'

'

'

Business Acquisition, Share Price

'

'

'

'

'

'

'

'

'

$86.08

'

$86.08

'

'

Business Acquisition, Percentage of Voting Interests Acquired

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

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

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

558

Equity Method Investments, Fair Value Disclosure

'

'

'

'

'

704

'

'

'

'

'

'

'

'

Equity Method Investments

'

5,943

5,796

'

'

146

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill

'

'

'

'

1,375

'

'

'

'

'

'

'

'

'

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

'

'

'

'

387

'

'

'

'

'

'

'

'

'

Finite-Lived Intangible Assets, Remaining Amortization Period

'

'

'

'

'25 years

'

'

'

'

'

'

'

'

'

Number of equity method investments acquired

'

'

'

'

'

7

'

'

'

'

'

'

'

'

Deferred Tax Liabilities, Goodwill

'

'

'

'

'

'

'

$260

'

'

'

'

'

'

Miles Of Pipeline

'

80,000

'

'

'

'

6,900

'

'

'

'

'

'

'

Natural gas transportation capacity

'

'

'

'

'

'

2,700

'

'

'

'

'

'

'

Number of Processing Plants

'

'

'

'

'

'

9

'

'

'

'

'

'

'

Gas Processing Capacity

'

'

'

'

'

'

1,000

'

'

'

'

'

'

'

Treating Capacity

'

'

'

'

'

'

315

'

'

'

'

'

'

'

Acquisitions_8_Goldsmith_Landr

Acquisitions (8) Goldsmith Landreth Field Unit (Details) (Kinder Morgan Energy Partners, L.P. [Member], USD $)	0 Months Ended
In Millions, unless otherwise specified	Jun. 02, 2013	31-May-13
Business Acquisition [Line Items]	'	'
Gas and Oil Area, Total	'	6,000
Barrels of Oil	'	1,230
Goldsmith-Landreth Field Unit [Member]	'	'
Business Acquisition [Line Items]	'	'
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	'	$298
Oil and Gas Delivery Commitments and Contracts, Remaining Contractual Volume	'	150
Legado Resources [Member]	'	'
Business Acquisition [Line Items]	'	'
Payments to Acquire Businesses, Gross	280	'
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities	'	18
Legado Resources [Member] | Goldsmith-Landreth Field Unit [Member]	'	'
Business Acquisition [Line Items]	'	'
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	'	$298

Acquisitions_Pro_Forma_Informa

Acquisitions Pro Forma Information (Details) (EP, Copano and the Goldsmith Landreth Unit acquisitions occurred as of January 1, 2012 [Member], USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Business Acquisition [Line Items]	'	'
Business Acquisition, Pro Forma Revenue	$14,775	$13,035
Business Acquisition, Pro Forma Income (Loss) from Continuing Operations before Changes in Accounting and Extraordinary Items, Net of Tax	2,655	866
Business Acquisition, Pro Forma Income (Loss) from Discontinued Operations before Changes in Accounting and Extraordinary Items, Net of Tax	-4	1,291
Business Acquisition, Pro Forma Net Income (Loss)	2,651	2,157
Pro Forma Income Attributable to Noncontrolling Interests	-1,486	-153
Class P [Member]	'	'
Business Acquisition [Line Items]	'	'
Business Acquisition, Pro Forma Earnings Per Share, Diluted	$1.12	$1.93
Common Class A [Member]	'	'
Business Acquisition [Line Items]	'	'
Business Acquisition, Pro Forma Earnings Per Share, Diluted	'	$1.84
Kinder Morgan, Inc. [Member]	'	'
Business Acquisition [Line Items]	'	'
Business Acquisition, Pro-forma, Net income (loss) attributable to parent	$1,165	$2,004

Acquisitions_Acquisition_Subse

Acquisitions Acquisition Subsequent to December 31, 2013 (Details) (USD $)	0 Months Ended	12 Months Ended					12 Months Ended
In Millions, unless otherwise specified	Jan. 17, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
					American Petroleum Tankers [Member]	State Class Tankers [Member]	Kinder Morgan G.P., Inc. [Member]	Kinder Morgan G.P., Inc. [Member]	Kinder Morgan G.P., Inc. [Member]	Kinder Morgan Energy Partners, L.P. [Member]
							American Petroleum Tankers [Member]	American Petroleum Tankers [Member]	American Petroleum Tankers [Member]	American Petroleum Tankers [Member]
										bbl
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'	'	'
Incentive Distribution Amounts Waived	'	'	'	'	'	'	$6	$19	$13	'
Number of Vessels	'	'	'	'	5	4	'	'	'	'
Tanker Capacity	'	'	'	'	'	'	'	'	'	330
Payments to acquire PPE, cash portion	'	3,369	2,022	1,200	'	'	'	'	'	214
Business Combination, Consideration Transferred	$962	'	'	'	'	'	'	'	'	'

Acquisitions_Dropdown_of_EP_As

Acquisitions Drop-down of EP Assets to KMP - August 2012 and March 2013 (Details) (USD $)

5 Months Ended

9 Months Ended

1 Months Ended

1 Months Ended

0 Months Ended

0 Months Ended

3 Months Ended

1 Months Ended

0 Months Ended

Dec. 31, 2012

Sep. 30, 2013

Aug. 01, 2012

Aug. 01, 2012

Mar. 01, 2013

Aug. 02, 2012

Aug. 31, 2012

Aug. 01, 2012

Aug. 31, 2012

Mar. 03, 2013

Mar. 04, 2013

Mar. 03, 2013

Jun. 30, 2013

Mar. 04, 2013

Aug. 31, 2013

Aug. 31, 2012

3-May-13

Mar. 03, 2013

Aug. 01, 2012

Mar. 01, 2013

Aug. 01, 2012

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

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

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

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

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

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

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

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

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

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

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

Reported Value Measurement [Member]

364 Day Bridge Loan [Member]

364 Day Bridge Loan [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

TGP [Member]

EPNG [Member]

EPNG [Member]

Common Units [Member]

TGP [Member]

EPNG [Member]

EPNG [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

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

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

NEW YORK STOCK EXCHANGE, INC. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

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

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

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

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

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

TGP and EPNG [Member]

TGP and EPNG [Member]

TGP and EPNG [Member]

EPNG and EP Midstreem Assets [Member]

EPNG and EP Midstreem Assets [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

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

Kinder Morgan, Inc. [Member]

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

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

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

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

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

EPNG and EP Midstreem Assets [Member]

EPNG and EP Midstreem Assets [Member]

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

EPNG and EP Midstreem Assets [Member]

Common Units [Member]

Common Units [Member]

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

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

$2,300,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

4,667,575

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Ownership Percentage

'

'

'

100.00%

50.00%

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

50.00%

50.00%

Consideration Transfered Between Entities Under Common Control, Total

'

'

'

'

'

'

'

6,200,000,000

'

'

1,700,000,000

'

'

'

'

'

'

'

'

'

'

Payments to Acquire Businesses, Gross

'

'

'

'

'

'

3,500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Entities Under Common Control Transaction, Proportional Share of Debt Borrowings

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

Consideration Transfered Between Entities Under Common Control, Cash

'

'

'

'

'

'

'

'

'

'

'

994,000,000

'

'

'

'

'

'

'

'

'

Consideration Transfered Between Entities Under Common Control, Working Capital Adjustment

'

'

'

'

'

'

'

'

'

'

'

'

6,000,000

'

'

'

'

'

'

'

'

Consideration Transfered Between Entities Under Common Control, Equity

'

'

'

'

'

'

'

'

'

1,249,452

'

'

'

'

'

'

'

'

'

'

'

Consideration Transfered Between Entities Under Common Control, Equity, Value

'

'

'

'

'

'

'

'

'

108,000,000

'

'

'

'

'

'

'

'

'

'

'

Share Price

'

'

'

'

'

'

'

'

'

'

'

'

'

$86.72

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

557,000,000

'

'

'

'

'

'

'

'

'

'

Repayments of Long-term Debt

2,300,000,000

839,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

947,000,000

'

'

'

Debt Instrument, Term

'3 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'364 days

'364 days

'5 years

'

'

'

'

Stock Issued During Period, Value, Acquisitions

'

'

'

'

'

'

'

'

$400,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Sale of Stock, Price Per Share

'

'

$81.52

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisitions_Dropdown_of_EP_As1

Acquisitions Drop-down of EP Assets to KMP - KMP Previous;y Held Investments in El Paso Midstream Investment Company and Income Tax Impact of the Drop-Down of EP Assets to KMP (Details) (USD $)

5 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

Dec. 31, 2012

Dec. 31, 2013

Jun. 01, 2012

Aug. 02, 2012

Mar. 04, 2013

Jun. 01, 2012

Jun. 04, 2012

Dec. 31, 2013

Jun. 01, 2012

Jun. 01, 2012

Jun. 01, 2012

Jun. 01, 2012

El Paso Midstream [Member]

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

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

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

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

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

Kinder Morgan subsidiaries [Member]

Kinder Morgan, Inc. [Member]

Kohlberg Kravis Roberts & Co. L.P. [Member]

Customer Relationships [Member]

Midstream Investment Company, LLC [Member]

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

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

El Paso Midstream Investment Company, LLC. [Member]

El Paso Midstream Investment Company, LLC. [Member]

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

El Paso Midstream [Member]

Common Units [Member]

Common Unit [Member]

El Paso Midstream Investment Company, LLC. [Member]

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Percentage of Voting Interests Acquired

'

'

'

'

'

50.00%

'

'

'

'

'

'

Equity Method Investment, Ownership Percentage

'

'

'

'

'

'

'

'

50.00%

100.00%

50.00%

'

Gain (Loss) on Sale of Equity Investments

'

'

'

'

'

'

'

'

'

$0

'

'

Sale of Stock, Price Per Share

'

'

'

'

'

'

$76.23

'

'

'

'

'

Deferred Tax Assets, Deferred Income

'

'

'

448,000,000

53,000,000

'

'

'

'

'

'

'

Significant Acquisitions and Disposals, Acquisition Costs or Sale Proceeds

'

'

'

'

'

'

'

'

'

578,000,000

289,000,000

'

Partners' Capital Account, Units, Sale of Units

'

'

'

'

'

'

'

3,792,461

'

'

'

'

Other Assets, Noncurrent

2,968,000,000

2,577,000,000

'

'

'

'

'

'

'

'

'

50,000,000

Change in Estimated Useful Life

'

'

'

'

'

'

'

'

'

'

'

'10 years

Goodwill, Acquired During Period

'

'

248,000,000

'

'

'

'

'

'

'

'

'

Income tax expense from deferred charges that arose from drop-down transactions

$7,000,000

$20,000,000

'

'

'

'

'

'

'

'

'

'

Acquisitions_Divestitures_KMPs

Acquisitions Divestitures - KMP's FTC Natural Gas Disposal Group - Discontinued Operations (Details) (USD $)	12 Months Ended			3 Months Ended	12 Months Ended		3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Mar. 31, 2012	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2012	Dec. 31, 2013
				KMP’s FTC Natural Gas Pipelines [Member]	KMP’s FTC Natural Gas Pipelines [Member]	KMP’s FTC Natural Gas Pipelines [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]
							FTC Natural Gas Pipeline Disposal Group [Member]	FTC Natural Gas Pipeline Disposal Group [Member]
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'
Proceeds from disposal of discontinued operations	$0	$1,791	$0	'	'	'	$1,791	'
Selling expenses on sale of assets held for sale	'	'	'	'	'	'	78	'
Disposal Group, Including Discontinued Operation, Revenue	'	'	'	'	227	322	'	'
Impairment of Long-Lived Assets to be Disposed of	'	'	'	937	'	'	'	'
Disposal Group, Including Discontinued Operation, Operating Expense	'	'	'	'	-131	-183	'	'
Disposal Group, Including Discontinued Operation, Depreciation and Amortization	'	'	'	'	-7	-24	'	'
Disposal group, Including Discontinued Operation, Other Expenses	'	'	'	'	-1	0	'	'
Disposal Group, Including Discontinued Operation, Earnings From Equity Investments	'	'	'	'	70	87	'	'
Disposal Group, Including Discontinued Operation, Interest Income and Other, Net	'	'	'	'	2	2	'	'
Discontinued Operation, Tax Effect of Discontinued Operation	'	0	-2	'	'	'	'	'
Income from operations of KMP’s FTC Natural Gas Pipelines disposal group and other, net of tax	0	160	211	'	160	202	'	'
Business Combination, Step Acquisition, Equity Interest in Acquiree, Remeasurement Loss	($558)	$0	$167	'	'	'	'	$4

Acquisitions_Divestitures_Expr

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

1 Months Ended

12 Months Ended

9 Months Ended

0 Months Ended

12 Months Ended

9 Months Ended

3 Months Ended

In Millions, unless otherwise specified

Jan. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 30, 2013

Mar. 14, 2013

Dec. 31, 2013

Mar. 14, 2013

Dec. 01, 2012

Dec. 31, 2013

Mar. 14, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 01, 2012

Jan. 02, 2012

Sep. 30, 2013

Dec. 01, 2012

Dec. 31, 2012

Express Pipeline System [Member]

Express Pipeline System [Member]

Kinder Morgan Canada [Member]

Kinder Morgan Canada [Member]

TransMontaigne [Member]

Express Pipeline System [Member]

Express Pipeline System [Member]

Assets Held-for-sale [Member]

Battleground Oil Specialty Terminal Company LLC [Member]

Battleground Oil Specialty Terminal Company LLC [Member]

Battleground Oil Specialty Terminal Company LLC [Member]

Battleground Oil Specialty Terminal Company LLC [Member]

TGP and EPNG [Member]

A [Member]

FTC Natural Gas Pipeline Disposal Group [Member]

KMP Sale of Express Pipeline System [Member]

Equity method investment & Suboordinated debt investment [Member]

Kinder Morgan Canada [Member]

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

TransMontaigne [Member]

TransMontaigne [Member]

Third party [Member]

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

Spectra Energy Corp. [Member]

KMP Sale of Express Pipeline System [Member]

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from disposal of discontinued operations

'

$0

$1,791

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1,791

Public Utilities, Property, Plant and Equipment, Equipment, Useful Life

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'25 years

'

'

Equity aguired from exercised option

'

'

'

'

'

'

'

'

'

'

'

'

'

'

42.50%

'

'

'

'

Proceeds from Sale of Equity Method Investments

88

490

0

0

'

402

'

'

'

'

'

'

1

'

'

'

'

'

'

Equity Method Investment, Realized Gain (Loss) on Disposal

'

'

'

'

224

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income Tax Expense (Benefit)

'

742

139

361

84

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investments

'

5,943

5,796

'

'

'

65

67

'

'

'

179

'

'

'

'

'

'

'

Option exercised, potential ownership interest

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

Notes Receivable, Related Parties

'

'

'

'

'

'

'

'

'

114

110

'

'

'

'

'

'

'

'

Equity Method Investment, Net Sales Proceeds

'

'

'

'

'

'

'

'

'

'

'

'

'

$79

'

'

'

'

'

Equity Method Investment, Ownership Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

55.00%

'

Equity method investment sold, percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.50%

'

'

'

Acquisitions_Divestitures_TGPs

Acquisitions Divestitures - TGP's Sale of Production Area Facilities and BBPP Holding Ltda (Details) (USD $)

1 Months Ended

12 Months Ended

0 Months Ended

In Millions, unless otherwise specified

Jan. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Sep. 03, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Mar. 14, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Bolivia to Brazil Pipeline [Member]

Bolivia to Brazil Pipeline [Member]

Sale of production area facilities [Domain]

Gas Transboliviano S.A. [Member]

Transportadora Brasileira Gasoduto Bolivia-Brasil S.A. [Member]

Express Pipeline System [Member]

Express Pipeline System [Member]

Bolivia to Brazil Pipeline [Member]

British Gas International Holdings B.V [Member]

Total [Member]

TGP [Member]

El Paso Corporation [Member]

BBPP Holdings Ltda [Member]

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

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

BBPP Holdings Ltda [Member]

Bolivia to Brazil Pipeline [Member]

Bolivia to Brazil Pipeline [Member]

El Paso Corporation [Member]

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Sale of Property, Plant, and Equipment

'

'

'

'

'

'

$32

'

'

'

'

'

'

'

Net Assets Sold

'

'

'

'

'

'

89

'

'

'

'

'

'

'

Increase (Decrease) in Other Regulatory Assets

'

'

'

'

'

'

93

'

'

'

'

'

'

'

Gain (Loss) on Disposition of Property Plant Equipment

'

'

'

'

'

'

36

'

'

'

'

'

'

'

Equity Method Investment, Ownership Percentage

'

'

'

'

33.33%

'

'

2.00%

29.00%

33.33%

33.33%

29.00%

'

'

Proceeds from Sale of Equity Method Investments

88

490

0

0

'

'

'

'

'

'

'

'

'

'

Assets held for sale

'

$0

$298

'

'

$88

'

'

'

'

'

'

'

'

Income_Taxes_Details

Income Taxes (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Tax Examination [Line Items]	'	'	'
Unrecognized Tax Benefits, Subtotal	$273,000,000	$346,000,000	$53,000,000
Income from Continuing Operations Before Income Taxes	'	'	'
U.S.	3,107,000,000	1,246,000,000	731,000,000
Foreign	331,000,000	97,000,000	79,000,000
Income from Continuing Operations Before Income Taxes	3,438,000,000	1,343,000,000	810,000,000
Current tax expense	'	'	'
Federal	57,000,000	48,000,000	241,000,000
State	36,000,000	34,000,000	33,000,000
Foreign	9,000,000	10,000,000	3,000,000
Current Income Tax Expense (Benefit)	102,000,000	92,000,000	277,000,000
Deferred tax expense	'	'	'
Federal	612,000,000	49,000,000	64,000,000
State	0	4,000,000	-1,000,000
Foreign	28,000,000	-6,000,000	21,000,000
Deferred Income Tax Expense (Benefit)	640,000,000	47,000,000	84,000,000
Total tax provision	742,000,000	139,000,000	361,000,000
Effective Income Tax Rate Reconciliation [Abstract]	'	'	'
Federal income tax	1,203,000,000	470,000,000	284,000,000
Federal income tax	35.00%	35.00%	35.00%
Taxes on foreign earnings	112,000,000	-6,000,000	24,000,000
Taxes on foreign earnings	3.30%	-0.50%	3.00%
Net effects of consolidating KMP’s and EPB’s U.S. income tax provision	-488,000,000	-288,000,000	34,000,000
Net effects of consolidating KMP’s and EPB’s U.S. income tax provision	-14.20%	-21.50%	4.20%
State income tax, net of federal benefit	45,000,000	21,000,000	26,000,000
State income tax, net of federal benefit	1.30%	1.60%	3.20%
Dividend received deduction	-54,000,000	-32,000,000	-10,000,000
Dividend received deduction	-1.60%	-2.40%	-1.20%
Adjustments to uncertain tax positions	-87,000,000	-72,000,000	-9,000,000
Adjustments to uncertain tax positions	-2.50%	-5.30%	-1.10%
Other	32,000,000	8,000,000	13,000,000
Other	0.90%	0.60%	1.60%
Total	21.60%	10.30%	44.60%
Deferred tax assets	'	'	'
Employee benefits	238,000,000	360,000,000	'
Book accruals	136,000,000	91,000,000	'
Net operating loss, capital loss, tax credits carryforwards (net of valuation allowance)	578,000,000	1,017,000,000	'
Derivative instruments	33,000,000	84,000,000	'
Interest rate and currency swaps	35,000,000	37,000,000	'
Debt fair value adjustment	112,000,000	155,000,000	'
Other	43,000,000	86,000,000	'
Total deferred tax assets	1,175,000,000	1,830,000,000	'
Deferred tax liabilities	'	'	'
Property, plant and equipment	351,000,000	328,000,000	'
Investments	4,888,000,000	5,008,000,000	'
Book accruals	10,000,000	22,000,000	'
Other	10,000,000	4,000,000	'
Total deferred tax liabilities	5,259,000,000	5,362,000,000	'
Net deferred tax liabilities	4,084,000,000	3,532,000,000	'
Current deferred tax asset	-567,000,000	-539,000,000	'
Non-current deferred tax liability	4,651,000,000	4,071,000,000	'
Deferred Tax Assets, Tax Credit Carryovers, Alt Min, Gen Bus and Foreign	'	298,000,000	'
Deferred Tax Assets, Valuation Allowance	0	104,000,000	'
Deferred Tax Assets, Operating Loss Carryforwards	'	823,000,000	'
Required minimum likelihood for benefits to be recognized in the financial statements	50.00%	'	'
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties	'	'	'
Unrecognized Tax Benefits	269,000,000	57,000,000	53,000,000
Unrecognized Tax Benefits, Increase Resulting from Current Period Tax Positions	11,000,000	11,000,000	11,000,000
Unrecognized Tax Benefits, Increase Resulting from Prior Period Tax Positions	26,000,000	1,000,000	2,000,000
Reductions based on settlements with taxing authority	-86,000,000	-55,000,000	0
Reductions due to lapse in statute of limitations	-15,000,000	-34,000,000	-9,000,000
Unrecognized Tax Benefits	209,000,000	269,000,000	57,000,000
Unrecognized Tax Benefits, Interest on Income Taxes Accrued	29,000,000	28,000,000	5,000,000
Unrecognized Tax Benefits, Income Tax Penalties Accrued	2,000,000	2,000,000	1,000,000
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued	209,000,000	'	'
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit	2,000,000	'	'
Unrecognized tax benefits, income tax penalties and interest accruing next year	207,000,000	'	'
KMI's Acquisition of EP [Member]	'	'	'
Deferred tax liabilities	'	'	'
Deferred Tax Assets, Tax Credit Carryovers, Alt Min, Gen Bus and Foreign	308,000,000	'	'
Deferred Tax Assets, Valuation Allowance	95,000,000	'	'
Deferred Tax Assets, Operating Loss Carryforwards	354,000,000	'	'
KMI's Acquisition of EP [Member] | El Paso LLC [Member]	'	'	'
Income Tax Examination [Line Items]	'	'	'
Unrecognized Tax Benefits, Increase Resulting from Acquisition	4,000,000	289,000,000	0
State and Local Jurisdiction [Member]	'	'	'
Effective Income Tax Rate Reconciliation [Abstract]	'	'	'
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, State, Amount	-21,000,000	20,000,000	-1,000,000
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, State, Percent	-0.60%	1.50%	-0.10%
General Business Tax Credit Carryforward [Member]	'	'	'
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties	'	'	'
Deferred Tax Assets, Operating Loss Carryforwards, Foreign	191,000,000	'	'
General Business Tax Credit Carryforward [Member] | Foreign Tax Authority [Member]	'	'	'
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties	'	'	'
Deferred Tax Assets, Operating Loss Carryforwards, Not Subject to Expiration	140,000,000	'	'
Expires from 2017 - 2031 [Member] | General Business Tax Credit Carryforward [Member] | Domestic Tax Authority [Member]	'	'	'
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties	'	'	'
Deferred Tax Assets, Operating Loss Carryforwards, Subject to Expiration	613,000,000	'	'
Expires from 2028 - 2032 [Member] | General Business Tax Credit Carryforward [Member] | Foreign Tax Authority [Member]	'	'	'
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties	'	'	'
Deferred Tax Assets, Operating Loss Carryforwards, Subject to Expiration	51,000,000	'	'
Does Not Expire [Member] | General Business Tax Credit Carryforward [Member]	'	'	'
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties	'	'	'
Deferred Tax Assets, Tax Credit Carryforwards, Alternative Minimum Tax	297,000,000	'	'
Majority expire from 2015 - 2023 [Member] | General Business Tax Credit Carryforward [Member]	'	'	'
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties	'	'	'
Deferred Tax Assets, Tax Credit Carryforwards, Foreign	11,000,000	'	'
Pakistan power plant [Member]	'	'	'
Deferred tax liabilities	'	'	'
Deferred Tax Assets, Capital Loss Carryforwards	11,000,000	'	'
Acquisition-related Costs [Member]	'	'	'
Effective Income Tax Rate Reconciliation [Abstract]	'	'	'
Other	0	18,000,000	0
Other	0.00%	1.30%	0.00%
State and Local Jurisdiction [Member] | Expires from 2014 - 2032 [Member] | General Business Tax Credit Carryforward [Member] | Domestic Tax Authority [Member]	'	'	'
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties	'	'	'
Deferred Tax Assets, Operating Loss Carryforwards, Subject to Expiration	$1,400,000,000	'	'

Property_Plant_and_Equipment_C

Property, Plant and Equipment Classes and Depreciation (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Public Utilities, Property, Plant and Equipment, Transmission and Distribution [Abstract]	'	'	'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	($6,757,000,000)	($5,278,000,000)	'
Public Utilities, Property, Plant and Equipment, Equipment	32,517,000,000	28,357,000,000	'
Land and land right-of-way	1,158,000,000	1,143,000,000	'
Construction in Progress, Gross	2,172,000,000	1,496,000,000	'
Net depreciable property plant and equipment	35,847,000,000	30,996,000,000	'
Public Utilities, Property, Plant and Equipment, Common	14,957,000,000	14,937,000,000	'
Regulated assets as a percentage of total property plant and equipment net	42.00%	48.00%	'
Depreciation, depletion and amortization	1,806,000,000	1,419,000,000	1,068,000,000
Asset Retirement Obligation	204,000,000	175,000,000	'
Asset Retirement Obligation, Current	25,000,000	31,000,000	'
Charged against PPE [Member]	'	'	'
Public Utilities, Property, Plant and Equipment, Transmission and Distribution [Abstract]	'	'	'
Depreciation, depletion and amortization	1,663,000,000	1,324,000,000	1,022,000,000
Gas Transmission Equipment [Member]	'	'	'
Public Utilities, Property, Plant and Equipment, Transmission and Distribution [Abstract]	'	'	'
Public Utilities, Property, Plant and Equipment, Transmission	17,399,000,000	14,649,000,000	'
Gas, Transmission and Distribution Equipment [Member]	'	'	'
Public Utilities, Property, Plant and Equipment, Transmission and Distribution [Abstract]	'	'	'
Public Utilities, Property, Plant and Equipment, Transmission and Distribution	17,960,000,000	15,309,000,000	'
Gas Gathering and Processing Equipment [Member]	'	'	'
Public Utilities, Property, Plant and Equipment, Transmission and Distribution [Abstract]	'	'	'
Public Utilities, Property, Plant and Equipment, Generation or Processing	259,000,000	358,000,000	'
Property, Plant and Equipment, Other Types [Member]	'	'	'
Public Utilities, Property, Plant and Equipment, Transmission and Distribution [Abstract]	'	'	'
Other depreciable property plant and equipment	$3,656,000,000	$3,319,000,000	'

Property_Plant_and_Equipment_A

Property, Plant and Equipment Asset Retirement Obligations (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Property, Plant and Equipment [Abstract]	'	'
Asset Retirement Obligation	$204	$175
Asset Retirement Obligation, Current	$25	$31

Investments_Details

Investments (Details) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

In Millions, except Share data, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

1-May-13

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

1-May-13

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

1-May-13

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jun. 30, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Citrus Corporation [Member]

Citrus Corporation [Member]

Citrus Corporation [Member]

Ruby Pipeline Holding Company LLC [Member]

Ruby Pipeline Holding Company LLC [Member]

Ruby Pipeline Holding Company LLC [Member]

Midcontinent Express Pipeline LLC [Member]

Midcontinent Express Pipeline LLC [Member]

Midcontinent Express Pipeline LLC [Member]

Gulf LNG Holdings Group LLC [Member]

Gulf LNG Holdings Group LLC [Member]

Gulf LNG Holdings Group LLC [Member]

Plantation Pipe Line Company [Member]

Plantation Pipe Line Company [Member]

Plantation Pipe Line Company [Member]

EagleHawk Field Services [Member]

EagleHawk Field Services [Member]

EagleHawk Field Services [Member]

Red Cedar Gathering company [Member]

Red Cedar Gathering company [Member]

Red Cedar Gathering company [Member]

Double Eagle Pipeline LLC

Double Eagle Pipeline LLC

Double Eagle Pipeline LLC

Double Eagle Pipeline LLC

Fayetteville Express [Member]

Fayetteville Express [Member]

Fayetteville Express [Member]

Parkway Pipeline LLC [Member]

Parkway Pipeline LLC [Member]

Parkway Pipeline LLC [Member]

Watco Companies LLC [Member]

Watco Companies LLC [Member]

Watco Companies LLC [Member]

Fort Union Gas Gathering L.L.C.

Fort Union Gas Gathering L.L.C.

Fort Union Gas Gathering L.L.C.

Fort Union Gas Gathering L.L.C.

Cortez Pipeline Company [Member]

Cortez Pipeline Company [Member]

Cortez Pipeline Company [Member]

Eagle Ford Gathering LLC [Member]

Eagle Ford Gathering LLC [Member]

Eagle Ford Gathering LLC [Member]

Eagle Ford Gathering LLC [Member]

NGPL Holdco LLC [Member]

NGPL Holdco LLC [Member]

NGPL Holdco LLC [Member]

KinderHawk [Member]

KinderHawk [Member]

KinderHawk [Member]

KinderHawk [Member]

Industrial, Miscellaneous, and All Others [Member]

Industrial, Miscellaneous, and All Others [Member]

Industrial, Miscellaneous, and All Others [Member]

Energy Transfers Partners LP [Member]

Energy Transfers Partners LP [Member]

Global Infrastructure Partners [Member]

Regency Energy Partners LP [Member]

GE Financial Services [Member]

BHP Billiton [Member]

Southern Ute Indian Tribe [Member]

Valero Energy Corp. [Member]

Exxon Mobil Corporation [Member]

Cortez Vickers Pipeline Company [Member]

Citrus Corporation [Member]

Fayetteville Express [Member]

Ruby Pipeline Holding Company LLC [Member]

Midcontinent Express Pipeline LLC [Member]

Gulf LNG Holdings Group LLC [Member]

EagleHawk Field Services [Member]

Red Cedar Gathering company [Member]

Parkway Pipeline LLC [Member]

Cortez Pipeline Company [Member]

Cortez Pipeline Company [Member]

Schedule of Equity Method Investments [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Ownership Percentage

'

'

'

50.00%

'

'

50.00%

'

'

50.00%

'

'

50.00%

'

'

51.17%

'

'

25.00%

'

'

49.00%

'

'

'

'

'

50.00%

50.00%

'

'

50.00%

'

'

'

'

'

'

'

'

37.00%

50.00%

'

'

'

'

'

50.00%

20.00%

'

'

'

'

'

50.00%

'

'

'

50.00%

50.00%

50.00%

50.00%

50.00%

75.00%

51.00%

50.00%

37.00%

13.00%

Miles Of Pipeline

80,000

'

'

5,300

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of KMP investments excluded from equity investment discussion

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred Stock, Value, Issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Quarterly preferred distribution rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Profit participation rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Other than Temporary Impairment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$65

$200

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent of investee information represented

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investments

5,943

5,796

'

1,875

1,966

'

1,153

1,185

'

602

633

'

578

596

'

307

313

'

272

208

'

176

172

'

144

0

'

'

144

159

'

131

58

'

103

103

'

161

0

'

'

12

11

'

'

151

'

'

0

68

'

'

'

'

'

285

173

'

'

'

'

'

'

'

'

'

'

'

Held-to-maturity Securities

8

8

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Investments

5,951

5,804

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Earnings from equity investments

327

153

226

84

53

0

-6

-5

0

40

42

43

47

22

0

35

32

28

9

11

3

31

32

32

1

0

0

'

55

55

24

1

0

0

13

13

6

11

0

0

'

24

25

24

14

34

11

'

-66

-198

19

0

0

22

'

34

37

14

'

'

'

'

'

'

'

'

'

'

Amortization of excess costs

-39

-23

-7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Summarized Financial Information, Revenue

3,615

3,681

3,145

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Summarized Financial Information, Cost of Sales

2,803

3,194

3,287

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Summarized Financial Information, Net Income (Loss)

812

487

-142

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Summarized Financial Information, Current Assets

950

917

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Summarized Financial Information, Noncurrent Assets

20,782

21,308

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Summarized Financial Information, Current Liabilities

1,451

1,538

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities

11,351

11,401

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Summarized Financial Information, Equity or Capital

$8,930

$9,286

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Goodwill_and_Other_Intangibles2

Goodwill and Other Intangibles Goodwill and Excess Investment Cost (Details) (USD $)

12 Months Ended

0 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

31-May-13

Dec. 31, 2011

31-May-13

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Jun. 30, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Reporting unit [Member]

Natural Gas Pipelines [Member]

Natural Gas Pipelines [Member]

Natural Gas Pipelines [Member]

CO2 - KMP [Member]

CO2 - KMP [Member]

CO2 - KMP [Member]

Products Pipelines - KMP [Member]

Products Pipelines - KMP [Member]

Products Pipelines - KMP [Member]

Terminals - KMP [Member]

Terminals - KMP [Member]

Terminals - KMP [Member]

Kinder Morgan Canada - KMP [Member]

Kinder Morgan Canada - KMP [Member]

Kinder Morgan Canada - KMP [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMI's Acquisition of El Paso Corporation [Member]

KinderHawk [Member]

May 31st [Member]

May 31, 2013 [Member]

Ammortized [Member]

Ammortized [Member]

Unamortization [Member]

Unamortization [Member]

unamortized excess cost over underlying fair value of net assets acquired [Member]

Natural Gas Pipelines [Member]

Natural Gas Pipelines [Member]

Goodwill [Member]

Natural Gas Pipelines Non-Regulated & Natural Gas Pipelines Regulated [Member]

segment

KMP Acquisiton of Copano Energy LLC [Member]

Goodwill [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of reporting units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7

'

'

'

'

'

'

Number of reportable segments for impairment testing

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

Goodwill, Impairment Loss

'

'

'

'

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Goodwill [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Historical goodwill including accumulated activities except impairments

'

'

'

9,485,000,000

'

'

'

3,723,000,000

'

'

1,528,000,000

'

'

2,129,000,000

'

'

1,484,000,000

'

'

621,000,000

'

'

'

'

'

'

'

'

'

'

Goodwill, Impaired, Accumulated Impairment Loss

'

'

0

-4,411,000,000

'

'

'

-2,090,000,000

'

'

0

'

'

-1,267,000,000

'

'

-677,000,000

'

'

-377,000,000

'

'

'

'

'

'

'

'

'

'

Goodwill

23,632,000,000

5,074,000,000

'

'

'

20,186,000,000

1,633,000,000

'

1,528,000,000

1,528,000,000

'

862,000,000

862,000,000

'

807,000,000

807,000,000

'

249,000,000

244,000,000

'

'

'

'

'

'

'

'

'

'

'

Goodwill, Other Changes

'

18,803,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Goodwill arising from acquisitions

888,000,000

'

'

'

'

888,000,000

18,803,000,000

'

0

0

'

0

0

'

0

0

'

0

0

'

881,000,000

7,000,000

'

'

'

'

'

'

'

'

Goodwill, Written off Related to Sale of Business Unit

'

-250,000,000

'

'

'

'

-250,000,000

'

'

0

'

'

0

'

'

0

'

'

0

'

'

'

'

'

'

'

'

'

'

'

Goodwill, Translation Adjustments

-16,000,000

5,000,000

'

'

'

0

0

'

0

0

'

0

0

'

0

0

'

-16,000,000

5,000,000

'

'

'

'

'

'

'

'

'

'

'

Goodwill

24,504,000,000

23,632,000,000

'

'

'

21,074,000,000

20,186,000,000

'

1,528,000,000

1,528,000,000

'

862,000,000

862,000,000

'

807,000,000

807,000,000

'

233,000,000

249,000,000

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Ownership Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

Equity Method Investment, Difference Between Carrying Amount and Underlying Equity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

809,000,000

714,000,000

138,000,000

138,000,000

'

Amortization period of excess cost of equity method investments, Estimated weighted average

'15 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Asset Impairment Charges

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0

Change in Estimated Useful Life

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'0 years

Goodwill_and_Other_Intangibles3

Goodwill and Other Intangibles Other Intangibles (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Finite-Lived Intangible Assets [Line Items]	'	'	'
Intangible Assets, Net (Excluding Goodwill)	$2,438	$1,171	'
Amortization of Intangible Assets	125	86	65
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months	141	'	'
Finite-Lived Intangible Assets, Amortization Expense, Year Two	136	'	'
Finite-Lived Intangible Assets, Amortization Expense, Year Three	134	'	'
Finite-Lived Intangible Assets, Amortization Expense, Year Four	132	'	'
Finite-Lived Intangible Assets, Amortization Expense, Year Five	$130	'	'
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	'20 years	'	'

Debt_Details

Debt (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Aug. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

1-May-13

Dec. 31, 2012

31-May-13

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

1-May-13

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Aug. 31, 2013

Dec. 31, 2013

Aug. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

El Paso LLC [Member]

El Paso LLC [Member]

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

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

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

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

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

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

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

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

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

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

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

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

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

Capital Trust [Member]

Colorado Interstate Gas (CIG) [Member]

Totem and High Plains [Member]

Totem and High Plains [Member]

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

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

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

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

Senior notes and debentures, 5.00% through 7.45% [Member]

Senior notes and debentures, 5.00% through 7.45% [Member]

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

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

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

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

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

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

KMI 7.76% Totem note payable due 2018 [Member]

KMI 7.76% Totem note payable due 2018 [Member]

KMI 7.76% Totem note payable due 2018 [Member]

KMI EP Capital Trust I, due 2028 [Member]

KMI EP Capital Trust I, due 2028 [Member]

KMI EP Capital Trust I, due 2028 [Member]

Capital Trust [Member]

Capital Trust [Member]

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

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

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

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

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

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

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

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

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

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

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

KMP Other Miscellaneous Subsidiary Debt [Member]

KMP Other Miscellaneous Subsidiary Debt [Member]

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

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

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

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

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

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

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

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

EPB Other Financial Obligations [Member] [Member]

EPB Other Financial Obligations [Member] [Member]

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

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

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

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

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

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

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

KMI 5% Senior Notes due February 15, 2021 [Member]

KMI 5.625% Senior Notes due November 15, 2023 [Member]

8.56% Capital I Trust Securities maturing on April 15, 2027 [Member]

7.63% Capital Trust III Securities maturing on April 15, 2028 [Member]

Capital Trust I [Member]

Capital Trust I [Member]

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

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

Totem and High Plains [Member]

Class P [Member]

Class P [Member]

Class P [Member]

Class P [Member]

Class P [Member]

Class P [Member]

Warrant [Member]

Warrant [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

High [Member]

High [Member]

High [Member]

High [Member]

High [Member]

High [Member]

High [Member]

High [Member]

High [Member]

High [Member]

High [Member]

WYCO Development L.L.C. [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Revolving Credit Facility [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan Finance Company, LLC [Member]

Kinder Morgan Finance Company, LLC [Member]

El Paso LLC [Member]

El Paso LLC [Member]

Colorado Interstate Gas Services Company [Member]

Colorado Interstate Gas Services Company [Member]

Colorado Interstate Gas (CIG) [Member]

Capital Trust I [Member]

Capital Trust I [Member]

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

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

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

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

TGP [Member]

TGP [Member]

EPNG [Member]

EPNG [Member]

Copano Energy LLC [Member]

Copano Energy LLC [Member]

Copano Energy LLC [Member]

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

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

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

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

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

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

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

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

SNG [Member]

SNG [Member]

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

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

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

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

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

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

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

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

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

EPC Building LLC [Member]

EPC Building LLC [Member]

KMI EP Capital Trust I, due 2028 [Member]

Capital Trust [Member]

Capital Trust [Member]

Capital Trust [Member]

Capital Trust [Member]

Senior notes and debentures, 5.00% through 7.45% [Member]

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

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

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

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

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

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

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

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

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

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

Senior notes and debentures, 5.00% through 7.45% [Member]

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

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

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

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

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

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

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

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

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

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

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

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan Finance Company, LLC [Member]

El Paso LLC [Member]

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

TGP [Member]

EPNG [Member]

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

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

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

SNG [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan Finance Company, LLC [Member]

El Paso LLC [Member]

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

TGP [Member]

EPNG [Member]

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

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

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

SNG [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior Notes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1,528,000,000

$2,714,000,000

$1,815,000,000

$315,000,000

$27,000,000

$27,000,000

$1,636,000,000

$1,636,000,000

$3,830,000,000

$3,860,000,000

'

'

'

'

$280,000,000

$286,000,000

'

'

'

'

$15,600,000,000

$13,350,000,000

$1,790,000,000

$1,790,000,000

$1,115,000,000

$1,115,000,000

$332,000,000

'

$0

'

'

$2,260,000,000

$2,348,000,000

$475,000,000

$475,000,000

$135,000,000

$135,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$13,000,000

$14,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Amount Outstanding

'

'

175,000,000

1,035,000,000

193,000,000

210,000,000

'

'

0

0

'

'

'

'

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Notes Payable

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,211,000,000

1,211,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

461,000,000

217,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000,000

100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Debt

'

'

10,046,000,000

10,401,000,000

'

'

'

'

19,914,000,000

17,062,000,000

'

'

'

'

'

'

'

4,256,000,000

4,347,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current portion of debt

'

'

-725,000,000

-1,153,000,000

'

'

'

'

-1,504,000,000

-1,155,000,000

'

'

'

'

'

'

'

-77,000,000

-93,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-141,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

9,321,000,000

9,248,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commercial Paper

'

'

'

'

'

'

'

'

979,000,000

621,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Long-term Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

98,000,000

186,000,000

'

'

'

'

'

'

'

'

175,000,000

178,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Debt, Excluding Current Maturities

33,887,000,000

32,000,000,000

'

'

'

'

'

'

18,410,000,000

15,907,000,000

'

'

'

'

'

'

'

4,179,000,000

4,254,000,000

'

'

'

'

22,589,000,000

20,161,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Redemption price of debt as a percentage of face amount

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt, Weighted Average Interest Rate

5.08%

4.92%

'

'

'

'

'

'

'

'

0.28%

'

0.45%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.67%

2.72%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate, stated percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7.76%

4.75%

4.75%

'

'

'

'

'

'

'

'

'

'

'

7.13%

7.13%

'

'

'

'

'

'

'

'

'

'

'

'

'

3.50%

5.00%

2.65%

2.65%

4.15%

4.15%

'

'

5.00%

5.63%

8.56%

7.63%

'

'

3.97%

3.97%

15.50%

'

'

'

'

'

'

'

'

5.00%

7.63%

5.70%

6.50%

2.65%

7.00%

5.95%

4.10%

5.95%

9.50%

4.40%

7.45%

8.56%

6.40%

12.00%

9.00%

8.38%

8.63%

8.00%

6.85%

9.75%

8.00%

'

Equity Method Investment, Ownership Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.00%

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

Debt Instrument, Face Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,600,000

'

468,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred Stock, Conversion, Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.7197

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Convertible, Conversion Price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$25.18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred Stock, Liquidation Preference Per Share

$50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class of Warrant or Right, Number of Securities Called by Warrants or Rights

'

'

1.1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Value of preferred securities value assigned to debt

247,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Value of preferred securities value assigned to equity

33,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Conversion of Stock, Shares Converted

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

107,618

781,633

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period, Shares, Conversion of Convertible Securities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

61,241,023

535,972,387

'

562,521

77,442

562,521

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Value of cash issued in debt conversion

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Conversion, Converted Instrument, Warrants or Options Issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

118,377

859,796

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock, shares outstanding (in shares)

0

0

'

'

'

'

'

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock, par value (in dollars per share)

$0.01

$0.01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred Stock, Dividend Rate, Percentage

'

'

'

'

'

'

8.33%

3.90%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Fair Value Adjustments

1,977,000,000

2,591,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity Increase

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

'

'

'

'

'

'

'

'

'

'

'

2,700,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Consolidated Leverage Ratio For Any Trailing Four Consecutive Quarter Periods

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest Coverage Ratio Restriction

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Construction Costs Funded

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capital Lease Obligations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$75,000,000

$94,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit_Facilities_and_Restrict

Credit Facilities and Restrictive Covenants (Details) (USD $)

5 Months Ended

1 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

25-May-12

Aug. 31, 2013

Aug. 31, 2012

Dec. 31, 2013

25-May-12

Dec. 31, 2013

Dec. 31, 2013

1-May-13

Apr. 30, 2013

Dec. 31, 2012

3-May-13

31-May-13

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Jan. 17, 2014

Jan. 17, 2014

Feb. 21, 2014

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

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

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

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

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

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

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

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

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

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

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

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

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

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

Minimum [Member]

Maximum [Member]

Maximum [Member]

Revolving Credit Facility [Member]

Period in which acquisition occured [Member]

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

Alternate Base Rate [Member]

Alternate Base Rate [Member]

Alternate Base Rate [Member]

Alternate Base Rate [Member]

London Interbank Offered Rate (LIBOR) [Member]

London Interbank Offered Rate (LIBOR) [Member]

London Interbank Offered Rate (LIBOR) [Member]

London Interbank Offered Rate (LIBOR) [Member]

Federal Funds Rate [Member]

London Interbank Offered Rate (LIBOR) [Member]

London Interbank Offered Rate (LIBOR) [Member]

Subsequent Event [Member]

Liquidity Facility [Member]

Liquidity Facility [Member]

364 Day Bridge Loan [Member]

364 Day Bridge Loan [Member]

Secured Debt [Member]

Three Year Term Loan [Member]

Restrictive covenant [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Commercial Paper [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

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

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

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

Kinder Morgan, Inc. [Member]

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

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

Minimum [Member]

Minimum [Member]

Maximum [Member]

Maximum [Member]

Minimum [Member]

Minimum [Member]

Maximum [Member]

Maximum [Member]

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

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

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

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

Subsequent Event [Member]

Subsequent Event [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

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

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

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit Facility [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capacity of previous credit facility

'

'

'

$1,000,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Increase in additional commitments

'

'

'

750,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Current Borrowing Capacity

'

1,750,000,000

'

'

'

'

'

5,000,000,000

'

2,700,000,000

2,700,000,000

2,200,000,000

'

'

'

'

'

'

'

'

'

1,000,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,700,000,000

'

'

Debt Instrument, Term

'3 years

'

'

'

'364 days

'364 days

'

'3 years

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'6 months

'

Consolidated Leverage Ratio

'

'

'

'

'

'

'

'

6

5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Amount Outstanding

'

175,000,000

1,035,000,000

'

'

'

175,000,000

'

'

0

'

'

0

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

LIBOR Basis, Period For Eurodollar Loan

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'1 month

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Basis Spread on Variable Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.00%

'

'

'

1.75%

'

'

100.00%

'

'

1.50%

2.00%

3.25%

3.75%

2.50%

3.00%

4.25%

4.75%

0.50%

1.00%

1.75%

'

'

'

Letters of Credit Outstanding, Amount

'

80,000,000

'

'

'

'

'

'

'

203,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Amount Current Borrowing Capacity is Reduced

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

979,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Remaining borrowing capacity

'

1,495,000,000

'

'

'

'

'

'

'

1,518,000,000

'

'

'

'

'

'

'

1,000,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of hedge payments missed that will constitute a debt default

'

'

'

'

'

'

'

'

'

75,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of any payments missed that will constitute a debt default

'

'

'

'

'

'

'

'

'

75,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of adverse judgement rendered against us that remains undischarged for 30 days that shall constitute a default on debt

'

'

'

'

'

'

'

'

'

75,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity Increase

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000,000

'

Line of Credit Facility, Capacity Available for Specific Purpose Other than for Trade Purchases

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20,000,000

'

'

1,500,000,000

'

'

25,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unused capacity, commitment fee percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.40%

'

'

'

0.30%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Consolidated Leverage Ratio For Any Trailing Four Consecutive Quarter Periods

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Consolidated leverage ratio for any such four quarter period during three full fiscal quarters

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Cedit Facility, Restrictive Covenant, Percent of Consolidated EBITDA

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Debt Default, Description of Violation or Event of Default

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$50,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Ownership Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.00%

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt_KMPs_Copano_Debt_Details

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

0 Months Ended

0 Months Ended

0 Months Ended

In Millions, unless otherwise specified

Jun. 06, 2013

Jun. 02, 2013

31-May-13

1-May-13

Sep. 05, 2013

Dec. 31, 2013

Sep. 04, 2013

1-May-13

Dec. 31, 2012

1-May-13

1-May-13

3-May-13

1-May-13

7.75% unsecured senior notes due June 1, 2018 [Member]

7.75% unsecured senior notes due June 1, 2018 [Member]

7.75% unsecured senior notes due June 1, 2018 [Member]

7.75% unsecured senior notes due June 1, 2018 [Member]

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

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

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

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

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

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

7.75% unsecured senior notes due June 1, 2018 [Member]

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

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

$249

$510

'

$404

Debt Instrument, Interest Rate, Stated Percentage

'

'

7.75%

7.75%

'

7.13%

'

7.13%

'

'

7.13%

'

'

Repayments of Copano Credit Facility

'

'

'

'

'

'

'

'

'

'

'

404

'

Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed

103.88%

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Repurchase Amount

'

259

'

'

'

'

191

'

'

'

'

'

'

Debt Instrument, Announced Expected Redemption Amount

'

'

'

'

'

'

178

'

'

259

191

'

'

Interest Paid

'

'

'

'

6

'

'

'

'

'

'

'

'

Debt Instrument, Percentage of Principal Amount To Be Redeemed

'

'

'

'

'

'

35.00%

'

'

'

'

'

'

Senior Notes

'

'

'

'

'

$332

'

'

$0

'

$510

'

'

Debt_Debt_Issuances_and_Repaym

Debt Debt Issuances and Repayments (Details) (USD $)

0 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

In Millions, unless otherwise specified

25-May-12

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Aug. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Aug. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Apr. 30, 2013

Feb. 19, 2014

Feb. 19, 2014

KMI Debt Assumed as of May 25, 2012 [Member]

EPC Building LLC [Member]

EPC Building LLC [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

High [Member]

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

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

Third parties [Member]

Third parties [Member]

Third parties [Member]

February 19, 2014 Debt Offering [Member]

February 19, 2014 Debt Offering [Member]

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

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

Senior notes due September 1, 2012 [Member]

KMI 5% Senior Notes due February 15, 2021 [Member]

KMI 5.625% Senior Notes due November 15, 2023 [Member]

Senior notes due 2042 [Member]

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

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

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

3.95% KMP Senior notes due September 1, 2022 [Member] [Member] [Member]

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

Senior notes due February 15, 2023 [Member]

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

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

Senior notes due August 15, 2042 [Member]

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

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

KMP 5% Senior Notes due December 15, 2013 [Member]

Senior notes due March 15, 2012 [Member]

Senior notes due September 15, 2012 [Member]

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

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

EPC Building LLC [Member]

EPC Building LLC [Member]

EPC Building LLC [Member]

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

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

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

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

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

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

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

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

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior Notes

'

'

'

'

'

'

'

'

'

'

$2,260

$2,348

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$750

$750

Debt Instrument, Interest Rate, Stated Percentage

'

3.97%

3.97%

'

'

'

6.50%

5.00%

5.63%

4.70%

'

'

3.50%

3.95%

5.00%

3.45%

2.65%

2.65%

5.00%

4.15%

4.15%

5.00%

7.13%

5.85%

8.00%

'

'

'

'

'

3.50%

5.50%

Noncash or Part Noncash Acquisition, Debt Assumed

12,178

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Issuance of Long-term Debt

'

'

'

'

'

'

'

750

750

475

'

'

600

1,000

700

625

800

'

625

650

'

'

'

'

'

'

5,000

251

217

'

'

'

Repayments of Debt

'

'

'

3,631

5,693

2,399

839

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500

450

500

88

1,186

2,286

'

'

'

'

'

Debt Instrument, Face Amount

'

'

$468

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$217

$251

'

'

Debt_Kinder_Morgan_GP_Inc_Pref

Debt Kinder Morgan G.P., Inc. Preferred Shares (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Jan. 15, 2014
			Kinder Morgan G.P., Inc. [Member]	Kinder Morgan G.P., Inc. [Member]	Subsequent Event [Member]
Debt Instrument [Line Items]	'	'	'	'	'
Preferred stock, shares outstanding (in shares)	0	0	100,000	'	'
Preferred Stock, Dividends Per Share, Declared	'	'	$42.10	$63.24	$10.57
Preferred Stock, Dividends, Per Share, Cash Paid	'	'	$42.17	$73.42	'

Debt_Maturities_of_Debt_Detail

Debt Maturities of Debt (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Kinder Morgan, Inc. [Member]	'
Debt Instrument [Line Items]	'
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$725
Long-term Debt, Maturities, Repayments of Principal in Year Two	1,788
Long-term Debt, Maturities, Repayments of Principal in Year Three	928
Long-term Debt, Maturities, Repayments of Principal in Year Four	798
Long-term Debt, Maturities, Repayments of Principal in Year Five	1,322
Long-term Debt, Maturities, Repayments of Principal after Year Five	4,485
Total debt outstanding	10,046
Kinder Morgan Energy Partners, L.P. [Member]	'
Debt Instrument [Line Items]	'
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	1,504
Long-term Debt, Maturities, Repayments of Principal in Year Two	300
Long-term Debt, Maturities, Repayments of Principal in Year Three	750
Long-term Debt, Maturities, Repayments of Principal in Year Four	1,255
Long-term Debt, Maturities, Repayments of Principal in Year Five	1,000
Long-term Debt, Maturities, Repayments of Principal after Year Five	15,105
Total debt outstanding	19,914
El Paso Pipeline Partners, L.P. [Member]	'
Debt Instrument [Line Items]	'
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	77
Long-term Debt, Maturities, Repayments of Principal in Year Two	756
Long-term Debt, Maturities, Repayments of Principal in Year Three	69
Long-term Debt, Maturities, Repayments of Principal in Year Four	505
Long-term Debt, Maturities, Repayments of Principal in Year Five	5
Long-term Debt, Maturities, Repayments of Principal after Year Five	2,844
Total debt outstanding	$4,256

Debt_Interest_Rates_Interest_R

Debt Interest Rates, Interest Rate Swaps and Contingent Debt (Details)	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]	'	'
Debt, Weighted Average Interest Rate	5.08%	4.92%

Debt_Subsequent_Event_Details

Debt Subsequent Event (Details) (USD $)	5 Months Ended								0 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	1-May-13	Apr. 30, 2013	Dec. 31, 2012	Jan. 17, 2014	Feb. 19, 2014	Feb. 19, 2014	Jan. 17, 2014	Feb. 21, 2014
		Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Subsequent Event [Member]	February 19, 2014 Debt Offering [Member]	February 19, 2014 Debt Offering [Member]	Liquidity Facility [Member]	Liquidity Facility [Member]
						Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Subsequent Event [Member]	Subsequent Event [Member]
							KMP 3.50% Senior Notes due March 1, 2021 [Member]	KMP 5.50% Senior Notes due March 1, 2044 [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]
Debt Instrument [Line Items]	'	'	'	'	'	'	'	'	'	'
Line of Credit Facility, Maximum Borrowing Capacity Increase	'	'	'	'	'	'	'	'	$1,000,000,000	'
Senior Notes	'	'	'	'	'	'	750,000,000	750,000,000	'	'
Debt Instrument, Interest Rate, Stated Percentage	'	'	'	'	'	'	3.50%	5.50%	'	'
Debt Instrument, Term	'3 years	'	'	'	'	'	'	'	'6 months	'
Line of Credit Facility, Current Borrowing Capacity	'	2,700,000,000	2,700,000,000	2,200,000,000	'	3,700,000,000	'	'	'	'
Line of Credit Facility, Amount Outstanding	'	$0	'	'	$0	'	'	'	'	$0

Kinder_Morgan_Inc_Equity_Inter

Kinder Morgan, Inc.- Equity Interests (Details) (USD $)

0 Months Ended

3 Months Ended

11 Months Ended

12 Months Ended

1 Months Ended

10 Months Ended

12 Months Ended

10 Months Ended

12 Months Ended

10 Months Ended

12 Months Ended

10 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

In Millions, except Share data, unless otherwise specified

Oct. 17, 2013

Jul. 18, 2013

23-May-12

Mar. 31, 2011

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 17, 2011

Dec. 31, 2011

Dec. 31, 2012

Feb. 17, 2011

Dec. 31, 2011

Dec. 31, 2012

Feb. 17, 2011

Dec. 31, 2011

Dec. 31, 2012

Feb. 17, 2011

Dec. 31, 2013

Dec. 31, 2012

25-May-12

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Mar. 31, 2011

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2011

Mar. 31, 2011

Jun. 30, 2013

Mar. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Jan. 15, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Class P [Member]

Class P [Member]

Class P [Member]

Class P [Member]

Class P [Member]

Class P [Member]

Common Class A [Member]

Common Class A [Member]

Common Class A [Member]

Common Class B [Member]

Common Class B [Member]

Common Class B [Member]

Common Class C [Member]

Common Class C [Member]

Common Class C [Member]

KMI's Acquisition of EP [Member]

KMI's Acquisition of EP [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

El Paso Corporation [Member]

KMI EP Capital Trust I, due 2028 [Member]

KMI EP Capital Trust I, due 2028 [Member]

KMI EP Capital Trust I, due 2028 [Member]

Related to activity from first 46 days of quarter [Member]

Sponsor investors [Member]

Conversion of Class A, B and C shares to P shares [Member]

Conversion of Class A, B and C shares to P shares [Member]

Related to prior quarter activity [Member]

Not part of stock repurchase program [Member]

Net of tax benefit [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Dividend Declared [Member]

KMI EP Capital Trust I, due 2028 [Member]

KMI EP Capital Trust I, due 2028 [Member]

Conversion of EP Trust I Preferred Securities [Member]

Conversion of EP Trust I Preferred Securities [Member]

Kinder Morgan, Inc. [Member]

Class P [Member]

Class P [Member]

Common Class A [Member]

Common Class B [Member]

Common Class C [Member]

Common Class A [Member]

Common Class B [Member]

Common Class C [Member]

Class P [Member]

Class P [Member]

Class P [Member]

Class P [Member]

Class P [Member]

Class P [Member]

Class P [Member]

Warrant [Member]

El Paso Corporation [Member]

Class of Stock [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock and or Warrant Repurchase Program, Authorized Amount

$250

$350

$250

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$38

'

'

'

'

'

'

'

'

'

Payments for Repurchase of Common Stock

'

'

'

'

'

172

'

'

172

'

'

71

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

94

'

'

'

'

'

'

'

Payments for Repurchase of Warrants

'

'

'

'

'

465

157

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock and or Warrant Repurchase Program Utilized

'

'

'

'

'

156

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at (in shares)

'

'

'

'

'

'

'

'

1,030,677,076

170,921,140

1,030,677,076

1,035,668,596

170,921,140

109,786,590

535,972,387

0

597,213,410

94,132,596

0

100,000,000

2,318,258

0

2,462,927

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares converted (in shares)

'

'

'

'

'

'

'

'

'

-61,241,023

'

-535,972,387

'

'

-61,241,023

-535,972,387

'

-5,867,404

-94,132,596

'

-144,669

-2,318,258

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

'

'

-562,521

'

'

'

Shares canceled (in shares)

'

'

'

'

'

'

'

'

'

-108,043

'

-2,049,615

'

'

0

0

'

0

0

'

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-2,000,000

-1,000,000

'

'

'

'

'

'

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period

'

'

'

'

0

-83,444

-102,033

'

'

1,570

89,154

107,553

'

'

0

0

'

0

0

'

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

77,442

'

'

'

'

Share issued (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

53

330,154,610

0

0

0

'

'

'

'

198,996,921

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Repurchased and Retired During Period, Shares

'

'

'

'

'

'

'

'

'

'

-5,175,055

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-3,000,000

'

'

'

'

'

'

Shares Issued During Period for Exercised Warrants

'

'

'

'

'

'

'

'

'

'

16,886

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share Settlement of Dissenter

'

'

'

'

'

128

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investor retained stock sold in overallotment to public offering

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Dividends Per Common Share Declared for the Period

'

'

'

'

$1.05

$1.60

$1.40

$1.05

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.41

'

'

'

'

'

Common Stock, Dividends, Per Share, Cash Paid

'

'

'

'

$0.74

$1.56

$1.34

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payments of Ordinary Dividends, Common Stock

'

'

'

246

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

105

'

'

'

205

'

'

'

'

'

'

'

'

'

'

Increase In Expense Due To One Time Special Bonus

'

'

'

$100

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$64

'

'

'

'

'

'

'

'

Debt Instrument, Convertible, Conversion Ratio

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class of Warrant or Right, Exercise Price of Warrants or Rights

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40

Class of Warrant or Right, Outstanding

'

'

'

'

0

347,933,107

439,809,442

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Warrants issued during the period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

81

504,598,883

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

118,377

859,796

'

Warrants Exercised, Number of Warrants

'

'

'

'

'

-21,208

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of warrants repurchased

'

'

'

'

'

-91,973,585

-65,649,237

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Sharebased_Compensation_and_Em2

Share-based Compensation and Employee Benefits Share-based Compensation (Details) (USD $)

11 Months Ended

12 Months Ended

10 Months Ended

12 Months Ended

10 Months Ended

12 Months Ended

10 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2012

Dec. 26, 2012

Feb. 17, 2011

Dec. 31, 2011

Dec. 31, 2012

Dec. 26, 2012

Feb. 17, 2011

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 17, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 10, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2011

Common Class C [Member]

Common Class C [Member]

Common Class C [Member]

Common Class C [Member]

Common Class B [Member]

Common Class B [Member]

Common Class B [Member]

Common Class B [Member]

Class P [Member]

Class P [Member]

Class P [Member]

Class P [Member]

Class P [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock Compensation Program [Member]

Restricted Stock Compensation Program [Member]

Restricted Stock Compensation Program [Member]

Restricted Stock Compensation Program [Member]

Restricted Stock Compensation Program [Member]

Restricted Stock Compensation Program [Member]

Restricted Stock Compensation Program [Member]

Restricted Stock Compensation Program [Member]

Restricted Stock Compensation Program [Member]

Restricted Stock Compensation Program [Member]

Kinder Morgan Energy Partners, L.P. Common Unit Compensation Plan for Non-Employee Directors [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan Energy Partners, L.P. Common Unit Compensation Plan for Non-Employee Directors [Member]

Kinder Morgan Energy Partners, L.P. Common Unit Compensation Plan for Non-Employee Directors [Member]

Minimum [Member]

Maximum [Member]

Restricted Stock [Member]

Year 2014 [Member]

Year 2015 [Member]

Year 2016 [Member]

Year 2017 [Member]

Year 2018 [Member]

Year 2019 [Member]

Year 2020 [Member]

Year 2021 [Member]

Year 2023 [Member]

Restricted Stock [Member]

Class P [Member]

Class P [Member]

Class P [Member]

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

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

Variable Vesting Periods [Member]

Variable Vesting Periods [Member]

Variable Vesting Periods [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Six Month Vesting Period [Member]

Variable Vesting Periods [Member]

Variable Vesting Periods [Member]

Variable Vesting Periods [Member]

Variable Vesting Periods [Member]

Variable Vesting Periods [Member]

Variable Vesting Periods [Member]

Variable Vesting Periods [Member]

Variable Vesting Periods [Member]

Variable Vesting Periods [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Restricted Stock or Unit Expense

'

'

'

'

'

'

'

'

'

'

'

'

'

$35,000,000

$14,000,000

$4,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Adjustments to Additional Paid in Capital, Share-based Compensation, Restricted Stock Unit or Restricted Stock Award, Requisite Service Period Recognition

'

'

'

2,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Employee Service Share-based Compensation, Nonvested Awards, Compensation Not yet Recognized, Share-based Awards Other than Options

'

177,000,000

49,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Kinder Morgan Inc. [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares Converted, Percent

'

'

'

'

'

'

100.00%

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Compensation Plan for Non-Employee Directors [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of directors

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

250,000

'

'

100,000

'

Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Net of Forfeitures

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,710

5,520

1,570

'

'

Stock Issued During Period, Value, Share-based Compensation, Net of Forfeitures

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

210,000

185,000

45,000

'

'

Restricted stock vested, percent

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period

'

'6 months

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'2 years

'7 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Restricted Stock and Long-term Incentive Retention Award Plan [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at (in shares)

'

'

'

'

'

2,318,258

'

2,462,927

'

94,132,596

'

100,000,000

'

1,035,668,596

170,921,140

'

109,786,590

6,382,885

2,154,022

1,163,090

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock, Value, Outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

239,000,000

69,000,000

33,000,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period, Shares, Restricted Stock Award, Gross

980,851

4,563,495

1,463,388

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period, Value, Restricted Stock Award, Gross

28,000,000

181,000,000

51,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares issued in exchange for cash awards

213,040

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair value of shares issued in exchange cash awards

6,000,000

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period

0

-83,444

-102,033

'

0

0

'

'

0

0

'

'

1,570

89,154

107,553

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value

0

-3,000,000

-3,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period, Shares, Restricted Stock Award, Forfeited

-30,801

-251,188

-370,423

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period, Value, Restricted Stock Award, Forfeitures

-1,000,000

-8,000,000

-12,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at (in shares)

'

'

'

'

2,318,258

0

'

2,462,927

94,132,596

0

'

100,000,000

170,921,140

1,030,677,076

1,035,668,596

170,921,140

109,786,590

6,382,885

2,154,022

1,163,090

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Intrinsic Value of Restricted Stock During Period

0

3,000,000

4,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,382,885

449,043

741,959

1,339,735

470,049

1,172,468

1,531,087

603,072

20,126

55,346

'

'

'

'

'

'

'

Share based compensation, adjustment to addition paid in capital

'

1,000,000

90,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share based compensation, amount vested, percent

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Allocated Share-based Compensation Expense

'

$2,000,000

$7,000,000

$13,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

TIme subject to forefeiture restrictions expire

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'6 months

'

Common units, units, issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,450

Noncontrolling_Interests_Detai

Noncontrolling Interests (Details) (USD $)

3 Months Ended

12 Months Ended

1 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

Jun. 30, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jun. 03, 2013

Dec. 31, 2012

Mar. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jun. 02, 2013

Mar. 31, 2012

Sep. 30, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Sep. 30, 2012

Dec. 31, 2013

31-May-13

3-May-13

1-May-13

Jun. 30, 2012

Dec. 31, 2013

Feb. 19, 2014

Feb. 14, 2014

Jan. 15, 2014

Feb. 14, 2014

Jan. 15, 2014

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Sep. 30, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jan. 15, 2014

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

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

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

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

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

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

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

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

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

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

Kinder Morgan Management, LLC [Member]

Kinder Morgan Management, LLC [Member]

Kinder Morgan Management, LLC [Member]

Other noncontrolling interests [Member]

Other noncontrolling interests [Member]

EPB [Member]

General Partner [Member]

General Partner [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

KMP Acquisiton of Copano Energy LLC [Member]

El Paso Midstream [Member]

Settlements subsequent to period [Member]

February 19, 2014 Public offering [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Dividend Declared [Member]

B Units [Member]

Common Unit [Member]

I-Units [Member]

Limited partner units [Member]

Limited partner units [Member]

General Partner and Limited Partner interests [Member]

Common Stock [Member]

Commercial Paper [Member]

common units, Class B units, and i-units and i-unit equivalents [Member]

Unitholder [Member]

General Partner [Member]

General Partner [Member]

Minimum [Member]

Minimum [Member]

First [Member]

First [Member]

First [Member]

First [Member]

First [Member]

Second [Member]

Second [Member]

Second [Member]

Second [Member]

Third [Member]

Third [Member]

Third [Member]

Third [Member]

Thereafter (after third) [Member]

Thereafter (after third) [Member]

Thereafter (after third) [Member]

Thereafter (after third) [Member]

Equity distribution agreement [Member]

Equity distribution agreement [Member]

Equity distribution agreement [Member]

Equity distribution agreement [Member]

Equity distribution agreement [Member]

Equity distribution agreement [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

Low [Member]

High [Member]

High [Member]

High [Member]

High [Member]

High [Member]

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

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

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

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

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

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

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

Common Units [Member]

Common Units [Member]

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

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

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

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

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

Kinder Morgan Management, LLC [Member]

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

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

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

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

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

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

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

Kinder Morgan Management, LLC [Member]

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

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

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

Unitholder [Member]

General Partner [Member]

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

Unitholder [Member]

Unitholder [Member]

General Partner [Member]

General Partner [Member]

Unitholder [Member]

Unitholder [Member]

General Partner [Member]

General Partner [Member]

Unitholder [Member]

Unitholder [Member]

General Partner [Member]

General Partner [Member]

Unitholder [Member]

Unitholder [Member]

General Partner [Member]

General Partner [Member]

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

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

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

Kinder Morgan Management, LLC [Member]

Kinder Morgan Management, LLC [Member]

Settlements subsequent to period [Member]

Minimum [Member]

First [Member]

Second [Member]

Second [Member]

Third [Member]

Third [Member]

Thereafter (after third) [Member]

Thereafter (after third) [Member]

First [Member]

Second [Member]

Second [Member]

Third [Member]

Third [Member]

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

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

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

KMP Acquisiton of Copano Energy LLC [Member]

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

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

EPB [Member]

EPB [Member]

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

EPB [Member]

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

EPB [Member]

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

EPB [Member]

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

EPB [Member]

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

EPB [Member]

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

EPB [Member]

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

EPB [Member]

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

EPB [Member]

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

EPB [Member]

EPB [Member]

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

EPB [Member]

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

EPB [Member]

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

EPB [Member]

EPB [Member]

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

EPB [Member]

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

EPB [Member]

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

Noncontrolling Interest [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Noncontrolling interests

'

$15,192,000,000

$10,234,000,000

'

'

$3,270,000,000

'

$7,642,000,000

$3,270,000,000

'

'

'

'

$4,122,000,000

$4,111,000,000

$3,142,000,000

$2,716,000,000

'

$286,000,000

$137,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investment Owned, Balance, Shares

'

'

'

'

'

'

'

43,000,000

'

'

'

'

'

90,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,000,000

22,000,000

16,000,000

'

'

'

16,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Ownership Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9.80%

41.00%

11.60%

13.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

2.00%

'

'

'

'

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Noncontrolling Interest, Shares or Equity Units Issued

'

'

'

'

'

'

4,600,000

'

'

'

'

'

8,165,000

'

'

'

'

'

'

'

'

'

'

43,371,000

'

'

3,792,000

198,110

7,935,000

'

'

'

'

'

'

'

'

'

'

'

4,485,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10,814,000

6,933,000

2,038,000

10,120,000

2,640,000

76,100

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Adjustments to Additional Paid in Capital, Reallocation of Noncontrolling Interest

'

5,059,000,000

2,112,000,000

'

'

349,000,000

385,000,000

'

'

'

'

'

272,000,000

'

'

'

'

'

'

'

'

'

'

0

'

'

0

16,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

900,000,000

560,000,000

85,000,000

727,000,000

210,000,000

6,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Value Of Units Available For Sale Under Fourth Amendment Of Equity Distribution Agreement With UBS

'

'

'

'

2,175,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Value of units available for sale under third amendment of equity distribution agreement with UBS

'

'

'

'

'

'

'

'

'

'

1,900,000,000

1,900,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Value of units available for sale under second amendment of equity distribution agreement with UBS

'

'

'

'

'

'

'

'

'

'

'

1,200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Consideration Transferred, Equity Interests Issued and Issuable

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,733,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Share Price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$86.08

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Value of units available for sale under equity distribution agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000,000

'

500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Issuance of Common Limited Partners Units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,000,000

2,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income Tax Effects Allocated Directly to Equity, Equity Transactions

'

93,000,000

38,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Adjustments to Additional Paid in Capital, Other

'

161,000,000

64,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution Made to Limited Partner, Distributions Declared, Per Unit

'

'

'

'

'

'

'

$5.33

$4.98

$4.61

'

'

'

$2.55

$1.74

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1.36

'

$0.65

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution Made to Limited Partner, Distributions Paid, Per Unit

'

'

'

'

'

'

'

$5.26

$4.85

$4.58

'

'

'

$2.51

$1.13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1.36

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash distributions paid to public unitholders

'

'

'

'

'

'

'

1,372,000,000

1,081,000,000

955,000,000

'

'

'

318,000,000

137,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

445,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock Dividends, Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,588,477

5,586,579

5,659,507

'

'

'

'

'

'

'

'

'

'

'

'

'

1,952,970

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Subsidiary Share Distribution, Shares Distributed to Parent

'

976,723

902,367

941,895

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share distribution per share outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.017841

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Noncontrolling Interest, Share Distribution Declared to Noncontrolling Interest Holders, Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,237,258

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent of available cash partnership requires to be distributed

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of days following each calendar quarter partnership agreement requires available cash to be distributed

'

'45 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash distribution from interim capital transactions

177,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Marginal percentage interest in distribution

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

98.00%

2.00%

'

98.00%

98.00%

2.00%

2.00%

85.00%

85.00%

15.00%

15.00%

75.00%

75.00%

25.00%

25.00%

50.00%

50.00%

50.00%

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Allocation of distribution from interim capital transactions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

98.00%

'

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Allocation of distribution from interim capital transactions, dollar cutoff adjusted for splits based on aggregate distribution since iniitial public offereing

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.75

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of all distributions levels when initial common unit price is fully recovered

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution of cash from operation allocation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

incentive distribution, amount reduced from waiveture in support of acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50,000,000

'

'

'

incentive distribution, amount reduced from waiveture

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11,000,000

27,000,000

28,000,000

25,000,000

Percent of incentive distribution from subsidiary allocated to income

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

excess percentage of aggregate value of cash distributions paid to El Paso Pipeline GP Compnay, L.L.C.

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

El Paso Pipeline Company L.L.C. general partner interest in EPB

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Economic interest, percent

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total quarterly distribution per unit target amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.15

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.29

$0.29

$0.15

$0.33

$0.18

$0.36

$0.23

$0.43

$0.33

$0.18

$0.36

$0.23

$0.43

'

'

'

'

Share Price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$78.32

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Sharebased_Compensation_and_Em3

Share-based Compensation and Employee Benefits Pensions and Other Postretirement Benefit Plans (Details) (USD $)

5 Months Ended

12 Months Ended

5 Months Ended

7 Months Ended

12 Months Ended

1 Months Ended

5 Months Ended

7 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

In Millions, unless otherwise specified

23-May-12

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

23-May-12

Jul. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Jan. 31, 2014

23-May-12

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Feb. 28, 2013

25-May-12

25-May-12

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Savings plan [Member]

Savings plan [Member]

Savings plan [Member]

United States Pension Plan of US Entity, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

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

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

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

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

El Paso LLC [Member]

El Paso LLC [Member]

El Paso LLC [Member]

Benefit obligation [Member]

Benefit obligation [Member]

Benefit obligation [Member]

Benefit obligation [Member]

Plan assets [Member]

Plan assets [Member]

Plan assets [Member]

Plan assets [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Alternative investments [Member]

Fixed Income Securities [Member]

Fixed Income Securities [Member]

Equity Securities [Member]

Equity Securities [Member]

Insurance Contract, Rights and Obligations [Member]

Insurance Contract, Rights and Obligations [Member]

Private Equity Funds [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

January 1, 2014 [Member]

2014 - 2018 [Member]

2019 - 2023 [Member]

Equity Securities [Member]

Equity Securities [Member]

Fixed Income Securities [Member]

Fixed Income Securities [Member]

Limited Partnership [Member]

Limited Partnership [Member]

Mutual funds investment type [Member]

Mutual funds investment type [Member]

Insurance Contract, Rights and Obligations [Member]

Insurance Contract, Rights and Obligations [Member]

Common collective trusts [Member]

Common collective trusts [Member]

Money Market Funds [Member]

Money Market Funds [Member]

Domestic Equity Securities [Member]

Domestic Equity Securities [Member]

Other Assets [Member]

Other Assets [Member]

Private Equity Funds [Member]

Private Equity Funds [Member]

Equity Trusts [Member]

Equity Trusts [Member]

Limited Partnership [Member]

Limited Partnership [Member]

Asset-backed Securities [Member]

Asset-backed Securities [Member]

US Government Agencies Debt Securities [Member]

US Government Agencies Debt Securities [Member]

Corporate Bond Securities [Member]

Corporate Bond Securities [Member]

Common and preferred stock [Member]

Common and preferred stock [Member]

Mutual funds investment type [Member]

Mutual funds investment type [Member]

Insurance Contract, Rights and Obligations [Member]

Insurance Contract, Rights and Obligations [Member]

Common collective trusts [Member]

Common collective trusts [Member]

Money Market Funds [Member]

Money Market Funds [Member]

Mutual funds [Member]

Mutual funds [Member]

Class P [Member]

Class P [Member]

Trans Mountain Pipeline [Member]

Trans Mountain Pipeline [Member]

Trans Mountain Pipeline [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Supplemental Executive Retirement Plan (SERP) [Member]

Defined Benefit Pension and Supplemental Executive retirement plan (SERP) [Member]

Retiree medical and life insurance [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Retiree medical and life insurance [Member]

Pension Plans, Defined Benefit [Member]

Retiree medical and life insurance [Member]

Pension Plans, Defined Benefit [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 2 [Member]

El Paso LLC [Member]

El Paso LLC [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Limited Partnership [Member]

Limited Partnership [Member]

Mutual funds investment type [Member]

Mutual funds investment type [Member]

Insurance Contract, Rights and Obligations [Member]

Insurance Contract, Rights and Obligations [Member]

Common collective trusts [Member]

Common collective trusts [Member]

Money Market Funds [Member]

Money Market Funds [Member]

Domestic Equity Securities [Member]

Domestic Equity Securities [Member]

Other Assets [Member]

Other Assets [Member]

Private Equity Funds [Member]

Private Equity Funds [Member]

Equity Trusts [Member]

Equity Trusts [Member]

Limited Partnership [Member]

Limited Partnership [Member]

Asset-backed Securities [Member]

Asset-backed Securities [Member]

US Government Agencies Debt Securities [Member]

US Government Agencies Debt Securities [Member]

Corporate Bond Securities [Member]

Corporate Bond Securities [Member]

Common and preferred stock [Member]

Common and preferred stock [Member]

Mutual funds investment type [Member]

Mutual funds investment type [Member]

Insurance Contract, Rights and Obligations [Member]

Insurance Contract, Rights and Obligations [Member]

Common collective trusts [Member]

Common collective trusts [Member]

Money Market Funds [Member]

Money Market Funds [Member]

Limited Partnership [Member]

Limited Partnership [Member]

Mutual funds investment type [Member]

Mutual funds investment type [Member]

Insurance Contract, Rights and Obligations [Member]

Insurance Contract, Rights and Obligations [Member]

Common collective trusts [Member]

Common collective trusts [Member]

Money Market Funds [Member]

Money Market Funds [Member]

Domestic Equity Securities [Member]

Domestic Equity Securities [Member]

Other Assets [Member]

Other Assets [Member]

Private Equity Funds [Member]

Equity Trusts [Member]

Equity Trusts [Member]

Limited Partnership [Member]

Limited Partnership [Member]

Asset-backed Securities [Member]

Asset-backed Securities [Member]

US Government Agencies Debt Securities [Member]

US Government Agencies Debt Securities [Member]

Corporate Bond Securities [Member]

Corporate Bond Securities [Member]

Common and preferred stock [Member]

Common and preferred stock [Member]

Mutual funds investment type [Member]

Mutual funds investment type [Member]

Insurance Contract, Rights and Obligations [Member]

Insurance Contract, Rights and Obligations [Member]

Common collective trusts [Member]

Common collective trusts [Member]

Money Market Funds [Member]

Money Market Funds [Member]

Limited Partnership [Member]

Limited Partnership [Member]

Mutual funds investment type [Member]

Mutual funds investment type [Member]

Insurance Contract, Rights and Obligations [Member]

Insurance Contract, Rights and Obligations [Member]

Common collective trusts [Member]

Common collective trusts [Member]

Money Market Funds [Member]

Money Market Funds [Member]

Domestic Equity Securities [Member]

Domestic Equity Securities [Member]

Other Assets [Member]

Other Assets [Member]

Private Equity Funds [Member]

Private Equity Funds [Member]

Equity Trusts [Member]

Equity Trusts [Member]

Limited Partnership [Member]

Limited Partnership [Member]

Asset-backed Securities [Member]

Asset-backed Securities [Member]

US Government Agencies Debt Securities [Member]

US Government Agencies Debt Securities [Member]

Corporate Bond Securities [Member]

Corporate Bond Securities [Member]

Common and preferred stock [Member]

Common and preferred stock [Member]

Mutual funds investment type [Member]

Mutual funds investment type [Member]

Insurance Contract, Rights and Obligations [Member]

Insurance Contract, Rights and Obligations [Member]

Common collective trusts [Member]

Common collective trusts [Member]

Money Market Funds [Member]

Money Market Funds [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Pension Plans, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Other Postretirement Benefit Plan, Defined Benefit [Member]

Savings Plan [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Contribution Plan, Employer Matching Contribution, Percent

'

'

'

5.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Contribution Plan, Cost Recognized

'

'

'

$40

$32

$24

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Percent of Employees Covered

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pension Plans [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan,Vesting Period

'

'

'

'

'

'

'3 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Benefit obligations settled upton plan termination

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

28

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Postretirement Benefit Plans [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchase of Medical Coverage through Medicare Exchange Participant, Age

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

65

'

'

Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Benefit Obligation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,516

2,773

'

'

'

2,407

606

720

91

2,792

343

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Service Cost

'

'

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25

18

13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

0

25

18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Interest Cost

'

'

'

'

'

'

'

'

'

'

'

23

18

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

92

67

17

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

23

18

92

67

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Actuarial Gain (Loss)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-38

40

-132

178

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Benefits Paid

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-54

-37

-239

-58

-54

-37

-239

-58

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Contributions by Plan Participants

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11

7

0

0

11

7

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Gross Prescription Drug Subsidy Receipts Received

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6

1

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Business Combinations and Acquisitions, Benefit Obligation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

606

0

2,407

0

273

0

1,949

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Plan Amendments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-37

-5

25

-17

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Curtailments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

-1

0

-146

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Benefit Obligation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,516

2,773

'

'

'

2,407

606

631

720

2,563

2,792

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Fair Value of Plan Assets

'

'

'

'

'

'

'

'

'

341

'

341

'

'

'

'

'

'

'

164

0

72

8

46

44

85

277

0

12

13

0

2,333

'

'

2,240

'

'

13

15

9

9

235

53

28

24

29

25

120

99

220

111

498

812

226

306

15

14

765

'

0

7

'

'

'

'

'

'

'

'

'

'

60

55

'

1,949

273

'

'

'

'

341

55

2,240

258

177

11

92

0

72

0

0

0

0

0

0

11

13

0

590

813

0

0

0

0

0

0

0

0

0

0

0

0

0

0

498

812

92

0

0

0

0

0

0

1

157

286

72

0

0

8

0

0

85

277

0

1

0

0

1,691

1,340

13

15

0

235

53

0

0

29

25

120

99

220

111

0

0

134

266

0

0

940

765

0

6

44

42

0

0

0

0

46

44

0

0

0

0

0

0

87

27

0

0

9

9

0

0

24

4

0

0

0

0

0

0

0

0

40

0

14

14

0

0

0

0

'

'

'

'

'

44

42

0

'

'

'

'

'

'

Defined Benefit Plan, Actual Return on Plan Assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40

24

254

203

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Contributions by Employer

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

42

19

78

32

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Settlements, Plan Assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

0

0

-144

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Fair Value of Plan Assets

'

'

'

'

'

'

'

380

'

'

341

380

341

'

'

'

'

'

'

164

0

72

8

46

44

85

277

0

12

13

0

'

'

2,240

2,333

2,240

'

13

15

9

9

235

53

28

24

29

25

120

99

220

111

498

812

226

306

15

14

940

765

0

7

'

'

'

'

'

'

'

'

'

'

60

55

'

1,949

273

'

'

'

'

380

341

2,333

2,240

177

11

92

0

72

0

0

0

0

0

0

11

13

0

590

813

0

0

0

0

0

0

0

0

0

0

0

0

0

0

498

812

92

0

0

0

0

0

0

1

157

286

72

0

0

8

0

0

85

277

0

1

0

0

1,691

1,340

13

15

0

235

53

0

0

29

25

120

99

220

111

0

0

134

266

0

0

940

765

0

6

46

44

0

0

0

0

46

44

0

0

0

0

0

0

52

87

0

0

9

9

0

0

28

24

0

0

0

0

0

0

0

0

0

40

15

14

0

0

0

0

'

'

'

'

'

46

44

0

'

'

'

'

'

'

Defined Benefit Plan, Funded Status of Plan

'

'

'

'

'

'

'

-251

'

'

-379

-251

-379

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-552

-230

-552

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-251

-379

-230

-552

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Expected Return on Plan Assets

'

'

'

'

'

'

'

'

'

'

'

-22

-15

-5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-175

-110

-22

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Components of Funded Status [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Assets for Plan Benefits, Noncurrent

'

'

'

'

'

'

'

224

'

'

135

224

135

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pension and Other Postretirement Defined Benefit Plans, Current Liabilities

'

'

'

'

'

'

'

-32

'

'

-33

-32

-33

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-28

0

-28

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent

'

'

'

'

'

'

'

-443

'

'

-481

-443

-481

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-524

-230

-524

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Components of Accumulated Other Comprehensive Income (Loss) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Gains (Losses), before Tax

'

'

'

'

'

'

'

-17

'

'

-70

-17

-70

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-218

-10

-218

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax

'

'

'

'

'

'

'

21

'

'

4

21

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20

-5

20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax

'

'

'

'

'

'

'

4

'

'

-66

4

-66

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-198

-15

-198

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Gains (Losses), before Tax

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unrecognized net actuarial loss

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unrecognized prior service credit

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

534

569

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Plan Assets [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Actual Plan Asset Allocations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

70.00%

65.00%

30.00%

35.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.00%

30.00%

45.00%

70.00%

50.00%

'

'

'

'

'

'

'

'

'

Pension Assets At Fair Value Classified in each Level [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent of funds invested in fixed income securities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

36.00%

59.00%

'

'

60.00%

28.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent of funds invested in equity securities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

62.00%

36.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent of funds invested in short-term securities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.00%

5.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent of fund invested in equity and other investments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40.00%

72.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of plan assets invested in parent company common stock

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

229

133

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Changes in Pension and OPEB Assets [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Transfers Between Measurement Levels

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

'

'

'

'

0

54

'

'

0

0

'

'

0

16

'

'

'

'

'

'

'

'

0

38

0

0

'

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

Gain (Loss) on Investments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

7

'

'

'

'

'

'

'

'

'

'

'

'

4

2

'

'

1

0

'

'

3

0

'

'

'

'

'

'

'

'

0

2

0

0

'

'

'

'

'

'

'

'

'

0

7

'

'

'

'

'

'

'

Defined Benefit Plan, Purchases, Sales, and Settlements

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

-5

'

'

'

'

'

'

'

'

'

'

'

'

-39

4

'

'

-1

0

'

'

1

4

'

'

'

'

'

'

'

'

-40

0

1

0

'

'

'

'

'

'

'

'

'

2

-5

'

'

'

'

'

'

'

Expected Payment of Future Benefits and Employer Contributions [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Expected Future Benefit Payments, 2014

'

'

'

'

'

'

'

52

'

'

'

52

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

191

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Expected Future Benefit Payments, 2015

'

'

'

'

'

'

'

51

'

'

'

51

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

192

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Expected Future Benefit Payments, 2016

'

'

'

'

'

'

'

50

'

'

'

50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

195

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Expected Future Benefit Payments, 2017

'

'

'

'

'

'

'

49

'

'

'

49

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

195

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Expected Future Benefit Payments, 2018

'

'

'

'

'

'

'

48

'

'

'

48

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

194

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Expected Future Benefit Payments, 2019-2023

'

'

'

'

'

'

'

223

'

'

'

223

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

964

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Medicare prescription drug, improvement and modernization act, annual subsidy

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3

13

Defined Benefit Plan, Expected Future Benefit Payments, Remainder of Fiscal Year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

32

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Actuarial Assumptions and Sensitivity Analysis [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate

'

'

'

'

'

'

'

4.34%

'

'

3.34%

4.34%

3.34%

4.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.40%

4.45%

3.40%

4.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.00%

3.50%

3.00%

3.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate

'

'

'

'

'

'

'

4.00%

'

3.34%

'

3.62%

4.11%

5.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4.50%

4.03%

3.40%

4.22%

5.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets

'

'

'

'

'

'

'

'

8.90%

'

7.72%

7.35%

8.21%

8.90%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8.90%

8.11%

8.00%

8.44%

8.90%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.00%

3.50%

3.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

discount rate, prior to aquisition

'

'

'

'

'

'

'

'

4.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

discount rate, post aquistion through year end

4.01%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

After-tax expected return on plan assets, used to determine benefit cost

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

24.00%

22.00%

'

'

'

Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6.57%

'

'

'

'

'

Per capita cost of covered health care benefits rate by year 2019

'

5.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components

'

2

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation

'

45

52

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components

'

-1

-1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation

'

-39

-45

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Components of Net Benefit Cost and Other Amounts Recognized in Other Comprehensive Income [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Amortization of Prior Service Cost (Credit)

'

'

'

'

'

'

'

'

'

'

'

-1

-1

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

-1

-1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Future Amortization of Gain (Loss)

'

'

'

'

'

'

'

'

'

'

'

3

4

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

10

7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Recognized Net Gain (Loss) Due to Settlements and Curtailments

'

'

'

'

'

'

'

'

'

'

'

0

-1

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-3

-2

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Net Periodic Benefit Cost

'

'

'

'

'

'

'

'

'

'

'

3

5

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-61

-18

14

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11

11

7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other comprehensive income defined benefit plan net loss gain arising during period

'

'

'

'

'

'

'

'

'

'

'

-50

25

13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-211

85

46

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Net Prior Service Cost (Credit) Arising During Period, before Tax

'

'

'

'

'

'

'

'

'

'

'

-18

-4

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25

-17

-6

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other comprehensive income defined benefit plan amortization of net actuarial gain loss

'

'

'

'

'

'

'

'

'

'

'

-3

-5

-4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3

-10

-7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax

'

'

'

'

'

'

'

'

'

'

'

1

1

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

1

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Gain (Loss), before Tax

'

'

'

'

'

'

'

'

'

'

'

-70

17

9

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-183

59

34

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Net benefit cost and other comprehensive income (loss) recognized

'

'

'

'

'

'

'

'

'

'

'

($67)

$22

$12

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

($244)

$41

$48

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Sharebased_Compensation_and_Em4

Share-based Compensation and Employee Benefits Other Plans (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Kinder Morgan Energy Partners, L.P. [Member] | Trans Mountain Pipeline [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Defined Benefit Plan, Net Periodic Benefit Cost	$11	$11	$7
Defined Benefit Plan, Net Periodic Benefit Cost, next twelve months	11	'	'
Expected Defined Benefit Pension and OPEB contribution, next twelve months	10	'	'
Kinder Morgan Energy Partners, L.P. [Domain]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Multi-employer pension plan expense	$11	$11	$12

Related_Party_Transactions_Aff

Related Party Transactions Affiliated Balances (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
ASSETS	'	'
Assets held for sale(a)	$0	$298
Other current assets	552	416
Total Assets	75,185	68,245
Liabilities [Abstract]	'	'
Total Liabilities	46,900	44,145
Affiliated Entity [Member]	'	'
ASSETS	'	'
Total Assets	69	201
Liabilities [Abstract]	'	'
Total Liabilities	184	189
Accounts Receivable [Member] | Affiliated Entity [Member]	'	'
ASSETS	'	'
Accounts receivable, net	19	25
Assets Held-for-sale [Member] | Affiliated Entity [Member]	'	'
ASSETS	'	'
Assets held for sale(a)	0	114
Other Current Assets [Member] | Affiliated Entity [Member]	'	'
ASSETS	'	'
Other current assets	3	14
Deferred charges and other assets [Member] | Affiliated Entity [Member]	'	'
ASSETS	'	'
Deferred charges and other assets	47	48
Short-term Debt [Member] | KMP and EPB [Member]	'	'
Liabilities [Abstract]	'	'
Current portion of debt – KMP and EPB(b)	6	5
Accounts Payable [Member] | Affiliated Entity [Member]	'	'
Liabilities [Abstract]	'	'
Accounts payable	9	11
Long-term Debt [Member] | KMP and EPB [Member]	'	'
Liabilities [Abstract]	'	'
Long-term debt - Outstanding - KMP and EPB(b)	$169	$173

Related_Party_Transactions_Not1

Related Party Transactions Notes Receivable (Details)

Dec. 31, 2013

Dec. 31, 2013

Mar. 14, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Feb. 04, 2014

Dec. 31, 2013

Mar. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

25-May-12

Feb. 04, 2014

Feb. 04, 2014

In Millions, unless otherwise specified

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

Express Pipeline System [Member]

Express Pipeline System [Member]

Corporation [Member]

Corporation [Member]

Term Loan Agreement [Member]

Term Loan Agreement [Member]

Term Loan Agreement [Member]

KMI's Acquisition of El Paso Corporation [Member]

Domestic Corporate Debt Securities [Member]

Domestic Corporate Debt Securities [Member]

Domestic Corporate Debt Securities [Member]

Domestic Corporate Debt Securities [Member]

Minimum [Member]

Maximum [Member]

Plantation Pipe Line Company [Member]

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

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

Spectra Energy Corp. [Member]

Spectra Energy Corp. [Member]

Exxon Mobil Corporation [Member]

Exxon Mobil Corporation [Member]

Energy Transfers Partners LP [Member]

Gulf LNG Holdings Group LLC [Member]

KMI's Acquisition of El Paso Corporation [Member]

KMI's Acquisition of El Paso Corporation [Member]

KMI's Acquisition of El Paso Corporation [Member]

KMI's Acquisition of El Paso Corporation [Member]

Term Loan Agreement [Member]

Term Loan Agreement [Member]

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

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

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

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

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

Equity Securities [Member]

Gulf LNG Holdings Group LLC [Member]

Gulf LNG Holdings Group LLC [Member]

Gulf LNG Holdings Group LLC [Member]

Gulf LNG Holdings Group LLC [Member]

Energy Transfers Partners LP [Member]

Energy Transfers Partners LP [Member]

Express Pipeline System [Member]

Express Pipeline System [Member]

Plantation Pipe Line Company [Member]

Plantation Pipe Line Company [Member]

Midcontinent Express Pipeline LLC [Member]

El Paso LLC [Member]

El Paso LLC [Member]

El Paso LLC [Member]

El Paso LLC [Member]

El Paso LLC [Member]

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

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

Canada, Dollars

Canada, Dollars

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Midcontinent Express Pipeline LLC [Member]

Midcontinent Express Pipeline LLC [Member]

USD ($)

CAD

USD ($)

USD ($)

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Ownership Percentage

51.17%

33.33%

33.33%

'

'

'

'

'

50.00%

'

'

'

'

'

'

Notes Receivable, Related Parties

'

'

'

$114

114

$48

$49

$0

'

'

$10

'

$85

$2

$40

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

12.00%

12.00%

4.25%

'

'

'

'

'

12.00%

'

'

'

Notes Receivable, Balloon Payment, Related Parties

'

'

'

'

'

45

'

'

'

'

'

'

'

'

'

Accounts Receivable, Related Parties, Current

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

Proceeds from Related Party Debt

'

'

'

'

'

'

'

'

'

$10

$75

'

'

'

'

Debt Instrument, Basis Spread on Variable Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.59%

Related_Party_Transactions_Sub

Related Party Transactions Subsequent Event (Details) (Midcontinent Express Pipeline LLC [Member], Kinder Morgan Energy Partners, L.P. [Member], Energy Transfers Partners LP [Member], Term Loan Agreement [Member], USD $)	0 Months Ended
In Millions, unless otherwise specified	Feb. 04, 2014
Subsequent Event [Line Items]	'
Notes Receivable, Related Parties	$0
Minimum [Member]	'
Subsequent Event [Line Items]	'
Notes Receivable, Related Parties	2
Maximum [Member]	'
Subsequent Event [Line Items]	'
Notes Receivable, Related Parties	$40
Number of Loan Agreement 's renewal provisions	1
Renewal Term	'1 year
Debt Instrument, Basis Spread on Variable Rate	1.59%

Commitments_and_Contingent_Lia2

Commitments and Contingent Liabilities Leases (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Leased Assets [Line Items]	'	'	'
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$70	'	'
Operating Leases, Future Minimum Payments, Due in Two Years	59	'	'
Operating Leases, Future Minimum Payments, Due in Three Years	50	'	'
Operating Leases, Future Minimum Payments, Due in Four Years	39	'	'
Operating Leases, Future Minimum Payments, Due in Five Years	37	'	'
Operating Leases, Future Minimum Payments, Due Thereafter	177	'	'
Operating Leases, Future Minimum Payments Due	432	'	'
Operating Leases, Rent Expense	126	94	146
Increase In Rent Expense Related To Right Of Way Liabilities	'	'	$70
Minimum [Member]	'	'	'
Operating Leased Assets [Line Items]	'	'	'
Lessee Leasing Arrangements, Operating Leases, Term of Contract	'1 year	'	'
Maximum [Member]	'	'	'
Operating Leased Assets [Line Items]	'	'	'
Lessee Leasing Arrangements, Operating Leases, Term of Contract	'40 years	'	'

Commitments_and_Contingent_Lia3

Commitments and Contingent Liabilities Commitments (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Oil and Gas Delivery Commitments and Contracts [Line Items]	'
Share of capital expenditures including ancillary facilities	$800
Elba Liquification Company LLC [Member]	'
Oil and Gas Delivery Commitments and Contracts [Line Items]	'
Equity Method Investment, Ownership Percentage	51.00%

Commitments_and_Contingent_Lia4

Commitments and Contingent Liabilities Contingent Debt (Details) (Letter of Credit [Member], USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Letter of Credit [Member]	'	'
Guarantor Obligations [Line Items]	'	'
Guarantor Obligations, Maximum Exposure, Undiscounted	$74	$86

Commitments_and_Contingent_Lia5

Commitments and Contingent Liabilities Contingent Lease Liabilities (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Guarantor Obligations [Line Items]	'
Range of annual lease payments guaranteed, low	$27
Range of annual lease payments guaranteed, high	$38

Commitments_and_Contingent_Lia6

Commitments and Contingent Liabilities KMI Guarantee of KMP and EPB Debt (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
El Paso Pipeline Partners, L.P. [Member]	'
Guarantor Obligations [Line Items]	'
Guarantor Obligations, Maximum Exposure, Undiscounted	$470
Kinder Morgan Energy Partners, L.P. [Member]	'
Guarantor Obligations [Line Items]	'
Guarantor Obligations, Maximum Exposure, Undiscounted	5,900
Elba Liquification Company LLC [Member]	'
Guarantor Obligations [Line Items]	'
Equity Method Investment, Ownership Percentage	51.00%
Cortez Pipeline Company [Member]	'
Guarantor Obligations [Line Items]	'
Equity Method Investment, Ownership Percentage	50.00%
KMI Asset Drop Down [Member] | Kinder Morgan Energy Partners, L.P. [Member]	'
Guarantor Obligations [Line Items]	'
Guarantor Obligations, Maximum Exposure, Undiscounted	$5,200

Commitments_and_Contingent_Lia7

Commitments and Contingent Liabilities Guarantees and Indemnifications (Details) (El Paso LLC [Member], USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
El Paso LLC [Member]	'
Guarantor Obligations [Line Items]	'
Guarantor Obligations, Maximum Exposure, Undiscounted	$814

Energy_Commodity_Price_Risk_Ma

Energy Commodity Price Risk Managment (Details) (Forward Contracts [Member])	Dec. 31, 2013
Crude Oil Fixed Price [Member] | Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-22,600,000
Crude Oil Fixed Price [Member] | Not Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-900,000
Natural Gas Fixed Price [Member] | Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-19,800,000,000
Natural Gas Fixed Price [Member] | Not Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-17,300,000,000
Natural Gas Basis [Member] | Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-18,900,000,000
Natural Gas Basis [Member] | Not Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-8,200,000,000
Natural Gas Liquids Fixed Price [Member] | Not Designated as Hedging Instrument [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	-1,100,000

Interest_Rate_Risk_Managment_D

Interest Rate Risk Managment (Details) (USD $)

1 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Jun. 30, 2013

Dec. 31, 2013

Aug. 31, 2013

Dec. 31, 2013

Aug. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Aug. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Jun. 30, 2013

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

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

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

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

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

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

KMP 5% Senior Notes due December 15, 2013 [Member]

fixed-to-variable interest rate swap agreement [Member]

fixed-to-variable interest rate swap agreement [Member]

fixed-to-variable interest rate swap agreement [Member]

fixed-to-variable interest rate swap agreement [Member]

fixed-to-variable interest rate swap agreement [Member]

Termination of Swap Agreement [Member]

Termination of Swap Agreement [Member]

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

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

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

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

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

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

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

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

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

fixed-to-variable interest rate swap agreement [Member]

fixed-to-variable interest rate swap agreement [Member]

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

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

Derivative [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Notional Amount

'

'

'

'

'

'

'

$725

$725

$4,675

$500

$5,525

$375

$975

Interest rate, stated percentage

'

'

2.65%

2.65%

4.15%

4.15%

5.00%

'

'

'

'

'

'

'

Proceeds from the early termination of swap agreement

'

$96

'

'

'

'

'

'

'

'

'

'

'

'

Number of Fixed-to-Variable Interest Rate Swap Agreements Terminated

3

3

'

'

'

'

'

'

'

'

'

'

'

'

Risk_Management_Fair_Value_of_

Risk Management Fair Value of Derivative Contracts (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	$357	$772
Liability derivatives	-311	-213
Designated as Hedging Instrument [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	335	747
Liability derivatives	-179	-30
Designated as Hedging Instrument [Member] | Commodity Contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	76	82
Liability derivatives	-63	-29
Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	18	42
Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Liability derivatives	-33	-18
Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	58	40
Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Non Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Liability derivatives	-30	-11
Designated as Hedging Instrument [Member] | Interest Rate Swap [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	259	665
Liability derivatives	-116	-1
Not Designated as Hedging Instrument [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	22	25
Liability derivatives	-132	-183
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	4	4
Liability derivatives	-5	-4
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	4	4
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Liability derivatives	-5	-3
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	0	0
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Non Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Liability derivatives	0	-1
Not Designated as Hedging Instrument [Member] | Power Derivative Contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	18	21
Liability derivatives	-127	-179
Not Designated as Hedging Instrument [Member] | Power Derivative Contract [Member] | Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	7	8
Not Designated as Hedging Instrument [Member] | Power Derivative Contract [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Liability derivatives	-54	-59
Not Designated as Hedging Instrument [Member] | Power Derivative Contract [Member] | Other Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	11	13
Not Designated as Hedging Instrument [Member] | Power Derivative Contract [Member] | Non Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Liability derivatives	-73	-120
Fair Value Hedging [Member] | Designated as Hedging Instrument [Member] | Interest Rate Swap [Member] | Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	87	9
Fair Value Hedging [Member] | Designated as Hedging Instrument [Member] | Interest Rate Swap [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Liability derivatives	0	0
Fair Value Hedging [Member] | Designated as Hedging Instrument [Member] | Interest Rate Swap [Member] | Other Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Asset derivatives	172	656
Fair Value Hedging [Member] | Designated as Hedging Instrument [Member] | Interest Rate Swap [Member] | Non Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Liability derivatives	-116	-1
Natural gas, crude and NGL derivative contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	80	86
Balance Sheet, Derivative Asset Reduction, Gross	0	0
Derivative Asset	80	86
Asset derivatives	36	69
Power Derivative Contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	18	21
Balance Sheet, Derivative Asset Reduction, Gross	0	0
Derivative Asset	18	21
Asset derivatives	0	0
Interest Rate Swap [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	259	665
Balance Sheet, Derivative Asset Reduction, Gross	0	0
Derivative Asset	259	665
Asset derivatives	231	665
Not Offset on Balance Sheet [Member] | Natural gas, crude and NGL derivative contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Financial Instruments, Asset	-44	-17
Derivative, Collateral, Obligation to Return Cash	0	0
Not Offset on Balance Sheet [Member] | Power Derivative Contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Financial Instruments, Asset	-18	-21
Derivative, Collateral, Obligation to Return Cash	0	0
Not Offset on Balance Sheet [Member] | Interest Rate Swap [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Financial Instruments, Asset	-28	0
Derivative, Collateral, Obligation to Return Cash	0	0
Natural gas, crude and NGL derivative contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	-68	-33
Balance Sheet, Derivative Liability Reduction, Gross	0	0
Derivative Liabilities Presented in Balance Sheet	-68	-33
Natural gas, crude and NGL derivative contracts [Member] | Not Offset on Balance Sheet [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability	44	17
Derivative, Collateral, Right to Reclaim Cash	17	5
Liability derivatives	-7	-11
Power Derivative Contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	-127	-179
Balance Sheet, Derivative Liability Reduction, Gross	0	0
Derivative Liabilities Presented in Balance Sheet	-127	-179
Power Derivative Contract [Member] | Not Offset on Balance Sheet [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability	18	21
Derivative, Collateral, Right to Reclaim Cash	0	0
Liability derivatives	-109	-158
Interest Rate Swap [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	-116	-1
Balance Sheet, Derivative Liability Reduction, Gross	0	0
Derivative Liabilities Presented in Balance Sheet	-116	-1
Interest Rate Swap [Member] | Not Offset on Balance Sheet [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability	28	0
Derivative, Collateral, Right to Reclaim Cash	0	0
Liability derivatives	-88	-1
Kinder Morgan Energy Partners, L.P. [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Cash Margin Deposits	$17	$5

Risk_Management_Debt_Fair_Valu

Risk Management Debt Fair Value Adjustments (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'	'
Increase (decrease) in debt fair value adjustment related to purchase accounting	$1,379	$1,470
Amount the adjustment to fair value of debt was increased by related to the fair value of interest rate swaps	143	664
Deferred Gain (Loss) on Discontinuation of Interest Rate Fair Value Hedge	517	490
Amount the fair value of debt adjustment was decreased by related to unamortized debt discounts	$62	$33
Amortization Period of Deferred Gain (Loss) on Discontinuation of Interest Rate Fair Value Hedge	'16 years	'

Effect_of_Derivative_Contracts

Effect of Derivative Contracts on the Income Statement (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Other Comprehensive Income (Loss) [Member] | Cash Flow Hedging [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	($38)	$82	$13
Revenues-Product sales and other [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	10	4	'
Commodity Contract [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Loss to be reclassified within twelve months	1	'	'
Commodity Contract [Member] | Cash Flow Hedging [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	-11	8	-184
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	3	-11	5
Commodity Contract [Member] | Other Comprehensive Income (Loss) [Member] | Cash Flow Hedging [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	-45	87	13
Commodity Contract [Member] | Revenues Natural Gas Sales [Member] | Cash Flow Hedging [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	0	4	2
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	0	0	0
Commodity Contract [Member] | Gas purchases and other costs of sales [Member] | Cash Flow Hedging [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	0	17	7
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	0	0	0
Commodity Contract [Member] | Revenues-Product sales and other [Member] | Cash Flow Hedging [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	-13	-15	-193
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	3	-11	5
Commodity Contract [Member] | Interest Expense [Member] | Cash Flow Hedging [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	2	2	0
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	0	0	0
Commodity Contract [Member] | Interest Expense [Member] | Fair Value Hedging [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Derivative Instruments, Gain (Loss) Recognized in Income, Net	425	-55	-545
Interest Rate Swap [Member] | Other Comprehensive Income (Loss) [Member] | Cash Flow Hedging [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	7	-5	0
Interest Rate Swap [Member] | Interest Expense [Member] | Fair Value Hedging [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Derivative Instruments, Gain (Loss) Recognized in Income, Net	($425)	$55	$545

Credit_Risks_Details

Credit Risks (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013
	Kinder Morgan, Inc. [Member]	Kinder Morgan, Inc. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Kinder Morgan Energy Partners, L.P. [Member]	Commodity [Member]	Commodity [Member]	Commodity [Member]
		One or two notch credit downgrade [Member]	notches	One notch credit downgrade [Member]	Two notch credit downgrade [Member]	Kinder Morgan, Inc. [Member]	Kinder Morgan, Inc. [Member]	Kinder Morgan Energy Partners, L.P. [Member]
Credit Derivatives [Line Items]	'	'	'	'	'	'	'	'
Letters of Credit Outstanding, Amount	$80,000,000	'	$203,000,000	'	'	$167,000,000	$300,000,000	$0
Additional Collateral, Aggregate Fair Value	'	$0	'	$0	$8,000,000	'	'	'
Number of Credit Rating Notches	'	'	2	'	'	'	'	'

Risk_Management_Risk_Managemen

Risk Management Risk Management Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Derivative [Line Items]	'	'	'
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	($3)	$7	'
Accumulated Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Net of Tax	2	51	'
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	-23	-176	'
Accumulated other comprehensive loss	-24	-118	'
Other Comprehensive Income Unrealized Gain Loss On Derivatives Arising During Period Net Of Tax Portion Attributable To Parent	-14	32	6
Change in fair value of derivatives utilized for hedging purposes (net of tax benefit (expense) of $10, $(26) and $(6), respectively)	4	-5	67
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Reclassification Adjustment from AOCI, Realized upon Sale or Liquidation, Net of Tax	0	'	'
Other Comprehensive Income Loss Reclassification Adjustment From AOCI Pension And Other Postretiremen tBenefit Plans Net Of Tax Portion Attributable To Parent	2	9	7
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax, Portion Attributable to Parent	-10	'	'
Foreign currency translation adjustments (net of tax benefit (expense) of $22, $(8), and $8, respectively)	-49	14	-14
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, before Reclassification Adjustments, Net of Tax	-151	53	45
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	-153	'	'
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	94	-3	21
OCI before Reclassifications [Member]	'	'	'
Derivative [Line Items]	'	'	'
Other comprehensive income (loss) before reclassifications, net of tax, portion attributable to parent	88	'	'
Amounts reclassified from AOCI [Member]	'	'	'
Derivative [Line Items]	'	'	'
Other comprehensive income reclassified from accumulated other comprehensive income, net of tax, portion attributable to parent	$6	'	'

Fair_Value_of_Derivative_Contr

Fair Value of Derivative Contracts (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	1-May-13	Dec. 31, 2011
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	$357	$772	'	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Liability Net, Value	-110	-155	18	7
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Liability Net, Gain (Loss) Included in Earnings	-5	-4	'	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Liability Net, Gain (Loss) Included in Other Comprehensive Income (Loss)	-1	-1	'	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Liability Net, Purchases	17	-194	'	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Liability Net, Settlements	34	37	'	'
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss)	-8	-2	'	'
Estimate of Fair Value [Member] | Commodity Contract [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Asset fair value, derivative	98	107	'	'
Liability fair value, derivative	-195	-212	'	'
Estimate of Fair Value [Member] | Interest Rate Swap [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Asset fair value, derivative	259	665	'	'
Liability fair value, derivative	-116	-1	'	'
Quoted prices in active markets for identical assets (Level 1) [Member] | Commodity Contract [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Asset fair value, derivative	4	3	'	'
Liability fair value, derivative	-6	-3	'	'
Quoted prices in active markets for identical assets (Level 1) [Member] | Interest Rate Swap [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Asset fair value, derivative	0	0	'	'
Liability fair value, derivative	0	0	'	'
Significant other observable inputs (Level 2) [Member] | Commodity Contract [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Asset fair value, derivative	46	76	'	'
Liability fair value, derivative	-31	-26	'	'
Significant other observable inputs (Level 2) [Member] | Interest Rate Swap [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Asset fair value, derivative	259	665	'	'
Liability fair value, derivative	-116	-1	'	'
Significant unobservable inputs (Level 3) [Member] | Commodity Contract [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Asset fair value, derivative	48	28	'	'
Liability fair value, derivative	-158	-183	'	'
Significant unobservable inputs (Level 3) [Member] | Interest Rate Swap [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Asset fair value, derivative	0	0	'	'
Liability fair value, derivative	0	0	'	'
El Paso Corporation [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Liability Net, Purchases	'	-197	'	'
Minimum [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Price of Mega Watts Per Hour	'	28.5	'	'
Maximum [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Price of Mega Watts Per Hour	'	57.32	'	'
Designated as Hedging Instrument [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	335	747	'	'
Designated as Hedging Instrument [Member] | Commodity Contract [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	76	82	'	'
Designated as Hedging Instrument [Member] | Interest Rate Swap [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	259	665	'	'
Other Current Assets [Member] | Designated as Hedging Instrument [Member] | Commodity Contract [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	$18	$42	'	'

Fair_Value_of_Financial_Instru

Fair Value of Financial Instruments (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Carrying Value [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total debt	$36,193	$34,401
Estimate of Fair Value [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total debt	$36,248	$36,720

Reportable_Segments_Revenues_D

Reportable Segments Revenues (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'
Revenues from external customers	$14,070	$9,973	$7,943
Natural Gas Pipelines [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues from external customers	8,613	5,230	3,943
Natural Gas Pipelines [Member] | Intersegment Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues from external customers	4	0	0
CO2 - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues from external customers	1,857	1,677	1,434
Products Pipelines - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues from external customers	1,853	1,370	914
Terminals - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues from external customers	1,408	1,356	1,314
Terminals - KMP [Member] | Intersegment Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues from external customers	2	3	1
Kinder Morgan Canada - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues from external customers	302	311	302
Other Segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues from external customers	1	-6	0
Total segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues from external customers	14,040	9,941	7,908
Unallocated [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues from external customers	36	35	36
Intersegment Eliminations [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues from external customers	($6)	($3)	($1)

Reportable_Segments_Operating_

Reportable Segments Operating expenses (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	$7,760	$5,045	$4,943
Natural Gas Pipelines [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	5,235	3,111	3,370
CO2 - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	439	381	342
Products Pipelines - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	1,295	759	500
Terminals - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	657	685	634
Kinder Morgan Canada - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	110	103	97
Other Segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	30	5	0
Total segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	7,766	5,044	4,943
Unallocated [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	0	4	1
Intersegment Eliminations [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	($6)	($3)	($1)

Reportable_Segments_Other_expe

Reportable Segments Other expense (income) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'
Other Cost and Expense, Operating	($99)	($13)	($6)
Natural Gas Pipelines [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Other Cost and Expense, Operating	-24	14	1
CO2 - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Other Cost and Expense, Operating	0	-7	0
Products Pipelines - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Other Cost and Expense, Operating	6	-5	-8
Terminals - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Other Cost and Expense, Operating	-74	-14	1
Other Segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Other Cost and Expense, Operating	($7)	($1)	$0

Reportable_Segments_Depreciati

Reportable Segments Depreciation, depletion and amortization (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'
Depreciation, depletion and amortization	$1,806,000,000	$1,419,000,000	$1,068,000,000
Natural Gas Pipelines [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Depreciation, depletion and amortization	797,000,000	478,000,000	163,000,000
CO2 - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Depreciation, depletion and amortization	533,000,000	494,000,000	492,000,000
Products Pipelines - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Depreciation, depletion and amortization	155,000,000	143,000,000	131,000,000
Terminals - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Depreciation, depletion and amortization	247,000,000	236,000,000	226,000,000
Kinder Morgan Canada - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Depreciation, depletion and amortization	54,000,000	56,000,000	56,000,000
Other Segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Depreciation, depletion and amortization	$20,000,000	$12,000,000	$0

Reportable_Segments_Earnings_l

Reportable Segments Earnings (loss) from equity investments (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'
Earnings from equity investments	$327	$153	$226
Natural Gas Pipelines [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Earnings from equity investments	232	52	158
CO2 - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Earnings from equity investments	24	25	24
Products Pipelines - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Earnings from equity investments	45	39	34
Terminals - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Earnings from equity investments	22	21	11
Kinder Morgan Canada - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Earnings from equity investments	4	5	-2
Other Segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Earnings from equity investments	$0	$11	$1

Reportable_Segments_Amortizati

Reportable Segments Amortization of excess cost of equity investments (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'
Other Depreciation and Amortization	$39	$23	$7
Natural Gas Pipelines [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Other Depreciation and Amortization	32	17	1
CO2 - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Other Depreciation and Amortization	2	2	2
Products Pipelines - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Other Depreciation and Amortization	$5	$4	$4

Reportable_Segments_Interest_i

Reportable Segments Interest income (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'
Interest income	$15	$28	$21
Natural Gas Pipelines [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Interest income	0	18	0
CO2 - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Interest income	0	0	1
Products Pipelines - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Interest income	2	2	3
Kinder Morgan Canada - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Interest income	3	14	14
Other Segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Interest income	8	3	0
Total segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Interest income	13	37	18
Unallocated [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Interest income	$2	($9)	$3

Reportable_Segments_Other_neti

Reportable Segments Other, net-income(expense) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'
Other Income	$835	$19	($150)
Natural Gas Pipelines [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Other Income	578	4	-164
CO2 - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Other Income	0	-1	4
Products Pipelines - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Other Income	1	9	5
Terminals - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Other Income	1	2	6
Kinder Morgan Canada - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Other Income	246	3	0
Other Segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Other Income	9	2	-1
Eagle Ford Gathering LLC [Member] | Natural Gas Pipelines [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Gain on sale of investments in Express pipeline system (Note 3)	558	'	'
Express Pipeline System [Member] | Kinder Morgan Canada [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Gain (Loss) on Sale of Investments	$224	'	'

Reportable_Segments_Income_tax

Reportable Segments Income tax benefit (expense) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'
Income Tax Expense (Benefit)	($742)	($139)	($361)
Natural Gas Pipelines [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Income Tax Expense (Benefit)	-9	-5	-3
CO2 - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Income Tax Expense (Benefit)	-7	-5	-4
Products Pipelines - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Income Tax Expense (Benefit)	2	2	-3
Terminals - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Income Tax Expense (Benefit)	-14	-3	5
Kinder Morgan Canada - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Income Tax Expense (Benefit)	-105	-1	-15
Total segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Income Tax Expense (Benefit)	-133	-12	-20
Unallocated [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Income Tax Expense (Benefit)	($609)	($127)	($341)

Reportable_Segments_Segment_ea

Reportable Segments Segment earnings before depreciation, depletion, amortization and amortization of excess cost of equity investments (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'
Depreciation, Depletion and Amortization	($1,806,000,000)	($1,419,000,000)	($1,068,000,000)
Amortization of excess cost of equity investments	-39,000,000	-23,000,000	-7,000,000
Product sales and other	3,788,000,000	2,449,000,000	1,588,000,000
General and Administrative Expense	-613,000,000	-929,000,000	-515,000,000
Unallocable Interest Expense Net Of Interest Income	-1,688,000,000	-1,441,000,000	-701,000,000
Income Tax Expense (Benefit)	-742,000,000	-139,000,000	-361,000,000
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	-4,000,000	-777,000,000	211,000,000
Net Income	2,692,000,000	427,000,000	660,000,000
Natural Gas Pipelines [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	4,207,000,000	2,174,000,000	563,000,000
Depreciation, Depletion and Amortization	-797,000,000	-478,000,000	-163,000,000
Amortization of excess cost of equity investments	-32,000,000	-17,000,000	-1,000,000
Income Tax Expense (Benefit)	-9,000,000	-5,000,000	-3,000,000
CO2 - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	1,435,000,000	1,322,000,000	1,117,000,000
Depreciation, Depletion and Amortization	-533,000,000	-494,000,000	-492,000,000
Amortization of excess cost of equity investments	-2,000,000	-2,000,000	-2,000,000
Income Tax Expense (Benefit)	-7,000,000	-5,000,000	-4,000,000
Products Pipelines - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	602,000,000	668,000,000	461,000,000
Depreciation, Depletion and Amortization	-155,000,000	-143,000,000	-131,000,000
Amortization of excess cost of equity investments	-5,000,000	-4,000,000	-4,000,000
Income Tax Expense (Benefit)	2,000,000	2,000,000	-3,000,000
Terminals - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	836,000,000	708,000,000	702,000,000
Depreciation, Depletion and Amortization	-247,000,000	-236,000,000	-226,000,000
Income Tax Expense (Benefit)	-14,000,000	-3,000,000	5,000,000
Kinder Morgan Canada - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	340,000,000	229,000,000	202,000,000
Depreciation, Depletion and Amortization	-54,000,000	-56,000,000	-56,000,000
Income Tax Expense (Benefit)	-105,000,000	-1,000,000	-15,000,000
Other Segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	-5,000,000	7,000,000	0
Depreciation, Depletion and Amortization	-20,000,000	-12,000,000	0
Total segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Segment Earnings Before Depreciation Depletion And Amortization	7,415,000,000	5,108,000,000	3,045,000,000
Income Tax Expense (Benefit)	-133,000,000	-12,000,000	-20,000,000
Unallocated [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Product sales and other	36,000,000	35,000,000	36,000,000
Income Tax Expense (Benefit)	($609,000,000)	($127,000,000)	($341,000,000)

Reportable_Segments_Capital_ex

Reportable Segments Capital expenditures (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'
Payments to Acquire Property, Plant, and Equipment	$3,369	$2,022	$1,200
Natural Gas Pipelines [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Payments to Acquire Property, Plant, and Equipment	1,085	499	153
CO2 - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Payments to Acquire Property, Plant, and Equipment	667	453	432
Products Pipelines - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Payments to Acquire Property, Plant, and Equipment	416	307	254
Terminals - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Payments to Acquire Property, Plant, and Equipment	1,108	707	332
Kinder Morgan Canada - KMP [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Payments to Acquire Property, Plant, and Equipment	77	16	28
Other Segments [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Payments to Acquire Property, Plant, and Equipment	$16	$40	$1

Reportable_Segments_Investment

Reportable Segments Investments (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Segment Reporting Information [Line Items]	'	'
Long-term Investments	$5,951	$5,804
Natural Gas Pipelines [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Long-term Investments	5,130	5,193
CO2 - KMP [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Long-term Investments	12	11
Products Pipelines - KMP [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Long-term Investments	611	400
Terminals - KMP [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Long-term Investments	196	179
Kinder Morgan Canada - KMP [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Long-term Investments	1	1
Other Segments [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Long-term Investments	$1	$20

Reportable_Segments_Assets_Det

Reportable Segments Assets (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Segment Reporting Information [Line Items]	'	'
Assets	$75,185	$68,245
Assets held for sale	0	298
Natural Gas Pipelines [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Assets	52,357	46,600
CO2 - KMP [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Assets	4,708	4,148
Products Pipelines - KMP [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Assets	6,648	6,089
Terminals - KMP [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Assets	6,888	5,931
Kinder Morgan Canada - KMP [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Assets	1,677	1,724
Other Segments [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Assets	568	601
Total segments [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Assets	72,846	65,093
Corporate Segment [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Assets	$2,339	$2,854

Reportable_Segments_Other_Deta

Reportable Segments Other (Details) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2013

Mar. 14, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

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

Revenues from External Customers [Member]

Revenues from External Customers [Member]

Revenues from External Customers [Member]

Eagle Ford Gathering LLC [Member]

KinderHawk [Member]

Express Pipeline System [Member]

Express Pipeline System [Member]

Unallocated [Member]

Unallocated [Member]

Unallocated [Member]

Unallocated [Member]

Natural Gas Pipelines [Member]

Natural Gas Pipelines [Member]

Natural Gas Pipelines [Member]

Natural Gas Pipelines [Member]

Natural Gas Pipelines [Member]

Natural Gas Pipelines [Member]

Natural Gas Pipelines [Member]

Kinder Morgan Canada [Member]

Single customer exceeding 10% of total [Member]

Single customer exceeding 10% of total [Member]

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

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

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

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

Certain items [Member]

NGPL Holdco LLC [Member]

NGPL Holdco LLC [Member]

Eagle Ford Gathering LLC [Member]

KinderHawk [Member]

Express Pipeline System [Member]

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Tax Expense On Sale of Investment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

($84)

'

'

Business Combination, Acquisition Related Costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

352

'

'

'

'

'

'

'

'

'

'

Percent of available cash partnership requires to be distributed

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenues

14,070

9,973

7,943

'

'

'

'

'

'

'

'

36

35

36

'

8,613

5,230

3,943

'

'

'

'

'

0

0

Concentration Risk, Percentage

'

'

'

'

10.00%

10.00%

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Asset Impairment Charges

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

65

200

'

'

'

'

'

Gain on sale of investments in Express pipeline system (Note 3)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

558

'

'

'

'

Equity Method Investment, Ownership Percentage

'

'

'

'

'

'

'

50.00%

50.00%

33.33%

33.33%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Step Acquisition, Equity Interest in Acquiree, Remeasurement Loss

-558

0

167

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

167

'

'

'

Write off of Deferred Debt Issuance Cost

'

108

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest Expense

$1,690

$1,427

$703

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reportable_Segments_Geographic

Reportable Segments Geographical information (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'
Revenues	$14,070	$9,973	$7,943
Long-Lived Assets	44,375	39,768	22,795
UNITED STATES	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues	13,656	9,488	7,513
Long-Lived Assets	42,080	37,651	20,848
CANADA	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues	398	407	411
Long-Lived Assets	2,214	2,035	1,863
MEXICO	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues	16	78	19
Long-Lived Assets	$81	$82	$84

Litigation_Environmental_and_O1

Litigation, Environmental and Other Contingencies Federal Energy Regulatory Commission Proceedings (Details) (Regulated Operation [Member], Federal Energy Regulatory Commission [Member], Various Shippers [Member], Unfavorable Regulatory Action [Member], USD $)	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Oct. 17, 2013
In Millions, unless otherwise specified	SFPP [Member]	SFPP [Member]	SFPP [Member]	2008 rate case and the 2010 rate case [Member]	Pro Forma [Member]
	Repreations, Refunds, and Rate Reductions [Member]	Annual Rate Reductions [Member]	Revenue Subject to Refund [Member]	EPNG [Member]	EPNG 2010 Rate Case [Member]
	Pending Litigation [Member]	Pending Litigation [Member]	Pending Litigation [Member]	Opinion 517 issued and implemented (rehearing pending); and Opinion 528 issued and is awaiting filing of court document) [Member]	EPNG [Member]
					Pending Litigation [Member]
SFPP [Abstract]	'	'	'	'	'
Loss Contingency, Period of Time Litigation Concerns (prior to the filing of their complaints)	'2 years	'	'	'	'
Loss Contingency, Damages Sought, Value	'	$20	$100	'	'
EPNG [Abstract]	'	'	'	'	'
Loss Contingency, Pending Claims, Number	'	'	'	2	'
Litigation, Court Order, Document Filing Period	'	'	'	'	'60 days

Litigation_Environmental_and_O2

Litigation, Environmental and Other Contingencies California Public Utilities Commission Proceedings (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Mar. 31, 2011	Jan. 30, 2012	Jul. 20, 2013
In Millions, unless otherwise specified	Regulated Operation [Member]	Regulated Operation [Member]	Regulated Operation [Member]	Allen vs El Paso GP [Member]	Intrastate [Member]	Intrastate [Member]
	California Public Utilities Commission [Member]	Reparations [Member]	Annual Revenue Reductions [Member]	SNG [Member]	Regulated Operation [Member]	Regulated Operation [Member]
	Various Shippers [Member]	California Public Utilities Commission [Member]	California Public Utilities Commission [Member]	EPB Acquisition of 25% Ownership Interest in SNG [Member]	California Public Utilities Commission [Member]	California Public Utilities Commission [Member]
	SFPP [Member]	Various Shippers [Member]	Various Shippers [Member]	El Paso Pipeline Partners, L.P. [Member]	Various Shippers [Member]	Various Shippers [Member]
	Pending Litigation [Member]	SFPP [Member]	SFPP [Member]		SFPP [Member]	Calnev Pipe Line LLC [Member]
		Unfavorable Regulatory Action [Member]	Unfavorable Regulatory Action [Member]		Pending Litigation [Member]	Pending Litigation [Member]
		Pending Litigation [Member]	Pending Litigation [Member]
Loss Contingencies [Line Items]	'	'	'	'	'	'
Business Acquisition, Additional Percentage of Interest Acquired	'	'	'	25.00%	'	'
Loss Contingency, Number of Judges	2	'	'	'	'	'
Public Utilities, Requested Rate Increase (Decrease), Percentage	'	'	'	'	7.00%	36.00%
Loss Contingency, Damages Sought, Value	'	$400	$30	'	'	'

Litigation_Environmental_and_O3

Litigation, Environmental and Other Contingencies Copano Shareholders’ Litigation (Details) (Settled [Member], Copano Energy LLC [Member], Punative Class Action Lawsuits [Member], USD $)	1-May-13	Dec. 31, 2013	Sep. 09, 2013
	Schultes v. Copano Ennergy, L.L.C., Bruen v. Copano Energy L.L.C., and In re Copano Energy, L.L.C. Shareholder Lititgation [Member]	In re Copano Energy, L.L.C. Shareholder Litigation [Member]	Legal fees and expenses [Member]
			Schultes v. Copano Ennergy, L.L.C., Bruen v. Copano Energy L.L.C., and In re Copano Energy, L.L.C. Shareholder Lititgation [Member]
Loss Contingencies [Line Items]	'	'	'
Loss Contingency, Pending Claims, Number	3	3	'
Litigation Settlement, Expense	'	'	$450,000

Litigation_Environmental_and_O4

Litigation, Environmental and Other Contingencies Other Commercial Matters (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Oct. 25, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Sep. 30, 2013	Mar. 31, 2011
In Millions, unless otherwise specified		Pending Litigation [Member]	Pending Litigation [Member]	Pending Litigation [Member]	Pending Litigation [Member]	Pending Litigation [Member]	Plains Gas Solutions, LLC v. Tennessee Gas Pipeline Company, L.L.C. et al [Member]	EPB Acquisition of 25% Ownership Interest in SNG [Member]
		Unfavorable Regulatory Action [Member]	Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al. [Member]	Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al. [Member]	Severstal Sparrows Point Crane Collapse [Member]	Price Reporting Litigation [Member]		Allen vs El Paso GP [Member]
			SFPP L.P. [Member]	SFPP L.P. [Member]	Kinder Morgan Bulk Terminals, Inc. [Member]	Kinder Morgan Bulk Terminals, Inc. [Member]		El Paso Pipeline Partners, L.P. [Member]
				Loss on Long-term Purchase Commitment [Member]	Negligence Claim [Member]			SNG [Member]
Loss Contingencies [Line Items]	'	'	'	'	'	'	'	'
Loss Contingency, Initial Award Amount, Annual Rent Payable	'	'	'	$15	'	'	'	'
Loss Contingency, Estimate of Possible Loss	'	'	'	90	'	'	'	'
Loss Contingency, Interest Associated with Settlement	'	'	'	20	'	'	'	'
Loss Contingency, Damages Sought, Value	'	'	22.25	'	30	140	'	'
Loss Contingency, Damages Sought	'	'	'	'	'	'	'100	'
Business Acquisition, Additional Percentage of Interest Acquired	'	'	'	'	'	'	'	25.00%
Estimated Litigation Liability	$624	$425	'	'	'	'	'	'

Litigation_Environmental_and_O5

Litigation, Environmental and Other Contingencies General (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified		Unfavorable Regulatory Action [Member]
		Pending Litigation [Member]
Loss Contingencies [Line Items]	'	'
Estimated Litigation Liability	$624	$425

Litigation_Environmental_and_O6

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

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 1969

Sep. 30, 2013

Dec. 31, 2012

Jul. 24, 2013

Jun. 30, 2013

Nov. 08, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2000

Sep. 30, 2013

Sep. 30, 2013

Jun. 30, 2011

Apr. 09, 2013

Apr. 09, 2013

Oct. 25, 2013

Dec. 31, 2013

Aug. 06, 2013

Sep. 30, 2013

Sep. 30, 2013

Aug. 31, 2007

Dec. 31, 2010

Oct. 25, 2013

Rare Metals Inc. [Member]

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

Environmental Issue [Member]

Environmental Issue [Member]

Environmental Issue [Member]

Environmental Issue [Member]

Settlement through Administrative Order on Consent [Member]

Allocation Process Negotiations and Awaiting Record of Decision [Member]

Allocation Process Negotiations and Awaiting Record of Decision [Member]

Allocation Process Negotiations and Awaiting Record of Decision [Member]

Settled [Member]

Settled [Member]

Settled [Member]

Settled [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

2014 - 2023 [Member]

Southeast Louisiana Flood Protection Litigation [Member]

Carteret Terminal, Carteret, NJ [Member]

Bastian Bay, Buras, Empire and Fort Jackson oil and gas fields of Plaquemines Parish [Member]

TGP's 300 Line Project [Member]

Southwestern Colorado [Member]

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

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

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

Environmental Issue [Member]

Environmental Issue [Member]

Environmental Issue [Member]

Lease Agreements [Member]

SFPP L.P. [Member]

SFPP L.P. [Member]

SFPP Phoenix Terminal [Member]

SFPP Phoenix Terminal [Member]

Newark Bay Complex [Member]

Environmental Issue [Member]

Environmental Issue [Member]

Pending Litigation [Member]

Board of Commissioners of the Southeast Louisiana Flood Protection Authority - East [Member]

PHMSA Inspection of Carteret Terminal [Member]

Plaquemines Parish, Louisiana (Docket No. 60-999) [Member]

Pennsylvania Department of Environmental Protection [Member]

Colorado Oil and Gas Conservation Commission [Member]

Environmental Protection Agency [Member]

Environmental Protection Agency [Member]

Environmental Protection Agency [Member]

Paulsboro, New Jersey Liquids Terminal [Member]

Paulsboro, New Jersey Liquids Terminal [Member]

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

Environmental Issue [Member]

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

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

KMEP and SFPP [Member]

KMEP and SFPP [Member]

New Jersey Department of Environmental Protection [Member]

Mission Valley Terminal Facility [Member]

Mission Valley Terminal Facility [Member]

SFPP L.P. [Member]

TGP and SNG [Member]

PHMSA [Member]

Parish of Plaquemines, Louisiana [Member]

TGP [Member]

Kinder Morgan CO2 [Member]

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

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

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

Kinder Morgan Liquids Terminals, LLC [Member]

Kinder Morgan Liquids Terminals, LLC [Member]

Kinder Morgan Liquids Terminals, LLC [Member]

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

Unfavorable Regulatory Action [Member]

Unfavorable Regulatory Action [Member]

Occidental Chemical Corporation [Member]

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

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

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

Kinder Morgan Liquids Terminals, LLC [Member]

TGP [Member]

Terminals

Terminals

Parties

Exxon Mobil Compliant [Member]

Exxon Mobil Corporation v. GATX Corporation, Kinder Morgan Liquids Terminals, LLC and ST Services, Inc. [Member]

California Superior Court, County of Los Angeles, Case No. NC041463 [Member]

Kinder Morgan Liquids Terminals, LLC [Member]

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

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

Superior Court of New Jersey, Law Division - Essex County, Docket No. L-9868-05 [Member]

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

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

California Superior Court, County of Los Angeles, Case No. NC041463 [Member]

Defendants

Defendants

Loss Contingencies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Lessee Leasing Arrangements, Operating Leases, Term of Contract

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'10 years

'

'

'

'

'

'10 years

Payments for Environmental Liabilities

'

'

'

'

'

'

'

'

'

$220,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Environmental Settlement, Maximum Amount Allowed Toward Public Project

'

'

'

'

'

'

'

'

'

80,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Litigation, Number of Third Party Defendants

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300

'

'

'

Loss Contingency, Number of Defendants

'

'

'

'

'

100

'

17

'

'

'

'

'

'

'

'

'

'

'

26

70

'

'

'

'

Loss Contingency, Range of Possible Loss, Percent of Expense

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

60.00%

'

'

'

'

'

'

'

'

'

Loss Contingency, Range of Possible Loss, Maximum

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15,000,000

'

'

'

'

'

'

'

'

'

Lessee Leasing Arrangements, Operating Leases, Renewal Term

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'

Loss Contingency, Duration of Damages Sought

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'40 years

'

'

'

Number of Liquid Terminals

'

'

'

'

'

'

'

'

'

'

2

2

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of Parties Involoved In Site Cleanup

'

'

'

'

'

'

'

'

'

'

'

'

90

'

'

'

'

'

'

'

'

'

'

'

'

Loss Contingency, Damages Sought, Value

'

'

'

'

'

'

'

'

1,500,000

'

'

'

'

'

'

'

'

22,250,000

'

'

175,000,000

'

170,000,000

365,000,000

'

Number of Uranium Mines

'

'

20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Litigation Settlement, Amount

'

'

'

'

'

'

63,100

'

'

'

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

Litigation, Environmental Settlement Amount, Percentage of Cost

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

Cost of Services, Environmental Remediation

'

'

'

'

'

'

'

'

'

'

'

'

'

750,000

'

'

'

'

'

'

'

'

'

'

'

Accrual for Environmental Loss Contingencies

378,000,000

421,000,000

'

208,000,000

253,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Recorded Third-Party Environmental Recoveries Receivable

$14,000,000

$22,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reconciliation_of_Significant_2

Reconciliation of Significant Asset and Liabilities Balances (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

In Millions, unless otherwise specified

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

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

Kinder Morgan, Inc. [Member]

Kinder Morgan, Inc. [Member]

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

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

Long-term Debt [Member]

Long-term Debt [Member]

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

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

Reconciliation of Significant Asset and Liability Balances [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Liabilities, Fair Value Adjustment

'

'

'

'

'

'

'

'

'

'

$8

$8

Cash and cash equivalents

598

714

411

502

404

529

116

71

78

114

'

'

Property, plant and equipment, net (Note 5)

35,847

30,996

'

'

27,405

22,330

2,563

2,735

5,879

5,931

'

'

Goodwill (Note 7)

24,504

23,632

5,074

'

6,547

5,417

17,935

18,193

22

22

'

'

Current portion of debt

2,306

2,401

'

'

1,504

1,155

725

1,153

77

93

'

'

Outstanding - KMI (Note 18)

'

'

'

'

'

'

9,221

9,148

'

'

'

'

Outstanding - KMP and EPB (Note 18)

'

'

'

'

18,410

15,907

'

'

4,179

4,254

'

'

Long-term Debt and Capital Lease Obligations, Excluding Preferred Interest

$31,810

$29,309

'

'

'

'

'

'

'

'

'

'

Guarantee_of_Securities_of_Sub2

Guarantee of Securities of Subsidiaries Balance Sheet (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013
					Parent Company [Member]	Parent Company [Member]	Subsidiary Issuers	Subsidiary Issuers	Non-Guarantor Subsidiaries [Member]	Non-Guarantor Subsidiaries [Member]	Consolidation, Eliminations [Member]	Consolidation, Eliminations [Member]	Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]	Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]	El Paso Holdco [Member]	El Paso Holdco [Member]	Kinder Morgan, Inc. [Member]	Kinder Morgan, Inc. [Member]	Kinder Morgan, Inc. [Member]
																			El Paso Holdco and Finance Corp [Member]
Guarantor Obligations [Line Items]	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'
Indemnified by parent of subsidiary debt	'	'	'	'	'	'	'	'	'	'	'	'	'	'	$3,800,000,000	$3,900,000,000	'	'	'
Subsidiary ownership percentage	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	100.00%
ASSETS	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'
Cash and cash equivalents	598,000,000	714,000,000	411,000,000	502,000,000	83,000,000	3,000,000	0	45,000,000	515,000,000	666,000,000	0	0	598,000,000	714,000,000	'	'	116,000,000	71,000,000	'
All other current assets	552,000,000	416,000,000	'	'	945,000,000	813,000,000	38,000,000	51,000,000	2,763,000,000	9,322,000,000	-476,000,000	-7,226,000,000	3,270,000,000	2,960,000,000	'	'	'	'	'
Property, plant and equipment, net (Note 5)	35,847,000,000	30,996,000,000	'	'	10,000,000	8,000,000	0	0	35,837,000,000	30,988,000,000	0	0	35,847,000,000	30,996,000,000	'	'	2,563,000,000	2,735,000,000	'
Long-term Investments	5,951,000,000	5,804,000,000	'	'	0	0	0	19,000,000	5,951,000,000	5,785,000,000	0	0	5,951,000,000	5,804,000,000	'	'	'	'	'
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	'	'	'	'	20,336,000,000	20,053,000,000	6,651,000,000	13,501,000,000	0	0	-26,987,000,000	-33,554,000,000	0	0	'	'	'	'	'
Goodwill (Note 7)	24,504,000,000	23,632,000,000	5,074,000,000	'	0	0	8,062,000,000	8,059,000,000	16,442,000,000	15,573,000,000	0	0	24,504,000,000	23,632,000,000	'	'	17,935,000,000	18,193,000,000	'
Due from Affiliate, Noncurrent	'	'	'	'	0	1,555,000,000	0	0	1,993,000,000	2,095,000,000	-1,993,000,000	-3,650,000,000	0	0	'	'	'	'	'
Deferred charges and other assets	'	'	'	'	227,000,000	202,000,000	841,000,000	879,000,000	4,759,000,000	3,914,000,000	-812,000,000	-856,000,000	5,015,000,000	4,139,000,000	'	'	'	'	'
Total Assets	75,185,000,000	68,245,000,000	'	'	21,601,000,000	22,634,000,000	15,592,000,000	22,554,000,000	68,260,000,000	68,343,000,000	-30,268,000,000	-45,286,000,000	75,185,000,000	68,245,000,000	'	'	'	'	'
LIABILITIES AND STOCKHOLDERS’ EQUITY	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'
Current portion of debt	'	'	'	'	175,000,000	1,035,000,000	400,000,000	115,000,000	1,731,000,000	1,251,000,000	0	0	2,306,000,000	2,401,000,000	'	'	725,000,000	1,153,000,000	'
All other current liabilities	'	'	'	'	228,000,000	196,000,000	135,000,000	7,024,000,000	3,882,000,000	2,833,000,000	-476,000,000	-7,226,000,000	3,769,000,000	2,827,000,000	'	'	'	'	'
Long-term Debt, Excluding Current Maturities	33,887,000,000	32,000,000,000	'	'	3,371,000,000	3,068,000,000	3,999,000,000	4,378,000,000	26,517,000,000	24,554,000,000	0	0	33,887,000,000	32,000,000,000	'	'	'	'	'
Due to Affiliate, Noncurrent	'	'	'	'	1,993,000,000	1,764,000,000	0	331,000,000	0	1,555,000,000	-1,993,000,000	-3,650,000,000	0	0	'	'	'	'	'
Deferred income taxes	4,651,000,000	4,071,000,000	'	'	2,426,000,000	2,095,000,000	0	0	3,037,000,000	2,832,000,000	-812,000,000	-856,000,000	4,651,000,000	4,071,000,000	'	'	'	'	'
Other long-term liabilities and deferred credits	'	'	'	'	315,000,000	610,000,000	69,000,000	169,000,000	1,903,000,000	2,067,000,000	0	0	2,287,000,000	2,846,000,000	'	'	'	'	'
Liabilities	46,900,000,000	44,145,000,000	'	'	8,508,000,000	8,768,000,000	4,603,000,000	12,017,000,000	37,070,000,000	35,092,000,000	-3,281,000,000	-11,732,000,000	46,900,000,000	44,145,000,000	'	'	'	'	'
Stockholders' Equity Attributable to Parent	13,093,000,000	13,866,000,000	'	'	13,093,000,000	13,866,000,000	10,989,000,000	10,537,000,000	15,596,000,000	22,858,000,000	-26,585,000,000	-33,395,000,000	13,093,000,000	13,866,000,000	'	'	'	'	'
Stockholders' Equity Attributable to Noncontrolling Interest	15,192,000,000	10,234,000,000	'	'	0	0	0	0	15,594,000,000	10,393,000,000	-402,000,000	-159,000,000	15,192,000,000	10,234,000,000	'	'	'	'	'
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	28,285,000,000	24,100,000,000	8,568,000,000	8,539,000,000	13,093,000,000	13,866,000,000	10,989,000,000	10,537,000,000	31,190,000,000	33,251,000,000	-26,987,000,000	-33,554,000,000	28,285,000,000	24,100,000,000	'	'	'	'	'
Total Liabilities and Stockholders’ Equity	$75,185,000,000	$68,245,000,000	'	'	$21,601,000,000	$22,634,000,000	$15,592,000,000	$22,554,000,000	$68,260,000,000	$68,343,000,000	($30,268,000,000)	($45,286,000,000)	$75,185,000,000	$68,245,000,000	'	'	'	'	'

Guarantee_of_Securities_of_Sub3

Guarantee of Securities of Subsidiaries Income Statement (Details) (USD $)	11 Months Ended	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Guarantor Obligations [Line Items]	'	'	'	'
Revenues	'	$14,070,000,000	$9,973,000,000	$7,943,000,000
Depreciation, depletion and amortization	'	1,806,000,000	1,419,000,000	1,068,000,000
Costs and Expenses	'	10,080,000,000	7,380,000,000	6,520,000,000
Operating Income (Loss)	'	3,990,000,000	2,593,000,000	1,423,000,000
Earnings from equity investments	'	327,000,000	153,000,000	226,000,000
Interest Income (Expense), Net	'	-1,675,000,000	-1,399,000,000	-682,000,000
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	'	3,438,000,000	1,343,000,000	810,000,000
Income Tax Expense (Benefit)	'	-742,000,000	-139,000,000	-361,000,000
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	449,000,000	2,696,000,000	1,204,000,000	449,000,000
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	-4,000,000	-777,000,000	211,000,000
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	'	2,692,000,000	427,000,000	660,000,000
Net Income Attributable to Noncontrolling Interests	'	-1,499,000,000	-112,000,000	-66,000,000
Net income	594,000,000	1,193,000,000	315,000,000	594,000,000
Parent Company [Member]	'	'	'	'
Guarantor Obligations [Line Items]	'	'	'	'
Revenues	'	36,000,000	35,000,000	36,000,000
Costs of sales	'	0	0	0
Depreciation, depletion and amortization	'	1,000,000	0	0
Other operating expenses	'	20,000,000	232,000,000	42,000,000
Costs and Expenses	'	21,000,000	232,000,000	42,000,000
Operating Income (Loss)	'	15,000,000	-197,000,000	-6,000,000
Earnings from equity investments	'	1,386,000,000	123,000,000	712,000,000
Interest Income (Expense), Net	'	-262,000,000	-381,000,000	-187,000,000
Amortization of excess cost of equity investments and other, net	'	0	-1,000,000	-1,000,000
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	'	1,139,000,000	-456,000,000	518,000,000
Income Tax Expense (Benefit)	'	54,000,000	771,000,000	68,000,000
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	1,193,000,000	315,000,000	586,000,000
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	0	0	8,000,000
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	'	1,193,000,000	315,000,000	594,000,000
Net Income Attributable to Noncontrolling Interests	'	0	0	0
Net income	'	1,193,000,000	315,000,000	594,000,000
Subsidiary Issuers	'	'	'	'
Guarantor Obligations [Line Items]	'	'	'	'
Revenues	'	0	0	0
Costs of sales	'	0	0	0
Depreciation, depletion and amortization	'	0	0	0
Other operating expenses	'	-3,000,000	62,000,000	0
Costs and Expenses	'	-3,000,000	62,000,000	0
Operating Income (Loss)	'	3,000,000	-62,000,000	0
Earnings from equity investments	'	553,000,000	276,000,000	0
Interest Income (Expense), Net	'	-305,000,000	-265,000,000	0
Amortization of excess cost of equity investments and other, net	'	0	0	0
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	'	251,000,000	-51,000,000	0
Income Tax Expense (Benefit)	'	89,000,000	-380,000,000	0
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	340,000,000	-431,000,000	0
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	0	0	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	'	340,000,000	-431,000,000	0
Net Income Attributable to Noncontrolling Interests	'	0	0	0
Net income	'	340,000,000	-431,000,000	0
Non-Guarantor Subsidiaries [Member]	'	'	'	'
Guarantor Obligations [Line Items]	'	'	'	'
Revenues	'	14,066,000,000	9,938,000,000	7,907,000,000
Costs of sales	'	5,253,000,000	3,057,000,000	3,278,000,000
Depreciation, depletion and amortization	'	1,805,000,000	1,419,000,000	1,068,000,000
Other operating expenses	'	3,036,000,000	2,610,000,000	2,132,000,000
Costs and Expenses	'	10,094,000,000	7,086,000,000	6,478,000,000
Operating Income (Loss)	'	3,972,000,000	2,852,000,000	1,429,000,000
Earnings from equity investments	'	327,000,000	153,000,000	226,000,000
Interest Income (Expense), Net	'	-1,108,000,000	-753,000,000	-495,000,000
Amortization of excess cost of equity investments and other, net	'	796,000,000	-3,000,000	-156,000,000
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	'	3,987,000,000	2,249,000,000	1,004,000,000
Income Tax Expense (Benefit)	'	-885,000,000	-530,000,000	-429,000,000
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	3,102,000,000	1,719,000,000	575,000,000
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	-4,000,000	-777,000,000	203,000,000
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	'	3,098,000,000	942,000,000	778,000,000
Net Income Attributable to Noncontrolling Interests	'	-1,595,000,000	-109,000,000	-71,000,000
Net income	'	1,503,000,000	833,000,000	707,000,000
Consolidation, Eliminations [Member]	'	'	'	'
Guarantor Obligations [Line Items]	'	'	'	'
Revenues	'	-32,000,000	0	0
Costs of sales	'	0	0	0
Depreciation, depletion and amortization	'	0	0	0
Other operating expenses	'	-32,000,000	0	0
Costs and Expenses	'	-32,000,000	0	0
Operating Income (Loss)	'	0	0	0
Earnings from equity investments	'	-1,939,000,000	-399,000,000	-712,000,000
Interest Income (Expense), Net	'	0	0	0
Amortization of excess cost of equity investments and other, net	'	0	0	0
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	'	-1,939,000,000	-399,000,000	-712,000,000
Income Tax Expense (Benefit)	'	0	0	0
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	-1,939,000,000	-399,000,000	-712,000,000
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	0	0	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	'	-1,939,000,000	-399,000,000	-712,000,000
Net Income Attributable to Noncontrolling Interests	'	96,000,000	-3,000,000	5,000,000
Net income	'	-1,843,000,000	-402,000,000	-707,000,000
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]	'	'	'	'
Guarantor Obligations [Line Items]	'	'	'	'
Revenues	'	14,070,000,000	9,973,000,000	7,943,000,000
Costs of sales	'	5,253,000,000	3,057,000,000	3,278,000,000
Depreciation, depletion and amortization	'	1,806,000,000	1,419,000,000	1,068,000,000
Other operating expenses	'	3,021,000,000	2,904,000,000	2,174,000,000
Costs and Expenses	'	10,080,000,000	7,380,000,000	6,520,000,000
Operating Income (Loss)	'	3,990,000,000	2,593,000,000	1,423,000,000
Earnings from equity investments	'	327,000,000	153,000,000	226,000,000
Interest Income (Expense), Net	'	-1,675,000,000	-1,399,000,000	-682,000,000
Amortization of excess cost of equity investments and other, net	'	796,000,000	-4,000,000	-157,000,000
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	'	3,438,000,000	1,343,000,000	810,000,000
Income Tax Expense (Benefit)	'	-742,000,000	-139,000,000	-361,000,000
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	2,696,000,000	1,204,000,000	449,000,000
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	-4,000,000	-777,000,000	211,000,000
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	'	2,692,000,000	427,000,000	660,000,000
Net Income Attributable to Noncontrolling Interests	'	-1,499,000,000	-112,000,000	-66,000,000
Net income	'	$1,193,000,000	$315,000,000	$594,000,000

Guarantee_of_Securities_of_Sub4

Guarantee of Securities of Subsidiaries Comprehensive income (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Guarantor Obligations [Line Items]	'	'	'
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	$2,692	$427	$660
Other Comprehensive Income (Loss), Net of Tax [Abstract]	'	'	'
Change in fair value of derivatives utilized for hedging purposes	-38	82	13
Reclassification of change in fair value of derivatives to net income	11	-8	184
Foreign currency translation adjustments	-103	32	-35
Adjustments to pension and other postretirement benefit plan liabilities	-166	40	61
Total other comprehensive income (loss)	40	71	108
Comprehensive income	2,732	498	768
Comprehensive income attributable to noncontrolling interests	-1,445	-186	-153
Comprehensive income attributable to controlling interests	1,287	312	615
Parent Company [Member]	'	'	'
Guarantor Obligations [Line Items]	'	'	'
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	1,193	315	594
Other Comprehensive Income (Loss), Net of Tax [Abstract]	'	'	'
Change in fair value of derivatives utilized for hedging purposes	-14	32	6
Reclassification of change in fair value of derivatives to net income	4	-5	67
Foreign currency translation adjustments	-49	14	-14
Adjustments to pension and other postretirement benefit plan liabilities	-153	44	38
Total other comprehensive income (loss)	94	-3	21
Comprehensive income	1,287	312	615
Comprehensive income attributable to noncontrolling interests	0	0	0
Comprehensive income attributable to controlling interests	1,287	312	615
Subsidiary Issuers	'	'	'
Guarantor Obligations [Line Items]	'	'	'
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	340	-431	0
Other Comprehensive Income (Loss), Net of Tax [Abstract]	'	'	'
Change in fair value of derivatives utilized for hedging purposes	7	-5	0
Reclassification of change in fair value of derivatives to net income	-2	-2	0
Foreign currency translation adjustments	0	0	0
Adjustments to pension and other postretirement benefit plan liabilities	-16	14	0
Total other comprehensive income (loss)	21	-21	0
Comprehensive income	361	-452	0
Comprehensive income attributable to noncontrolling interests	0	0	0
Comprehensive income attributable to controlling interests	361	-452	0
Non-Guarantor Subsidiaries [Member]	'	'	'
Guarantor Obligations [Line Items]	'	'	'
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	3,098	942	778
Other Comprehensive Income (Loss), Net of Tax [Abstract]	'	'	'
Change in fair value of derivatives utilized for hedging purposes	-38	86	11
Reclassification of change in fair value of derivatives to net income	11	-8	176
Foreign currency translation adjustments	-102	33	-31
Adjustments to pension and other postretirement benefit plan liabilities	-50	4	23
Total other comprehensive income (loss)	-79	107	133
Comprehensive income	3,019	1,049	911
Comprehensive income attributable to noncontrolling interests	-1,445	186	153
Comprehensive income attributable to controlling interests	1,574	863	758
Consolidation, Eliminations [Member]	'	'	'
Guarantor Obligations [Line Items]	'	'	'
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	-1,939	-399	-712
Other Comprehensive Income (Loss), Net of Tax [Abstract]	'	'	'
Change in fair value of derivatives utilized for hedging purposes	7	-31	-4
Reclassification of change in fair value of derivatives to net income	-2	7	-59
Foreign currency translation adjustments	48	-15	10
Adjustments to pension and other postretirement benefit plan liabilities	49	-27	-7
Total other comprehensive income (loss)	4	-12	-46
Comprehensive income	-1,935	-411	-758
Comprehensive income attributable to noncontrolling interests	0	0	0
Comprehensive income attributable to controlling interests	-1,935	-411	-758
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]	'	'	'
Guarantor Obligations [Line Items]	'	'	'
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	2,692	427	660
Other Comprehensive Income (Loss), Net of Tax [Abstract]	'	'	'
Change in fair value of derivatives utilized for hedging purposes	-38	82	13
Reclassification of change in fair value of derivatives to net income	11	-8	184
Foreign currency translation adjustments	-103	32	-35
Adjustments to pension and other postretirement benefit plan liabilities	-170	35	54
Total other comprehensive income (loss)	40	71	108
Comprehensive income	2,732	498	768
Comprehensive income attributable to noncontrolling interests	-1,445	186	153
Comprehensive income attributable to controlling interests	$1,287	$312	$615

Guarantee_of_Securities_of_Sub5

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

1 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Jan. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Parent Company [Member]

Parent Company [Member]

Parent Company [Member]

Parent Company [Member]

Parent Company [Member]

Parent Company [Member]

Parent Company [Member]

Parent Company [Member]

Parent Company [Member]

Parent Company [Member]

Parent Company [Member]

Parent Company [Member]

Subsidiary Issuers

Subsidiary Issuers

Subsidiary Issuers

Subsidiary Issuers

Subsidiary Issuers

Subsidiary Issuers

Subsidiary Issuers

Subsidiary Issuers

Subsidiary Issuers

Subsidiary Issuers

Subsidiary Issuers

Subsidiary Issuers

Non-Guarantor Subsidiaries [Member]

Non-Guarantor Subsidiaries [Member]

Non-Guarantor Subsidiaries [Member]

Non-Guarantor Subsidiaries [Member]

Non-Guarantor Subsidiaries [Member]

Non-Guarantor Subsidiaries [Member]

Non-Guarantor Subsidiaries [Member]

Non-Guarantor Subsidiaries [Member]

Non-Guarantor Subsidiaries [Member]

Non-Guarantor Subsidiaries [Member]

Non-Guarantor Subsidiaries [Member]

Non-Guarantor Subsidiaries [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

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

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

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

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

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

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

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

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

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

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

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

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

KMP and EPB [Member]

KMP and EPB [Member]

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

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

Other Acquisitions [Member]

Other Acquisitions [Member]

Other Acquisitions [Member]

KMI's Acquisition of El Paso Corporation [Member]

KMP and EPB [Member]

KMP and EPB [Member]

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

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

Other Acquisitions [Member]

Other Acquisitions [Member]

Other Acquisitions [Member]

KMI's Acquisition of El Paso Corporation [Member]

KMP and EPB [Member]

KMP and EPB [Member]

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

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

Other Acquisitions [Member]

Other Acquisitions [Member]

Other Acquisitions [Member]

KMI's Acquisition of El Paso Corporation [Member]

KMP and EPB [Member]

KMP and EPB [Member]

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

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

Other Acquisitions [Member]

Other Acquisitions [Member]

Other Acquisitions [Member]

KMI's Acquisition of El Paso Corporation [Member]

KMP and EPB [Member]

KMP and EPB [Member]

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

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

Other Acquisitions [Member]

Other Acquisitions [Member]

Other Acquisitions [Member]

KMI's Acquisition of El Paso Corporation [Member]

Guarantor Obligations [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net Cash Provided by (Used in) Operating Activities

'

$4,064

$2,795

$2,366

$1,693

$1,014

$957

'

'

'

'

'

'

'

'

'

$91

($369)

$0

'

'

'

'

'

'

'

'

'

$4,506

$3,757

$2,766

'

'

'

'

'

'

'

'

'

($2,226)

($1,607)

($1,357)

'

'

'

'

'

'

'

'

'

$4,064

$2,795

$2,366

'

'

'

'

'

'

'

'

'

Capital expenditures

'

-3,369

-2,022

-1,200

-6

-5

-1

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

-3,363

-2,017

-1,199

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

-3,369

-2,022

-1,200

'

'

'

'

'

'

'

'

'

Proceeds from disposal of discontinued operations

'

0

1,791

0

'

0

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

1,791

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

1,791

'

'

'

'

'

'

'

'

'

'

Proceeds from Sale of Investments

88

490

0

0

0

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

490

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

490

'

'

'

'

'

'

'

'

'

'

'

Acquisition Of Investments

'

'

'

'

'

'

'

'

'

'

994

3,485

0

0

0

-5,212

'

'

'

'

'

'

0

0

0

0

0

0

'

'

'

'

'

'

-994

-3,485

-292

-83

-1,179

242

'

'

'

'

'

'

0

0

0

0

0

0

'

'

'

'

'

'

0

0

-292

-83

-1,179

-4,970

Repayments from related party

'

11

76

31

0

0

0

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

11

76

31

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

11

76

31

'

'

'

'

'

'

'

'

'

Funding to Affiliates

'

'

'

'

-376

-701

-852

'

'

'

'

'

'

'

'

'

-597

-968

0

'

'

'

'

'

'

'

'

'

-623

-1,280

-1

'

'

'

'

'

'

'

'

'

1,596

2,949

853

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

Contributions to investments

'

-217

-192

-371

-6

-15

-92

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

-217

-177

-371

'

'

'

'

'

'

'

'

'

6

0

92

'

'

'

'

'

'

'

'

'

-217

-192

-371

'

'

'

'

'

'

'

'

'

Investments in KMP and EPB

'

'

'

'

'

'

'

'

-65

-85

'

'

'

'

'

'

'

'

'

'

-3

-9

'

'

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

'

'

68

94

'

'

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

Distributions from equity investments in excess of cumulative earnings

'

'

'

'

18

16

22

'

'

'

'

'

'

'

'

'

23

0

0

'

'

'

'

'

'

'

'

'

183

188

214

'

'

'

'

'

'

'

'

'

-39

-4

0

'

'

'

'

'

'

'

'

'

185

200

236

'

'

'

'

'

'

'

'

'

Other, net

'

41

-38

68

0

0

0

'

'

'

'

'

'

'

'

'

0

1

0

'

'

'

'

'

'

'

'

'

128

115

91

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

128

116

91

'

'

'

'

'

'

'

'

'

Net Cash Provided by (Used in) Investing Activities

'

-3,064

-5,084

-2,392

559

-2,517

-923

'

'

'

'

'

'

'

'

'

-577

-976

0

'

'

'

'

'

'

'

'

'

-4,677

-4,630

-2,414

'

'

'

'

'

'

'

'

'

1,631

3,039

945

'

'

'

'

'

'

'

'

'

-3,064

-5,084

-2,392

'

'

'

'

'

'

'

'

'

Issuance of debt

'

'

'

'

2,895

7,889

2,070

'

'

'

'

'

'

'

'

'

133

112

0

'

'

'

'

'

'

'

'

'

10,553

10,147

7,502

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

13,581

18,148

9,572

'

'

'

'

'

'

'

'

'

Payment of debt

'

'

'

'

-3,444

-5,418

-1,649

'

'

'

'

'

'

'

'

'

-180

-274

0

'

'

'

'

'

'

'

'

'

-8,769

-9,063

-7,144

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

-12,393

-14,755

-8,793

'

'

'

'

'

'

'

'

'

Funding from affiliates

'

'

'

'

651

539

1

'

'

'

'

'

'

'

'

'

488

1,552

0

'

'

'

'

'

'

'

'

'

457

858

852

'

'

'

'

'

'

'

'

'

-1,596

-2,949

-853

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

Debt issue costs

'

-38

-111

-76

-15

-91

-57

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

-23

-20

-19

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

-38

-111

-76

'

'

'

'

'

'

'

'

'

Cash dividends/distributions

'

'

'

'

-1,622

-1,184

-770

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

-1,622

-1,184

-770

'

'

'

'

'

'

'

'

'

Repurchases of shares and warrants

'

-637

-157

0

-637

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

-637

'

'

'

'

'

'

'

'

'

'

'

Repurchases of Warrants

'

-465

-157

'

'

-157

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

-157

'

'

'

'

'

'

'

'

'

'

Distributions to parent

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

-2,253

-1,597

-1,275

'

'

'

'

'

'

'

'

'

2,253

1,597

1,275

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

Contributions from noncontrolling interests

'

1,706

1,939

970

0

0

0

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

1,762

2,012

980

'

'

'

'

'

'

'

'

'

-56

-73

-10

'

'

'

'

'

'

'

'

'

1,706

1,939

970

'

'

'

'

'

'

'

'

'

Distributions to noncontrolling interests

'

-1,692

-1,219

-956

0

0

0

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

-1,692

-1,219

-956

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

-1,692

-1,219

-956

'

'

'

'

'

'

'

'

'

Other, net

'

0

-77

-4

0

-74

0

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

6

4

-4

'

'

'

'

'

'

'

'

'

-6

-7

0

'

'

'

'

'

'

'

'

'

0

-77

-4

'

'

'

'

'

'

'

'

'

Net Cash Provided by (Used in) Financing Activities

'

-1,095

2,584

-57

-2,172

1,504

-405

'

'

'

'

'

'

'

'

'

441

1,390

0

'

'

'

'

'

'

'

'

'

41

1,122

-64

'

'

'

'

'

'

'

'

'

595

-1,432

412

'

'

'

'

'

'

'

'

'

-1,095

2,584

-57

'

'

'

'

'

'

'

'

'

Effect of Exchange Rate on Cash and Cash Equivalents

'

-21

8

-8

0

0

0

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

-21

8

-8

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

-21

8

-8

'

'

'

'

'

'

'

'

'

Cash and Cash Equivalents, Period Increase (Decrease)

'

-116

303

-91

80

1

-371

'

'

'

'

'

'

'

'

'

-45

45

0

'

'

'

'

'

'

'

'

'

-151

257

280

'

'

'

'

'

'

'

'

'

0

0

0

'

'

'

'

'

'

'

'

'

-116

303

-91

'

'

'

'

'

'

'

'

'

Total Cash and Cash Equivalents

'

'

'

'

$83

$3

$2

$373

'

'

'

'

'

'

'

'

$0

$45

$0

$0

'

'

'

'

'

'

'

'

$515

$666

$409

$129

'

'

'

'

'

'

'

'

$0

$0

$0

$0

'

'

'

'

'

'

'

'

$598

$714

$411

$502

'

'

'

'

'

'

'

'