SOUTHERN Co GAS (GAS) 10-Q/A 26 Nov 14 2014 Q3 Quarterly report (amended) Financial data

Document_And_Entity_Informatio

Document And Entity Information	9 Months Ended
	Sep. 30, 2014	Oct. 31, 2014
Document and Entity Information [Abstract]	'	'
Entity Registrant Name	'AGL RESOURCES INC.	'
Document Type	'10-Q	'
Current Fiscal Year End Date	'--12-31	'
Entity Common Stock, Shares Outstanding	'	119,572,999
Amendment Flag	'true	'
Amendment Description	'Amendment	'
Entity Central Index Key	'0001004155	'
Entity Current Reporting Status	'Yes	'
Entity Voluntary Filers	'No	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Well-known Seasoned Issuer	'Yes	'
Document Period End Date	30-Sep-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q3	'

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Financial Position (Unaudited) (USD $)	Sep. 30, 2014		Dec. 31, 2013		Sep. 30, 2013
In Millions, unless otherwise specified
Current assets	'		'		'
Cash and cash equivalents	$32		$81		$97
Short-term investments	8		49		41
Receivables	'		'		'
Energy marketing	544		786		502
Gas, unbilled and other	409		736		308
Less allowance for uncollectible accounts	37		29		32
Total receivables, net	916		1,493		778
Inventories, net	796		658		788
Regulatory assets	105		114	[1]	87	[1]
Derivative instruments	102		99		97
Assets held for sale	'		283		294
Other	134		118		70
Total current assets	2,093	[2]	2,895	[2]	2,252	[2]
Long-term assets and other deferred debits	'		'		'
Property, plant and equipment	11,352		10,938		10,761
Less accumulated depreciation	2,427		2,295		2,281
Property, plant and equipment, net	8,925		8,643		8,480
Goodwill	1,827		1,827	[3]	1,822	[3]
Regulatory assets	637		705	[1]	845	[1]
Intangible assets	130		145		152
Other	341		335		259
Total long-term assets and other deferred debits	11,860		11,655		11,558
Total assets	13,953	[2]	14,550	[2]	13,810	[2]
Current liabilities	'		'		'
Short-term debt	681		1,171		832
Energy marketing trade payables	612		671		539
Other accounts payable - trade	298		421		295
Current portion of long-term debt	200		'		'
Accrued expenses	173		203		149
Customer deposits and credit balances	122		136		140
Regulatory liabilities	118		183	[1]	174	[1]
Accrued environmental remediation liabilities	82		70		48
Derivative instruments	45		75		38
Liabilities held for sale	'		40		39
Other	131		148		153
Total current liabilities	2,462	[2]	3,118	[2]	2,407	[2]
Long-term liabilities and other deferred credits	'		'		'
Long-term debt	3,605		3,813		3,816
Accumulated deferred income taxes	1,655		1,628		1,551
Regulatory liabilities	1,567		1,518	[1]	1,524	[1]
Accrued pension and retiree welfare benefits	406		404		511
Accrued environmental remediation liabilities	372		377		416
Other	84		79		79
Total long-term liabilities and other deferred credits	7,689	[2]	7,819	[2]	7,897	[2]
Total liabilities and other deferred credits	10,151	[2]	10,937	[2]	10,304	[2]
Equity	'		'		'
Common stock, $5 par value; 750,000,000 shares authorized: outstanding: 119,564,666 shares at September 30, 2014, 118,888,876 shares at December 31, 2013, and 118,778,298 shares at September 30, 2013	599		595		595
Additional paid-in capital	2,080		2,054		2,047
Retained earnings	1,222		1,063		1,042
Accumulated other comprehensive loss	-133	[4]	-136	[4]	-208	[4]
Treasury shares, at cost: 216,523 shares at September 30, 2014, December 31, 2013, and September 30, 2013	-8		-8		-8
Total common shareholders’ equity	3,760		3,568		3,468
Noncontrolling interest	42		45		38
Total equity	3,802	[2]	3,613	[2]	3,506	[2]
Total liabilities and equity	$13,953	[2]	$14,550	[2]	$13,810	[2]
[1]	Amounts revised for prior period adjustments. See Note 13 for additional information.
[2]	Amounts revised and include prior period adjustments. See Note 13 for additional information.
[3]	Excludes goodwill at Tropical Shipping which is classified as held for sale. See Note 12 for additional information.
[4]	All amounts are net of income taxes. Amounts in parentheses indicate increases to our accumulated other comprehensive loss.

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Financial Position (Unaudited) (Parentheticals) (USD $)	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013
Common stock, par value (in Dollars per share)	$5	$5	$5
Common stock, shares authorized	750,000,000	750,000,000	750,000,000
Common stock, shares outstanding	119,564,666	118,888,876	118,778,298
Treasury shares, shares	216,523	216,523	216,523

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements of Income (Unaudited) (USD $)	3 Months Ended				9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Operating revenues (includes revenue taxes of $9 and $103 for the three and nine months in 2014 and $9 and $83 for the three and nine months in 2013)	$589		$574	[1]	$3,940	[1]	$2,991	[1]
Operating expenses	'		'		'		'
Cost of goods sold	198		174	[1]	2,000	[1]	1,447	[1]
Operation and maintenance	193		199	[1]	693	[1]	634	[1]
Depreciation and amortization	93		104	[1]	281	[1]	309	[1]
Taxes other than income taxes	30		27	[1]	160	[1]	139	[1]
Total operating expenses	514		504	[1]	3,134	[1]	2,529	[1]
Gain on disposition of assets	3		'		3	[1]	11	[1]
Operating income	78		70	[1]	809	[1]	473	[1]
Other income	3		7	[1]	8	[1]	18	[1]
Interest expense, net	-44		-37		-135		-126
Income before income taxes	37		40		682		365
Income tax expense	14		16		254		137
Income from continuing operations	23		24		428		228
(Loss) income from discontinued operations, net of tax	-31		1		-80		1
Net (loss) income	-8		25		348		229
Less net income attributable to the noncontrolling interest	'		'		14		11
Net (loss) income attributable to AGL Resources Inc.	($8)		$25	[2]	$334	[2]	$218	[2]
Basic earnings (loss) per common share	'		'		'		'
Continuing operations (in Dollars per share)	$0.19		$0.20	[2],[3]	$3.48	[2]	$1.85	[2],[3]
Discontinued operations (in Dollars per share)	($0.25)		$0.01	[2],[3]	($0.67)	[2]	$0.01	[2],[3]
Basic (loss) earnings per common share attributable to AGL Resources Inc. common shareholders (in Dollars per share)	($0.06)		$0.21	[2]	$2.81	[2]	$1.86	[2]
Diluted earnings (loss) per common share	'		'		'		'
Continuing operations (in Dollars per share)	$0.19		$0.20	[2],[3]	$3.47	[2]	$1.84	[2],[3]
Discontinued operations (in Dollars per share)	($0.25)		$0.01	[2],[3]	($0.67)	[2]	$0.01	[2],[3]
Diluted (loss) earnings per common share attributable to AGL Resources Inc. common shareholders (in Dollars per share)	($0.06)		$0.21	[2]	$2.80	[2]	$1.85	[2]
Cash dividends declared per common share (in Dollars per share)	$0.49		$0.47		$1.47		$1.41
Weighted average number of common shares outstanding	'		'		'		'
Basic (in Shares)	119	[4]	118.2	[2],[4]	118.8	[2],[4]	117.8	[2],[4]
Diluted (in Shares)	119.4		118.5	[2]	119.2	[2]	118.1	[2]
[1]	Amounts revised and include prior period adjustments. See Note 13 for additional information.
[2]	Amounts revised and or include prior period adjustments. See Note 13 for additional information.
[3]	Excludes net income attributable to the noncontrolling interest.
[4]	Daily weighted average shares outstanding.

Condensed_Consolidated_Stateme3

Condensed Consolidated Statements of Income (Unaudited) (Parentheticals) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Operating revenues, revenue taxes	$9	$9	$103	$83

Condensed_Consolidated_Stateme4

Condensed Consolidated Statements of Comprehensive Income (Unaudited) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Net (loss) income	($8)		$25		$348		$229
Retirement benefit plans	'		'		'		'
Reclassification of actuarial losses to net benefit cost (net of income tax of $2 and $5 for the three and nine months ended September 30, 2014, and $3 and $8 for the three and nine months ended September 30, 2013)	2		3		7		11
Reclassification of prior service credits to net benefit cost (net of income tax of $(1) for the nine months ended September 30, 2013)	'		-2		-1		-3
Retirement benefit plans	2	[1]	1	[1]	6	[1]	8	[1]
Cash flow hedges, net of tax	'		'		'		'
Net derivative instrument (losses) gains arising during the period	-2		'		2		'
Reclassification of realized derivative instrument (gains) losses to net income (net of income tax of $(1) for the nine months ended September 30, 2014 and $1 for the nine months ended September 30, 2013)	'	[1]	'	[1]	-5	[1]	2	[1]
Cash flow hedges, net	-2	[1]	'	[1]	-3	[1]	2	[1]
Other comprehensive income, net of tax	'	[1]	1	[1]	3	[1]	10	[1]
Comprehensive (loss) income	-8		26		351		239
Less comprehensive income attributable to noncontrolling interest	'		'		14		11
Comprehensive (loss) income attributable to AGL Resources Inc.	($8)		$26		$337		$228
[1]	All amounts are net of income taxes. Amounts in parentheses indicate increases to our accumulated other comprehensive loss.

Condensed_Consolidated_Stateme5

Condensed Consolidated Statements of Comprehensive Income (Unaudited) (Parentheticals) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Reclassification of losses to net benefit cost, income tax	$2	$3	$5	$8
Reclassification of prior service credits to net benefit cost, income tax	'	'	'	-1
Reclassification of realized derivative losses to net income, income tax	'	'	($1)	$1

Condensed_Consolidated_Stateme6

Condensed Consolidated Statements of Equity (Unaudited) (USD $)	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Treasury Stock [Member]	Noncontrolling Interest [Member]	Total
In Millions, except Share data
Balance at Dec. 31, 2012	$590	$2,015	$990	($218)	($8)	$22	$3,391
Balance (in Shares) at Dec. 31, 2012	117,900,000	'	'	'	'	'	'
Net income	'	'	218	'	'	11	229
Other comprehensive income	'	'	'	10	'	'	10	[1]
Dividends on common stock	'	'	-166	'	'	'	-166
Contribution from noncontrolling interest	'	'	'	'	'	22	22
Distributions to noncontrolling interest	'	'	'	'	'	-17	-17
Stock granted, share-based compensation, net of forfeitures	'	-6	'	'	'	'	-6
Stock issued, dividend reinvestment plan	1	7	'	'	'	'	8
Stock issued, dividend reinvestment plan (in Shares)	200,000	'	'	'	'	'	'
Stock issued, share-based compensation, net of forfeitures	4	22	'	'	'	'	26
Stock issued, share-based compensation, net of forfeitures (in Shares)	700,000	'	'	'	'	'	'
Stock-based compensation expense, net of tax	'	9	'	'	'	'	9
Balance at Sep. 30, 2013	595	2,047	1,042	-208	-8	38	3,506	[2]
Balance (in Shares) at Sep. 30, 2013	118,800,000	'	'	'	'	'	118,778,298
Balance at Dec. 31, 2013	595	2,054	1,063	-136	-8	45	3,613	[2]
Balance (in Shares) at Dec. 31, 2013	118,900,000	'	'	'	'	'	118,888,876
Net income	'	'	334	'	'	14	348
Other comprehensive income	'	'	'	3	'	'	3	[1]
Dividends on common stock	'	'	-175	'	'	'	-175
Distributions to noncontrolling interest	'	'	'	'	'	-17	-17
Stock granted, share-based compensation, net of forfeitures	'	-11	'	'	'	'	-11
Stock issued, dividend reinvestment plan	1	8	'	'	'	'	9
Stock issued, dividend reinvestment plan (in Shares)	100,000	'	'	'	'	'	'
Stock issued, share-based compensation, net of forfeitures	3	19	'	'	'	'	22
Stock issued, share-based compensation, net of forfeitures (in Shares)	600,000	'	'	'	'	'	'
Stock-based compensation expense, net of tax	'	10	'	'	'	'	10
Balance at Sep. 30, 2014	$599	$2,080	$1,222	($133)	($8)	$42	$3,802	[2]
Balance (in Shares) at Sep. 30, 2014	119,600,000	'	'	'	'	'	119,564,666
[1]	All amounts are net of income taxes. Amounts in parentheses indicate increases to our accumulated other comprehensive loss.
[2]	Amounts revised and include prior period adjustments. See Note 13 for additional information.

Condensed_Consolidated_Stateme7

Condensed Consolidated Statements of Equity (Unaudited) (Parentheticals) (USD $)	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Dividends on common stock, per share	$1.47	$1.41

Condensed_Consolidated_Stateme8

Condensed Consolidated Statements of Cash Flows (Unaudited) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013
Cash flows from operating activities	'		'
Net income	$348		$229
Adjustments to reconcile net income to net cash flow provided by operating activities	'		'
Depreciation and amortization	281	[1]	309	[1]
Loss (income) from discontinued operations, net of taxes	80		-1
Deferred income taxes	47		-32
Change in derivative instrument assets and liabilities	-27		37
Gain on disposition of assets	-3	[1]	-11	[1]
Changes in certain assets and liabilities	'		'
Inventories	-138		-89
Receivables, other than energy marketing	335		359
Energy marketing receivables and trade payables, net	183		98
Income and miscellaneous taxes	-113		75
Trade payables, other than energy marketing	-81		-20
Accrued/deferred natural gas costs	-65		14
Other, net	37		82
Net cash flow (used in) provided by operating activities of discontinued operations	-10		20
Net cash flow provided by operating activities	874		1,070
Cash flows from investing activities	'		'
Expenditures for property, plant and equipment	-543	[1]	-526	[1]
Acquisitions of assets	'		-154
Disposition of assets	225		12
Other	47		16
Net cash flow used in investing activities of discontinued operations	-13		-9
Net cash flow used in investing activities	-284		-661
Cash flows from financing activities	'		'
Net repayments of commercial paper	-490		-545
Dividends paid on common shares	-175		-166
Distribution to noncontrolling interest	-17		-17
Payment of senior notes	'		-225
Issuance of senior notes	'		494
Contribution from noncontrolling interest	'		22
Other, net	19		28
Net cash flow used in financing activities	-663		-409
Net decrease in cash and cash equivalents - continuing operations	-50		-11
Net (decrease) increase in cash and cash equivalents - discontinued operations	-23		11
Cash and cash equivalents (including held for sale) at beginning of period	105		131
Cash and cash equivalents (including held for sale) at end of period	32		131
Less cash and cash equivalents held for sale at end of period	'		34
Cash and cash equivalents (excluding held for sale) at end of period	32		97
Cash paid during the period for	'		'
Interest	150		138
Income taxes	317		90
Non cash financing transaction	'		'
Refinancing of gas facility revenue bonds	'		$200
[1]	Amounts revised and include prior period adjustments. See Note 13 for additional information.

Note_1_Organization_and_Basis_

Note 1 - Organization and Basis of Presentation	9 Months Ended
	Sep. 30, 2014
Disclosure Text Block [Abstract]	'
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]	'
	Note 1 - Organization and Basis of Presentation
	General
	AGL Resources Inc. is an energy services holding company that conducts substantially all of its operations through its subsidiaries. Unless the context requires otherwise, references to “we,” “us,” “our,” the “company,” or “AGL Resources” mean consolidated AGL Resources Inc. and its subsidiaries.
	The December 31, 2013, Condensed Consolidated Statement of Financial Position data was derived from our revised audited consolidated financial statements filed on November 7, 2014 but does not include all disclosures required by GAAP. We have prepared the accompanying unaudited Condensed Consolidated Financial Statements under the rules and regulations of the SEC. In accordance with such rules and regulations, we have condensed or omitted certain information and notes normally included in financial statements prepared in conformity with GAAP. Our unaudited Condensed Consolidated Financial Statements reflect all adjustments of a normal recurring nature that are, in the opinion of management, necessary for a fair presentation of our financial results for the interim periods. These unaudited Condensed Consolidated Financial Statements should be read in conjunction with our Consolidated Financial Statements and related notes included in Item 8 of our 2013 Form 10-K/A filed on November 7, 2014.
	Due to the seasonal nature of our business and other factors, our results of operations and our financial condition for the periods presented are not necessarily indicative of the results of operations or financial condition to be expected for or as of any other period.
	Basis of Presentation
	Our unaudited Condensed Consolidated Financial Statements include our accounts, the accounts of our wholly owned subsidiaries, the accounts of our majority owned or otherwise controlled subsidiaries and the accounts of our consolidated VIE for which we are the primary beneficiary. For unconsolidated entities that we do not control, but exercise significant influence over, we use the equity method of accounting and our proportionate share of income or loss is recorded on the unaudited Condensed Consolidated Statements of Income. See Note 9 for additional information. We have eliminated intercompany profits and transactions in consolidation except for intercompany profits where recovery of such amounts is probable under the affiliates’ rate regulation process.
	On September 1, 2014, we closed on the sale of Tropical Shipping, which historically operated within our cargo shipping segment. The assets and liabilities of these businesses are classified as held for sale on the unaudited Condensed Consolidated Statements of Financial Position, and the financial results of these businesses are reflected as discontinued operations on the unaudited Condensed Consolidated Statements of Income. Amounts shown in the following notes, unless otherwise indicated, exclude assets held for sale and discontinued operations. Cargo shipping also included our investment in Triton, which was not part of the sale and has been reclassified into our “other” segment. See Note 12 for additional information.
	In the third quarter of 2014, we revised our financial statements and other affected disclosures for items related to the recognition of revenues for certain of our regulatory infrastructure programs and the amortization of our intangible assets. On November 7, 2014, we filed an amended Form 10-K/A revising certain prior period information with respect to our Annual Report on Form 10-K for the year ended December 31, 2013. See Note 13 for additional information.
	We previously disclosed in our Form 10-K/A that the revisions did not impact any incentive compensation that was based on our results for 2013, 2012 and 2011. However, subsequent to the filing of our Form 10-K/A, we determined that for 2011, had the underlying accounting originally reflected the distinction between regulatory accounting principles and GAAP, certain long-term incentives that were based on our results for the performance period ended December 31, 2011, would not have been awarded. Specifically, in February 2012, based upon results for the performance period ended December 31, 2011, we would not have awarded officers (as defined for purposes of Section 16 of the Securities Exchange Act of 1934, as amended) (1) performance cash unit awards with an aggregate value of approximately $1 million and (2) a total of 37,290 shares of restricted stock. Management has evaluated this item in relation to its previously filed Form 10-K/A and materiality conclusions under Staff Accounting Bulletin No. 99 and has concluded that it does not change its prior materiality conclusion.

Note_2_Significant_Accounting_

Note 2 - Significant Accounting Policies and Methods of Application	9 Months Ended
	Sep. 30, 2014
Accounting Policies [Abstract]	'
Significant Accounting Policies [Text Block]	'
	Note 2 - Significant Accounting Policies and Methods of Application
	Our accounting policies are described in Note 2 to our Consolidated Financial Statements and related notes included in Item 8 of our 2013 Form 10-K/A. Other than as described in Note 13, there were no significant changes to our accounting policies during the nine months ended September 30, 2014.
	Use of Accounting Estimates
	The preparation of our financial statements in conformity with GAAP requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses and the related disclosures. Our estimates are based on historical experience and various other assumptions that we believe to be reasonable under the circumstances. Our estimates may involve complex situations requiring a high degree of judgment either in the application and interpretation of existing literature or in the development of estimates that impact our financial statements. The most significant estimates relate to our rate-regulated subsidiaries, uncollectible accounts and other allowances for contingent losses, goodwill and other intangible assets, retirement plan benefit obligations, derivative and hedging activities and provisions for income taxes. We evaluate our estimates on an ongoing basis, and our actual results could differ from our estimates.
	Cash and Cash Equivalents
	Our cash and cash equivalents primarily consist of cash on deposit, money market accounts and certificates of deposit held by domestic subsidiaries with original maturities of three months or less. At December 31, 2013, and September 30, 2013, there were $24 million and $34 million, respectively, of cash and cash equivalents held by Tropical Shipping that were excluded from cash and cash equivalents within our unaudited Condensed Consolidated Statements of Financial Position and included in assets held for sale. For more information on the sale of Tropical Shipping, see Note 12.
	Energy Marketing Receivables and Payables
	Our wholesale services segment provides services to retail and wholesale marketers and utility and industrial customers. These customers, also known as counterparties, utilize netting agreements that enable our wholesale services segment to net receivables and payables by counterparty upon settlement. Wholesale services also nets across product lines and against cash collateral, provided the master netting and cash collateral agreements include such provisions. While the amounts due from, or owed to, wholesale services’ counterparties are settled net, they are recorded on a gross basis in our unaudited Condensed Consolidated Statements of Financial Position as energy marketing receivables and energy marketing payables.
	Our wholesale services segment has trade and credit contracts that contain minimum credit rating requirements. These credit rating requirements typically give counterparties the right to suspend or terminate credit if our credit ratings are downgraded to non-investment grade status. Under such circumstances, wholesale services would need to post collateral to continue transacting business with some of its counterparties. To date, our credit ratings have exceeded the minimum requirements. As of September 30, 2014 and 2013, and December 31, 2013, the collateral that wholesale services would have been required to post if our credit ratings had been downgraded to non-investment grade status would not have had a material impact to our consolidated results of operations, cash flows or financial condition. If such collateral were not posted, wholesale services’ ability to continue transacting business with these counterparties would be negatively impacted.
	Inventories
	For our regulated utilities, except Nicor Gas, our natural gas inventories and the inventories we hold for Marketers in Georgia are carried at cost on a WACOG basis. Nicor Gas’ inventory is carried at cost on a LIFO basis. In Georgia’s competitive environment, Marketers sell natural gas to firm end-use customers at market-based prices. Part of the unbundling process, which resulted from deregulation and provides this competitive environment, is the assignment to Marketers of certain pipeline services that Atlanta Gas Light has under contract. On a monthly basis, Atlanta Gas Light assigns the majority of the pipeline storage services that it has under contract to Marketers, along with a corresponding amount of inventory. Atlanta Gas Light also retains and manages a portion of its pipeline storage assets and related natural gas inventories for system balancing and to serve system demand. See Note 10 for information regarding a regulatory filing by Atlanta Gas Light related to natural gas inventory.
	Our natural gas inventories at our retail operations, wholesale services and midstream operations segments carry inventory at the lower of cost or market value, where cost is determined on a WACOG basis. For these segments, we evaluate the weighted average cost of their natural gas inventories against market prices to determine whether any declines in market prices below the WACOG are other than temporary. For any declines considered to be other than temporary, we record adjustments to reduce the weighted average cost of the natural gas inventory to market value. For the three and nine months ended September 30, 2014, we recorded $5 million and $11 million, respectively, total LOCOM adjustment to reduce the value of our inventories to market value and $1 million and $9 million, respectively, for the three and nine months ended September 30, 2013. Additionally, we have $19 million of inventory at wholesale services that is currently inaccessible due to operational issues at a third party storage facility. The owner of the storage facility is working to resolve these issues. While we expect this inventory to be fully recovered, the timing of withdrawal of this gas may be impacted by the operational issues.
	At midstream operations, mechanical integrity tests and engineering studies are periodically performed on the storage facilities in accordance with certain state regulatory requirements. However, such tests may be performed in advance of such state requirements for operational purposes. During 2014, an engineering study and mechanical integrity tests were performed at one of our storage facilities, identifying a lower amount of working gas capacity that is the result of naturally occurring shrinkage of the storage caverns. Further, based on the lower capacity and an analysis of the volume of natural gas stored in the facility, we recorded natural gas costs to true-up the amount of retained fuel at this facility in the amount of $10 million for the nine months ended September 30, 2014. Our other storage facilities at midstream operations were not impacted.
	Fair Value Measurements
	We have financial and nonfinancial assets and liabilities subject to fair value measurement. The financial assets and liabilities measured and carried at fair value include cash and cash equivalents, and derivative assets and liabilities. The carrying values of receivables, short- and long-term investments, accounts payable, short-term debt, other current assets and liabilities, and accrued interest approximate fair value. Our nonfinancial assets and liabilities include pension and other retirement benefits, which are presented in Note 4 to our Consolidated Financial Statements and in related notes included in Item 8 of our 2013 Form 10-K/A.
	As defined in the authoritative guidance related to fair value measurements and disclosures, fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We utilize market data or assumptions that market participants would use in valuing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable. We primarily apply the market approach for recurring fair value measurements to utilize the best available information. Accordingly, we use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. We classify fair value balances based on the observance of those inputs in accordance with the fair value hierarchy.
	Derivative Instruments
	The fair value of the natural gas and weather derivative instruments that we use to manage exposures arising from changing natural gas prices and weather risk reflects the estimated amounts that we would receive or pay to terminate or close the contracts at the reporting date, taking into account the current unrealized gains or losses on open contracts. We use external market quotes and indices to value substantially all of our derivative instruments. See Note 4 and Note 5 for additional derivative disclosures.
	Property, Plant and Equipment
	On April 11, 2014, we entered into two arrangements associated with the Dalton Pipeline. The first was a construction and ownership agreement through which we will have a 50% undivided ownership interest in the 106 mile Dalton Pipeline that will be constructed in Georgia and serve as an extension of the Transco natural gas pipeline system into northwest Georgia. We also entered into an agreement to lease our 50% undivided ownership in the Dalton Pipeline once it is placed in-service. The lease payments to be received are $26 million annually for an initial term of 25 years. The lessee will be responsible for maintaining the pipeline during the lease term and for providing service to transportation customers under its FERC regulated tariff. Engineering design work has commenced and construction is expected to begin in the second quarter of 2016 with a targeted completion date in the second quarter of 2017. The capacity from this pipeline will further enhance system reliability as well as provide access to a more diverse supply of natural gas.
	Goodwill
	In 2014, we completed an engineering study at our midstream operations storage facilities that indicated a reduced forecast of working gas capacity from what was projected when our 2013 annual goodwill impairment analysis was performed during the fourth quarter of 2013. Given that the 2013 annual goodwill impairment test indicated that the estimated fair value of this reporting unit exceeded its carrying amount by less than 5%, we considered this reduced storage capacity as an indicator of potential impairment and accordingly conducted an interim goodwill impairment analysis during the first quarter of 2014.
	The estimated fair value of this reporting unit was determined utilizing the income approach, which estimated the fair value based upon the present value of estimated future cash flows. The forecasts used in the income approach, which were updated during the first quarter of 2014 to reflect the contracting activity that occurred during the quarter, assume discrete period revenue growth through fiscal 2022 to reflect the recovery of subscription rates, stabilization of earnings and establishment of a reasonable base year that was used to estimate the terminal value in the valuation model. Consistent with our 2013 annual goodwill impairment testing, we assumed a long-term earnings growth rate in the terminal year of 2.5%, which we believe is appropriate given the current economic and industry-specific expectations. As of the valuation date, we utilized a discount rate of 7.0%, which we believe is appropriate as it reflects the relative risk and the time value of money, and is consistent with the peer group of this reporting unit as well as the discount rates that were utilized in our 2013 annual goodwill impairment tests.
	Our interim goodwill impairment test assumed a cash flow forecast providing for growth over the next eight years. This forecast indicated that the estimated fair value of this reporting unit continues to exceed its carrying amount with a cushion of less than 10%. However, continued declines in capacity or subscription rates, reductions to our cash flow forecasts, a sustained period at the current subscription rates or other changes to the assumptions and factors used in this analysis may result in a future failure of step one of the goodwill impairment test and require us to proceed to step two of the goodwill impairment test in a future period.
	The risk of impairment of the underlying long-lived assets is not estimated to be significant as the assets have long remaining useful lives, and authoritative guidance requires such assets to be tested for impairment on the basis of undiscounted cash flows over their remaining useful lives. We will continue to monitor this reporting unit for potential impairment. Our goodwill balances by segment as of September 30, 2014, and December 31, 2013, and changes in the amount of goodwill for the nine months ended September 30, 2013, are provided in the following table.
	In millions		Distribution Operations			Retail Operations		Midstream Operations			Consolidated
	31-Dec-12		$	1,640		$	122	$	14		$	1,776
	2013 acquisitions			-			46		-			46
	September 30, 2013 (1)		$	1,640		$	168	$	14		$	1,822
	December 31, 2013 (1)		$	1,640		$	173	$	14		$	1,827
	30-Sep-14		$	1,640		$	173	$	14		$	1,827
	-1	Excludes goodwill at Tropical Shipping which is classified as held for sale. See Note 12 for additional information.
	Other Income
	Our other income is detailed in the following table.
			Three months ended					Nine months ended
			September 30,					September 30,
	In millions		2014			2013		2014			2013
	Equity method investment income (1)		$	2		$	3	$	6		$	8
	AFUDC - equity			1			3		2			8
	Other, net			-			1		-			2
	Total other income		$	3		$	7	$	8		$	18
		-1	For more information on our equity method investment income, see Note 9.
	Earnings Per Common Share
	We compute basic earnings per common share attributable to AGL Resources Inc. common shareholders by dividing our net income attributable to AGL Resources Inc. by the daily weighted average number of common shares outstanding. Diluted earnings per common share attributable to AGL Resources Inc. common shareholders reflect the potential reduction in earnings per common share attributable to AGL Resources Inc. common shareholders that occurs when potentially dilutive common shares are added to common shares outstanding.
	We derive our potentially dilutive common shares by calculating the number of shares issuable under restricted stock, restricted stock units and stock options award programs. The vesting of certain shares of the restricted stock and restricted stock units depends on the satisfaction of defined performance and/or time-based criteria. The future issuance of shares underlying the outstanding stock options depends on whether the market price of the common shares underlying the options exceeds the respective exercise prices of the stock options. The following table shows the calculation of our diluted shares attributable to AGL Resources Inc. common shareholders for the periods presented, as if performance units currently earned under the plan ultimately vest and as if stock options currently exercisable at prices below the average market prices are exercised.
			Three months ended					Nine months ended
			September 30,					September 30,
	In millions (except per share amounts)		2014			2013 (1)		2014 (1)			2013 (1)
	Income from continuing operations (2)		$	23		$	24	$	414		$	217
	(Loss) income from discontinued operations, net of tax (3)			(31	)		1		(80	)		1
	Net (loss) income attributable to AGL Resources Inc.		$	(8	)	$	25	$	334		$	218
	Denominator:
	Basic weighted average number of common shares outstanding (4)			119			118.2		118.8			117.8
	Effect of dilutive securities			0.4			0.3		0.4			0.3
	Diluted weighted average number of common shares outstanding			119.4			118.5		119.2			118.1
	Basic earnings (loss) per common share
	From continuing operations		$	0.19		$	0.2	$	3.48		$	1.85
	From discontinued operations			(0.25	)		0.01		(0.67	)		0.01
	Basic (loss) earnings per common share attributable to AGL Resources Inc. common shareholders		$	(0.06	)	$	0.21	$	2.81		$	1.86
	Diluted earnings (loss) per common share
	From continuing operations		$	0.19		$	0.2	$	3.47		$	1.84
	From discontinued operations			(0.25	)		0.01		(0.67	)		0.01
	Diluted (loss) earnings per common share attributable to AGL Resources Inc. common shareholders		$	(0.06	)	$	0.21	$	2.8		$	1.85
	-1	Amounts revised and or include prior period adjustments. See Note 13 for additional information.
	-2	Excludes net income attributable to the noncontrolling interest.
	-3	For additional information on our discontinued operations, see Note 12.
	-4	Daily weighted average shares outstanding.
Sale of Compass Energy
On May 1, 2013, we sold Compass Energy, a non-regulated retail natural gas business supplying commercial and industrial customers, which was part of our wholesale services segment. We received an initial cash payment of $12 million, which resulted in an $11 million pre-tax gain ($5 million net of tax) for the nine months ended September 30, 2013. Under the terms of the purchase and sale agreement, we were eligible to receive contingent cash consideration up to $8 million with a guaranteed minimum receipt of $3 million that was recognized during 2013. The remaining $5 million of contingent cash consideration was to be received from the buyer annually over a five-year earn-out period based upon the financial performance of Compass Energy. In the third quarter of 2014, we negotiated with the buyer to settle the future earn-out payments and we received $4 million, resulting in the recognition of a $3 million gain. We have a five year agreement to supply natural gas to our former customers. Accordingly, as a result of our continued involvement, the sale of Compass Energy did not meet the criteria for treatment as a discontinued operation.
Accounting Developments
On April 10, 2014, the FASB issued authoritative guidance related to reporting discontinued operations. The guidance generally raises the threshold for disposals to qualify as discontinued operations and requires new disclosures of both discontinued operations and certain other material disposals that do not meet the definition of a discontinued operation. The guidance will be effective for us prospectively beginning January 1, 2015. It is not expected to have a material impact on our consolidated financial statements, and it will have no impact on our accounting for the sale of Tropical Shipping.
On May 28, 2014, the FASB issued an update to authoritative guidance related to revenue from contracts with customers. The update replaces most of the existing guidance with a single set of principles for recognizing revenue from contracts with customers. The guidance will be effective for us beginning January 1, 2017. Early adoption is not permitted. The new guidance must be applied retrospectively to each prior period presented or via a cumulative effect upon the date of initial application. We have not yet determined the impact of this new guidance, nor have we selected a transition method.
On June 19, 2014, the FASB issued an update to authoritative guidance related to accounting for share-based payments when the terms of an award provide that a performance target could be achieved after the requisite service period. The guidance will be effective for us beginning January 1, 2016, and will have no material impact on our consolidated financial statements for our existing share-based plans.

Note_3_Regulated_Operations

Note 3 - Regulated Operations	9 Months Ended
	Sep. 30, 2014
Regulatory Assets and Liabilities Disclosure [Abstract]	'
Schedule of Regulatory Assets and Liabilities [Text Block]	'
	Note 3 - Regulated Operations
	We account for the financial effects of regulation in accordance with authoritative guidance related to regulated entities whose rates are designed to recover the costs of providing service. In accordance with this guidance, incurred costs and estimated future expenditures that would otherwise be charged to expense in the current period are capitalized as regulatory assets when it is probable that such costs or expenditures will be recovered in rates in the future. Similarly, we recognize regulatory liabilities when it is probable that regulators will require customer refunds through future rates or when revenue is collected from customers for estimated expenditures that have not yet been incurred. Generally, regulatory assets are amortized into expense, and regulatory liabilities are amortized into income over the period authorized by the regulatory commissions. The following table summarizes our regulatory assets and liabilities as of the dates presented.
	In millions		September 30,			December 31,			September 30,
			2014			2013 (1)			2013 (1)
	Regulatory assets
	Recoverable ERC		$	41		$	45		$	30
	Recoverable pension and retiree welfare benefit costs			9			9			19
	Recoverable seasonal rates			9			10			9
	Deferred natural gas costs			3			1			-
	Other			43			49			29
	Total regulatory assets - current			105			114			87
	Recoverable ERC			363			433			456
	Recoverable pension and retiree welfare benefit costs			91			99			183
	Long-term debt fair value adjustment			76			82			84
	Recoverable regulatory infrastructure program costs (1)			62			55			78
	Other			45			36			44
	Total regulatory assets - long-term			637			705			845
	Total regulatory assets		$	742		$	819		$	932
	Regulatory liabilities
	Bad debt over collection		$	31		$	41		$	37
	Accrued natural gas costs			29			92			104
	Accumulated removal costs			27			27			17
	Other			31			23			16
	Total regulatory liabilities - current			118			183			174
	Accumulated removal costs			1,499			1,445			1,448
	Regulatory income tax liability			26			27			26
	Unamortized investment tax credit			23			26			26
	Bad debt over collection			7			17			20
	Other			12			3			4
	Total regulatory liabilities - long-term			1,567			1,518			1,524
	Total regulatory liabilities		$	1,685		$	1,701		$	1,698
		-1	Amounts revised for prior period adjustments. See Note 13 for additional information.
	Base rates are designed to provide the opportunity for both a recovery of cost and a return on investment during the period rates are in effect. As such, all of our regulatory assets recoverable through base rates are subject to review by the respective state regulatory commission during future rate proceedings. We believe that we will be able to recover such costs consistent with our historical recoveries.
	Unrecognized Ratemaking Amounts We have authorized unrecognized ratemaking amounts that are not reflected within our unaudited Condensed Consolidated Statements of Financial Position as indicated in the following table. These amounts are primarily composed of an allowed equity rate of return on assets associated with certain of our regulatory infrastructure programs. These amounts will be recognized as revenues in our financial statements in the periods they are collected in rates from our customers. For additional information, see Note 13.
	In millions
	30-Sep-14		$	118
	31-Dec-13		$	93
	30-Sep-13		$	86
	Natural Gas Costs We charge our utility customers for natural gas consumed using natural gas cost recovery mechanisms established by the state regulatory agencies. Under these mechanisms, all prudently incurred natural gas costs are passed through to customers without markup, subject to regulatory review. We defer or accrue the difference between the actual cost of gas and the amount of commodity revenue earned in a given period, such that no operating margin is recognized related to these costs. The deferred or accrued amount is either billed or refunded to our customers prospectively through adjustments to the commodity rate. Deferred natural gas costs are reflected as regulatory assets and accrued natural gas costs are reflected as regulatory liabilities. The following table illustrates the change in net position of these costs from September 30, 2013 to September 30, 2014.
	In millions		30-Sep-14			30-Sep-13			Change
	Deferred natural gas costs		$	3		$	-		$	3
	Accrued natural gas costs			(29	)		(104	)		75
	Total (1)		$	(26	)	$	(104	)	$	78
		-1	The $78 million change resulted from increased natural gas prices during the first nine months of 2014 compared to the first nine months of 2013, primarily driven by colder weather experienced in 2014.
	Environmental Remediation Costs We are subject to federal, state and local laws and regulations governing environmental quality and pollution control that require us to remove or remedy the effect on the environment of the disposal or release of specified substances at our current and former operating sites, substantially all of which is related to our MGP sites. The ERC assets and liabilities are associated with our distribution operations segment and remediation costs are generally recoverable from customers through rate mechanisms approved by regulators. Accordingly, both costs incurred to remediate the former MGP sites, plus the future estimated cost recorded as liabilities, net of amounts previously collected, are recognized as a regulatory asset until recovered from customers.
	Our ERC liabilities are estimates of future remediation costs for investigation and cleanup of our current and former operating sites that are contaminated. These estimates are based on conventional engineering estimates and the use of probabilistic models of potential costs when such estimates cannot be made, on an undiscounted basis. As cleanup options and plans mature and cleanup contracts are entered into, we are increasingly able to provide conventional engineering estimates of the likely costs of many elements of the remediation program. These estimates contain various engineering assumptions, which we refine and update on an ongoing basis. These liabilities do not include other potential expenses, such as unasserted property damage claims, personal injury or natural resource damage claims, legal expenses or other costs for which we may be held liable but for which we cannot reasonably estimate an amount. The following table provides additional information on the costs related to remediation of our current and former operating sites as of September 30, 2014 and reflects changes in estimates since December 31, 2013.
	In millions		Probabilistic model cost estimates			Engineering			Amount			Expected costs over next 12 months
						estimates			recorded
	Illinois		$	205-462		$	46		$	244		$	41
	New Jersey			107-174			16			122			16
	Georgia and Florida			66-106			9			77			17
	North Carolina (1)			n/a			11			11			8
	Total		$	378-742		$	82		$	454	-2	$	82
		-1	We have no regulatory recovery mechanisms for the site in North Carolina. Therefore, there is no amount included within our regulatory assets and changes in estimated costs are recognized in income in the period of change.
		-2	Increase of $7 million from December 31, 2013, primarily relates to a scope increase required by the Georgia Environmental Protection Division for a site in Georgia and an adjustment for a site in Florida. This was partially offset by a decrease for a site in New Jersey where remediation is almost complete.
	In July 2014, we reached a $77 million settlement with an insurance company for environmental claims relating to potential contamination at several of our MGP sites in New Jersey and North Carolina. The terms of the settlement required the $77 million to be paid in two installments. We received the first $45 million installment in the third quarter of 2014 and this payment was primarily recorded as a reduction to our recoverable ERC regulatory asset. The remaining $32 million is due in the third quarter of 2015. We will file for approval with the New Jersey BPU to utilize the insurance proceeds related to the New Jersey sites to reduce the ERC expenditures that otherwise would have been recovered from our customers in future periods. As such, the settlement, once approved, is expected to reduce our recoverable ERC regulatory asset and have a favorable impact on the rates for our Elizabethtown Gas customers.

Note_4_Fair_Value_Measurements

Note 4 - Fair Value Measurements	9 Months Ended
	Sep. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Disclosures [Text Block]	'
	Note 4 - Fair Value Measurements
	The methods used to determine the fair values of our assets and liabilities are described within Note 2.
	Derivative Instruments
	The following table summarizes, by level within the fair value hierarchy, our derivative assets and liabilities that were carried at fair value on a recurring basis in our unaudited Condensed Consolidated Statements of Financial Position as of the dates presented. See Note 5 for additional derivative instrument information.
			30-Sep-14					31-Dec-13					30-Sep-13
	In millions		Assets (1)		Liabilities			Assets (1)		Liabilities			Assets (1)		Liabilities
	Natural gas derivatives
	Quoted prices in active markets (Level 1)		$	4	$	(72	)	$	6	$	(79	)	$	4	$	(52	)
	Significant other observable inputs (Level 2)			57		(51	)		67		(79	)		60		(41	)
	Netting of cash collateral			49		76			43		78			45		49
	Total carrying value (2) (3)		$	110	$	(47	)	$	116	$	(80	)	$	109	$	(44	)
		-1	Balances of $3 million at September 30, 2014, December 31, 2013 and September 30, 2013, associated with certain weather derivatives have been excluded, as they are accounted for based on intrinsic value rather than fair value.
		-2	There were no significant unobservable inputs (Level 3) for any of the dates presented.
		-3	There were no significant transfers between Level 1, Level 2 or Level 3 for any of the dates presented.
	Debt
	Our long-term debt is recorded at amortized cost, with the exception of Nicor Gas’ first mortgage bonds, which are recorded at their acquisition date fair value. The fair value adjustment of Nicor Gas’ first mortgage bonds is being amortized over the lives of the bonds. The following table lists the carrying amount and fair value of our long-term debt as of the dates presented.
	In millions		30-Sep-14		31-Dec-13			30-Sep-13
	Long-term debt carrying amount		$	3,805	$	3,813		$	3,816
	Long-term debt fair value (1)			4,165		3,956			4,024
		-1	Fair value determined using Level 2 inputs.

Note_5_Derivative_Instruments

Note 5 - Derivative Instruments	9 Months Ended
	Sep. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Instruments and Hedging Activities Disclosure [Text Block]	'
	Note 5 - Derivative Instruments
	A description of our objectives and strategies for using derivative instruments, related accounting policies and methods used to determine their fair values are described in Note 2 to our Consolidated Financial Statements and related notes included in Item 8 of our 2013 Form 10-K/A. See Note 4 for additional fair value disclosures.
	Certain of our derivative instruments contain credit risk-related or other contingent features that could require us to post collateral in the normal course of business when our financial instruments are in net liability positions. As of September 30, 2014, for agreements with such features, derivative instruments with liability fair values for which we had posted no collateral to our counterparties totaled $47 million. The maximum collateral that could be required with these features is $10 million. For more information, see “Energy Marketing Receivables and Payables” in Note 2, which also have credit risk-related or other contingent features. Our derivative instrument activities are included within operating cash flows as an increase (decrease) to net income of $(27) million and $37 million for the nine months ended September 30, 2014 and 2013, respectively. See Note 4 for additional derivative instrument information. The following table summarizes the various ways in which we account for our derivative instruments and the impact on our unaudited Condensed Consolidated Financial Statements.
		Recognition and Measurement
	Accounting Treatment	Statements of Financial Position	Statements of Income
	Cash flow hedge	Derivative carried at fair value	Ineffective portion of the gain or loss on the derivative instrument is recognized in earnings
		Effective portion of the gain or loss on the derivative instrument is reported initially as a component of accumulated OCI (loss)	Effective portion of the gain or loss on the derivative instrument is reclassified out of accumulated OCI (loss) and into earnings when the hedged transaction affects earnings
	Fair value hedge	Derivative carried at fair value	Gains or losses on the derivative instrument and the hedged item are recognized in earnings. As a result, to the extent the hedge is effective, the gains or losses will offset and there is no impact on earnings. Any hedge ineffectiveness will impact earnings
		Changes in fair value of the hedged item are recorded as adjustments to the carrying amount of the hedged item
	Not designated as hedges	Derivative carried at fair value	Realized and unrealized gains or losses on the derivative instrument are recognized in earnings
		Distribution operations’ gains and losses on derivative instruments are deferred as regulatory assets or liabilities until included	Gains or losses on these derivative instruments are ultimately included in billings to customers and are recognized in cost of goods sold in the same period as the related revenues
		in cost of goods sold
	Quantitative Disclosures Related to Derivative Instruments
	As of the dates presented, our derivative instruments were comprised of both long and short natural gas positions. A long position is a contract to purchase natural gas, and a short position is a contract to sell natural gas. We had a net long natural gas contracts position outstanding in the following quantities:
	In Bcf (1)		September 30,				December 31,				September 30,
			2014 (2)				2013				2013
	Cash flow hedges			7				6				3
	Not designated as hedges			97				183				40
	Total volumes			104				189				43
	Short position			(2,756	)			(2,622	)			(2,788	)
	Long position			2,860				2,811				2,831
	Net long position			104				189				43
	-1	Volumes related to Nicor Gas exclude variable-priced contracts, which are carried at fair value, but whose fair values are not directly impacted by changes in commodity prices.
	-2	Approximately 98% of these contracts have durations of 2 years or less and the remaining 2% expire between 2 and 5 years.
	Derivative Instruments in our Unaudited Condensed Consolidated Statements of Financial Position
	In accordance with regulatory requirements, gains and losses on derivative instruments used to hedge natural gas purchases for customer use at distribution operations are reflected in accrued natural gas costs within our Consolidated Statements of Financial Position until billed to customers. The following amounts deferred as a regulatory asset or liability on our unaudited Condensed Consolidated Statements of Financial Position represent the net realized gains (losses) related to these natural gas cost hedges for the periods presented.
			Three months ended								Nine months ended
			September 30,								September 30,
	In millions		2014				2013				2014				2013
	Nicor Gas		$	(4	)		$	(6	)		$	8			$	2
	Elizabethtown Gas			(1	)			(1	)			4				(5	)
	The following table presents the fair values and unaudited Condensed Consolidated Statements of Financial Position classifications of our derivative instruments as of the dates presented.
				September 30,								December 31,							September 30,
				2014								2013							2013
	In millions	Classification		Assets				Liabilities				Assets				Liabilities			Assets			Liabilities
	Designated as cash flow or fair value hedges
	Natural gas contracts	Current		$	2			$	(2	)		$	3			$	(1	)	$	6		$	(5	)
	Not designated as hedges
	Natural gas contracts	Current			834				(891	)			691				(761	)		445			(462	)
	Natural gas contracts	Long-term			78				(80	)			206				(220	)		143			(153	)
	Total				912				(971	)			897				(981	)		588			(615	)
	Gross amount of recognized assets and liabilities (1) (2)				914				(973	)			900				(982	)		594			(620	)
	Gross amounts offset in our unaudited Condensed Consolidated Statements of Financial Position (2)				(801	)			926				(781	)			902			(482	)		576
	Net amounts of assets and liabilities presented in our unaudited Condensed Consolidated Statements of Financial Position (3)			$	113			$	(47	)		$	119			$	(80	)	$	112		$	(44	)
	-1	The gross amounts of recognized assets and liabilities are netted within our unaudited Condensed Consolidated Statements of Financial Position to the extent that we have netting arrangements with the counterparties.
	-2	As required by the authoritative guidance related to derivatives and hedging, the gross amounts of recognized assets and liabilities above do not include cash collateral held on deposit in broker margin accounts of $125 million as of September 30, 2014, $121 million as of December 31, 2013, and $94 million as of September 30, 2013. Cash collateral is included in the “Gross amounts offset in our unaudited Condensed Consolidated Statements of Financial Position” line of this table.
	-3	At September 30, 2014, December 31, 2013, and September 30, 2013, we held letters of credit from counterparties that would offset, under master netting arrangements, an insignificant portion of these assets.
	Derivative Instruments in the UnauditedCondensed Consolidated Statements of Income
	The following table presents the impacts of our derivative instruments in our unaudited Condensed Consolidated Statements of Income for the periods presented.
			Three months ended								Nine months ended
			September 30,								September 30,
	In millions		2014				2013				2014				2013
	Designated as cash flow or fair value hedges
	Natural gas contracts - net gain reclassified from OCI into cost of goods sold		$	(1	)		$	(1	)		$	4			$	-
	Natural gas contracts - net gain reclassified from OCI into operation and maintenance expense			1				-				2				-
	Interest rate swaps - net loss reclassified from OCI into interest expense			-				1				-				(2	)
	Income tax benefit			-				-				(1	)			1
	Net of tax			-				-				5				(1	)
	Not designated as hedges (1)
	Natural gas contracts - net fair value adjustments recorded in operating revenues			(6	)			(14	)			(6	)			(16	)
	Natural gas contracts - net fair value adjustments recorded in cost of goods sold (2)			(1	)			-				-				(1	)
	Income tax benefit			2				5				2				7
	Net of tax			(5	)			(9	)			(4	)			(10	)
Total (losses) gains on derivative instruments		$	(5	)		$	(9	)		$	1			$	(11	)
	-1	Associated with the fair value of derivative instruments held at September 30, 2014 and 2013.
	-2	Excludes losses recorded in cost of goods sold associated with weather derivatives of $6 million and $3 million for the nine months ended September 30, 2014 and 2013, respectively.
Any amounts recognized in operating income related to ineffectiveness or due to a forecasted transaction that is no longer expected to occur were immaterial for the three and nine months ended September 30, 2014 and 2013. Our expected gains to be reclassified from OCI into cost of goods sold, operation and maintenance expense, interest expense and operating revenues and recognized in our unaudited Condensed Consolidated Statements of Income over the next 12 months are less than $1 million. These deferred gains and losses are related to natural gas derivative contracts associated with retail operations and Nicor Gas’ system use. The expected gains are based upon the fair values of these financial instruments at September 30, 2014. The effective portion of gains and losses on derivative instruments qualifying as cash flow hedges that were recognized in OCI during the periods is presented on our unaudited Condensed Consolidated Statements of Income. See Note 8 for these amounts.
There have been no other significant changes to our derivative instruments, as described in Note 2, Note 4 and Note 5 to our Consolidated Financial Statements and related notes included in Item 8 of our 2013 Form 10-K/A.

Note_6_Employee_Benefit_Plans

Note 6 - Employee Benefit Plans	9 Months Ended
	Sep. 30, 2014
Compensation and Retirement Disclosure [Abstract]	'
Pension and Other Postretirement Benefits Disclosure [Text Block]	'
	Note 6 - Employee Benefit Plans
	Pension Benefits
	We sponsor the AGL Resources Inc. Retirement Plan, a tax-qualified defined benefit retirement plan for our eligible employees, which is described in Note 6 to our Consolidated Financial Statements and related notes included in Item 8 of our 2013 Form 10-K/A. Following are the components of our pension costs for the periods indicated.
		Three months ended September 30,						Nine months ended September 30,
	In millions	2014			2013			2014			2013
	Service cost	$	6		$	7		$	18		$	22
	Interest cost		12			11			35			32
	Expected return on plan assets		(16	)		(16	)		(48	)		(47	)
	Net amortization of prior service cost		(1	)		-			(2	)		(1	)
	Recognized actuarial loss		5			9			16			26
	Net periodic pension benefit cost	$	6		$	11		$	19		$	32
	Welfare Benefits
	The benefits of our Health and Welfare Plan for Retirees and Inactive Employees of AGL Resources Inc. (AGL Welfare Plan) are described in Note 6 to our Consolidated Financial Statements and related notes included in Item 8 of our 2013 Form 10-K/A. Following are the components of our welfare costs for the periods indicated.
		Three months ended September 30,						Nine months ended September 30,
	In millions	2014			2013			2014			2013
	Service cost	$	1		$	1		$	2		$	2
	Interest cost		4			3			11			10
	Expected return on plan assets		(2	)		(1	)		(5	)		(4	)
	Net amortization of prior service cost		(1	)		(1	)		(2	)		(3	)
	Recognized actuarial loss		1			2			4			6
	Net periodic welfare benefit cost	$	3		$	4		$	10		$	11

Note_7_Debt_and_Credit_Facilit

Note 7 - Debt and Credit Facilities	9 Months Ended
	Sep. 30, 2014
Debt Disclosure [Abstract]	'
Debt Disclosure [Text Block]	'
	Note 7 - Debt and Credit Facilities
	The following table provides maturity dates, year-to-date weighted average interest rates and amounts outstanding for our various debt securities and facilities for the periods presented. We fully and unconditionally guarantee all debt issued by AGL Capital. For additional information on our debt, see Note 8 in our Consolidated Financial Statements and related notes in Item 8 of our 2013 Form 10-K/A.
						30-Sep-14								30-Sep-13
	Dollars in millions		Year(s) due			Weighted average interest rate (1)			Outstanding			Outstanding at December 31, 2013		Weighted average interest rate (1)			Outstanding
	Short-term debt
	Commercial paper - AGL Capital (2)			2014			0.3	%	$	292		$	857		0.4	%	$	680
	Commercial paper - Nicor Gas (2)			2014			0.2			389			314		0.3			152
	Total short-term debt						0.3	%	$	681		$	1,171		0.4	%	$	832
	Current portion of long-term debt			2015			5	%	$	200		$	-		-		$	-
	Long-term debt - excluding current portion
	Senior notes			2016-2043			5	%	$	2,625		$	2,825		5.1	%	$	2,825
	First mortgage bonds			2016-2038			5.6			500			500		5.6			500
	Gas facility revenue bonds			2022-2033			0.9			200			200		0.8			200
	Medium-term notes			2017-2027			7.8			181			181		7.8			181
	Total principal long-term debt						4.9	%		3,506			3,706		4.9	%		3,706
	Fair value adjustment of long-term debt (3)			n/a			n/a			83			91		n/a			94
	Unamortized debt premium, net			n/a			n/a			16			16		n/a			16
	Total non-principal long-term debt						n/a			99			107		n/a			110
	Total long-term debt								$	3,605		$	3,813				$	3,816
	Total debt								$	4,486		$	4,984				$	4,648
	-1	Interest rates are calculated based on the daily weighted average balance outstanding for the nine months ended September 30.
	-2	As of September 30, 2014, the effective interest rates on our commercial paper borrowings were 0.3% for AGL Capital and 0.2% for Nicor Gas.
	-3	See Note 4 for additional information on our fair value measurements.
	Commercial Paper Programs
	We maintain commercial paper programs at AGL Capital and Nicor Gas that consist of short-term, unsecured promissory notes used in conjunction with cash from operations to fund our seasonal working capital requirements. Working capital needs fluctuate during the year and are highest during the injection period in advance of the Heating Season. The Nicor Gas commercial paper program supports working capital needs at Nicor Gas, while all of our other subsidiaries and SouthStar participate in the AGL Capital commercial paper program. During the first nine months of 2014, our commercial paper maturities ranged from 1 to 108 days, and at September 30, 2014, remaining terms to maturity ranged from 1 to 24 days. Total borrowings and repayments netted to a payment of $490 million during the first nine months of 2014. For commercial paper issuances with original maturities over three months, borrowings and repayments were $50 million and $145 million, respectively, during the first nine months of 2014. During the three months ended September 30, 2014, we utilized a portion of the $225 million in proceeds from the sale of Tropical Shipping to reduce our commercial paper borrowings.
	Financial and Non-Financial Covenants
	The AGL Credit Facility and the Nicor Gas Credit Facility each include a financial covenant that requires us to maintain a ratio of total debt to total capitalization of no more than 70% at the end of any fiscal month. These ratios, as calculated in accordance with the debt covenants, include standby letters of credit and surety bonds and exclude accumulated OCI items related to non-cash pension adjustments, welfare benefits liability adjustments and accounting adjustments for cash flow hedges. Adjusting for these items, the following table contains our debt-to-capitalization ratios for the dates presented, which are below the maximum allowed.
			30-Sep-14			31-Dec-13			30-Sep-13
	AGL Credit Facility			53	%		57	%		56	%
	Nicor Gas Credit Facility			57	%		55	%		50	%
	The credit facilities contain certain non-financial covenants that, among other things, restrict liens and encumbrances, loans and investments, acquisitions, dividends and other restricted payments, asset dispositions, mergers and consolidations and other matters customarily restricted in such agreements.
	Default Provisions
	Our credit facilities and other financial obligations include provisions that, if not complied with, could require early payment or similar actions. The most important default events include the following:
		●	a maximum leverage ratio
		●	insolvency events and or nonpayment of scheduled principal or interest payments
		●	acceleration of other financial obligations
		●	change of control provisions
	We have no triggering events in our debt instruments that are tied to changes in our specified credit ratings or our stock price, and have not entered into any transaction that requires us to issue equity based on credit ratings or other triggering events. We were in compliance with all existing debt provisions and covenants, both financial and non-financial, for all periods presented.

Note_8_Equity

Note 8 - Equity	9 Months Ended
	Sep. 30, 2014
Stockholders' Equity Note [Abstract]	'
Stockholders' Equity Note Disclosure [Text Block]	'
	Note 8 - Equity
	Our OCI amounts are aggregated within our accumulated other comprehensive loss. The following table provides changes in the components of our accumulated other comprehensive loss balance, net of the related income tax effects.
			2014									2013
	In millions (1)		Cash flow			Retirement benefit plans			Total			Cash flow			Retirement benefit plans			Total
			hedges									hedges
	For the three months ended September 30
	As of beginning of period		$	-		$	(133	)	$	(133	)	$	(1	)	$	(208	)	$	(209	)
	OCI, before reclassifications			(2	)		-			(2	)		-			-			-
	Amounts reclassified from accumulated OCI			-			2			2			-			1			1
	Net current-period other comprehensive (loss) income			(2	)		2			-			-			1			1
	As of end of period		$	(2	)	$	(131	)	$	(133	)	$	(1	)	$	(207	)	$	(208	)
	For the nine months ended September 30
	As of beginning of period		$	1		$	(137	)	$	(136	)	$	(3	)	$	(215	)	$	(218	)
	OCI, before reclassifications			2			-			2			-			-			-
	Amounts reclassified from accumulated OCI			(5	)		6			1			2			8			10
	Net current-period other comprehensive (loss) income			(3	)		6			3			2			8			10
	As of end of period		$	(2	)	$	(131	)	$	(133	)	$	(1	)	$	(207	)	$	(208	)
		-1	All amounts are net of income taxes. Amounts in parentheses indicate increases to our accumulated other comprehensive loss.
	The following table provides details of the reclassifications out of accumulated other comprehensive loss and the impact on net income.
			Three months ended						Nine months ended
			September 30,						September 30,
	In millions (1)		2014			2013			2014			2013
	Cash flow hedges
	Cost of goods sold (natural gas contracts)		$	(1	)	$	(1	)	$	4		$	-
	Operation and maintenance expense (natural gas contracts)			1			-			2			-
	Interest expense (interest rate contracts)			-			1			-			(3	)
	Total before income tax			-			-			6			(3	)
	Income tax benefit			-			-			(1	)		1
	Total cash flow hedges			-			-			5			(2	)
	Retirement benefit plans
	Operation and maintenance expense (actuarial losses)(2)			(4	)		(6	)		(12	)		(19	)
	Operation and maintenance expense (prior service credits) (2)			-			2			1			4
	Total before income tax			(4	)		(4	)		(11	)		(15	)
	Income tax benefit			2			3			5			7
	Total retirement benefit plans			(2	)		(1	)		(6	)		(8	)
	Total reclassification for the period		$	(2	)	$	(1	)	$	(1	)	$	(10	)
		-1	Amounts in parentheses indicate reductions to our net income and accumulated other comprehensive loss. Except for retirement benefit plan amounts, the net income impacts are immediate.
		-2	Amortization of these accumulated other comprehensive loss components is included in the computation of net periodic benefit cost. See Note 6 for additional details about net periodic benefit cost.

Note_9_NonWholly_Owned_Entitie

Note 9 - Non-Wholly Owned Entities	9 Months Ended
	Sep. 30, 2014
Noncontrolling Interest [Abstract]	'
Noncontrolling Interest Disclosure [Text Block]	'
	Note 9 - Non-Wholly Owned Entities
	SouthStar, a joint venture owned by us and Piedmont, is our only significant VIE for which we are the primary beneficiary. This requires us to consolidate its assets, liabilities and statements of income. For additional information on SouthStar, see Note 10 to our Consolidated Financial Statements and related notes included in Item 8 of our 2013 Form 10-K/A. Earnings from SouthStar in 2014 and 2013 were allocated entirely in accordance with the ownership interests.
	Cash flows used in our investing activities include capital expenditures for SouthStar of $6 million for the nine months ended September 30, 2014, and $2 million for the nine months ended September 30, 2013. Cash flows used in our financing activities include SouthStar’s distribution to Piedmont for its portion of SouthStar’s annual earnings from the previous year. Generally, this distribution occurs in the first quarter of each fiscal year. For each of the nine months ended September 30, 2014 and 2013, SouthStar distributed $17 million to Piedmont. SouthStar’s creditors have no recourse to our general credit beyond our corporate guarantees that we have provided to SouthStar’s counterparties and natural gas suppliers. The following table provides additional information about SouthStar’s assets and liabilities as of the dates presented, which are consolidated within our unaudited Condensed Consolidated Statements of Financial Position.
			September 30, 2014 (1)								December 31, 2013 (1)							September 30, 2013 (1)
	In millions		Consolidated		SouthStar (2)			-3%			Consolidated		SouthStar (2)		-3%			Consolidated		SouthStar (2)		-3%
	Current assets		$	2,093	$	188			9	%	$	2,895	$	264		9	%	$	2,252	$	192		9	%
	Goodwill and intangible assets			1,957		127			6			1,972		133		7			1,974		136		7
	Long-term assets and other deferred debits			9,903		17			-			9,683		13		-			9,584		13		-
	Total assets		$	13,953	$	332			2	%	$	14,550	$	410		3	%	$	13,810	$	341		2	%
	Current liabilities		$	2,462	$	47			2	%	$	3,118	$	95		3	%	$	2,407	$	73		3	%
	Long-term liabilities and other deferred credits			7,689		-			-			7,819		-		-			7,897		-		-
	Total Liabilities			10,151		47			1			10,937		95		1			10,304		73		1
	Equity			3,802		285			7			3,613		315		9			3,506		268		8
	Total liabilities and equity		$	13,953	$	332			2	%	$	14,550	$	410		3	%	$	13,810	$	341		2	%
	-1	Amounts revised and include prior period adjustments. See Note 13 for additional information.
	-2	These amounts reflect information for SouthStar and exclude intercompany eliminations and the balances of our wholly owned subsidiary with an 85% ownership interest in SouthStar.
	-3	SouthStar’s percentage of the amount on our unaudited Condensed Consolidated Statements of Financial Position.
	The following table provides information on SouthStar’s operating revenues and operating expenses for the periods presented, which are consolidated within our unaudited Condensed Consolidated Statements of Income.
			Three months ended					Nine months ended
			September 30,					September 30,
	In millions		2014		2013			2014			2013
	Operating revenues		$	113	$	98		$	633		$	464
	Operating expenses
	Cost of goods sold			89		81			470			340
	Operation and maintenance			19		16			62			49
	Depreciation and amortization			3		2			8			3
	Taxes other than income taxes			-		-			1			1
	Total operating expenses			111		99			541			393
	Operating income (loss)		$	2	$	(1	)	$	92		$	71
	Equity Method Investments
	For more information about our equity method investments, see Note 10 to our Consolidated Financial Statements and related notes in Item 8 of our 2013 Form 10-K/A. The carrying amounts of our equity method investments within our unaudited Condensed Consolidated Statements of Financial Position were as follows:
			September 30,		December 31,			September 30,
	In millions		2014		2013			2013
	Triton		$	64	$	70		$	71
	Horizon Pipeline			14		15			15
	Other			2		1			9
	Total		$	80	$	86		$	95
	Income from our equity method investments is classified as other income in our unaudited Condensed Consolidated Statements of Income. The following table provides the income from our equity method investments for the periods presented.
			Three months ended					Nine months ended
			September 30,					September 30,
	In millions		2014		2013			2014			2013
	Triton (1)		$	2	$	3		$	5		$	7
	Other			-		-			1			1
		-1	Reported within our “other” segment. For more information, see Note 11.
	In the third quarter of 2014, we entered into two interstate pipeline joint ventures within our midstream operations segment as described below. The capacity from these joint ventures will further enhance system reliability as well as provide access to a more diverse supply of natural gas. We have concluded that, at present, both are VIEs. We are not considered the primary beneficiary and we have not consolidated the financial statements for these joint ventures in our unaudited Condensed Consolidated Financial Statements, because we share in the ability to direct the activities that most significantly impact their economic performance with their other member companies. We have accounted for our investment in these joint ventures using the equity method of accounting, and have classified the investment in other noncurrent assets in our unaudited Condensed Consolidated Statements of Financial Position.
	PennEast Pipeline On August 11, 2014, we entered into a joint venture to develop and operate a 108-mile natural gas pipeline between New Jersey and Pennsylvania with initial transportation capacity of 800,000 dekatherms per day, which may be expanded to 1.2 Bcf per day. Our current investment in PennEast Pipeline is less than $1 million and represents a 20% ownership interest, and is the maximum extent of our current exposure to loss. Construction is expected to begin in the first quarter of 2017 with a targeted completion date in the fourth quarter of 2017.
	Atlantic Coast Pipeline On September 2, 2014, we entered into a joint venture to develop and operate a 550-mile natural gas pipeline in North Carolina, Virginia, and West Virginia with initial transportation capacity of 1.5 Bcf per day, which may be expanded to 2.0 Bcf per day. Our current investment in Atlantic Coast Pipeline is less than $1 million and represents a 5% ownership interest, and is the maximum extent of our current exposure to loss. Construction is expected to begin in the second half of 2016 with a targeted completion date in the second half of 2018.

Note_10_Commitments_Guarantees

Note 10 - Commitments, Guarantees and Contingencies	9 Months Ended
	Sep. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies Disclosure [Text Block]	'
	Note 10 - Commitments, Guarantees and Contingencies
	We have incurred various contractual obligations and financial commitments in the normal course of our operating and financing activities that are reasonably likely to have a material effect on liquidity or the availability of capital resources. Contractual obligations include future cash payments required under existing contractual arrangements, such as debt and lease agreements. These obligations may result from both general financing activities and from commercial arrangements that are directly supported by related revenue-producing activities.
	In 2014, we entered into several unconditional purchase obligations in the ordinary course of business. These include capacity and supply agreements related to the Dalton Pipeline, PennEast Pipeline, Atlantic Coast Pipeline and wholesale services, which are reflected in the table below. In addition, other contracts in the ordinary course of business have expired or ended. The following table illustrates our expected future contractual payments under our obligations and other commitments as of September 30, 2014.
															2019 &
	In millions		Total		2014		2015		2016		2017		2018		thereafter
	Recorded contractual obligations:
	Long-term debt (1)		$	3,706	$	-	$	200	$	545	$	22	$	155	$	2,784
	Short-term debt			681		681		-		-		-		-		-
	Environmental remediation liabilities (2)			454		16		83		104		50		38		163
	Pipeline replacement program costs (2)			1		1		-		-		-		-		-
	Total		$	4,842	$	698	$	283	$	649	$	72	$	193	$	2,947
	Unrecorded contractual obligations and commitments(3) (8):
	Pipeline charges, storage capacity and gas supply (4)		$	3,837	$	304	$	564	$	292	$	185	$	174	$	2,318
	Interest charges (5)			2,798		36		179		171		147		146		2,119
	Operating leases (6)			207		11		35		31		24		18		88
	Asset management agreements (7)			31		2		9		8		6		4		2
	Standby letters of credit, performance/surety bonds (8)			27		9		17		1		-		-		-
	Other			9		1		3		3		1		1		-
	Total		$	6,909	$	363	$	807	$	506	$	363	$	343	$	4,527
		-1	Excludes the $77 million step up to fair value of first mortgage bonds, $16 million unamortized debt premium and $6 million interest rate swaps fair value adjustment. Includes current portion of long-term debt of $200 million, which matures in January 2015.
		-2	Includes charges recoverable through base rates or rate rider mechanisms.
		-3	In accordance with GAAP, these items are not reflected in our unaudited Condensed Consolidated Statements of Financial Position.
		-4	Includes charges recoverable through a natural gas cost recovery mechanism or alternatively billed to Marketers and demand charges associated with Sequent. The gas supply balance includes amounts for Nicor Gas and SouthStar gas commodity purchase commitments of 66 Bcf at floating gas prices calculated using forward natural gas prices as of September 30, 2014, and is valued at $271 million. As we do for other subsidiaries, we provide guarantees to certain gas suppliers for SouthStar in support of payment obligations.
		-5	Floating rate interest charges are calculated based on the interest rate as of September 30, 2014, and the maturity date of the underlying debt instrument. As of September 30, 2014, we have $42 million of accrued interest on our unaudited Condensed Consolidated Statements of Financial Position that will be paid in the next 12 months.
		-6	We have certain operating leases with provisions for step rent or escalation payments and certain lease concessions. We account for these leases by recognizing the future minimum lease payments on a straight-line basis over the respective minimum lease terms, in accordance with GAAP. However, this lease accounting treatment does not affect the future annual operating lease cash obligations as shown herein. Our operating leases are primarily for real estate.
		-7	Represent fixed-fee minimum payments for Sequent’s affiliated asset management agreements.
		-8	We provide guarantees to certain municipalities and other agencies and certain gas suppliers of SouthStar in support of payment obligations.
	We also are involved in legal or administrative proceedings before various courts and agencies with respect to general claims, taxes, environmental, gas cost prudence reviews and other matters. Although we are unable to determine the ultimate outcomes of these other contingencies, we believe that our financial statements appropriately reflect these amounts, including the recording of liabilities when a loss is probable and reasonably estimable. For more information on these matters, see Note 11 in our Consolidated Financial Statements and related notes in Item 8 of our 2013 Form 10-K/A.
	Contingencies and Guarantees
	Contingent financial commitments, such as financial guarantees, represent obligations that become payable only if certain predefined events occur. We have certain subsidiaries that enter into various financial and performance guarantees and indemnities providing assurance to third parties. We believe the likelihood of payment under our guarantees is remote. No liability has been recorded for such guarantees and indemnifications as the fair value was inconsequential at inception.
	Regulatory Matters
	On December 21, 2012, Atlanta Gas Light filed a petition with the Georgia Commission for approval to resolve a volumetric imbalance of natural gas related to Atlanta Gas Light’s use of retained storage assets to operationally balance the system for the benefit of the natural gas market. On September 11, 2014, we filed a stipulation that was entered between us, staff of the Georgia Commission and several marketers that include a resolution of the 4.6 Bcf imbalance over a five-year period from January 1, 2015 through December 31, 2019. Over the five-year period, discretionary funds available from the Universal Service Fund, which is controlled by the Georgia Commission, would be used to resolve 25% of the imbalance, or 1.15 Bcf of natural gas. Atlanta Gas Light would be obligated for 25% as well and we have recorded a reserve in our unaudited Condensed Consolidated Statements of Financial Position representing the future estimated cost to purchase the 1.15 Bcf of natural gas. Marketers would be obligated to resolve the remaining 50% of the imbalance, or 2.3 Bcf of natural gas. The Georgia Commission is expected to vote on the petition in December 2014. We are currently unable to predict the ultimate outcome.
	On August 7, 2014, staff of the Illinois Commission and the Citizens Utility Board (CUB) filed testimony in the 2003 gas cost prudence review disputing certain gas loan transactions offered by Nicor Gas under its Chicago Hub services requesting refunds of $18 million and $22 million, respectively. We have filed testimony in this proceeding disputing that any refund is due. Similar gas loan transactions were provided in other open review years. The resolution will ultimately be decided by the Illinois Commission. We are currently unable to predict the ultimate outcome and have recorded no liability for this matter.
	Environmental Matters
	We are subject to federal, state and local laws and regulations governing environmental quality and pollution control that require us to remove or remedy the effect on the environment of the disposal or release of specified substances at our current and former operating sites. See Note 3 for additional information.
	Litigation
	We are involved in litigation arising in the normal course of business. Although in some cases the company is unable to estimate the amount of loss reasonably possible in addition to any amounts already recognized, it is possible that the resolution of these contingencies, either individually or in aggregate, will require us to take charges against, or will result in reductions in, future earnings. Management believes that while the resolution of these contingencies, whether individually or in aggregate, could be material to earnings in a particular period, they will not have a material adverse effect on our consolidated financial position or cash flows. For additional litigation information, see Note 11 in our Consolidated Financial Statements and related notes in Item 8 of our 2013 Form 10-K/A.
	PBR Proceeding Nicor Gas’ PBR plan was a regulatory plan that provided economic incentives based on natural gas cost performance. The PBR plan went into effect in 2000 and was terminated effective January 1, 2003, following allegations that Nicor Gas acted improperly in connection with the plan. Under this plan, Nicor Gas’ total gas supply costs were compared to a market-sensitive benchmark. Savings and losses relative to the benchmark were determined annually and shared equally with sales customers. Since 2002, the amount of the savings and losses required to be shared has been disputed by the CUB and others, with the Illinois Attorney General (IAG) intervening, and subject to extensive contested discovery and other regulatory proceedings before administrative law judges and the Illinois Commission. In 2009, the staff of the Illinois Commission, IAG and CUB requested refunds of $85 million, $255 million and $305 million, respectively.
	In February 2012, we committed to a stipulation with the staff of the Illinois Commission for a resolution of the dispute through credits to Nicor Gas customers of $64 million. On November 5, 2012, the Administrative Law Judges issued a proposed order for a refund of $72 million to ratepayers. In the fourth quarter of 2012, we increased our accrual for this dispute by $8 million for a total of $72 million as a result of these developments and their effect on the estimated liability.
	On June 7, 2013, the Illinois Commission issued an order requiring us to refund $72 million to current Nicor Gas customers through our purchased gas adjustment mechanism based upon natural gas throughput over 12 months beginning on July 1, 2013. Approximately $43 million was refunded during the first half of 2014, which resulted in the completion of all refunds. On February 28, 2014, the CUB appealed the Illinois Commission’s order requesting refunds consistent with its 2009 request to the appellate court in Illinois and Nicor Gas filed its response brief on July 25, 2014. The CUB filed its reply brief on October 17, 2014. There is no set time frame for a final ruling by the appellate court.

Note_11_Segment_Information

Note 11 - Segment Information	9 Months Ended
	Sep. 30, 2014
Segment Reporting [Abstract]	'
Segment Reporting Disclosure [Text Block]	'
	Note 11 - Segment Information
	Our operating segments comprise revenue-generating components of our company for which we produce separate financial information internally that regularly is used to make operating decisions and assess performance. Our determination of reportable segments considers the strategic operating units under which we manage sales of various products and services to customers in differing regulatory environments. We manage our businesses through four operating segments - distribution operations, retail operations, wholesale services and midstream operations - and other, a non-operating segment.
	Effective September 1, 2014, we closed on the sale of Tropical Shipping, which historically operated within our cargo shipping segment. The assets and liabilities of these businesses are classified as held for sale on the unaudited Condensed Consolidated Statements of Financial Position, and the financial results of these businesses are reflected as discontinued operations on the unaudited Condensed Consolidated Statements of Income. Amounts shown in this note, unless otherwise indicated, exclude assets held for sale and discontinued operations. Cargo shipping also included our investment in Triton, which was not part of the sale and has been reclassified into our “other” segment. See Note 12 for additional information.
	Our distribution operations segment is the largest component of our business and includes natural gas local distribution utilities in seven states. These utilities construct, manage and maintain intrastate natural gas pipelines and distribution facilities. Although the operations of our distribution operations segment are geographically dispersed, the operating subsidiaries within the distribution operations segment are all regulated utilities, with rates determined by individual state regulatory commissions. These natural gas distribution utilities have similar economic and risk characteristics.
	We are also involved in several related and complementary businesses. Our retail operations segment includes retail natural gas marketing to end-use customers primarily in Georgia and Illinois. Additionally, retail operations provide home protection products and services. Our wholesale services segment engages in natural gas storage and gas pipeline arbitrage and related activities. Additionally, they provide natural gas asset management and/or related logistics services for each of our utilities except Nicor Gas, as well as for nonaffiliated companies. Our midstream operations segment includes our non-utility storage and pipeline operations, including the operation of high-deliverability natural gas storage assets. Our “other” segment includes aggregated subsidiaries that individually are not significant on a stand-alone basis and that do not fit into one of our operating segments.
	The chief operating decision maker of the company is the Chairman, President and Chief Executive Officer, who utilizes EBIT as the primary measure of profit and loss in assessing the results of each segment’s operations. EBIT includes operating income and other income and expenses. Items we do not include in EBIT are income taxes and financing costs, including interest expense, each of which we evaluate on a consolidated basis. Summarized Statements of Income, Statements of Financial Position and capital expenditure information by segment as of and for the periods presented are shown in the following tables.
	Three months ended September 30, 2014
	In millions		Distributionoperations			Retail operations		Wholesale services (1)			Midstream operations			Other (3)			Intercompany eliminations			Consolidated
	Operating revenues from external parties		$	439		$	146	$	5		$	4		$	1		$	(6	)	$	589
	Intercompany revenues			35			-		-			-			-			(35	)		-
	Total operating revenues			474			146		5			4			1			(41	)		589
	Operating expenses
	Cost of goods sold			138			99		3			(3	)		-			(39	)		198
	Operation and maintenance			145			34		10			5			1			(2	)		193
	Depreciation and amortization			79			7		-			5			2			-			93
	Taxes other than income taxes			24			1		1			1			3			-			30
	Total operating expenses			386			141		14			8			6			(41	)		514
	Gain on disposition of assets			-			-		3			-			-			-			3
	Operating income (loss)			88			5		(6	)		(4	)		(5	)		-			78
	Other income (expense)			1			-		(1	)		-			3			-			3
	EBIT		$	89		$	5	$	(7	)	$	(4	)	$	(2	)	$	-		$	81
	Capital expenditures		$	196		$	3	$	-		$	3		$	9		$	-		$	211
	Three months ended September 30, 2013
	In millions		Distribution operations (4)			Retail operations (4)		Wholesale services (1)			Midstream operations			Other (3)			Intercompany eliminations			Consolidated (4)
	Operating revenues from external parties		$	409		$	138	$	13		$	19		$	1		$	(6	)	$	574
	Intercompany revenues			36			-		-			-			-			(36	)		-
	Total operating revenues			445			138		13			19			1			(42	)		574
	Operating expenses
	Cost of goods sold			111			92		1			9			-			(39	)		174
	Operation and maintenance			150			31		13			5			3			(3	)		199
	Depreciation and amortization			89			8		-			5			2			-			104
	Taxes other than income taxes			22			1		1			1			2			-			27
	Total operating expenses			372			132		15			20			7			(42	)		504
	Operating income (loss)			73			6		(2	)		(1	)		(6	)		-			70
	Other income			4			-		-			-			3			-			7
	EBIT		$	77		$	6	$	(2	)	$	(1	)	$	(3	)	$	-		$	77
	Capital expenditures		$	200		$	3	$	-		$	3		$	5		$	-		$	211
	Nine months ended September 30, 2014
	In millions		Distribution operations (4)			Retail operations (4)		Wholesale services (1)			Midstream operations			Other (3)			Intercompany eliminations			Consolidated (4)
	Operating revenues from external parties		$	2,821		$	728	$	383		$	65		$	5		$	(62	)	$	3,940
	Intercompany revenues			153			1		-			-			-			(154	)		-
	Total operating revenues			2,974			729		383			65			5			(216	)		3,940
	Operating expenses
	Cost of goods sold			1,655			498		13			44			-			(210	)		2,000
	Operation and maintenance			515			105		59			18			2			(6	)		693
	Depreciation and amortization			235			21		1			14			10			-			281
	Taxes other than income taxes			146			3		2			4			5			-			160
	Total operating expenses			2,551			627		75			80			17			(216	)		3,134
	Gain on disposition of assets			-			-		3			-			-			-			3
	Operating income (loss)			423			102		311			(15	)		(12	)		-			809
	Other income (expense)			5			-		(3	)		1			5			-			8
	EBIT		$	428		$	102	$	308		$	(14	)	$	(7	)	$	-		$	817
	Identifiable and total assets (2)		$	11,628		$	663	$	1,056		$	692		$	9,167		$	(9,253	)	$	13,953
	Capital expenditures		$	504		$	9	$	1		$	8		$	21		$	-		$	543
	Nine months ended September 30, 2013
	In millions		Distribution operations (4)			Retail operations (4)		Wholesale services (1)			Midstream operations			Other (3)			Intercompany eliminations			Consolidated
																				-4
	Operating revenues from external parties		$	2,266		$	605	$	73		$	58		$	5		$	(16	)	$	2,991
	Intercompany revenues			134			-		-			-			-			(134	)		-
	Total operating revenues			2,400			605		73			58			5			(150	)		2,991
	Operating expenses
	Cost of goods sold			1,142			402		21			25			-			(143	)		1,447
	Operation and maintenance			493			94		36			17			1			(7	)		634
Depreciation and amortization			265			20		1			13			10			-			309
Taxes other than income taxes			124			3		2			4			6			-			139
Total operating expenses			2,024			519		60			59			17			(150	)		2,529
Gain on disposition of assets			-			-		11			-			-			-			11
Operating income (loss)			376			86		24			(1	)		(12	)		-			473
Other income			11			-		-			2			5			-			18
EBIT		$	387		$	86	$	24		$	1		$	(7	)	$	-		$	491
Identifiable and total assets (2)		$	11,215		$	644	$	930		$	726		$	9,784		$	(9,783	)	$	13,516
Capital expenditures		$	495		$	7	$	-		$	11		$	13		$	-		$	526
-1	The revenues for wholesale services are netted with costs associated with its energy and risk management activities. A reconciliation of our operating revenues and our intercompany revenues is shown in the following table.
In millions		Third party gross revenues (4)			Intercompany		Total gross			Less gross			Operating
					revenues		revenues (4)			gas costs			revenues (4)
Three months ended September 30, 2014		$	1,885		$	126	$	2,011		$	2,006		$	5
Three months ended September 30, 2013			1,716			69		1,785			1,772			13
Nine months ended September 30, 2014			8,313			584		8,897			8,514			383
Nine months ended September 30, 2013			5,792			312		6,104			6,031			73
-2	Identifiable assets are those used in each segment’s operations and exclude assets held for sale.
-3	Our other segment now also includes our investment in Triton, which was part of our cargo shipping segment that has been classified as discontinued operations. For more information, see Note 12.
-4	Amounts revised and include prior period adjustments. See Note 13 for additional information.
Information by segment on our Statements of Financial Position as of December 31, 2013, is as follows:
In millions		Identifiable and total assets
Distribution operations (1)		$	11,634
Retail operations (1)			685
Wholesale services (1)			1,163
Midstream operations			713
Other			10,160
Intercompany elimination			(10,088	)
Consolidated (1)		$	14,267
	-1	Amounts revised for prior period adjustments. See Note 13 for additional information.

Note_12_Discontinued_Operation

Note 12 - Discontinued Operations	9 Months Ended
	Sep. 30, 2014
Discontinued Operations and Disposal Groups [Abstract]	'
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]	'
	Note 12 - Discontinued Operations
	On September 1, 2014, we closed on the sale of Tropical Shipping to an unrelated third party. The after-tax cash proceeds and distributions from the transaction were $225 million. We determined that the cumulative foreign earnings of Tropical Shipping would no longer be indefinitely reinvested offshore. Accordingly, we recognized income tax expense of $60 million, of which $31 million was recorded in the first quarter of 2014, and the remaining $29 million was recorded in the third quarter of 2014 related to the cumulative foreign earnings for which no tax liabilities had been previously recorded, resulting in our repatriation of $86 million in cash.
	During the first quarter of 2014, based upon the negotiated sales price, we also recorded a goodwill impairment charge of $19 million, for which there is no income tax benefit. Additionally, we recognized a total of $7 million charge in the second and third quarters of 2014 related to the suspension of depreciation and amortization for assets that we were not compensated for by the buyer. The assets and liabilities of Tropical Shipping classified as held for sale on the unaudited Condensed Consolidated Statements of Financial Position are as follows:
			December 31,			September 30,
	In millions		2013			2013
	Current assets
	Cash and cash equivalents		$	24		$	34
	Short-term investments			1			1
	Receivables			36			33
	Inventories			9			9
	Other			1			3
	Total current assets			71			80
	Long-term assets and other deferred debits
	Property, plant and equipment, net			124			126
	Goodwill			61			61
	Intangible assets			19			19
	Other			8			8
	Total long-term assets and other deferred debits			212			214
	Total assets held for sale		$	283		$	294
	Current liabilities
	Other accounts payable - trade		$	11		$	9
	Accrued expenses			7			7
	Other			22			23
	Total liabilities held for sale		$	40		$	39
	The financial results of these businesses are reflected as discontinued operations, and all prior periods presented have been recast to reflect the discontinued operations. The components of discontinued operations recorded on the unaudited Condensed Consolidated Statements of Income are as follows:
			Three months ended					Nine months ended
			September 30,					September 30,
	In millions		2014			2013		2014			2013
	Operating revenues		$	62		$	89	$	243		$	264
	Operating expenses
	Cost of goods sold			38			55		149			162
	Operation and maintenance (1)			20			27		75			82
	Depreciation and amortization (2)			-			4		5			14
	Taxes other than income taxes			1			2		5			5
	Loss on sale and goodwill impairment (3)			5			-		28			-
	Total operating expenses			64			88		262			263
	Operating (loss) income			(2	)		1		(19	)		1
	(Loss) income before income taxes			(2	)		1		(19	)		1
	Income tax expense (4)			(29	)		-		(61	)		-
	(Loss) Income from discontinued operations, net of tax		$	(31	)	$	1	$	(80	)	$	1
	-1	Includes $1 million for the three and nine months ended September 30, 2014, for another business not related to Tropical Shipping that we discontinued in the third quarter of 2014 and was included in our “other” segment.
	-2	We ceased depreciating and amortizing Tropical Shipping’s assets on April 4, 2014, as a result of entering into an agreement to sell this business and the assets were classified as held for sale.
	-3	Primarily relates to the suspension of depreciation and amortization for the nine months ended September 30, 2014 of $7 million and $19 million of goodwill attributable to Tropical Shipping that was impaired as of March 31, 2014, based on the negotiated sales price.
	-4	Includes $31 million and $29 million that were recorded in the first and third quarters of 2014, respectively, related to the cumulative foreign earnings for which no tax liabilities had been previously recorded.

Note_13_Revision_to_Prior_Peri

Note 13 - Revision to Prior Period Financial Statements	9 Months Ended
	Sep. 30, 2014
Accounting Changes and Error Corrections [Abstract]	'
Accounting Changes and Error Corrections [Text Block]	'
	Note 13 - Revision to Prior Period Financial Statements
	In October 2014, we identified an accounting issue in our revenue recognition related to certain of our regulatory infrastructure programs. Historically, our regulatory accounting models used to record revenues under these programs did not differentiate between allowable costs based on what the regulator has approved compared to an incurred cost that would otherwise be charged to expense under the accounting literature. Specifically, Accounting Standards Codification (ASC) 980 - Regulated Operations prohibits capitalizing allowed, but not incurred, costs such as shareholder return, even if allowed by a respective state regulatory body. Shareholder returns and other allowed, but not incurred, costs can generally only be recognized in earnings when they are collected through rates. This change is only applicable to our distribution operations segment and primarily affects our operating revenues, operation and maintenance expense, depreciation and amortization, interest expense and income tax expense amounts.
	The adjustments impacted each year since 1998. The cumulative decrease to January 1, 2013 retained earnings as a result of the adjustment was $45 million. This adjustment resulted in a decrease to net income of $4 million and $13 million for the three and nine months ended September 30, 2013, respectively. These amounts will be recognized in future periods, when collected through rates from customers.
	Additionally, we recorded other adjustments that we identified for prior periods that were included for completeness. The most significant of these include the intangible asset amortization. We have determined that our use of the straight-line method of amortizing our customer relationships and trade names was not applied consistent with the requirements of ASC 350 Intangibles-Goodwill and Other (ASC 350). ASC 350 requires that an intangible asset be amortized over its useful life in a manner to reflect the pattern in which the economic benefits of the intangible assets are consumed. The impact for this adjustment was an increase in depreciation and amortization expense of $1 million and $3 million for the three and nine months ended September 30, 2013, respectively. These amounts were generally offset within our unaudited Condensed Consolidated Statements of Income by the previously discussed adjustments related to our regulatory infrastructure programs for the deferral of depreciation expenses. Additionally, these adjustments resulted in a decrease to intangible assets, net of $8 million as of September 30, 2013. We have determined that we should be utilizing the undiscounted cash flows as a basis to amortize these assets. Other previously identified immaterial uncorrected amounts are reflected in the revised amounts
	We assessed the materiality of these issues on our prior period financial statements and concluded they were not material to any prior annual or interim periods; however, the cumulative impact would have been material to the interim period ended September 30, 2014, if adjusted in 2014. As a result, in accordance with accounting standards, we revised our prior period financial statements as described below to correct for these adjustments. The revision had no effect on reported cash flows. The following tables present the effects of the revisions to our unaudited Condensed Consolidated Statements of Income, unaudited Condensed Consolidated Statements of Financial Position and unaudited Condensed Consolidated Statements of Cash Flows for the following interim periods:
			For the three months ended									For the nine months ended
			30-Sep-13									30-Sep-13
	In millions, except per share amounts		As filed (1)			Adjustment			Revised			As filed (1)			Adjustment			Revised
	Operating revenues		$	586		$	(12	)	$	574		$	3,024		$	(33	)	$	2,991
	Operating expenses
	Cost of goods sold			174			-			174			1,447			-			1,447
	Operation and maintenance			199			-			199			636			(2	)		634
	Depreciation and amortization			105			(1	)		104			311			(2	)		309
	Taxes other than income taxes			27			-			27			139			-			139
	Total operating expenses			505			(1	)		504			2,533			(4	)		2,529
	Gain on disposition of assets			-			-			-			11			-			11
	Operating income			81			(11	)		70			502			(29	)		473
	Other income			7			-			7			19			(1	)		18
	Interest expense, net			(43	)		6			(37	)		(135	)		9			(126	)
	Income before income taxes			45			(5	)		40			386			(21	)		365
	Income tax expense			18			(2	)		16			145			(8	)		137
	Income from continuing operations			27			(3	)		24			241			(13	)		228
	Income from discontinued operations			1			-			1			1			-			1
	Net income			28			(3	)		25			242			(13	)		229
	Less net income attributable to the noncontrolling interest			-			-			-			11			-			11
	Net income attributable to AGL Resources Inc.		$	28		$	(3	)	$	25		$	231		$	(13	)	$	218
	Per common share information
	Basic earnings per common share (2)
	Continuing operations		$	0.23		$	(0.03	)	$	0.2		$	1.95		$	(0.10	)	$	1.85
	Discontinued operations			0.01			-			0.01			0.01			-			0.01
	Basic earnings per common share attributable to AGL Resources Inc. common shareholders		$	0.24		$	(0.03	)	$	0.21		$	1.96		$	(0.10	)	$	1.86
	Diluted earnings per common share (2)
	Continuing operations		$	0.23		$	(0.03	)	$	0.2		$	1.95		$	(0.11	)	$	1.84
	Discontinued operations			0.01			-			0.01			0.01			-			0.01
	Diluted earnings per common share attributable to AGL Resources Inc. common shareholders		$	0.24		$	(0.03	)	$	0.21		$	1.96		$	(0.11	)	$	1.85
		-1	Reflects the reclassification of the Tropical Shipping amounts as discontinued operations.
		-2	Excludes net income attributable to the noncontrolling interest.
			As of September 30, 2013
	In millions		As filed (1)			Revised
	Current assets
	Regulatory assets		$	133		$	87
	Total current assets			2,091			2,252
	Long-term assets and other deferred debits
	Property, plant and equipment			10,920			10,761
	Less accumulated depreciation			2,307			2,281
	Property, plant and equipment, net			8,613			8,480
	Regulatory assets			871			845
	Intangible assets			160			152
	Other			251			259
	Total long-term assets and other deferred debits			11,813			11,558
	Total assets		$	13,904		$	13,810
	Current liabilities
	Accrued expenses		$	157		$	149
	Total current liabilities			2,407			2,407
	Long-term liabilities and other deferred credits
	Accumulated deferred income taxes			1,587			1,551
	Total long-term liabilities and other deferred credits			7,934			7,897
	Total liabilities and other deferred credits		$	10,341		$	10,304
	Equity
	Additional paid-in capital		$	2,046		$	2,047
	Retained earnings			1,100			1,042
	Total equity			3,563			3,506
	Total liabilities and equity		$	13,904		$	13,810
	-1	Reflects the reclassification of the Tropical Shipping amounts as held for sale.
		For the nine months ended
		30-Sep-13
In millions		As filed (1)			Adjustment			Revised
Cash flows from operating activities
Net income		$	242		$	(13	)	$	229
Adjustments to reconcile net income to net cash flow provided by operating activities
Depreciation and amortization			311			(2	)		309
Deferred income taxes			(28	)		(4	)		(32	)
Changes to certain assets and liabilities
Other, net			63			19			82
Net cash flow provided by operating activities		$	1,070			-		$	1,070
	-1	Reflects the reclassification of the Tropical Shipping amounts as discontinued operations.
Revision to Previously Reported Intangible Assets Disclosures As discussed above, the adjustment of our intangible asset amortization affects our customer relationships and trade names. The revisions to our previously reported intangible assets and accumulated amortization in our Original Filing within the unaudited Condensed Consolidated Statements of Financial Position are presented in the following table.
		30-Sep-13
In millions		Gross			Accumulated			Net
					amortization
Customer relationships
Retail operations as reported		$	131		$	(12	)	$	119
Adjustments			-			(9	)		(9	)
Revised total		$	131		$	(21	)	$	110
Trade names
Retail operations as reported		$	46		$	(5	)	$	41
Adjustments			-			1			1
Revised total		$	46		$	(4	)	$	42

Accounting_Policies_by_Policy_

Accounting Policies, by Policy (Policies)	9 Months Ended
	Sep. 30, 2014
Accounting Policies [Abstract]	'
Use of Estimates, Policy [Policy Text Block]	'
	Use of Accounting Estimates
	The preparation of our financial statements in conformity with GAAP requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses and the related disclosures. Our estimates are based on historical experience and various other assumptions that we believe to be reasonable under the circumstances. Our estimates may involve complex situations requiring a high degree of judgment either in the application and interpretation of existing literature or in the development of estimates that impact our financial statements. The most significant estimates relate to our rate-regulated subsidiaries, uncollectible accounts and other allowances for contingent losses, goodwill and other intangible assets, retirement plan benefit obligations, derivative and hedging activities and provisions for income taxes. We evaluate our estimates on an ongoing basis, and our actual results could differ from our estimates.
Cash and Cash Equivalents, Policy [Policy Text Block]	'
	Cash and Cash Equivalents
	Our cash and cash equivalents primarily consist of cash on deposit, money market accounts and certificates of deposit held by domestic subsidiaries with original maturities of three months or less. At December 31, 2013, and September 30, 2013, there were $24 million and $34 million, respectively, of cash and cash equivalents held by Tropical Shipping that were excluded from cash and cash equivalents within our unaudited Condensed Consolidated Statements of Financial Position and included in assets held for sale. For more information on the sale of Tropical Shipping, see Note 12.
Energy Marketing Receivables And Payables [Policy Text Block]	'
	Energy Marketing Receivables and Payables
	Our wholesale services segment provides services to retail and wholesale marketers and utility and industrial customers. These customers, also known as counterparties, utilize netting agreements that enable our wholesale services segment to net receivables and payables by counterparty upon settlement. Wholesale services also nets across product lines and against cash collateral, provided the master netting and cash collateral agreements include such provisions. While the amounts due from, or owed to, wholesale services’ counterparties are settled net, they are recorded on a gross basis in our unaudited Condensed Consolidated Statements of Financial Position as energy marketing receivables and energy marketing payables.
	Our wholesale services segment has trade and credit contracts that contain minimum credit rating requirements. These credit rating requirements typically give counterparties the right to suspend or terminate credit if our credit ratings are downgraded to non-investment grade status. Under such circumstances, wholesale services would need to post collateral to continue transacting business with some of its counterparties. To date, our credit ratings have exceeded the minimum requirements. As of September 30, 2014 and 2013, and December 31, 2013, the collateral that wholesale services would have been required to post if our credit ratings had been downgraded to non-investment grade status would not have had a material impact to our consolidated results of operations, cash flows or financial condition. If such collateral were not posted, wholesale services’ ability to continue transacting business with these counterparties would be negatively impacted.
Inventory, Policy [Policy Text Block]	'
	Inventories
	For our regulated utilities, except Nicor Gas, our natural gas inventories and the inventories we hold for Marketers in Georgia are carried at cost on a WACOG basis. Nicor Gas’ inventory is carried at cost on a LIFO basis. In Georgia’s competitive environment, Marketers sell natural gas to firm end-use customers at market-based prices. Part of the unbundling process, which resulted from deregulation and provides this competitive environment, is the assignment to Marketers of certain pipeline services that Atlanta Gas Light has under contract. On a monthly basis, Atlanta Gas Light assigns the majority of the pipeline storage services that it has under contract to Marketers, along with a corresponding amount of inventory. Atlanta Gas Light also retains and manages a portion of its pipeline storage assets and related natural gas inventories for system balancing and to serve system demand. See Note 10 for information regarding a regulatory filing by Atlanta Gas Light related to natural gas inventory.
	Our natural gas inventories at our retail operations, wholesale services and midstream operations segments carry inventory at the lower of cost or market value, where cost is determined on a WACOG basis. For these segments, we evaluate the weighted average cost of their natural gas inventories against market prices to determine whether any declines in market prices below the WACOG are other than temporary. For any declines considered to be other than temporary, we record adjustments to reduce the weighted average cost of the natural gas inventory to market value. For the three and nine months ended September 30, 2014, we recorded $5 million and $11 million, respectively, total LOCOM adjustment to reduce the value of our inventories to market value and $1 million and $9 million, respectively, for the three and nine months ended September 30, 2013. Additionally, we have $19 million of inventory at wholesale services that is currently inaccessible due to operational issues at a third party storage facility. The owner of the storage facility is working to resolve these issues. While we expect this inventory to be fully recovered, the timing of withdrawal of this gas may be impacted by the operational issues.
	At midstream operations, mechanical integrity tests and engineering studies are periodically performed on the storage facilities in accordance with certain state regulatory requirements. However, such tests may be performed in advance of such state requirements for operational purposes. During 2014, an engineering study and mechanical integrity tests were performed at one of our storage facilities, identifying a lower amount of working gas capacity that is the result of naturally occurring shrinkage of the storage caverns. Further, based on the lower capacity and an analysis of the volume of natural gas stored in the facility, we recorded natural gas costs to true-up the amount of retained fuel at this facility in the amount of $10 million for the nine months ended September 30, 2014. Our other storage facilities at midstream operations were not impacted.
Fair Value Measurement, Policy [Policy Text Block]	'
	Fair Value Measurements
	We have financial and nonfinancial assets and liabilities subject to fair value measurement. The financial assets and liabilities measured and carried at fair value include cash and cash equivalents, and derivative assets and liabilities. The carrying values of receivables, short- and long-term investments, accounts payable, short-term debt, other current assets and liabilities, and accrued interest approximate fair value. Our nonfinancial assets and liabilities include pension and other retirement benefits, which are presented in Note 4 to our Consolidated Financial Statements and in related notes included in Item 8 of our 2013 Form 10-K/A.
	As defined in the authoritative guidance related to fair value measurements and disclosures, fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We utilize market data or assumptions that market participants would use in valuing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable. We primarily apply the market approach for recurring fair value measurements to utilize the best available information. Accordingly, we use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. We classify fair value balances based on the observance of those inputs in accordance with the fair value hierarchy.
Derivatives, Policy [Policy Text Block]	'
	Derivative Instruments
	The fair value of the natural gas and weather derivative instruments that we use to manage exposures arising from changing natural gas prices and weather risk reflects the estimated amounts that we would receive or pay to terminate or close the contracts at the reporting date, taking into account the current unrealized gains or losses on open contracts. We use external market quotes and indices to value substantially all of our derivative instruments. See Note 4 and Note 5 for additional derivative disclosures.
Property, Plant and Equipment, Policy [Policy Text Block]	'
	Property, Plant and Equipment
	On April 11, 2014, we entered into two arrangements associated with the Dalton Pipeline. The first was a construction and ownership agreement through which we will have a 50% undivided ownership interest in the 106 mile Dalton Pipeline that will be constructed in Georgia and serve as an extension of the Transco natural gas pipeline system into northwest Georgia. We also entered into an agreement to lease our 50% undivided ownership in the Dalton Pipeline once it is placed in-service. The lease payments to be received are $26 million annually for an initial term of 25 years. The lessee will be responsible for maintaining the pipeline during the lease term and for providing service to transportation customers under its FERC regulated tariff. Engineering design work has commenced and construction is expected to begin in the second quarter of 2016 with a targeted completion date in the second quarter of 2017. The capacity from this pipeline will further enhance system reliability as well as provide access to a more diverse supply of natural gas.
Goodwill and Intangible Assets, Goodwill, Policy [Policy Text Block]	'
	Goodwill
	In 2014, we completed an engineering study at our midstream operations storage facilities that indicated a reduced forecast of working gas capacity from what was projected when our 2013 annual goodwill impairment analysis was performed during the fourth quarter of 2013. Given that the 2013 annual goodwill impairment test indicated that the estimated fair value of this reporting unit exceeded its carrying amount by less than 5%, we considered this reduced storage capacity as an indicator of potential impairment and accordingly conducted an interim goodwill impairment analysis during the first quarter of 2014.
	The estimated fair value of this reporting unit was determined utilizing the income approach, which estimated the fair value based upon the present value of estimated future cash flows. The forecasts used in the income approach, which were updated during the first quarter of 2014 to reflect the contracting activity that occurred during the quarter, assume discrete period revenue growth through fiscal 2022 to reflect the recovery of subscription rates, stabilization of earnings and establishment of a reasonable base year that was used to estimate the terminal value in the valuation model. Consistent with our 2013 annual goodwill impairment testing, we assumed a long-term earnings growth rate in the terminal year of 2.5%, which we believe is appropriate given the current economic and industry-specific expectations. As of the valuation date, we utilized a discount rate of 7.0%, which we believe is appropriate as it reflects the relative risk and the time value of money, and is consistent with the peer group of this reporting unit as well as the discount rates that were utilized in our 2013 annual goodwill impairment tests.
	Our interim goodwill impairment test assumed a cash flow forecast providing for growth over the next eight years. This forecast indicated that the estimated fair value of this reporting unit continues to exceed its carrying amount with a cushion of less than 10%. However, continued declines in capacity or subscription rates, reductions to our cash flow forecasts, a sustained period at the current subscription rates or other changes to the assumptions and factors used in this analysis may result in a future failure of step one of the goodwill impairment test and require us to proceed to step two of the goodwill impairment test in a future period.
	The risk of impairment of the underlying long-lived assets is not estimated to be significant as the assets have long remaining useful lives, and authoritative guidance requires such assets to be tested for impairment on the basis of undiscounted cash flows over their remaining useful lives. We will continue to monitor this reporting unit for potential impairment. Our goodwill balances by segment as of September 30, 2014, and December 31, 2013, and changes in the amount of goodwill for the nine months ended September 30, 2013, are provided in the following table.
	In millions		Distribution Operations			Retail Operations		Midstream Operations			Consolidated
	31-Dec-12		$	1,640		$	122	$	14		$	1,776
	2013 acquisitions			-			46		-			46
	September 30, 2013 (1)		$	1,640		$	168	$	14		$	1,822
	December 31, 2013 (1)		$	1,640		$	173	$	14		$	1,827
	30-Sep-14		$	1,640		$	173	$	14		$	1,827
	-1	Excludes goodwill at Tropical Shipping which is classified as held for sale. See Note 12 for additional information.
Other Income [Policy Text Block]	'
	Other Income
	Our other income is detailed in the following table.
			Three months ended					Nine months ended
			September 30,					September 30,
	In millions		2014			2013		2014			2013
	Equity method investment income (1)		$	2		$	3	$	6		$	8
	AFUDC - equity			1			3		2			8
	Other, net			-			1		-			2
	Total other income		$	3		$	7	$	8		$	18
		-1	For more information on our equity method investment income, see Note 9.
Earnings Per Share, Policy [Policy Text Block]	'
	Earnings Per Common Share
	We compute basic earnings per common share attributable to AGL Resources Inc. common shareholders by dividing our net income attributable to AGL Resources Inc. by the daily weighted average number of common shares outstanding. Diluted earnings per common share attributable to AGL Resources Inc. common shareholders reflect the potential reduction in earnings per common share attributable to AGL Resources Inc. common shareholders that occurs when potentially dilutive common shares are added to common shares outstanding.
	We derive our potentially dilutive common shares by calculating the number of shares issuable under restricted stock, restricted stock units and stock options award programs. The vesting of certain shares of the restricted stock and restricted stock units depends on the satisfaction of defined performance and/or time-based criteria. The future issuance of shares underlying the outstanding stock options depends on whether the market price of the common shares underlying the options exceeds the respective exercise prices of the stock options. The following table shows the calculation of our diluted shares attributable to AGL Resources Inc. common shareholders for the periods presented, as if performance units currently earned under the plan ultimately vest and as if stock options currently exercisable at prices below the average market prices are exercised.
			Three months ended					Nine months ended
			September 30,					September 30,
	In millions (except per share amounts)		2014			2013 (1)		2014 (1)			2013 (1)
	Income from continuing operations (2)		$	23		$	24	$	414		$	217
	(Loss) income from discontinued operations, net of tax (3)			(31	)		1		(80	)		1
	Net (loss) income attributable to AGL Resources Inc.		$	(8	)	$	25	$	334		$	218
	Denominator:
	Basic weighted average number of common shares outstanding (4)			119			118.2		118.8			117.8
	Effect of dilutive securities			0.4			0.3		0.4			0.3
	Diluted weighted average number of common shares outstanding			119.4			118.5		119.2			118.1
	Basic earnings (loss) per common share
	From continuing operations		$	0.19		$	0.2	$	3.48		$	1.85
	From discontinued operations			(0.25	)		0.01		(0.67	)		0.01
	Basic (loss) earnings per common share attributable to AGL Resources Inc. common shareholders		$	(0.06	)	$	0.21	$	2.81		$	1.86
	Diluted earnings (loss) per common share
	From continuing operations		$	0.19		$	0.2	$	3.47		$	1.84
	From discontinued operations			(0.25	)		0.01		(0.67	)		0.01
	Diluted (loss) earnings per common share attributable to AGL Resources Inc. common shareholders		$	(0.06	)	$	0.21	$	2.8		$	1.85
		-1	Amounts revised and or include prior period adjustments. See Note 13 for additional information.
		-2	Excludes net income attributable to the noncontrolling interest.
		-3	For additional information on our discontinued operations, see Note 12.
		-4	Daily weighted average shares outstanding.
Discontinued Operations, Policy [Policy Text Block]	'
	Sale of Compass Energy
	On May 1, 2013, we sold Compass Energy, a non-regulated retail natural gas business supplying commercial and industrial customers, which was part of our wholesale services segment. We received an initial cash payment of $12 million, which resulted in an $11 million pre-tax gain ($5 million net of tax) for the nine months ended September 30, 2013. Under the terms of the purchase and sale agreement, we were eligible to receive contingent cash consideration up to $8 million with a guaranteed minimum receipt of $3 million that was recognized during 2013. The remaining $5 million of contingent cash consideration was to be received from the buyer annually over a five-year earn-out period based upon the financial performance of Compass Energy. In the third quarter of 2014, we negotiated with the buyer to settle the future earn-out payments and we received $4 million, resulting in the recognition of a $3 million gain. We have a five year agreement to supply natural gas to our former customers. Accordingly, as a result of our continued involvement, the sale of Compass Energy did not meet the criteria for treatment as a discontinued operation.
New Accounting Pronouncements, Policy [Policy Text Block]	'
	Accounting Developments
	On April 10, 2014, the FASB issued authoritative guidance related to reporting discontinued operations. The guidance generally raises the threshold for disposals to qualify as discontinued operations and requires new disclosures of both discontinued operations and certain other material disposals that do not meet the definition of a discontinued operation. The guidance will be effective for us prospectively beginning January 1, 2015. It is not expected to have a material impact on our consolidated financial statements, and it will have no impact on our accounting for the sale of Tropical Shipping.
	On May 28, 2014, the FASB issued an update to authoritative guidance related to revenue from contracts with customers. The update replaces most of the existing guidance with a single set of principles for recognizing revenue from contracts with customers. The guidance will be effective for us beginning January 1, 2017. Early adoption is not permitted. The new guidance must be applied retrospectively to each prior period presented or via a cumulative effect upon the date of initial application. We have not yet determined the impact of this new guidance, nor have we selected a transition method.
	On June 19, 2014, the FASB issued an update to authoritative guidance related to accounting for share-based payments when the terms of an award provide that a performance target could be achieved after the requisite service period. The guidance will be effective for us beginning January 1, 2016, and will have no material impact on our consolidated financial statements for our existing share-based plans.

Note_2_Significant_Accounting_1

Note 2 - Significant Accounting Policies and Methods of Application (Tables)	9 Months Ended
	Sep. 30, 2014
Accounting Policies [Abstract]	'
Schedule of Goodwill [Table Text Block]	'
	In millions	Distribution Operations			Retail Operations		Midstream Operations			Consolidated
	31-Dec-12	$	1,640		$	122	$	14		$	1,776
	2013 acquisitions		-			46		-			46
	September 30, 2013 (1)	$	1,640		$	168	$	14		$	1,822
	December 31, 2013 (1)	$	1,640		$	173	$	14		$	1,827
	30-Sep-14	$	1,640		$	173	$	14		$	1,827
Schedule of Other Nonoperating Income (Expense) [Table Text Block]	'
		Three months ended					Nine months ended
		September 30,					September 30,
	In millions	2014			2013		2014			2013
	Equity method investment income (1)	$	2		$	3	$	6		$	8
	AFUDC - equity		1			3		2			8
	Other, net		-			1		-			2
	Total other income	$	3		$	7	$	8		$	18
Schedule of Weighted Average Number of Shares [Table Text Block]	'
		Three months ended					Nine months ended
		September 30,					September 30,
	In millions (except per share amounts)	2014			2013 (1)		2014 (1)			2013 (1)
	Income from continuing operations (2)	$	23		$	24	$	414		$	217
	(Loss) income from discontinued operations, net of tax (3)		(31	)		1		(80	)		1
	Net (loss) income attributable to AGL Resources Inc.	$	(8	)	$	25	$	334		$	218
	Denominator:
	Basic weighted average number of common shares outstanding (4)		119			118.2		118.8			117.8
	Effect of dilutive securities		0.4			0.3		0.4			0.3
	Diluted weighted average number of common shares outstanding		119.4			118.5		119.2			118.1
	Basic earnings (loss) per common share
	From continuing operations	$	0.19		$	0.2	$	3.48		$	1.85
	From discontinued operations		(0.25	)		0.01		(0.67	)		0.01
	Basic (loss) earnings per common share attributable to AGL Resources Inc. common shareholders	$	(0.06	)	$	0.21	$	2.81		$	1.86
	Diluted earnings (loss) per common share
	From continuing operations	$	0.19		$	0.2	$	3.47		$	1.84
	From discontinued operations		(0.25	)		0.01		(0.67	)		0.01
	Diluted (loss) earnings per common share attributable to AGL Resources Inc. common shareholders	$	(0.06	)	$	0.21	$	2.8		$	1.85

Note_3_Regulated_Operations_Ta

Note 3 - Regulated Operations (Tables)	9 Months Ended
	Sep. 30, 2014
Note 3 - Regulated Operations (Tables) [Line Items]	'
Schedule of Regulatory Assets [Table Text Block]	'
	In millions	September 30,			December 31,			September 30,
		2014			2013 (1)			2013 (1)
	Regulatory assets
	Recoverable ERC	$	41		$	45		$	30
	Recoverable pension and retiree welfare benefit costs		9			9			19
	Recoverable seasonal rates		9			10			9
	Deferred natural gas costs		3			1			-
	Other		43			49			29
	Total regulatory assets - current		105			114			87
	Recoverable ERC		363			433			456
	Recoverable pension and retiree welfare benefit costs		91			99			183
	Long-term debt fair value adjustment		76			82			84
	Recoverable regulatory infrastructure program costs (1)		62			55			78
	Other		45			36			44
	Total regulatory assets - long-term		637			705			845
	Total regulatory assets	$	742		$	819		$	932
	Regulatory liabilities
	Bad debt over collection	$	31		$	41		$	37
	Accrued natural gas costs		29			92			104
	Accumulated removal costs		27			27			17
	Other		31			23			16
	Total regulatory liabilities - current		118			183			174
	Accumulated removal costs		1,499			1,445			1,448
	Regulatory income tax liability		26			27			26
	Unamortized investment tax credit		23			26			26
	Bad debt over collection		7			17			20
	Other		12			3			4
	Total regulatory liabilities - long-term		1,567			1,518			1,524
	Total regulatory liabilities	$	1,685		$	1,701		$	1,698
Schedule of Net Regulatory Assets [Table Text Block]	'
	In millions	30-Sep-14			30-Sep-13			Change
	Deferred natural gas costs	$	3		$	-		$	3
	Accrued natural gas costs		(29	)		(104	)		75
	Total (1)	$	(26	)	$	(104	)	$	78
Environmental Exit Costs by Cost [Table Text Block]	'
	In millions	Probabilistic model cost estimates			Engineering			Amount			Expected costs over next 12 months
					estimates			recorded
	Illinois	$	205-462		$	46		$	244		$	41
	New Jersey		107-174			16			122			16
	Georgia and Florida		66-106			9			77			17
	North Carolina (1)		n/a			11			11			8
	Total	$	378-742		$	82		$	454	-2	$	82
Regulatory Assett Off Balance Sheet [Member]	'
Note 3 - Regulated Operations (Tables) [Line Items]	'
Schedule of Regulatory Assets [Table Text Block]	'
	In millions
	30-Sep-14	$	118
	31-Dec-13	$	93
	30-Sep-13	$	86

Note_4_Fair_Value_Measurements1

Note 4 - Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2014
Fair Value Disclosures [Abstract]	'
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	'
		30-Sep-14					31-Dec-13					30-Sep-13
	In millions	Assets (1)		Liabilities			Assets (1)		Liabilities			Assets (1)		Liabilities
	Natural gas derivatives
	Quoted prices in active markets (Level 1)	$	4	$	(72	)	$	6	$	(79	)	$	4	$	(52	)
	Significant other observable inputs (Level 2)		57		(51	)		67		(79	)		60		(41	)
	Netting of cash collateral		49		76			43		78			45		49
	Total carrying value (2) (3)	$	110	$	(47	)	$	116	$	(80	)	$	109	$	(44	)
Fair Value, Liabilities Measured on Recurring Basis [Table Text Block]	'
	In millions	30-Sep-14		31-Dec-13			30-Sep-13
	Long-term debt carrying amount	$	3,805	$	3,813		$	3,816
	Long-term debt fair value (1)		4,165		3,956			4,024

Note_5_Derivative_Instruments_

Note 5 - Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule of Notional Amounts of Outstanding Derivative Positions [Table Text Block]	'
	In Bcf (1)		September 30,				December 31,				September 30,
			2014 (2)				2013				2013
	Cash flow hedges			7				6				3
	Not designated as hedges			97				183				40
	Total volumes			104				189				43
	Short position			(2,756	)			(2,622	)			(2,788	)
	Long position			2,860				2,811				2,831
	Net long position			104				189				43
Loss Recognized In Income [Table Text Block]	'
			Three months ended								Nine months ended
			September 30,								September 30,
	In millions		2014				2013				2014				2013
	Nicor Gas		$	(4	)		$	(6	)		$	8			$	2
	Elizabethtown Gas			(1	)			(1	)			4				(5	)
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	'
				September 30,								December 31,							September 30,
				2014								2013							2013
	In millions	Classification		Assets				Liabilities				Assets				Liabilities			Assets			Liabilities
	Designated as cash flow or fair value hedges
	Natural gas contracts	Current		$	2			$	(2	)		$	3			$	(1	)	$	6		$	(5	)
	Not designated as hedges
	Natural gas contracts	Current			834				(891	)			691				(761	)		445			(462	)
	Natural gas contracts	Long-term			78				(80	)			206				(220	)		143			(153	)
	Total				912				(971	)			897				(981	)		588			(615	)
	Gross amount of recognized assets and liabilities (1) (2)				914				(973	)			900				(982	)		594			(620	)
	Gross amounts offset in our unaudited Condensed Consolidated Statements of Financial Position (2)				(801	)			926				(781	)			902			(482	)		576
	Net amounts of assets and liabilities presented in our unaudited Condensed Consolidated Statements of Financial Position (3)			$	113			$	(47	)		$	119			$	(80	)	$	112		$	(44	)
Schedule of Derivative Instruments [Table Text Block]	'
			Three months ended								Nine months ended
			September 30,								September 30,
	In millions		2014				2013				2014				2013
	Designated as cash flow or fair value hedges
	Natural gas contracts - net gain reclassified from OCI into cost of goods sold		$	(1	)		$	(1	)		$	4			$	-
	Natural gas contracts - net gain reclassified from OCI into operation and maintenance expense			1				-				2				-
	Interest rate swaps - net loss reclassified from OCI into interest expense			-				1				-				(2	)
	Income tax benefit			-				-				(1	)			1
	Net of tax			-				-				5				(1	)
	Not designated as hedges (1)
	Natural gas contracts - net fair value adjustments recorded in operating revenues			(6	)			(14	)			(6	)			(16	)
	Natural gas contracts - net fair value adjustments recorded in cost of goods sold (2)			(1	)			-				-				(1	)
	Income tax benefit			2				5				2				7
	Net of tax			(5	)			(9	)			(4	)			(10	)
	Total (losses) gains on derivative instruments		$	(5	)		$	(9	)		$	1			$	(11	)

Note_6_Employee_Benefit_Plans_

Note 6 - Employee Benefit Plans (Tables)	9 Months Ended
	Sep. 30, 2014
Compensation and Retirement Disclosure [Abstract]	'
Schedule of Net Benefit Costs [Table Text Block]	'
		Three months ended September 30,						Nine months ended September 30,
	In millions	2014			2013			2014			2013
	Service cost	$	6		$	7		$	18		$	22
	Interest cost		12			11			35			32
	Expected return on plan assets		(16	)		(16	)		(48	)		(47	)
	Net amortization of prior service cost		(1	)		-			(2	)		(1	)
	Recognized actuarial loss		5			9			16			26
	Net periodic pension benefit cost	$	6		$	11		$	19		$	32
		Three months ended September 30,						Nine months ended September 30,
	In millions	2014			2013			2014			2013
	Service cost	$	1		$	1		$	2		$	2
	Interest cost		4			3			11			10
	Expected return on plan assets		(2	)		(1	)		(5	)		(4	)
	Net amortization of prior service cost		(1	)		(1	)		(2	)		(3	)
	Recognized actuarial loss		1			2			4			6
	Net periodic welfare benefit cost	$	3		$	4		$	10		$	11

Note_7_Debt_and_Credit_Facilit1

Note 7 - Debt and Credit Facilities (Tables)	9 Months Ended
	Sep. 30, 2014
Debt Disclosure [Abstract]	'
Schedule of Debt [Table Text Block]	'
					30-Sep-14								30-Sep-13
	Dollars in millions	Year(s) due			Weighted average interest rate (1)			Outstanding			Outstanding at December 31, 2013		Weighted average interest rate (1)			Outstanding
	Short-term debt
	Commercial paper - AGL Capital (2)		2014			0.3	%	$	292		$	857		0.4	%	$	680
	Commercial paper - Nicor Gas (2)		2014			0.2			389			314		0.3			152
	Total short-term debt					0.3	%	$	681		$	1,171		0.4	%	$	832
	Current portion of long-term debt		2015			5	%	$	200		$	-		-		$	-
	Long-term debt - excluding current portion
	Senior notes		2016-2043			5	%	$	2,625		$	2,825		5.1	%	$	2,825
	First mortgage bonds		2016-2038			5.6			500			500		5.6			500
	Gas facility revenue bonds		2022-2033			0.9			200			200		0.8			200
	Medium-term notes		2017-2027			7.8			181			181		7.8			181
	Total principal long-term debt					4.9	%		3,506			3,706		4.9	%		3,706
	Fair value adjustment of long-term debt (3)		n/a			n/a			83			91		n/a			94
	Unamortized debt premium, net		n/a			n/a			16			16		n/a			16
	Total non-principal long-term debt					n/a			99			107		n/a			110
	Total long-term debt							$	3,605		$	3,813				$	3,816
	Total debt							$	4,486		$	4,984				$	4,648
Schedule of Capitalization [Table Text Block]	'
		30-Sep-14			31-Dec-13			30-Sep-13
	AGL Credit Facility		53	%		57	%		56	%
	Nicor Gas Credit Facility		57	%		55	%		50	%

Note_8_Equity_Tables

Note 8 - Equity (Tables)	9 Months Ended
	Sep. 30, 2014
Stockholders' Equity Note [Abstract]	'
Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]	'
		2014									2013
	In millions (1)	Cash flow			Retirement benefit plans			Total			Cash flow			Retirement benefit plans			Total
		hedges									hedges
	For the three months ended September 30
	As of beginning of period	$	-		$	(133	)	$	(133	)	$	(1	)	$	(208	)	$	(209	)
	OCI, before reclassifications		(2	)		-			(2	)		-			-			-
	Amounts reclassified from accumulated OCI		-			2			2			-			1			1
	Net current-period other comprehensive (loss) income		(2	)		2			-			-			1			1
	As of end of period	$	(2	)	$	(131	)	$	(133	)	$	(1	)	$	(207	)	$	(208	)
	For the nine months ended September 30
	As of beginning of period	$	1		$	(137	)	$	(136	)	$	(3	)	$	(215	)	$	(218	)
	OCI, before reclassifications		2			-			2			-			-			-
	Amounts reclassified from accumulated OCI		(5	)		6			1			2			8			10
	Net current-period other comprehensive (loss) income		(3	)		6			3			2			8			10
	As of end of period	$	(2	)	$	(131	)	$	(133	)	$	(1	)	$	(207	)	$	(208	)
Reclassification out of Accumulated Other Comprehensive Income [Table Text Block]	'
		Three months ended						Nine months ended
		September 30,						September 30,
	In millions (1)	2014			2013			2014			2013
	Cash flow hedges
	Cost of goods sold (natural gas contracts)	$	(1	)	$	(1	)	$	4		$	-
	Operation and maintenance expense (natural gas contracts)		1			-			2			-
	Interest expense (interest rate contracts)		-			1			-			(3	)
	Total before income tax		-			-			6			(3	)
	Income tax benefit		-			-			(1	)		1
	Total cash flow hedges		-			-			5			(2	)
	Retirement benefit plans
	Operation and maintenance expense (actuarial losses)(2)		(4	)		(6	)		(12	)		(19	)
	Operation and maintenance expense (prior service credits) (2)		-			2			1			4
	Total before income tax		(4	)		(4	)		(11	)		(15	)
	Income tax benefit		2			3			5			7
	Total retirement benefit plans		(2	)		(1	)		(6	)		(8	)
	Total reclassification for the period	$	(2	)	$	(1	)	$	(1	)	$	(10	)

Note_9_NonWholly_Owned_Entitie1

Note 9 - Non-Wholly Owned Entities (Tables)	9 Months Ended
	Sep. 30, 2014
Noncontrolling Interest [Abstract]	'
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Table Text Block]	'
		September 30, 2014 (1)								December 31, 2013 (1)							September 30, 2013 (1)
	In millions	Consolidated		SouthStar (2)			-3%			Consolidated		SouthStar (2)		-3%			Consolidated		SouthStar (2)		-3%
	Current assets	$	2,093	$	188			9	%	$	2,895	$	264		9	%	$	2,252	$	192		9	%
	Goodwill and intangible assets		1,957		127			6			1,972		133		7			1,974		136		7
	Long-term assets and other deferred debits		9,903		17			-			9,683		13		-			9,584		13		-
	Total assets	$	13,953	$	332			2	%	$	14,550	$	410		3	%	$	13,810	$	341		2	%
	Current liabilities	$	2,462	$	47			2	%	$	3,118	$	95		3	%	$	2,407	$	73		3	%
	Long-term liabilities and other deferred credits		7,689		-			-			7,819		-		-			7,897		-		-
	Total Liabilities		10,151		47			1			10,937		95		1			10,304		73		1
	Equity		3,802		285			7			3,613		315		9			3,506		268		8
	Total liabilities and equity	$	13,953	$	332			2	%	$	14,550	$	410		3	%	$	13,810	$	341		2	%
Schedule of Variable Interest Entities [Table Text Block]	'
		Three months ended					Nine months ended
		September 30,					September 30,
	In millions	2014		2013			2014			2013
	Operating revenues	$	113	$	98		$	633		$	464
	Operating expenses
	Cost of goods sold		89		81			470			340
	Operation and maintenance		19		16			62			49
	Depreciation and amortization		3		2			8			3
	Taxes other than income taxes		-		-			1			1
	Total operating expenses		111		99			541			393
	Operating income (loss)	$	2	$	(1	)	$	92		$	71
Equity Method Investments [Table Text Block]	'
		September 30,		December 31,			September 30,
	In millions	2014		2013			2013
	Triton	$	64	$	70		$	71
	Horizon Pipeline		14		15			15
	Other		2		1			9
	Total	$	80	$	86		$	95
Schedule of Other Nonoperating Income, by Component [Table Text Block]	'
		Three months ended					Nine months ended
		September 30,					September 30,
	In millions	2014		2013			2014			2013
	Triton (1)	$	2	$	3		$	5		$	7
	Other		-		-			1			1

Note_10_Commitments_Guarantees1

Note 10 - Commitments, Guarantees and Contingencies (Tables)	9 Months Ended
	Sep. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Unrecorded Unconditional Purchase Obligations Disclosure [Table Text Block]	'
														2019 &
	In millions	Total		2014		2015		2016		2017		2018		thereafter
	Recorded contractual obligations:
	Long-term debt (1)	$	3,706	$	-	$	200	$	545	$	22	$	155	$	2,784
	Short-term debt		681		681		-		-		-		-		-
	Environmental remediation liabilities (2)		454		16		83		104		50		38		163
	Pipeline replacement program costs (2)		1		1		-		-		-		-		-
	Total	$	4,842	$	698	$	283	$	649	$	72	$	193	$	2,947
	Unrecorded contractual obligations and commitments(3) (8):
	Pipeline charges, storage capacity and gas supply (4)	$	3,837	$	304	$	564	$	292	$	185	$	174	$	2,318
	Interest charges (5)		2,798		36		179		171		147		146		2,119
	Operating leases (6)		207		11		35		31		24		18		88
	Asset management agreements (7)		31		2		9		8		6		4		2
	Standby letters of credit, performance/surety bonds (8)		27		9		17		1		-		-		-
	Other		9		1		3		3		1		1		-
	Total	$	6,909	$	363	$	807	$	506	$	363	$	343	$	4,527

Note_11_Segment_Information_Ta

Note 11 - Segment Information (Tables)	9 Months Ended
	Sep. 30, 2014
Segment Reporting [Abstract]	'
Schedule of Segment Reporting Information, by Segment [Table Text Block]	'
	In millions	Distributionoperations			Retail operations		Wholesale services (1)			Midstream operations			Other (3)			Intercompany eliminations			Consolidated
	Operating revenues from external parties	$	439		$	146	$	5		$	4		$	1		$	(6	)	$	589
	Intercompany revenues		35			-		-			-			-			(35	)		-
	Total operating revenues		474			146		5			4			1			(41	)		589
	Operating expenses
	Cost of goods sold		138			99		3			(3	)		-			(39	)		198
	Operation and maintenance		145			34		10			5			1			(2	)		193
	Depreciation and amortization		79			7		-			5			2			-			93
	Taxes other than income taxes		24			1		1			1			3			-			30
	Total operating expenses		386			141		14			8			6			(41	)		514
	Gain on disposition of assets		-			-		3			-			-			-			3
	Operating income (loss)		88			5		(6	)		(4	)		(5	)		-			78
	Other income (expense)		1			-		(1	)		-			3			-			3
	EBIT	$	89		$	5	$	(7	)	$	(4	)	$	(2	)	$	-		$	81
	Capital expenditures	$	196		$	3	$	-		$	3		$	9		$	-		$	211
	In millions	Distribution operations (4)			Retail operations (4)		Wholesale services (1)			Midstream operations			Other (3)			Intercompany eliminations			Consolidated (4)
	Operating revenues from external parties	$	409		$	138	$	13		$	19		$	1		$	(6	)	$	574
	Intercompany revenues		36			-		-			-			-			(36	)		-
	Total operating revenues		445			138		13			19			1			(42	)		574
	Operating expenses
	Cost of goods sold		111			92		1			9			-			(39	)		174
	Operation and maintenance		150			31		13			5			3			(3	)		199
	Depreciation and amortization		89			8		-			5			2			-			104
	Taxes other than income taxes		22			1		1			1			2			-			27
	Total operating expenses		372			132		15			20			7			(42	)		504
	Operating income (loss)		73			6		(2	)		(1	)		(6	)		-			70
	Other income		4			-		-			-			3			-			7
	EBIT	$	77		$	6	$	(2	)	$	(1	)	$	(3	)	$	-		$	77
	Capital expenditures	$	200		$	3	$	-		$	3		$	5		$	-		$	211
	In millions	Distribution operations (4)			Retail operations (4)		Wholesale services (1)			Midstream operations			Other (3)			Intercompany eliminations			Consolidated (4)
	Operating revenues from external parties	$	2,821		$	728	$	383		$	65		$	5		$	(62	)	$	3,940
	Intercompany revenues		153			1		-			-			-			(154	)		-
	Total operating revenues		2,974			729		383			65			5			(216	)		3,940
	Operating expenses
	Cost of goods sold		1,655			498		13			44			-			(210	)		2,000
	Operation and maintenance		515			105		59			18			2			(6	)		693
	Depreciation and amortization		235			21		1			14			10			-			281
	Taxes other than income taxes		146			3		2			4			5			-			160
	Total operating expenses		2,551			627		75			80			17			(216	)		3,134
	Gain on disposition of assets		-			-		3			-			-			-			3
	Operating income (loss)		423			102		311			(15	)		(12	)		-			809
	Other income (expense)		5			-		(3	)		1			5			-			8
	EBIT	$	428		$	102	$	308		$	(14	)	$	(7	)	$	-		$	817
	Identifiable and total assets (2)	$	11,628		$	663	$	1,056		$	692		$	9,167		$	(9,253	)	$	13,953
	Capital expenditures	$	504		$	9	$	1		$	8		$	21		$	-		$	543
	In millions	Distribution operations (4)			Retail operations (4)		Wholesale services (1)			Midstream operations			Other (3)			Intercompany eliminations			Consolidated
																			-4
	Operating revenues from external parties	$	2,266		$	605	$	73		$	58		$	5		$	(16	)	$	2,991
	Intercompany revenues		134			-		-			-			-			(134	)		-
	Total operating revenues		2,400			605		73			58			5			(150	)		2,991
	Operating expenses
	Cost of goods sold		1,142			402		21			25			-			(143	)		1,447
	Operation and maintenance		493			94		36			17			1			(7	)		634
	Depreciation and amortization		265			20		1			13			10			-			309
	Taxes other than income taxes		124			3		2			4			6			-			139
	Total operating expenses		2,024			519		60			59			17			(150	)		2,529
	Gain on disposition of assets		-			-		11			-			-			-			11
	Operating income (loss)		376			86		24			(1	)		(12	)		-			473
	Other income		11			-		-			2			5			-			18
	EBIT	$	387		$	86	$	24		$	1		$	(7	)	$	-		$	491
	Identifiable and total assets (2)	$	11,215		$	644	$	930		$	726		$	9,784		$	(9,783	)	$	13,516
	Capital expenditures	$	495		$	7	$	-		$	11		$	13		$	-		$	526
Reconciliation of Revenue from Segments to Consolidated [Table Text Block]	'
	In millions	Third party gross revenues (4)			Intercompany		Total gross			Less gross			Operating
					revenues		revenues (4)			gas costs			revenues (4)
	Three months ended September 30, 2014	$	1,885		$	126	$	2,011		$	2,006		$	5
	Three months ended September 30, 2013		1,716			69		1,785			1,772			13
	Nine months ended September 30, 2014		8,313			584		8,897			8,514			383
	Nine months ended September 30, 2013		5,792			312		6,104			6,031			73
Schedule Of Segment Reporting Information By Segment Total Assets Goodwill [Table Text Block]	'
	In millions	Identifiable and total assets
	Distribution operations (1)	$	11,634
	Retail operations (1)		685
	Wholesale services (1)		1,163
	Midstream operations		713
	Other		10,160
	Intercompany elimination		(10,088	)
	Consolidated (1)	$	14,267

Note_12_Discontinued_Operation1

Note 12 - Discontinued Operations (Tables)	9 Months Ended
	Sep. 30, 2014
Balance Sheet [Member]	'
Note 12 - Discontinued Operations (Tables) [Line Items]	'
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	'
		December 31,			September 30,
	In millions	2013			2013
	Current assets
	Cash and cash equivalents	$	24		$	34
	Short-term investments		1			1
	Receivables		36			33
	Inventories		9			9
	Other		1			3
	Total current assets		71			80
	Long-term assets and other deferred debits
	Property, plant and equipment, net		124			126
	Goodwill		61			61
	Intangible assets		19			19
	Other		8			8
	Total long-term assets and other deferred debits		212			214
	Total assets held for sale	$	283		$	294
	Current liabilities
	Other accounts payable - trade	$	11		$	9
	Accrued expenses		7			7
	Other		22			23
	Total liabilities held for sale	$	40		$	39
Income Statement [Member]	'
Note 12 - Discontinued Operations (Tables) [Line Items]	'
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	'
		Three months ended					Nine months ended
		September 30,					September 30,
	In millions	2014			2013		2014			2013
	Operating revenues	$	62		$	89	$	243		$	264
	Operating expenses
	Cost of goods sold		38			55		149			162
	Operation and maintenance (1)		20			27		75			82
	Depreciation and amortization (2)		-			4		5			14
	Taxes other than income taxes		1			2		5			5
	Loss on sale and goodwill impairment (3)		5			-		28			-
	Total operating expenses		64			88		262			263
	Operating (loss) income		(2	)		1		(19	)		1
	(Loss) income before income taxes		(2	)		1		(19	)		1
	Income tax expense (4)		(29	)		-		(61	)		-
	(Loss) Income from discontinued operations, net of tax	$	(31	)	$	1	$	(80	)	$	1

Note_13_Revision_to_Prior_Peri1

Note 13 - Revision to Prior Period Financial Statements (Tables)	9 Months Ended
	Sep. 30, 2013																			Sep. 30, 2013					Sep. 30, 2014										Sep. 30, 2014
	Revisions to Income Statement [Member]																			Revisions to Balance Sheets [Member]					Revisions to Statement of Cash Flows [Member]										Revision to Intangible Assets [Member]
Note 13 - Revision to Prior Period Financial Statements (Tables) [Line Items]	'																			'					'										'
Schedule of Error Corrections and Prior Period Adjustments [Table Text Block]	'																			'					'										'
		For the three months ended									For the nine months ended										As of September 30, 2013					For the nine months ended										30-Sep-13
		30-Sep-13									30-Sep-13									In millions	As filed (1)		Revised			30-Sep-13									In millions	Gross		Accumulated			Net
	In millions, except per share amounts	As filed (1)			Adjustment			Revised			As filed (1)			Adjustment			Revised			Current assets					In millions	As filed (1)			Adjustment			Revised						amortization
	Operating revenues	$	586		$	(12	)	$	574		$	3,024		$	(33	)	$	2,991		Regulatory assets	$	133	$	87	Cash flows from operating activities										Customer relationships
	Operating expenses																			Total current assets		2,091		2,252	Net income	$	242		$	(13	)	$	229		Retail operations as reported	$	131	$	(12	)	$	119
	Cost of goods sold		174			-			174			1,447			-			1,447		Long-term assets and other deferred debits					Adjustments to reconcile net income to net cash flow provided by operating activities										Adjustments		-		(9	)		(9	)
	Operation and maintenance		199			-			199			636			(2	)		634		Property, plant and equipment		10,920		10,761	Depreciation and amortization		311			(2	)		309		Revised total	$	131	$	(21	)	$	110
	Depreciation and amortization		105			(1	)		104			311			(2	)		309		Less accumulated depreciation		2,307		2,281	Deferred income taxes		(28	)		(4	)		(32	)	Trade names
	Taxes other than income taxes		27			-			27			139			-			139		Property, plant and equipment, net		8,613		8,480	Changes to certain assets and liabilities										Retail operations as reported	$	46	$	(5	)	$	41
	Total operating expenses		505			(1	)		504			2,533			(4	)		2,529		Regulatory assets		871		845	Other, net		63			19			82		Adjustments		-		1			1
	Gain on disposition of assets		-			-			-			11			-			11		Intangible assets		160		152	Net cash flow provided by operating activities	$	1,070			-		$	1,070		Revised total	$	46	$	(4	)	$	42
	Operating income		81			(11	)		70			502			(29	)		473		Other		251		259
	Other income		7			-			7			19			(1	)		18		Total long-term assets and other deferred debits		11,813		11,558
	Interest expense, net		(43	)		6			(37	)		(135	)		9			(126	)	Total assets	$	13,904	$	13,810
	Income before income taxes		45			(5	)		40			386			(21	)		365		Current liabilities
	Income tax expense		18			(2	)		16			145			(8	)		137		Accrued expenses	$	157	$	149
	Income from continuing operations		27			(3	)		24			241			(13	)		228		Total current liabilities		2,407		2,407
	Income from discontinued operations		1			-			1			1			-			1		Long-term liabilities and other deferred credits
	Net income		28			(3	)		25			242			(13	)		229		Accumulated deferred income taxes		1,587		1,551
	Less net income attributable to the noncontrolling interest		-			-			-			11			-			11		Total long-term liabilities and other deferred credits		7,934		7,897
	Net income attributable to AGL Resources Inc.	$	28		$	(3	)	$	25		$	231		$	(13	)	$	218		Total liabilities and other deferred credits	$	10,341	$	10,304
	Per common share information																			Equity
	Basic earnings per common share (2)																			Additional paid-in capital	$	2,046	$	2,047
	Continuing operations	$	0.23		$	(0.03	)	$	0.2		$	1.95		$	(0.10	)	$	1.85		Retained earnings		1,100		1,042
	Discontinued operations		0.01			-			0.01			0.01			-			0.01		Total equity		3,563		3,506
	Basic earnings per common share attributable to AGL Resources Inc. common shareholders	$	0.24		$	(0.03	)	$	0.21		$	1.96		$	(0.10	)	$	1.86		Total liabilities and equity	$	13,904	$	13,810
	Diluted earnings per common share (2)
	Continuing operations	$	0.23		$	(0.03	)	$	0.2		$	1.95		$	(0.11	)	$	1.84
	Discontinued operations		0.01			-			0.01			0.01			-			0.01
	Diluted earnings per common share attributable to AGL Resources Inc. common shareholders	$	0.24		$	(0.03	)	$	0.21		$	1.96		$	(0.11	)	$	1.85

Note_1_Organization_and_Basis_1

Note 1 - Organization and Basis of Presentation (Details) (Incentive Compensation [Member], USD $)	1 Months Ended
In Millions, except Share data, unless otherwise specified	Feb. 28, 2012
Performance Shares [Member]	'
Note 1 - Organization and Basis of Presentation (Details) [Line Items]	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Vested	$1
Restricted Stock [Member]	'
Note 1 - Organization and Basis of Presentation (Details) [Line Items]	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	37,290

Note_2_Significant_Accounting_2

Note 2 - Significant Accounting Policies and Methods of Application (Details) (USD $)

3 Months Ended

9 Months Ended

9 Months Ended

9 Months Ended

0 Months Ended

9 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Dec. 31, 2013

Apr. 11, 2014

Sep. 30, 2013

Apr. 11, 2014

Apr. 11, 2014

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2013

Inaccessible [Member]

Midstream Operations [Member]

Midstream Operations [Member]

Midstream Operations [Member]

Annual Lease Receivable [Member]

Net of Tax [Member]

Dalton Pipeline Arrangement 1 [Member]

Dalton Pipeline Arrangement 2 [Member]

Integrity Tests Performed at Storage Facilities [Member]

Compass Energy [Member]

Compass Energy [Member]

Compass Energy [Member]

Tropical Shipping [Member]

Tropical Shipping [Member]

Goodwill [Member]

Less Than [Member]

Dalton Pipeline Arrangement 2 [Member]

Compass Energy [Member]

mi

Note 2 - Significant Accounting Policies and Methods of Application (Details) [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investments and Cash

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$24

$34

Inventory Write-down

5

1

11

9

'

'

'

'

'

'

'

'

10

'

'

'

'

'

Inventory, Gross

'

'

'

'

19

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Percentage of Voting Interests Acquired

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

Natural Gas Pipeline, Length (in Miles)

'

'

'

'

'

'

'

'

'

'

106

'

'

'

'

'

'

'

Undivided Ownership Interest to Be Leased

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

Operating Leases, Future Minimum Payments Receivable

'

'

'

'

'

'

'

'

26

'

'

'

'

'

'

'

'

'

Lessor Leasing Arrangements, Operating Leases, Term of Contract

'

'

'

'

'

'

'

'

'

'

'

'25 years

'

'

'

'

'

'

Percent Goodwill Exceeds Carrying Value

'

'

'

'

'

'

10.00%

5.00%

'

'

'

'

'

'

'

'

'

'

Fair Value Inputs, Long-term Revenue Growth Rate

'

'

'

'

'

2.50%

'

'

'

'

'

'

'

'

'

'

'

'

Fair Value Inputs, Discount Rate

'

'

'

'

'

7.00%

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Sales of Business, Affiliate and Productive Assets

'

'

'

'

'

'

'

'

'

'

'

'

'

12

'

'

'

'

Gain (Loss) on Disposition of Business

'

'

'

'

'

'

'

'

'

5

'

'

'

11

'

'

'

'

Business Combination, Contingent Consideration Arrangements, Range of Outcomes, Value, High

'

'

'

'

'

'

'

'

'

'

'

'

'

8

'

'

'

'

Business Combination, Contingent Consideration, Asset

'

'

'

'

'

'

'

'

'

'

'

'

'

3

'

4

'

'

Business Combination, Contingent Consideration Arrangements, Range of Outcomes, Value, Low

'

'

'

'

'

'

'

'

'

'

'

'

'

5

'

'

'

'

Business Combination Contingent Consideration Arrangements Earn Out Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

Former Gain Contingency, Recognized in Current Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$3

'

'

Note_2_Significant_Accounting_3

Note 2 - Significant Accounting Policies and Methods of Application (Details) - Changes in Amount of Goodwill (USD $)

9 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2012

Distribution Operations [Member]

Distribution Operations [Member]

Distribution Operations [Member]

Distribution Operations [Member]

Retail Operations [Member]

Retail Operations [Member]

Retail Operations [Member]

Midstream Operations [Member]

Midstream Operations [Member]

Midstream Operations [Member]

Midstream Operations [Member]

Goodwill [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Goodwill

$1,776

$1,827

$1,827

[1]

$1,640

$1,640

[1]

$1,640

[1]

$1,640

$122

$173

$173

[1]

$14

$14

[1]

$14

[1]

$14

2013 acquisitions

46

'

'

'

'

'

'

46

'

'

'

'

'

'

Goodwill

$1,822

[1]

$1,827

$1,827

[1]

$1,640

$1,640

[1]

$1,640

[1]

$1,640

$168

[1]

$173

$173

[1]

$14

$14

[1]

$14

[1]

$14

[1]

Excludes goodwill at Tropical Shipping which is classified as held for sale. See Note 12 for additional information.

Note_2_Significant_Accounting_4

Note 2 - Significant Accounting Policies and Methods of Application (Details) - Other Income (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Component of Operating Income [Abstract]	'		'		'		'
Equity method investment income (1)	$2	[1]	$3	[1]	$6	[1]	$8	[1]
AFUDC - equity	1		3		2		8
Other, net	'		1		'		2
Total other income	$3		$7	[2]	$8	[2]	$18	[2]
[1]	For more information on our equity method investment income, see Note 9.
[2]	Amounts revised and include prior period adjustments. See Note 13 for additional information.

Note_2_Significant_Accounting_5

Note 2 - Significant Accounting Policies and Methods of Application (Details) - Potentially Dilutive Common Share Calculation (USD $)	3 Months Ended				9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Potentially Dilutive Common Share Calculation [Abstract]	'		'		'		'
Income from continuing operations (2) (in Dollars)	$23	[1]	$24	[1],[2]	$414	[1],[2]	$217	[1],[2]
(Loss) income from discontinued operations, net of tax (3) (in Dollars)	-31	[3]	1	[2],[3]	-80	[2],[3]	1	[2],[3]
Net (loss) income attributable to AGL Resources Inc. (in Dollars)	($8)		$25	[2]	$334	[2]	$218	[2]
Basic weighted average number of common shares outstanding (4) (in Shares)	119	[4]	118.2	[2],[4]	118.8	[2],[4]	117.8	[2],[4]
Effect of dilutive securities (in Shares)	0.4		0.3	[2]	0.4	[2]	0.3	[2]
Diluted weighted average number of common shares outstanding (in Shares)	119.4		118.5	[2]	119.2	[2]	118.1	[2]
Basic earnings (loss) per common share	'		'		'		'
From continuing operations	$0.19		$0.20	[1],[2]	$3.48	[2]	$1.85	[1],[2]
From discontinued operations	($0.25)		$0.01	[1],[2]	($0.67)	[2]	$0.01	[1],[2]
Basic (loss) earnings per common share attributable to AGL Resources Inc. common shareholders	($0.06)		$0.21	[2]	$2.81	[2]	$1.86	[2]
Diluted earnings (loss) per common share	'		'		'		'
From continuing operations	$0.19		$0.20	[1],[2]	$3.47	[2]	$1.84	[1],[2]
From discontinued operations	($0.25)		$0.01	[1],[2]	($0.67)	[2]	$0.01	[1],[2]
Diluted (loss) earnings per common share attributable to AGL Resources Inc. common shareholders	($0.06)		$0.21	[2]	$2.80	[2]	$1.85	[2]
[1]	Excludes net income attributable to the noncontrolling interest.
[2]	Amounts revised and or include prior period adjustments. See Note 13 for additional information.
[3]	For additional information on our discontinued operations, see Note 12.
[4]	Daily weighted average shares outstanding.

Note_3_Regulated_Operations_De

Note 3 - Regulated Operations (Details) (USD $)	1 Months Ended	9 Months Ended
In Millions, unless otherwise specified	Jul. 31, 2014	Sep. 30, 2014	Sep. 30, 2013
Note 3 - Regulated Operations (Details) [Line Items]	'	'	'
Increase (Decrease) in Other Regulatory Assets	'	$65	($14)
Other Increase (Decrease) in Environmental Liabilities	'	7	'
Increase (Decrease) in Insurance Settlements Receivable	77	'	'
Insurance Settlements Receivable, Number of Installments	2	'	'
Proceeds from Insurance Settlement, Operating Activities	45	'	'
Insurance Settlements Receivable, Current	'	32	'
Natural Gas Costs [Member]	'	'	'
Note 3 - Regulated Operations (Details) [Line Items]	'	'	'
Increase (Decrease) in Other Regulatory Assets	'	$78	'

Note_3_Regulated_Operations_De1

Note 3 - Regulated Operations (Details) - Summary of Regulatory Assets and Liabilities (USD $)	Sep. 30, 2014		Dec. 31, 2013		Sep. 30, 2013
In Millions, unless otherwise specified
Regulatory assets	'		'		'
Regulatory assets, current	$105		$114	[1]	$87	[1]
Regulatory assets, long-term	637		705	[1]	845	[1]
Total regulatory assets	742		819	[1]	932	[1]
Regulatory liabilities, current	118		183	[1]	174	[1]
Regulatory liabilities, long-term	1,567		1,518	[1]	1,524	[1]
Total regulatory liabilities	1,685		1,701	[1]	1,698	[1]
Seasonal Rates [Member]	'		'		'
Regulatory assets	'		'		'
Regulatory liabilities, current	9		10	[1]	9	[1]
Bad Debt Rider [Member]	'		'		'
Regulatory assets	'		'		'
Regulatory liabilities, current	31		41	[1]	37	[1]
Regulatory liabilities, long-term	7		17	[1]	20	[1]
Accrued natural gas costs [Member]	'		'		'
Regulatory assets	'		'		'
Regulatory liabilities, current	29		92	[1]	104	[1]
Accumulated removal costs [Member]	'		'		'
Regulatory assets	'		'		'
Regulatory liabilities, current	27		27	[1]	17	[1]
Regulatory liabilities, long-term	1,499		1,445	[1]	1,448	[1]
Other Regulatory Liabilities [Member]	'		'		'
Regulatory assets	'		'		'
Regulatory liabilities, current	31		23	[1]	16	[1]
Regulatory liabilities, long-term	12		3	[1]	4	[1]
Regulatory Income Tax Liability [Member]	'		'		'
Regulatory assets	'		'		'
Regulatory liabilities, long-term	26		27	[1]	26	[1]
Unamortized investment tax credit [Member]	'		'		'
Regulatory assets	'		'		'
Regulatory liabilities, long-term	23		26	[1]	26	[1]
Recoverable Environmental Remediation Costs [Member]	'		'		'
Regulatory assets	'		'		'
Regulatory assets, current	41		45	[1]	30	[1]
Regulatory assets, long-term	363		433	[1]	456	[1]
Recoverable Pension And Other Retirement Benefit Costs [Member]	'		'		'
Regulatory assets	'		'		'
Regulatory assets, current	9		9	[1]	19	[1]
Regulatory assets, long-term	91		99	[1]	183	[1]
Deferred Natural Gas Costs [Member]	'		'		'
Regulatory assets	'		'		'
Regulatory assets, current	3		1	[1]	'	[1]
Other Regulatory Assets [Member]	'		'		'
Regulatory assets	'		'		'
Regulatory assets, current	43		49	[1]	29	[1]
Regulatory assets, long-term	45		36	[1]	44	[1]
Long-Term Debt Fair Value Adjustment [Member]	'		'		'
Regulatory assets	'		'		'
Regulatory assets, long-term	76		82	[1]	84	[1]
Recoverable Regulatory Infrastructure Program Costs [Member]	'		'		'
Regulatory assets	'		'		'
Regulatory assets, long-term	$62	[1]	$55	[1]	$78	[1]
[1]	Amounts revised for prior period adjustments. See Note 13 for additional information.

Note_3_Regulated_Operations_De2

Note 3 - Regulated Operations (Details) - Estimated Recognition of Rate Making Assets (USD $)	Sep. 30, 2014	Dec. 31, 2013		Sep. 30, 2013
In Millions, unless otherwise specified
Regulatory Assets [Line Items]	'	'		'
Rate-Making Asset	$742	$819	[1]	$932	[1]
Regulatory Assett Off Balance Sheet [Member]	'	'		'
Regulatory Assets [Line Items]	'	'		'
Rate-Making Asset	$118	$93		$86
[1]	Amounts revised for prior period adjustments. See Note 13 for additional information.

Note_3_Regulated_Operations_De3

Note 3 - Regulated Operations (Details) - Change in Net Position of Deferred and Accrued Natural Gas Costs (USD $)

9 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2013

Natural Gas Costs [Member]

Natural Gas Costs [Member]

Accrued natural gas costs [Member]

Accrued natural gas costs [Member]

Accrued natural gas costs [Member]

Deferred Natural Gas Costs [Member]

Deferred Natural Gas Costs [Member]

Deferred Natural Gas Costs [Member]

Note 3 - Regulated Operations (Details) - Change in Net Position of Deferred and Accrued Natural Gas Costs [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Deferred natural gas costs

$105

$87

[1]

$114

[1]

'

'

'

'

'

$3

$1

[1]

'

[1]

Deferred natural gas costs

65

-14

'

'

'

'

'

'

3

'

'

Accrued natural gas costs

-118

-174

[1]

-183

[1]

'

'

-29

-92

[1]

-104

[1]

'

'

'

Accrued natural gas costs

'

'

'

'

'

75

'

'

'

'

'

Total (1)

'

'

'

-26

[2]

-104

[2]

'

'

'

'

'

'

Total (1)

'

'

'

$78

[2]

'

'

'

'

'

'

'

[1]

Amounts revised for prior period adjustments. See Note 13 for additional information.

[2]

The $78 million change resulted from increased natural gas prices during the first nine months of 2014 compared to the first nine months of 2013, primarily driven by colder weather experienced in 2014.

Note_3_Regulated_Operations_De4

Note 3 - Regulated Operations (Details) - Costs Related to Remediation of Former Operating Sites (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014
Environmental Exit Cost [Line Items]	'
Probabilistic model cost estimates, low estimate	$378
Probabilistic model cost estimates, high estimate	742
Engineering estimates	82
Amount recorded	454	[1]
Expected costs over next 12 months	82
Illinois Environmental [Member]	'
Environmental Exit Cost [Line Items]	'
Probabilistic model cost estimates, low estimate	205
Probabilistic model cost estimates, high estimate	462
Engineering estimates	46
Amount recorded	244
Expected costs over next 12 months	41
New Jersey Environmental [Member]	'
Environmental Exit Cost [Line Items]	'
Probabilistic model cost estimates, low estimate	107
Probabilistic model cost estimates, high estimate	174
Engineering estimates	16
Amount recorded	122
Expected costs over next 12 months	16
Georgia And Florida [Member]	'
Environmental Exit Cost [Line Items]	'
Probabilistic model cost estimates, low estimate	66
Probabilistic model cost estimates, high estimate	106
Engineering estimates	9
Amount recorded	77
Expected costs over next 12 months	17
North Carolina Environmental [Member]	'
Environmental Exit Cost [Line Items]	'
Probabilistic model cost estimates, low estimate	'	[2]
Probabilistic model cost estimates, high estimate	'	[2]
Engineering estimates	11	[2]
Amount recorded	11	[2]
Expected costs over next 12 months	$8	[2]
[1]	Increase of $7 million from December 31, 2013, primarily relates to a scope increase required by the Georgia Environmental Protection Division for a site in Georgia and an adjustment for a site in Florida. This was partially offset by a decrease for a site in New Jersey where remediation is almost complete.
[2]	We have no regulatory recovery mechanisms for the site in North Carolina. Therefore, there is no amount included within our regulatory assets and changes in estimated costs are recognized in income in the period of change.

Note_4_Fair_Value_Measurements2

Note 4 - Fair Value Measurements (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013
In Millions, unless otherwise specified
Fair Value Disclosures [Abstract]	'	'	'
Weather Derivative Premium	$3	$3	$3

Note_4_Fair_Value_Measurements3

Note 4 - Fair Value Measurements (Details) - Derivative Assets and Liabilities (Natural Gas Derivatives [Member], USD $)	Sep. 30, 2014		Dec. 31, 2013		Sep. 30, 2013
In Millions, unless otherwise specified
Natural gas derivatives	'		'		'
Derivative Assets	$110	[1],[2],[3]	$116	[1],[2],[3]	$109	[1],[2],[3]
Derivative Liabilities	-47	[2],[3]	-80	[2],[3]	-44	[2],[3]
Netting of cash collateral	49	[1]	43	[1]	45	[1]
Netting of cash collateral	76		78		49
Fair Value, Inputs, Level 1 [Member]	'		'		'
Natural gas derivatives	'		'		'
Derivative Assets	4	[1]	6	[1]	4	[1]
Derivative Liabilities	-72		-79		-52
Fair Value, Inputs, Level 2 [Member]	'		'		'
Natural gas derivatives	'		'		'
Derivative Assets	57	[1]	67	[1]	60	[1]
Derivative Liabilities	($51)		($79)		($41)
[1]	Balances of $3 million at September 30, 2014, December 31, 2013 and September 30, 2013, associated with certain weather derivatives have been excluded, as they are accounted for based on intrinsic value rather than fair value.
[2]	There were no significant unobservable inputs (Level 3) for any of the dates presented.
[3]	There were no significant transfers between Level 1, Level 2 or Level 3 for any of the dates presented.

Note_4_Fair_Value_Measurements4

Note 4 - Fair Value Measurements (Details) - Amortized Cost and Fair Value of Long-Term Debt (USD $)	Sep. 30, 2014		Dec. 31, 2013		Sep. 30, 2013
In Millions, unless otherwise specified
Note 4 - Fair Value Measurements (Details) - Amortized Cost and Fair Value of Long-Term Debt [Line Items]	'		'		'
Long-term debt carrying amount	$3,805		$3,813		$3,816
Fair Value, Inputs, Level 2 [Member]	'		'		'
Note 4 - Fair Value Measurements (Details) - Amortized Cost and Fair Value of Long-Term Debt [Line Items]	'		'		'
Long-term debt fair value (1)	$4,165	[1]	$3,956	[1]	$4,024	[1]
[1]	Fair value determined using Level 2 inputs.

Note_5_Derivative_Instruments_1

Note 5 - Derivative Instruments (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Note 5 - Derivative Instruments (Details) [Line Items]	'	'	'
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	$47	'	'
Increase (Decrease) in Risk Management Assets and Liabilities	27	-37	'
Collateral Already Posted, Aggregate Fair Value	125	94	121
Price Risk Cash Flow Hedge Unrealized Gain (Loss) to be Reclassified During Next 12 Months	1	'	'
Less Than Two Years [Member] | Natural Gas Derivatives [Member]	'	'	'
Note 5 - Derivative Instruments (Details) [Line Items]	'	'	'
Percent Of Derivative Contracts	98.00%	'	'
Derivative, Term of Contract	'2 years	'	'
Expiring in Two to Five Years [Member] | Natural Gas Derivatives [Member] | Maximum [Member]	'	'	'
Note 5 - Derivative Instruments (Details) [Line Items]	'	'	'
Derivative, Term of Contract	'5 years	'	'
Expiring in Two to Five Years [Member] | Natural Gas Derivatives [Member] | Minimum [Member]	'	'	'
Note 5 - Derivative Instruments (Details) [Line Items]	'	'	'
Derivative, Term of Contract	'2 years	'	'
Expiring in Two to Five Years [Member] | Natural Gas Derivatives [Member]	'	'	'
Note 5 - Derivative Instruments (Details) [Line Items]	'	'	'
Percent Of Derivative Contracts	2.00%	'	'
Weather Derivatives [Member]	'	'	'
Note 5 - Derivative Instruments (Details) [Line Items]	'	'	'
Derivative, Gain (Loss) on Derivative, Net	-6	-3	'
Maximum [Member]	'	'	'
Note 5 - Derivative Instruments (Details) [Line Items]	'	'	'
Derivative, Collateral, Obligation to Return Cash	$10	'	'

Note_5_Derivative_Instruments_2

Note 5 - Derivative Instruments (Details) - Net Long Natural Gas Contracts	Sep. 30, 2014		Dec. 31, 2013		Sep. 30, 2013
	ft3		ft3		ft3
Net Long Natural Gas Contracts [Abstract]	'		'		'
Cash flow hedges	7,000,000,000	[1],[2]	6,000,000,000	[1]	3,000,000,000	[1]
Not designated as hedges	97,000,000,000	[1],[2]	183,000,000,000	[1]	40,000,000,000	[1]
Total volumes	104,000,000,000	[1],[2]	189,000,000,000	[1]	43,000,000,000	[1]
Short position	-2,756,000,000,000	[1],[2]	-2,622,000,000,000	[1]	-2,788,000,000,000	[1]
Long position	2,860,000,000,000	[1],[2]	2,811,000,000,000	[1]	2,831,000,000,000	[1]
Net long position	104,000,000,000	[1],[2]	189,000,000,000	[1]	43,000,000,000	[1]
[1]	Volumes related to Nicor Gas exclude variable-priced contracts, which are carried at fair value, but whose fair values are not directly impacted by changes in commodity prices.
[2]	Approximately 98% of these contracts have durations of 2 years or less and the remaining 2% expire between 2 and 5 years.

Note_5_Derivative_Instruments_3

Note 5 - Derivative Instruments (Details) - Gains and Losses on Derivative Instruments (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Nicor Gas [Member]	'	'	'	'
Note 5 - Derivative Instruments (Details) - Gains and Losses on Derivative Instruments [Line Items]	'	'	'	'
Realized losses related to hedging natural gas costs	($4)	($6)	$8	$2
Elizabethtown Gas [Member]	'	'	'	'
Note 5 - Derivative Instruments (Details) - Gains and Losses on Derivative Instruments [Line Items]	'	'	'	'
Realized losses related to hedging natural gas costs	($1)	($1)	$4	($5)

Note_5_Derivative_Instruments_4

Note 5 - Derivative Instruments (Details) - Derivative Instruments on the Condensed Consolidated Statements of Financial Position (USD $)	Sep. 30, 2014		Dec. 31, 2013		Sep. 30, 2013
In Millions, unless otherwise specified
Designated as cash flow or fair value hedges	'		'		'
Net amounts of assets and liabilities presented in our unaudited Condensed Consolidated Statements of Financial Position (3)	($47)		'		'
Current Natural Gas Contracts [Member] | Designated as Hedging Instrument [Member]	'		'		'
Designated as cash flow or fair value hedges	'		'		'
Assets	2		3		6
Liabilities	-2		-1		-5
Current Natural Gas Contracts [Member] | Not Designated as Hedging Instrument [Member]	'		'		'
Designated as cash flow or fair value hedges	'		'		'
Assets	834		691		445
Liabilities	-891		-761		-462
Long-Term Natural Gas Contracts [Member] | Not Designated as Hedging Instrument [Member]	'		'		'
Designated as cash flow or fair value hedges	'		'		'
Assets	78		206		143
Liabilities	-80		-220		-153
Long-Term Natural Gas Contracts [Member]	'		'		'
Designated as cash flow or fair value hedges	'		'		'
Assets	914	[1],[2]	900	[1],[2]	594	[1],[2]
Liabilities	-973	[1],[2]	-982	[1],[2]	-620	[1],[2]
Gross amounts offset in our unaudited Condensed Consolidated Statements of Financial Position (2)	-801	[2]	-781	[2]	-482	[2]
Gross amounts offset in our unaudited Condensed Consolidated Statements of Financial Position (2)	926	[2]	902	[2]	576	[2]
Designated as Hedging Instrument [Member]	'		'		'
Designated as cash flow or fair value hedges	'		'		'
Net amounts of assets and liabilities presented in our unaudited Condensed Consolidated Statements of Financial Position (3)	113	[3]	119	[3]	112	[3]
Net amounts of assets and liabilities presented in our unaudited Condensed Consolidated Statements of Financial Position (3)	-47	[3]	-80	[3]	-44	[3]
Not Designated as Hedging Instrument [Member]	'		'		'
Designated as cash flow or fair value hedges	'		'		'
Assets	912		897		588
Liabilities	($971)		($981)		($615)
[1]	The gross amounts of recognized assets and liabilities are netted within our unaudited Condensed Consolidated Statements of Financial Position to the extent that we have netting arrangements with the counterparties.
[2]	As required by the authoritative guidance related to derivatives and hedging, the gross amounts of recognized assets and liabilities above do not include cash collateral held on deposit in broker margin accounts of $125 million as of September 30, 2014, $121 million as of December 31, 2013, and $94 million as of September 30, 2013. Cash collateral is included in the "Gross amounts offset in our unaudited Condensed Consolidated Statements of Financial Position" line of this table.
[3]	At September 30, 2014, December 31, 2013, and September 30, 2013, we held letters of credit from counterparties that would offset, under master netting arrangements, an insignificant portion of these assets.

Note_5_Derivative_Instruments_5

Note 5 - Derivative Instruments (Details) - Derivative Instruments on the Consolidated Statements of Income (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Designated as cash flow or fair value hedges	'		'		'		'
Income tax benefit	'		'		($1)		$1
Net of tax	'	[1]	'	[1]	5	[1]	-2	[1]
Not designated as hedges (1)	'		'		'		'
Total (losses) gains on derivative instruments	-5		-9		1		-11
Cost of Sales [Member] | Cash Flow Hedging [Member]	'		'		'		'
Designated as cash flow or fair value hedges	'		'		'		'
Natural gas contracts - gain (loss) reclassified from OCI	-1		-1		4		'
Cost of Sales [Member] | Fair Value Hedging [Member]	'		'		'		'
Not designated as hedges (1)	'		'		'		'
Natural gas contracts - net value adjustments	-1	[2],[3]	'	[2],[3]	'	[2],[3]	-1	[2],[3]
Operating Expense [Member] | Cash Flow Hedging [Member]	'		'		'		'
Designated as cash flow or fair value hedges	'		'		'		'
Natural gas contracts - gain (loss) reclassified from OCI	1		'		2		'
Interest Expense [Member] | Cash Flow Hedging [Member]	'		'		'		'
Designated as cash flow or fair value hedges	'		'		'		'
Natural gas contracts - gain (loss) reclassified from OCI	'		1		'		-2
Sales [Member] | Fair Value Hedging [Member]	'		'		'		'
Not designated as hedges (1)	'		'		'		'
Natural gas contracts - net value adjustments	-6	[2]	-14	[2]	-6	[2]	-16	[2]
Cash Flow Hedging [Member]	'		'		'		'
Designated as cash flow or fair value hedges	'		'		'		'
Income tax benefit	'		'		-1		1
Net of tax	'		'		5		-1
Fair Value Hedging [Member]	'		'		'		'
Not designated as hedges (1)	'		'		'		'
Income tax benefit	2	[2]	5	[2]	2	[2]	7	[2]
Net of tax	($5)	[2]	($9)	[2]	($4)	[2]	($10)	[2]
[1]	All amounts are net of income taxes. Amounts in parentheses indicate increases to our accumulated other comprehensive loss.
[2]	Associated with the fair value of derivative instruments held at September 30, 2014 and 2013.
[3]	Excludes losses recorded in cost of goods sold associated with weather derivatives of $6 million and $3 million for the nine months ended September 30, 2014 and 2013, respectively.

Note_6_Employee_Benefit_Plans_1

Note 6 - Employee Benefit Plans (Details) - Components of Pension and Other Retirement Benefit Costs (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Pension Plan [Member]	'	'	'	'
Note 6 - Employee Benefit Plans (Details) - Components of Pension and Other Retirement Benefit Costs [Line Items]	'	'	'	'
Service cost	$6	$7	$18	$22
Interest cost	12	11	35	32
Expected return on plan assets	-16	-16	-48	-47
Net amortization of prior service cost	-1	'	-2	-1
Recognized actuarial loss	5	9	16	26
Net periodic benefit cost	6	11	19	32
Other Postretirement Benefit Plan [Member]	'	'	'	'
Note 6 - Employee Benefit Plans (Details) - Components of Pension and Other Retirement Benefit Costs [Line Items]	'	'	'	'
Service cost	1	1	2	2
Interest cost	4	3	11	10
Expected return on plan assets	-2	-1	-5	-4
Net amortization of prior service cost	-1	-1	-2	-3
Recognized actuarial loss	1	2	4	6
Net periodic benefit cost	$3	$4	$10	$11

Note_7_Debt_and_Credit_Facilit2

Note 7 - Debt and Credit Facilities (Details) (USD $)

3 Months Ended

9 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2013

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Maximum [Member]

Nicor Gas [Member]

Nicor Gas [Member]

Nicor Gas [Member]

Minimum [Member]

Maximum [Member]

AGL Capital [Member]

Nicor Gas [Member]

Note 7 - Debt and Credit Facilities (Details) [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Effective Percentage

'

'

'

'

'

0.30%

0.20%

'

'

'

'

'

Debt Instrument, Term

'

'

'

'1 day

'108 days

'

'

'

'

'

'

'

Debt Instrument, Remaining Maturity Term

'

'

'

'1 day

'24 days

'

'

'

'

'

'

'

Proceeds from (Repayments of) Commercial Paper

'

($490)

($545)

'

'

'

'

'

'

'

'

'

Proceeds from Short-term Debt, Maturing in More than Three Months

'

'

'

'

'

'

'

50

'

'

'

'

Repayments of Short-term Debt, Maturing in More than Three Months

'

'

'

'

'

'

'

145

'

'

'

'

Repayments of Commercial Paper

$225

'

'

'

'

'

'

'

'

'

'

'

Ratio of Indebtedness to Net Capital

'

'

'

'

'

'

'

'

0.7

0.57

0.55

0.5

Note_7_Debt_and_Credit_Facilit3

Note 7 - Debt and Credit Facilities (Details) - Debt Schedule (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Dec. 31, 2013		Sep. 30, 2013
Long-term debt - excluding current portion	'		'		'
Maturity date	NaN, NaN		'		'
Outstanding	$3,605		$3,813		$3,816
Unamortized debt premium, net	NaN, NaN		'		'
Unamortized debt premium, net	'	[1]	'		'	[1]
Unamortized debt premium, net	16		16	[1]	16
Total debt	4,486		4,984		4,648
Commercial Paper [Member] | AGL Capital [Member]	'		'		'
Short-term debt	'		'		'
Weighted average interest rate	0.30%	[1],[2]	'		0.40%	[1],[2]
Outstanding	292	[2]	857	[1],[2]	680	[2]
Commercial Paper [Member] | Nicor Gas [Member]	'		'		'
Short-term debt	'		'		'
Weighted average interest rate	0.20%	[1],[2]	'		0.30%	[1],[2]
Outstanding	389	[2]	314	[1],[2]	152	[2]
Commercial Paper [Member]	'		'		'
Short-term debt	'		'		'
Weighted average interest rate	0.30%	[1]	'		0.40%	[1]
Outstanding	681		1,171		832
Current Portion Long-Term Debt [Member]	'		'		'
Short-term debt	'		'		'
Weighted average interest rate	5.00%	[1]	'		'	[1]
Outstanding	200		'	[1]	'
Senior Notes [Member]	'		'		'
Long-term debt - excluding current portion	'		'		'
Weighted average interest rate	5.00%	[1]	'		5.10%	[1]
Outstanding	2,625		2,825	[1]	2,825
First Mortgage Bonds [Member]	'		'		'
Long-term debt - excluding current portion	'		'		'
Weighted average interest rate	5.60%	[1]	'		5.60%	[1]
Outstanding	500		500	[1]	500
Gas Facility Revenue Bonds [Member]	'		'		'
Long-term debt - excluding current portion	'		'		'
Weighted average interest rate	0.90%	[1]	'		0.80%	[1]
Outstanding	200		200	[1]	200
Medium-term Notes [Member]	'		'		'
Long-term debt - excluding current portion	'		'		'
Weighted average interest rate	7.80%	[1]	'		7.80%	[1]
Outstanding	181		181	[1]	181
Long-Term Debt Principal [Member]	'		'		'
Long-term debt - excluding current portion	'		'		'
Weighted average interest rate	4.90%	[1]	'		4.90%	[1]
Outstanding	3,506		3,706		3,706
Fair Value Adjustment [Member]	'		'		'
Long-term debt - excluding current portion	'		'		'
Maturity date	NaN, NaN	[3]	'		'
Weighted average interest rate	'	[1],[3]	'		'	[1],[3]
Outstanding	83	[3]	91	[1],[3]	94	[3]
Unamortized debt premium, net	NaN, NaN	[3]	'		'
Long-Term Debt Non-Principal [Member]	'		'		'
Long-term debt - excluding current portion	'		'		'
Weighted average interest rate	'	[1]	'		'	[1]
Outstanding	$99		$107		$110
[1]	Interest rates are calculated based on the daily weighted average balance outstanding for the nine months ended September 30.
[2]	As of September 30, 2014, the effective interest rates on our commercial paper borrowings were 0.3% for AGL Capital and 0.2% for Nicor Gas.
[3]	See Note 4 for additional information on our fair value measurements.

Note_7_Debt_and_Credit_Facilit4

Note 7 - Debt and Credit Facilities (Details) - Debt-to-Capitalization Ratios	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013
AGL Resources Inc [Member]	'	'	'
Schedule of Capitalization [Line Items]	'	'	'
Debt-to-capitalization ratios	0.53	0.57	0.56
Nicor Gas [Member]	'	'	'
Schedule of Capitalization [Line Items]	'	'	'
Debt-to-capitalization ratios	0.57	0.55	0.5

Note_8_Equity_Details_Other_Co

Note 8 - Equity (Details) - Other Comprehensive Income (Loss) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Other Comprehensive Income (Loss) [Abstract]	'		'		'		'
As of beginning of period	'	[1]	($1)	[1]	$1	[1]	($3)	[1]
As of beginning of period	-133	[1]	-208	[1]	-137	[1]	-215	[1]
As of beginning of period	-133	[1]	-209	[1]	-136	[1]	-218	[1]
OCI, before reclassifications	-2	[1]	'	[1]	2	[1]	'	[1]
OCI, before reclassifications	'	[1]	'	[1]	'	[1]	'	[1]
OCI, before reclassifications	-2	[1]	'	[1]	2	[1]	'	[1]
Amounts reclassified from accumulated OCI	'	[1]	'	[1]	-5	[1]	2	[1]
Amounts reclassified from accumulated OCI	2	[1]	1	[1]	6	[1]	8	[1]
Amounts reclassified from accumulated OCI	2	[1]	1	[1]	1	[1]	10	[1]
Net current-period other comprehensive (loss) income	-2	[1]	'	[1]	-3	[1]	2	[1]
Net current-period other comprehensive (loss) income	2	[1]	1	[1]	6	[1]	8	[1]
Net current-period other comprehensive (loss) income	'	[1]	1	[1]	3	[1]	10	[1]
As of end of period	-2	[1]	-1	[1]	-2	[1]	-1	[1]
As of end of period	-131	[1]	-207	[1]	-131	[1]	-207	[1]
As of end of period	($133)	[1]	($208)	[1]	($133)	[1]	($208)	[1]
[1]	All amounts are net of income taxes. Amounts in parentheses indicate increases to our accumulated other comprehensive loss.

Note_8_Equity_Details_Reclassi

Note 8 - Equity (Details) - Reclassifications out of Accumulated Other Comprehensive Loss (USD $)	3 Months Ended				9 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Cash flow hedges	'		'		'		'
Interest expense (interest rate contracts)	($44,000,000)		($37,000,000)		($135,000,000)		($126,000,000)
Total before income tax	37,000,000		40,000,000		682,000,000		365,000,000
Income tax benefit	14,000,000		16,000,000		254,000,000		137,000,000
Net of tax	-8,000,000		25,000,000	[1]	334,000,000	[1]	218,000,000	[1]
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] | Natural Gas Derivatives [Member]	'		'		'		'
Cash flow hedges	'		'		'		'
Cost of goods sold (natural gas contracts)	-1,000,000	[2]	-1,000,000	[2]	4,000,000	[2]	'	[2]
Operation and maintenance expense (natural gas contracts)	1,000,000		'		2,000,000		'
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]	'		'		'		'
Cash flow hedges	'		'		'		'
Interest expense (interest rate contracts)	'	[2]	1,000,000	[2]	'	[2]	-3,000,000	[2]
Total before income tax	'	[2]	'	[2]	6,000,000	[2]	-3,000,000	[2]
Income tax benefit	'	[2]	'	[2]	-1,000,000	[2]	1,000,000	[2]
Net of tax	'	[2]	'	[2]	5,000,000	[2]	-2,000,000	[2]
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment [Member]	'		'		'		'
Cash flow hedges	'		'		'		'
Total before income tax	-4,000,000	[2]	-4,000,000	[2]	-11,000,000	[2]	-15,000,000	[2]
Income tax benefit	2,000,000	[2]	3,000,000	[2]	5,000,000	[2]	7,000,000	[2]
Net of tax	-2,000,000	[2]	-1,000,000	[2]	-6,000,000	[2]	-8,000,000	[2]
Retirement benefit plans	'		'		'		'
Operation and maintenance expense (actuarial losses)(2)	-4,000,000	[2],[3]	-6,000,000	[2],[3]	-12,000,000	[2],[3]	-19,000,000	[2],[3]
Operation and maintenance expense (prior service credits) (2)	'	[2],[3]	2,000,000	[2],[3]	1,000,000	[2],[3]	4,000,000	[2],[3]
Reclassification out of Accumulated Other Comprehensive Income [Member]	'		'		'		'
Cash flow hedges	'		'		'		'
Net of tax	($2,000,000)	[2]	($1,000,000)	[2]	($1,000,000)	[2]	($10,000,000)	[2]
[1]	Amounts revised and or include prior period adjustments. See Note 13 for additional information.
[2]	Amounts in parentheses indicate reductions to our net income and accumulated other comprehensive loss. Except for retirement benefit planamounts, the net income impacts are immediate.
[3]	Amortization of these accumulated other comprehensive loss components is included in the computation of net periodic benefit cost. SeeNote 6 for additional details about net periodic benefit cost.

Note_9_NonWholly_Owned_Entitie2

Note 9 - Non-Wholly Owned Entities (Details) (USD $)

3 Months Ended

9 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Aug. 11, 2014

Sep. 02, 2014

Sep. 30, 2014

Aug. 11, 2014

Sep. 30, 2014

Sep. 02, 2014

South Star [Member]

South Star [Member]

South Star [Member]

South Star [Member]

South Star [Member]

Scenario, Forecast [Member]

Scenario, Forecast [Member]

PennEast Pipeline [Member]

PennEast Pipeline [Member]

Atlantic Coast Pipeline [Member]

Atlantic Coast Pipeline [Member]

AGL Resources Inc [Member]

Piedmont [Member]

Piedmont [Member]

PennEast Pipeline [Member]

Atlantic Coast Pipeline [Member]

Corporate Joint Venture [Member]

Corporate Joint Venture [Member]

Corporate Joint Venture [Member]

Corporate Joint Venture [Member]

Corporate Joint Venture [Member]

Corporate Joint Venture [Member]

mi

mi

ft3

ft3

ft3

ft3

Note 9 - Non-Wholly Owned Entities (Details) [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payments to Acquire Property, Plant, and Equipment

$211

$211

[1]

$543

[1]

$526

[1]

'

'

'

$6

$2

'

'

'

'

'

'

Payments of Ordinary Dividends, Noncontrolling Interest

'

'

$17

$17

'

$17

$17

'

'

'

'

'

'

'

'

Equity Method Investment, Ownership Percentage

'

'

'

'

85.00%

'

'

'

'

'

'

20.00%

'

5.00%

'

Natural Gas Pipeline, Length

'

'

'

'

'

'

'

'

'

'

'

'

108

'

550

Natural Gas Pipeline, Capacity

'

'

'

'

'

'

'

'

'

1,200,000,000

2,000,000,000

'

800,000,000

'

1,500,000,000

[1]

Amounts revised and include prior period adjustments. See Note 13 for additional information.

Note_9_NonWholly_Owned_Entitie3

Note 9 - Non-Wholly Owned Entities (Details) - SouthStar’s Assets and Liabilities (USD $)	Sep. 30, 2014		Dec. 31, 2013		Sep. 30, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]	'		'		'		'
Current assets	$2,093	[1]	$2,895	[1]	$2,252	[1]	'
Goodwill and intangible assets	1,957	[1]	1,972	[1]	1,974	[1]	'
Long-term assets and other deferred debits	9,903	[1]	9,683	[1]	9,584	[1]	'
Total assets	13,953	[1]	14,550	[1]	13,810	[1]	'
Current liabilities	2,462	[1]	3,118	[1]	2,407	[1]	'
Long-term liabilities and other deferred credits	7,689	[1]	7,819	[1]	7,897	[1]	'
Total Liabilities	10,151	[1]	10,937	[1]	10,304	[1]	'
Equity	3,802	[1]	3,613	[1]	3,506	[1]	3,391
Total liabilities and equity	13,953	[1]	14,550	[1]	13,810	[1]	'
South Star [Member]	'		'		'		'
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]	'		'		'		'
Current assets	188	[1],[2]	264	[1],[2]	192	[1],[2]	'
Goodwill and intangible assets	127	[1],[2]	133	[1],[2]	136	[1],[2]	'
Long-term assets and other deferred debits	17	[1],[2]	13	[1],[2]	13	[1],[2]	'
Total assets	332	[1],[2]	410	[1],[2]	341	[1],[2]	'
Current liabilities	47	[1],[2]	95	[1],[2]	73	[1],[2]	'
Long-term liabilities and other deferred credits	'	[1],[2]	'	[1],[2]	'	[1],[2]	'
Total Liabilities	47	[1],[2]	95	[1],[2]	73	[1],[2]	'
Equity	285	[1],[2]	315	[1],[2]	268	[1],[2]	'
Total liabilities and equity	$332	[1],[2]	$410	[1],[2]	$341	[1],[2]	'
South Star Percentage To Consolidated [Member]	'		'		'		'
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]	'		'		'		'
Current assets	9.00%	[1],[3]	9.00%	[1],[3]	9.00%	[1],[3]	'
Goodwill and intangible assets	6.00%	[1],[3]	7.00%	[1],[3]	7.00%	[1],[3]	'
Long-term assets and other deferred debits	'	[1],[3]	'	[1],[3]	'	[1],[3]	'
Total assets	2.00%	[1],[3]	3.00%	[1],[3]	2.00%	[1],[3]	'
Current liabilities	2.00%	[1],[3]	3.00%	[1],[3]	3.00%	[1],[3]	'
Long-term liabilities and other deferred credits	'	[1],[3]	'	[1],[3]	'	[1],[3]	'
Total Liabilities	1.00%	[1],[3]	1.00%	[1],[3]	1.00%	[1],[3]	'
Equity	7.00%	[1],[3]	9.00%	[1],[3]	8.00%	[1],[3]	'
Total liabilities and equity	2.00%	[1],[3]	3.00%	[1],[3]	2.00%	[1],[3]	'
[1]	Amounts revised and include prior period adjustments. See Note 13 for additional information.
[2]	These amounts reflect information for SouthStar and exclude intercompany eliminations and the balances of our wholly owned subsidiary with an 85% ownership interest in SouthStar.
[3]	SouthStar's percentage of the amount on our unaudited Condensed Consolidated Statements of Financial Position.

Note_9_NonWholly_Owned_Entitie4

Note 9 - Non-Wholly Owned Entities (Details) - SouthStar’s Revenues and Expenses (USD $)	3 Months Ended			9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Variable Interest Entity [Line Items]	'	'		'		'
Operating revenues	$589	$574	[1]	$3,940	[1]	$2,991	[1]
Operating income (loss)	78	70	[1]	809	[1]	473	[1]
Cost of goods sold	198	174	[1]	2,000	[1]	1,447	[1]
Operation and maintenance	193	199	[1]	693	[1]	634	[1]
Depreciation and amortization	93	104	[1]	281	[1]	309	[1]
Taxes other than income taxes	30	27	[1]	160	[1]	139	[1]
Total operating expenses	514	504	[1]	3,134	[1]	2,529	[1]
South Star [Member]	'	'		'		'
Variable Interest Entity [Line Items]	'	'		'		'
Operating revenues	113	98		633		464
Operating income (loss)	2	-1		92		71
Cost of goods sold	89	81		470		340
Operation and maintenance	19	16		62		49
Depreciation and amortization	3	2		8		3
Taxes other than income taxes	'	'		1		1
Total operating expenses	$111	$99		$541		$393
[1]	Amounts revised and include prior period adjustments. See Note 13 for additional information.

Note_9_NonWholly_Owned_Entitie5

Note 9 - Non-Wholly Owned Entities (Details) - Equity Method Investments (USD $)	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013
In Millions, unless otherwise specified
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity Method Investments	$80	$86	$95
Triton [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity Method Investments	64	70	71
Horizon Pipeline [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity Method Investments	14	15	15
Other Equity Investments [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity Method Investments	$2	$1	$9

Note_9_NonWholly_Owned_Entitie6

Note 9 - Non-Wholly Owned Entities (Details) - Income from Equity Method Investments (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Note 9 - Non-Wholly Owned Entities (Details) - Income from Equity Method Investments [Line Items]	'		'		'		'
Income from Equity Methdod Investment	$2	[1]	$3	[1]	$6	[1]	$8	[1]
Triton [Member]	'		'		'		'
Note 9 - Non-Wholly Owned Entities (Details) - Income from Equity Method Investments [Line Items]	'		'		'		'
Income from Equity Methdod Investment	2	[2]	3	[2]	5	[2]	7	[2]
Other Equity Investments [Member]	'		'		'		'
Note 9 - Non-Wholly Owned Entities (Details) - Income from Equity Method Investments [Line Items]	'		'		'		'
Income from Equity Methdod Investment	'		'		$1		$1
[1]	For more information on our equity method investment income, see Note 9.
[2]	Reported within our "other" segment. For more information, see Note 11.

Note_10_Commitments_Guarantees2

Note 10 - Commitments, Guarantees and Contingencies (Details) (USD $)

0 Months Ended

3 Months Ended

60 Months Ended

3 Months Ended

0 Months Ended

0 Months Ended

3 Months Ended

6 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

In Millions, unless otherwise specified

Sep. 11, 2014

Sep. 30, 2014

Sep. 11, 2014

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2012

Dec. 31, 2019

Sep. 30, 2014

Sep. 30, 2014

Sep. 11, 2014

Sep. 11, 2014

Aug. 07, 2014

Jun. 07, 2013

Nov. 05, 2012

Dec. 31, 2012

Jun. 30, 2014

Dec. 31, 2009

Feb. 01, 2012

Aug. 07, 2014

Dec. 31, 2009

Dec. 31, 2009

Sep. 11, 2014

Sep. 11, 2014

ft3

ft3

ft3

Scenario, Forecast [Member]

First Mortgage Bonds [Member]

Interest Rate Swap [Member]

Natural Gas Remainder [Member]

Natural Gas Remainder [Member]

Illinois Commission [Member]

Illinois Commission [Member]

Illinois Commission [Member]

Illinois Commission [Member]

Illinois Commission [Member]

Illinois Commission [Member]

Illinois Commission [Member]

CUB [Member]

CUB [Member]

IAG [Member]

Atlanta Gas Light [Member]

Atlanta Gas Light [Member]

ft3

Note 10 - Commitments, Guarantees and Contingencies (Details) [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liabilities, Fair Value Adjustment

'

'

'

'

'

'

'

$77

$6

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Unamortized Premium

'

16

'

16

[1]

16

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Debt, Current Maturities

'

200

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Purchase Commitment, Minimum Volume Required (in Cubic Feet)

'

66

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Purchase Commitment, Amount

'

271

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest Payable, Current

'

42

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gas Balancing Volume Amount (in Cubic Feet)

'

'

1,150,000,000

'

'

4,600,000,000

'

'

'

'

2,300,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Natural Gas Imbalance Resolution Period

'

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent of Discretionary Funds Used for Natural Gas Imbalance

25.00%

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent of Natural Gas Imbalance Obligated

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

Natural Gas Imbalance Estimated Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.15

Loss Contingency, Damages Sought, Value

'

'

'

'

'

'

'

'

'

'

'

18

'

'

'

'

85

'

22

305

255

'

'

Loss Contingency, Estimate of Possible Loss

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

64

'

'

'

'

'

Loss Contingency, Damages Awarded, Value

'

'

'

'

'

'

'

'

'

'

'

'

72

72

'

'

'

'

'

'

'

'

'

Loss Contingency Accrual, Period Increase (Decrease)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8

'

'

'

'

'

'

'

'

Loss Contingency Accrual

'

'

'

'

'

'

'

'

'

'

'

'

'

'

72

'

'

'

'

'

'

'

'

Loss Contingency, Damages Paid, Value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$43

'

'

'

'

'

'

'

[1]

Interest rates are calculated based on the daily weighted average balance outstanding for the nine months ended September 30.

Note_10_Commitments_Guarantees3

Note 10 - Commitments, Guarantees and Contingencies (Details) - Contractual Obligations and Commitments (USD $)	Sep. 30, 2014
In Millions, unless otherwise specified
Recorded contractual obligations:	'
Recorded contractual obligations,Total	$4,842
Recorded contractual obligations,2014	698
Recorded contractual obligations 2015	283
Recorded contractual obligations, 2016	649
Recorded contractual obligations, 2017	72
Recorded contractual obligations, 2018	193
Recorded contractual obligations, 2019 & thereafter	2,947
Unrecorded contractual obligations and commitments(3) (8):	'
Unrecorded contractual obligations and commitments, Total	6,909	[1],[2]
Unrecorded contractual obligations and commitments, 2014	363	[1],[2]
Unrecorded contractual obligations and commitments, 2015	807	[1],[2]
Unrecorded contractual obligations and commitments, 2016	506	[1],[2]
Unrecorded contractual obligations and commitments, 2017	363	[1],[2]
Unrecorded contractual obligations and commitments, 2018	343	[1],[2]
Unrecorded contractual obligations and commitments, 2019 & thereafter	4,527	[1],[2]
Long Term Contractual Obligations [Member]	'
Recorded contractual obligations:	'
Recorded contractual obligations,Total	3,706	[3]
Recorded contractual obligations,2014	'	[3]
Recorded contractual obligations 2015	200	[3]
Recorded contractual obligations, 2016	545	[3]
Recorded contractual obligations, 2017	22	[3]
Recorded contractual obligations, 2018	155	[3]
Recorded contractual obligations, 2019 & thereafter	2,784	[3]
Short Term Contractual Obligations [Member]	'
Recorded contractual obligations:	'
Recorded contractual obligations,Total	681
Recorded contractual obligations,2014	681
Environmental Remediation Liabilities [Member]	'
Recorded contractual obligations:	'
Recorded contractual obligations,Total	454	[4]
Recorded contractual obligations,2014	16	[4]
Recorded contractual obligations 2015	83	[4]
Recorded contractual obligations, 2016	104	[4]
Recorded contractual obligations, 2017	50	[4]
Recorded contractual obligations, 2018	38	[4]
Recorded contractual obligations, 2019 & thereafter	163	[4]
Pipeline Replacement Program Costs [Member]	'
Recorded contractual obligations:	'
Recorded contractual obligations,Total	1	[4]
Recorded contractual obligations,2014	1	[4]
Recorded contractual obligations 2015	'	[4]
Recorded contractual obligations, 2016	'	[4]
Recorded contractual obligations, 2017	'	[4]
Recorded contractual obligations, 2018	'	[4]
Recorded contractual obligations, 2019 & thereafter	'	[4]
Pipeline Charges, Storage Capacity and Gas Supply [Member]	'
Unrecorded contractual obligations and commitments(3) (8):	'
Unrecorded contractual obligations and commitments, Total	3,837	[1],[2],[5]
Unrecorded contractual obligations and commitments, 2014	304	[1],[2],[5]
Unrecorded contractual obligations and commitments, 2015	564	[1],[2],[5]
Unrecorded contractual obligations and commitments, 2016	292	[1],[2],[5]
Unrecorded contractual obligations and commitments, 2017	185	[1],[2],[5]
Unrecorded contractual obligations and commitments, 2018	174	[1],[2],[5]
Unrecorded contractual obligations and commitments, 2019 & thereafter	2,318	[1],[2],[5]
Interest Charges [Member]	'
Unrecorded contractual obligations and commitments(3) (8):	'
Unrecorded contractual obligations and commitments, Total	2,798	[1],[2],[6]
Unrecorded contractual obligations and commitments, 2014	36	[1],[2],[6]
Unrecorded contractual obligations and commitments, 2015	179	[1],[2],[6]
Unrecorded contractual obligations and commitments, 2016	171	[1],[2],[6]
Unrecorded contractual obligations and commitments, 2017	147	[1],[2],[6]
Unrecorded contractual obligations and commitments, 2018	146	[1],[2],[6]
Unrecorded contractual obligations and commitments, 2019 & thereafter	2,119	[1],[2],[6]
Operating Leases [Member]	'
Unrecorded contractual obligations and commitments(3) (8):	'
Unrecorded contractual obligations and commitments, Total	207	[1],[2],[7]
Unrecorded contractual obligations and commitments, 2014	11	[1],[2],[7]
Unrecorded contractual obligations and commitments, 2015	35	[1],[2],[7]
Unrecorded contractual obligations and commitments, 2016	31	[1],[2],[7]
Unrecorded contractual obligations and commitments, 2017	24	[1],[2],[7]
Unrecorded contractual obligations and commitments, 2018	18	[1],[2],[7]
Unrecorded contractual obligations and commitments, 2019 & thereafter	88	[1],[2],[7]
Asset Management Agreements [Member]	'
Unrecorded contractual obligations and commitments(3) (8):	'
Unrecorded contractual obligations and commitments, Total	31	[1],[2],[8]
Unrecorded contractual obligations and commitments, 2014	2	[1],[2],[8]
Unrecorded contractual obligations and commitments, 2015	9	[1],[2],[8]
Unrecorded contractual obligations and commitments, 2016	8	[1],[2],[8]
Unrecorded contractual obligations and commitments, 2017	6	[1],[2],[8]
Unrecorded contractual obligations and commitments, 2018	4	[1],[2],[8]
Unrecorded contractual obligations and commitments, 2019 & thereafter	2	[1],[2],[8]
Standby Letterrs Of Credit And Performance Surety Bonds Obligations [Member]	'
Unrecorded contractual obligations and commitments(3) (8):	'
Unrecorded contractual obligations and commitments, Total	27	[1],[2]
Unrecorded contractual obligations and commitments, 2014	9	[1],[2]
Unrecorded contractual obligations and commitments, 2015	17	[1],[2]
Unrecorded contractual obligations and commitments, 2016	1	[1],[2]
Unrecorded contractual obligations and commitments, 2017	'	[1],[2]
Unrecorded contractual obligations and commitments, 2018	'	[1],[2]
Unrecorded contractual obligations and commitments, 2019 & thereafter	'	[1],[2]
Other Obligations [Member]	'
Unrecorded contractual obligations and commitments(3) (8):	'
Unrecorded contractual obligations and commitments, Total	9	[1],[2]
Unrecorded contractual obligations and commitments, 2014	1	[1],[2]
Unrecorded contractual obligations and commitments, 2015	3	[1],[2]
Unrecorded contractual obligations and commitments, 2016	3	[1],[2]
Unrecorded contractual obligations and commitments, 2017	1	[1],[2]
Unrecorded contractual obligations and commitments, 2018	1	[1],[2]
Unrecorded contractual obligations and commitments, 2019 & thereafter	'	[1],[2]
[1]	In accordance with GAAP, these items are not reflected in our unaudited Condensed Consolidated Statements of Financial Position.
[2]	We provide guarantees to certain municipalities and other agencies and certain gas suppliers of SouthStar in support of payment obligations.
[3]	Excludes the $77 million step up to fair value of first mortgage bonds, $16 million unamortized debt premium and $6 million interest rate swaps fair value adjustment. Includes current portion of long-term debt of $200 million, which matures in January 2015.
[4]	Includes charges recoverable through base rates or rate rider mechanisms.
[5]	Includes charges recoverable through a natural gas cost recovery mechanism or alternatively billed to Marketers and demand charges associated with Sequent. The gas supply balance includes amounts for Nicor Gas and SouthStar gas commodity purchase commitments of 66 Bcf at floating gas prices calculated using forward natural gas prices as of September 30, 2014, and is valued at $271 million. As we do for other subsidiaries, we provide guarantees to certain gas suppliers for SouthStar in support of payment obligations.
[6]	Floating rate interest charges are calculated based on the interest rate as of September 30, 2014, and the maturity date of the underlying debt instrument. As of September 30, 2014, we have $42 million of accrued interest on our unaudited Condensed Consolidated Statements of Financial Position that will be paid in the next 12 months.
[7]	We have certain operating leases with provisions for step rent or escalation payments and certain lease concessions. We account for these leases by recognizing the future minimum lease payments on a straight-line basis over the respective minimum lease terms, in accordance with GAAP. However, this lease accounting treatment does not affect the future annual operating lease cash obligations as shown herein. Our operating leases are primarily for real estate.
[8]	Represent fixed-fee minimum payments for Sequent's affiliated asset management agreements.

Note_11_Segment_Information_De

Note 11 - Segment Information (Details)	9 Months Ended
	Sep. 30, 2014
Note 11 - Segment Information (Details) [Line Items]	'
Number of Operating Segments	4
Distribution Operations [Member]	'
Note 11 - Segment Information (Details) [Line Items]	'
Number of States in which Entity Operates	7

Note_11_Segment_Information_De1

Note 11 - Segment Information (Details) - Intersegment Reporting (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013		Dec. 31, 2013
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	$589		$574	[1]	$3,940	[1]	$2,991	[1]	'
Operating expenses	'		'		'		'		'
Cost of goods sold	198		174	[1]	2,000	[1]	1,447	[1]	'
Operation and maintenance	193		199	[1]	693	[1]	634	[1]	'
Depreciation and amortization	93		104	[1]	281	[1]	309	[1]	'
Taxes other than income taxes	30		27	[1]	160	[1]	139	[1]	'
Total operating expenses	514		504	[1]	3,134	[1]	2,529	[1]	'
Gain on disposition of assets	3		'		3	[1]	11	[1]	'
Operating income (loss)	78		70	[1]	809	[1]	473	[1]	'
Other income	3		7	[1]	8	[1]	18	[1]	'
EBIT	81		77	[1]	817	[1]	491	[1]	'
Identifiable and total assets	13,953	[1]	13,810	[1]	13,953	[1]	13,810	[1]	14,550	[1]
Capital expenditures	211		211	[1]	543	[1]	526	[1]	'
Consolidation, Eliminations [Member] | Distribution Operations [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	35		36	[1]	153	[1]	134	[1]	'
Consolidation, Eliminations [Member] | Retail Operations [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	'		'	[1]	1	[1]	'	[1]	'
Consolidation, Eliminations [Member] | Wholesale Services [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	'	[2]	'		'	[2]	'	[2]	'
Consolidation, Eliminations [Member] | Other Segments [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	'	[3]	'	[3]	'	[3]	'	[3]	'
Consolidation, Eliminations [Member] | Intercompany Eliminations [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	-35		-36		-154		-134		'
Consolidation, Eliminations [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	'		'	[1]	'	[1]	'	[1]	'
Operating Segments [Member] | Distribution Operations [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	474		445	[1]	2,974	[1]	2,400	[1]	'
Operating Segments [Member] | Retail Operations [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	146		138	[1]	729	[1]	605	[1]	'
Operating Segments [Member] | Wholesale Services [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	5	[1],[2]	13	[1],[2]	383	[1],[2]	73	[1],[2]	'
Operating Segments [Member] | Midstream Operations [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	4		19		65		58		'
Operating Segments [Member] | Other Segments [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	1	[3]	1	[3]	5	[3]	5	[3]	'
Operating Segments [Member] | Intercompany Eliminations [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	-41		-42		-216		-150		'
Operating Segments [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	589		574	[1]	3,940	[1]	2,991	[1]	'
Distribution Operations [Member] | Continuing Operations [Member]	'		'		'		'		'
Operating expenses	'		'		'		'		'
Identifiable and total assets	11,628	[1],[4]	11,215	[1],[4]	11,628	[1],[4]	11,215	[1],[4]	'
Distribution Operations [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	439		409	[1]	2,821	[1]	2,266	[1]	'
Operating expenses	'		'		'		'		'
Cost of goods sold	138		111	[1]	1,655	[1]	1,142	[1]	'
Operation and maintenance	145		150	[1]	515	[1]	493	[1]	'
Depreciation and amortization	79		89	[1]	235	[1]	265	[1]	'
Taxes other than income taxes	24		22	[1]	146	[1]	124	[1]	'
Total operating expenses	386		372	[1]	2,551	[1]	2,024	[1]	'
Gain on disposition of assets	'		'		'	[1]	'	[1]	'
Operating income (loss)	88		73	[1]	423	[1]	376	[1]	'
Other income	1		4	[1]	5	[1]	11	[1]	'
EBIT	89		77	[1]	428	[1]	387	[1]	'
Identifiable and total assets	'		'		'		'		11,634	[5]
Capital expenditures	196		200	[1]	504	[1]	495	[1]	'
Retail Operations [Member] | Continuing Operations [Member]	'		'		'		'		'
Operating expenses	'		'		'		'		'
Identifiable and total assets	663	[1],[4]	644	[1],[4]	663	[1],[4]	644	[1],[4]	'
Retail Operations [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	146		138	[1]	728	[1]	605	[1]	'
Operating expenses	'		'		'		'		'
Cost of goods sold	99		92	[1]	498	[1]	402	[1]	'
Operation and maintenance	34		31	[1]	105	[1]	94	[1]	'
Depreciation and amortization	7		8	[1]	21	[1]	20	[1]	'
Taxes other than income taxes	1		1	[1]	3	[1]	3	[1]	'
Total operating expenses	141		132	[1]	627	[1]	519	[1]	'
Gain on disposition of assets	'		'		'	[1]	'	[1]	'
Operating income (loss)	5		6	[1]	102	[1]	86	[1]	'
Other income	'		'	[1]	'	[1]	'	[1]	'
EBIT	5		6	[1]	102	[1]	86	[1]	'
Identifiable and total assets	'		'		'		'		685	[5]
Capital expenditures	3		3	[1]	9	[1]	7	[1]	'
Wholesale Services [Member] | Continuing Operations [Member]	'		'		'		'		'
Operating expenses	'		'		'		'		'
Identifiable and total assets	1,056	[2],[4]	930	[2],[4]	1,056	[2],[4]	930	[2],[4]	'
Wholesale Services [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	5	[2]	13	[2]	383	[2]	73	[2]	'
Operating expenses	'		'		'		'		'
Cost of goods sold	3	[2]	1	[2]	13	[2]	21	[2]	'
Operation and maintenance	10	[2]	13	[2]	59	[2]	36	[2]	'
Depreciation and amortization	'	[2]	'	[2]	1	[2]	1	[2]	'
Taxes other than income taxes	1	[2]	1	[2]	2	[2]	2	[2]	'
Total operating expenses	14	[2]	15	[2]	75	[2]	60	[2]	'
Gain on disposition of assets	3	[2]	'		3	[2]	11	[2]	'
Operating income (loss)	-6	[2]	-2	[2]	311	[2]	24	[2]	'
Other income	-1	[2]	'	[2]	-3	[2]	'	[2]	'
EBIT	-7	[2]	-2	[2]	308	[2]	24	[2]	'
Identifiable and total assets	'		'		'		'		1,163	[5]
Capital expenditures	'	[2]	'	[2]	1	[2]	'	[2]	'
Midstream Operations [Member] | Continuing Operations [Member]	'		'		'		'		'
Operating expenses	'		'		'		'		'
Identifiable and total assets	692	[4]	726	[4]	692	[4]	726	[4]	'
Midstream Operations [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	4		19		65		58		'
Operating expenses	'		'		'		'		'
Cost of goods sold	-3		9		44		25		'
Operation and maintenance	5		5		18		17		'
Depreciation and amortization	5		5		14		13		'
Taxes other than income taxes	1		1		4		4		'
Total operating expenses	8		20		80		59		'
Operating income (loss)	-4		-1		-15		-1		'
Other income	'		'		1		2		'
EBIT	-4		-1		-14		1		'
Identifiable and total assets	'		'		'		'		713
Capital expenditures	3		3		8		11		'
Other Segments [Member] | Continuing Operations [Member]	'		'		'		'		'
Operating expenses	'		'		'		'		'
Identifiable and total assets	9,167	[3],[4]	9,784	[3],[4]	9,167	[3],[4]	9,784	[3],[4]	'
Other Segments [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	1	[3]	1	[3]	5	[3]	5	[3]	'
Operating expenses	'		'		'		'		'
Cost of goods sold	'	[3]	'	[3]	'	[3]	'	[3]	'
Operation and maintenance	1	[3]	3	[3]	2	[3]	1	[3]	'
Depreciation and amortization	2	[3]	2	[3]	10	[3]	10	[3]	'
Taxes other than income taxes	3	[3]	2	[3]	5	[3]	6	[3]	'
Total operating expenses	6	[3]	7	[3]	17	[3]	17	[3]	'
Gain on disposition of assets	'	[3]	'		'	[3]	'	[3]	'
Operating income (loss)	-5	[3]	-6	[3]	-12	[3]	-12	[3]	'
Other income	3	[3]	3	[3]	5	[3]	5	[3]	'
EBIT	-2	[3]	-3	[3]	-7	[3]	-7	[3]	'
Identifiable and total assets	'		'		'		'		10,160
Capital expenditures	9	[3]	5	[3]	21	[3]	13	[3]	'
Intercompany Eliminations [Member] | Continuing Operations [Member]	'		'		'		'		'
Operating expenses	'		'		'		'		'
Identifiable and total assets	-9,253	[4]	-9,783	[4]	-9,253	[4]	-9,783	[4]	'
Intercompany Eliminations [Member]	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenues	-6		-6		-62		-16		'
Operating expenses	'		'		'		'		'
Cost of goods sold	-39		-39		-210		-143		'
Operation and maintenance	-2		-3		-6		-7		'
Total operating expenses	-41		-42		-216		-150		'
Continuing Operations [Member]	'		'		'		'		'
Operating expenses	'		'		'		'		'
Identifiable and total assets	$13,953	[1],[4]	$13,516	[1],[4]	$13,953	[1],[4]	$13,516	[1],[4]	$14,267	[5]
[1]	Amounts revised and include prior period adjustments. See Note 13 for additional information.
[2]	The revenues for wholesale services are netted with costs associated with its energy and risk management activities. A reconciliation of our operating revenues and our intercompany revenues is shown in the following table.
[3]	Our other segment now also includes our investment in Triton, which was part of our cargo shipping segment that has been classified as discontinued operations. For more information, see Note 12.
[4]	Identifiable assets are those used in each segment's operations and exclude assets held for sale.
[5]	Amounts revised for prior period adjustments. See Note 13 for additional information.

Note_11_Segment_Information_De2

Note 11 - Segment Information (Details) - Operating Revenues (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Segment Reporting, Revenue Reconciling Item [Line Items]	'		'		'		'
Revenues	$589		$574	[1]	$3,940	[1]	$2,991	[1]
Thrid Party Gross Costs	198		174	[1]	2,000	[1]	1,447	[1]
Third Party Gross Revenues [Member] | Operating Segments [Member] | Wholesale Services [Member]	'		'		'		'
Segment Reporting, Revenue Reconciling Item [Line Items]	'		'		'		'
Revenues	1,885	[1]	1,716	[1]	8,313	[1]	5,792	[1]
Intercompany Revenues [Member] | Operating Segments [Member] | Wholesale Services [Member]	'		'		'		'
Segment Reporting, Revenue Reconciling Item [Line Items]	'		'		'		'
Revenues	126		69		584		312
Total Gross Revenues [Member] | Operating Segments [Member] | Wholesale Services [Member]	'		'		'		'
Segment Reporting, Revenue Reconciling Item [Line Items]	'		'		'		'
Revenues	2,011	[1]	1,785	[1]	8,897	[1]	6,104	[1]
Third Party Gross Costs [Member] | Operating Segments [Member] | Wholesale Services [Member]	'		'		'		'
Segment Reporting, Revenue Reconciling Item [Line Items]	'		'		'		'
Thrid Party Gross Costs	2,006		1,772		8,514		6,031
Operating Segments [Member] | Wholesale Services [Member]	'		'		'		'
Segment Reporting, Revenue Reconciling Item [Line Items]	'		'		'		'
Revenues	5	[1],[2]	13	[1],[2]	383	[1],[2]	73	[1],[2]
Operating Segments [Member]	'		'		'		'
Segment Reporting, Revenue Reconciling Item [Line Items]	'		'		'		'
Revenues	589		574	[1]	3,940	[1]	2,991	[1]
Wholesale Services [Member]	'		'		'		'
Segment Reporting, Revenue Reconciling Item [Line Items]	'		'		'		'
Revenues	5	[2]	13	[2]	383	[2]	73	[2]
Thrid Party Gross Costs	$3	[2]	$1	[2]	$13	[2]	$21	[2]
[1]	Amounts revised and include prior period adjustments. See Note 13 for additional information.
[2]	The revenues for wholesale services are netted with costs associated with its energy and risk management activities. A reconciliation of our operating revenues and our intercompany revenues is shown in the following table.

Note_11_Segment_Information_De3

Note 11 - Segment Information (Details) - Segment Reporting (USD $)	Sep. 30, 2014		Dec. 31, 2013		Sep. 30, 2013
In Millions, unless otherwise specified
Note 11 - Segment Information (Details) - Segment Reporting [Line Items]	'		'		'
Identifiable and total assets	$13,953	[1]	$14,550	[1]	$13,810	[1]
Distribution Operations [Member] | Continuing Operations [Member]	'		'		'
Note 11 - Segment Information (Details) - Segment Reporting [Line Items]	'		'		'
Identifiable and total assets	11,628	[1],[2]	'		11,215	[1],[2]
Distribution Operations [Member]	'		'		'
Note 11 - Segment Information (Details) - Segment Reporting [Line Items]	'		'		'
Identifiable and total assets	'		11,634	[3]	'
Retail Operations [Member] | Continuing Operations [Member]	'		'		'
Note 11 - Segment Information (Details) - Segment Reporting [Line Items]	'		'		'
Identifiable and total assets	663	[1],[2]	'		644	[1],[2]
Retail Operations [Member]	'		'		'
Note 11 - Segment Information (Details) - Segment Reporting [Line Items]	'		'		'
Identifiable and total assets	'		685	[3]	'
Wholesale Services [Member] | Continuing Operations [Member]	'		'		'
Note 11 - Segment Information (Details) - Segment Reporting [Line Items]	'		'		'
Identifiable and total assets	1,056	[2],[4]	'		930	[2],[4]
Wholesale Services [Member]	'		'		'
Note 11 - Segment Information (Details) - Segment Reporting [Line Items]	'		'		'
Identifiable and total assets	'		1,163	[3]	'
Midstream Operations [Member] | Continuing Operations [Member]	'		'		'
Note 11 - Segment Information (Details) - Segment Reporting [Line Items]	'		'		'
Identifiable and total assets	692	[2]	'		726	[2]
Midstream Operations [Member]	'		'		'
Note 11 - Segment Information (Details) - Segment Reporting [Line Items]	'		'		'
Identifiable and total assets	'		713		'
Other Segments [Member] | Continuing Operations [Member]	'		'		'
Note 11 - Segment Information (Details) - Segment Reporting [Line Items]	'		'		'
Identifiable and total assets	9,167	[2],[5]	'		9,784	[2],[5]
Other Segments [Member]	'		'		'
Note 11 - Segment Information (Details) - Segment Reporting [Line Items]	'		'		'
Identifiable and total assets	'		10,160		'
Intersegment Eliminations [Member]	'		'		'
Note 11 - Segment Information (Details) - Segment Reporting [Line Items]	'		'		'
Identifiable and total assets	'		-10,088		'
Continuing Operations [Member]	'		'		'
Note 11 - Segment Information (Details) - Segment Reporting [Line Items]	'		'		'
Identifiable and total assets	$13,953	[1],[2]	$14,267	[3]	$13,516	[1],[2]
[1]	Amounts revised and include prior period adjustments. See Note 13 for additional information.
[2]	Identifiable assets are those used in each segment's operations and exclude assets held for sale.
[3]	Amounts revised for prior period adjustments. See Note 13 for additional information.
[4]	The revenues for wholesale services are netted with costs associated with its energy and risk management activities. A reconciliation of our operating revenues and our intercompany revenues is shown in the following table.
[5]	Our other segment now also includes our investment in Triton, which was part of our cargo shipping segment that has been classified as discontinued operations. For more information, see Note 12.

Note_12_Discontinued_Operation2

Note 12 - Discontinued Operations (Details) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

3 Months Ended

6 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 01, 2014

Sep. 30, 2014

Mar. 31, 2014

Sep. 30, 2014

Sep. 30, 2014

Distributed Earnings of Foreign Subsidiaries [Member]

Distributed Earnings of Foreign Subsidiaries [Member]

Tropical Shipping [Member]

Tropical Shipping [Member]

Tropical Shipping [Member]

Tropical Shipping [Member]

Tropical Shipping [Member]

Tropical Shipping [Member]

Tropical Shipping [Member]

Note 12 - Discontinued Operations (Details) [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Divestiture of Businesses

'

'

'

'

'

'

$225,000,000

'

'

'

'

Discontinued Operation, Tax Effect of Discontinued Operation

-29,000,000

[1]

'

[1]

-61,000,000

[1]

'

[1]

29,000,000

60,000,000

'

'

31,000,000

'

'

Effective Income Tax Rate Reconciliation, Repatriation of Foreign Earnings, Amount

'

'

'

'

'

'

'

86,000,000

'

'

'

Goodwill, Impairment Loss, Net of Tax

'

'

'

'

'

'

'

'

19,000,000

'

'

Income Tax Expense (Benefit)

14,000,000

16,000,000

254,000,000

137,000,000

'

'

'

'

0

'

'

Depreciation And Amortization Suspension

'

'

'

'

'

'

'

'

'

7,000,000

'

$20,000,000

[2]

$27,000,000

[2]

$75,000,000

[2]

$82,000,000

[2]

'

'

'

$1,000,000

'

'

$1,000,000

[1]

Includes $31 million and $29 million that were recorded in the first and third quarters of 2014, respectively, related to the cumulative foreign earnings for which no tax liabilities had been previously recorded.

[2]

Includes $1 million for the three and nine months ended September 30, 2014, for another business not related to Tropical Shipping that we discontinued in the third quarter of 2014 and was included in our "other" segment.

Note_12_Discontinued_Operation3

Note 12 - Discontinued Operations (Details) - Assets and Liabilities of Tropical Shipping (USD $)	Dec. 31, 2013	Sep. 30, 2013
In Millions, unless otherwise specified
Current assets	'	'
Cash and cash equivalents	'	$34
Total current assets	283	294
Tropical Shipping [Member]	'	'
Current assets	'	'
Cash and cash equivalents	24	34
Short-term investments	1	1
Receivables	36	33
Inventories	9	9
Other	1	3
Total current assets	71	80
Long-term assets and other deferred debits	'	'
Property, plant and equipment, net	124	126
Goodwill	61	61
Intangible assets	19	19
Other	8	8
Total long-term assets and other deferred debits	212	214
Total assets held for sale	283	294
Current liabilities	'	'
Other accounts payable - trade	11	9
Accrued expenses	7	7
Other	22	23
Total liabilities held for sale	$40	$39

Note_12_Discontinued_Operation4

Note 12 - Discontinued Operations (Details) - Discontinued Operations from Statement of Income (USD $)	3 Months Ended					9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Mar. 31, 2014	Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'		'	'		'		'
Operating revenues	$62		'	$89		$243		$264
Operating expenses	'		'	'		'		'
Cost of goods sold	38		'	55		149		162
Operation and maintenance (1)	20	[1]	'	27	[1]	75	[1]	82	[1]
Depreciation and amortization (2)	'	[2]	'	4	[2]	5	[2]	14	[2]
Taxes other than income taxes	1		'	2		5		5
Loss on sale and goodwill impairment (3)	-3		'	'		-3	[3]	-11	[3]
Total operating expenses	64		'	88		262		263
Operating (loss) income	-2		'	1		-19		1
(Loss) income before income taxes	-2		'	1		-19		1
Income tax expense (4)	-29	[4]	'	'	[4]	-61	[4]	'	[4]
(Loss) Income from discontinued operations, net of tax	-31		'	1		-80		1
Tropical Shipping [Member]	'		'	'		'		'
Operating expenses	'		'	'		'		'
Operation and maintenance (1)	1		'	'		1		'
Loss on sale and goodwill impairment (3)	5	[5]	'	'	[5]	28	[5]	'	[5]
Income tax expense (4)	'		$31	'		'		'
[1]	Includes $1 million for the three and nine months ended September 30, 2014, for another business not related to Tropical Shipping that we discontinued in the third quarter of 2014 and was included in our "other" segment.
[2]	We ceased depreciating and amortizing Tropical Shipping's assets on April 4, 2014, as a result of entering into an agreement to sell this business and the assets were classified as held for sale.
[3]	Amounts revised and include prior period adjustments. See Note 13 for additional information.
[4]	Includes $31 million and $29 million that were recorded in the first and third quarters of 2014, respectively, related to the cumulative foreign earnings for which no tax liabilities had been previously recorded.
[5]	Primarily relates to the suspension of depreciation and amortization for the nine months ended September 30, 2014 of $7 million and $19 million of goodwill attributable to Tropical Shipping that was impaired as of March 31, 2014, based on the negotiated sales price.

Note_13_Revision_to_Prior_Peri2

Note 13 - Revision to Prior Period Financial Statements (Details) (USD $)	3 Months Ended			9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013		Dec. 31, 2013	Jan. 01, 2013
Note 13 - Revision to Prior Period Financial Statements (Details) [Line Items]	'	'		'		'		'	'
Impact of Restatement on Opening Retained Earnings, Net of Tax	'	'		'		'		'	$45
Net Income (Loss) Attributable to Parent	-8	25	[1]	334	[1]	218	[1]	'	'
Depreciation, Depletion and Amortization, Nonproduction	93	104	[2]	281	[2]	309	[2]	'	'
Intangible Assets, Net (Excluding Goodwill)	130	152		130		152		145	'
Scenario, Adjustment [Member]	'	'		'		'		'	'
Note 13 - Revision to Prior Period Financial Statements (Details) [Line Items]	'	'		'		'		'	'
Net Income (Loss) Attributable to Parent	'	4		'		13		'	'
Depreciation, Depletion and Amortization, Nonproduction	'	1		'		3		'	'
Intangible Assets, Net (Excluding Goodwill)	'	$8		'		$8		'	'
[1]	Amounts revised and or include prior period adjustments. See Note 13 for additional information.
[2]	Amounts revised and include prior period adjustments. See Note 13 for additional information.

Note_13_Revision_to_Prior_Peri3

Note 13 - Revision to Prior Period Financial Statements (Details) - Revisions to Condensed Consolidated Statements of Income (USD $)	3 Months Ended			9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Operating revenues	$589,000,000	$574,000,000	[1]	$3,940,000,000	[1]	$2,991,000,000	[1]
Operating expenses	'	'		'		'
Cost of goods sold	198,000,000	174,000,000	[1]	2,000,000,000	[1]	1,447,000,000	[1]
Operation and maintenance	193,000,000	199,000,000	[1]	693,000,000	[1]	634,000,000	[1]
Depreciation and amortization	93,000,000	104,000,000	[1]	281,000,000	[1]	309,000,000	[1]
Taxes other than income taxes	30,000,000	27,000,000	[1]	160,000,000	[1]	139,000,000	[1]
Total operating expenses	514,000,000	504,000,000	[1]	3,134,000,000	[1]	2,529,000,000	[1]
Gain on disposition of assets	3,000,000	'		3,000,000	[1]	11,000,000	[1]
Operating income	78,000,000	70,000,000	[1]	809,000,000	[1]	473,000,000	[1]
Other income	3,000,000	7,000,000	[1]	8,000,000	[1]	18,000,000	[1]
Interest expense, net	-44,000,000	-37,000,000		-135,000,000		-126,000,000
Income before income taxes	37,000,000	40,000,000		682,000,000		365,000,000
Income tax expense	14,000,000	16,000,000		254,000,000		137,000,000
Income from continuing operations	23,000,000	24,000,000		428,000,000		228,000,000
Income from discontinued operations	-31,000,000	1,000,000		-80,000,000		1,000,000
Net income	-8,000,000	25,000,000		348,000,000		229,000,000
Less net income attributable to the noncontrolling interest	'	'		14,000,000		11,000,000
Net income attributable to AGL Resources Inc.	-8,000,000	25,000,000	[2]	334,000,000	[2]	218,000,000	[2]
Basic earnings per common share (2)	'	'		'		'
Continuing operations (in Dollars per share)	$0.19	$0.20	[2],[3]	$3.48	[2]	$1.85	[2],[3]
Discontinued operations (in Dollars per share)	($0.25)	$0.01	[2],[3]	($0.67)	[2]	$0.01	[2],[3]
Basic earnings per common share attributable to AGL Resources Inc. common shareholders (in Dollars per share)	($0.06)	$0.21	[2]	$2.81	[2]	$1.86	[2]
Diluted earnings per common share (2)	'	'		'		'
Continuing operations (in Dollars per share)	$0.19	$0.20	[2],[3]	$3.47	[2]	$1.84	[2],[3]
Discontinued operations (in Dollars per share)	($0.25)	$0.01	[2],[3]	($0.67)	[2]	$0.01	[2],[3]
Diluted earnings per common share attributable to AGL Resources Inc. common shareholders (in Dollars per share)	($0.06)	$0.21	[2]	$2.80	[2]	$1.85	[2]
Scenario, Previously Reported [Member]	'	'		'		'
Operating revenues	'	586,000,000	[4]	'		3,024,000,000	[4]
Operating expenses	'	'		'		'
Cost of goods sold	'	174,000,000	[4]	'		1,447,000,000	[4]
Operation and maintenance	'	199,000,000	[4]	'		636,000,000	[4]
Depreciation and amortization	'	105,000,000	[4]	'		311,000,000	[4]
Taxes other than income taxes	'	27,000,000	[4]	'		139,000,000	[4]
Total operating expenses	'	505,000,000	[4]	'		2,533,000,000	[4]
Gain on disposition of assets	'	'	[4]	'		11,000,000	[4]
Operating income	'	81,000,000	[4]	'		502,000,000	[4]
Other income	'	7,000,000	[4]	'		19,000,000	[4]
Interest expense, net	'	-43,000,000	[4]	'		-135,000,000	[4]
Income before income taxes	'	45,000,000	[4]	'		386,000,000	[4]
Income tax expense	'	18,000,000	[4]	'		145,000,000	[4]
Income from continuing operations	'	27,000,000	[4]	'		241,000,000	[4]
Income from discontinued operations	'	1,000,000	[4]	'		1,000,000	[4]
Net income	'	28,000,000	[4]	'		242,000,000	[4]
Less net income attributable to the noncontrolling interest	'	'	[4]	'		11,000,000	[4]
Net income attributable to AGL Resources Inc.	'	28,000,000	[4]	'		231,000,000	[4]
Basic earnings per common share (2)	'	'		'		'
Continuing operations (in Dollars per share)	'	$0.23	[3],[4]	'		$1.95	[3],[4]
Discontinued operations (in Dollars per share)	'	$0.01	[3],[4]	'		$0.01	[3],[4]
Basic earnings per common share attributable to AGL Resources Inc. common shareholders (in Dollars per share)	'	$0.24	[4]	'		$1.96	[4]
Diluted earnings per common share (2)	'	'		'		'
Continuing operations (in Dollars per share)	'	$0.23	[3],[4]	'		$1.95	[3],[4]
Discontinued operations (in Dollars per share)	'	$0.01	[3],[4]	'		$0.01	[3],[4]
Diluted earnings per common share attributable to AGL Resources Inc. common shareholders (in Dollars per share)	'	$0.24	[4]	'		$1.96	[4]
Restatement Adjustment [Member]	'	'		'		'
Operating revenues	'	-12,000,000		'		-33,000,000
Operating expenses	'	'		'		'
Operation and maintenance	'	'		'		-2,000,000
Depreciation and amortization	'	-1,000,000		'		-2,000,000
Total operating expenses	'	-1,000,000		'		-4,000,000
Operating income	'	-11,000,000		'		-29,000,000
Other income	'	'		'		-1,000,000
Interest expense, net	'	6,000,000		'		9,000,000
Income before income taxes	'	-5,000,000		'		-21,000,000
Income tax expense	'	-2,000,000		'		-8,000,000
Income from continuing operations	'	-3,000,000		'		-13,000,000
Net income	'	-3,000,000		'		-13,000,000
Net income attributable to AGL Resources Inc.	'	($3,000,000)		'		($13,000,000)
Basic earnings per common share (2)	'	'		'		'
Continuing operations (in Dollars per share)	'	($0.03)	[3]	'		($0.10)	[3]
Discontinued operations (in Dollars per share)	'	'	[3]	'		'	[3]
Basic earnings per common share attributable to AGL Resources Inc. common shareholders (in Dollars per share)	'	($0.03)		'		($0.10)
Diluted earnings per common share (2)	'	'		'		'
Continuing operations (in Dollars per share)	'	($0.03)	[3]	'		($0.11)	[3]
Discontinued operations (in Dollars per share)	'	'	[3]	'		'	[3]
Diluted earnings per common share attributable to AGL Resources Inc. common shareholders (in Dollars per share)	'	($0.03)		'		($0.11)
[1]	Amounts revised and include prior period adjustments. See Note 13 for additional information.
[2]	Amounts revised and or include prior period adjustments. See Note 13 for additional information.
[3]	Excludes net income attributable to the noncontrolling interest.
[4]	Reflects the reclassification of the Tropical Shipping amounts as discontinued operations.

Note_13_Revision_to_Prior_Peri4

Note 13 - Revision to Prior Period Financial Statements (Details) - Revisions to Condensed Consolidated Statements of Financial Position (USD $)	Sep. 30, 2014		Dec. 31, 2013		Sep. 30, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Current assets	'		'		'		'
Regulatory assets	$105		$114	[1]	$87	[1]	'
Total current assets	2,093	[2]	2,895	[2]	2,252	[2]	'
Long-term assets and other deferred debits	'		'		'		'
Property, plant and equipment	11,352		10,938		10,761		'
Less accumulated depreciation	2,427		2,295		2,281		'
Property, plant and equipment, net	8,925		8,643		8,480		'
Regulatory assets	637		705	[1]	845	[1]	'
Intangible assets	130		145		152		'
Other	341		335		259		'
Total long-term assets and other deferred debits	11,860		11,655		11,558		'
Total assets	13,953	[2]	14,550	[2]	13,810	[2]	'
Current liabilities	'		'		'		'
Accrued expenses	173		203		149		'
Total current liabilities	2,462	[2]	3,118	[2]	2,407	[2]	'
Long-term liabilities and other deferred credits	'		'		'		'
Accumulated deferred income taxes	1,655		1,628		1,551		'
Total long-term liabilities and other deferred credits	7,689	[2]	7,819	[2]	7,897	[2]	'
Total liabilities and other deferred credits	10,151	[2]	10,937	[2]	10,304	[2]	'
Equity	'		'		'		'
Additional paid-in capital	2,080		2,054		2,047		'
Retained earnings	1,222		1,063		1,042		'
Total equity	3,802	[2]	3,613	[2]	3,506	[2]	3,391
Total liabilities and equity	13,953	[2]	14,550	[2]	13,810	[2]	'
Scenario, Previously Reported [Member]	'		'		'		'
Current assets	'		'		'		'
Regulatory assets	'		'		133	[3]	'
Total current assets	'		'		2,091	[3]	'
Long-term assets and other deferred debits	'		'		'		'
Property, plant and equipment	'		'		10,920	[3]	'
Less accumulated depreciation	'		'		2,307	[3]	'
Property, plant and equipment, net	'		'		8,613	[3]	'
Regulatory assets	'		'		871	[3]	'
Intangible assets	'		'		160	[3]	'
Other	'		'		251	[3]	'
Total long-term assets and other deferred debits	'		'		11,813	[3]	'
Total assets	'		'		13,904	[3]	'
Current liabilities	'		'		'		'
Accrued expenses	'		'		157	[3]	'
Total current liabilities	'		'		2,407	[3]	'
Long-term liabilities and other deferred credits	'		'		'		'
Accumulated deferred income taxes	'		'		1,587	[3]	'
Total long-term liabilities and other deferred credits	'		'		7,934	[3]	'
Total liabilities and other deferred credits	'		'		10,341	[3]	'
Equity	'		'		'		'
Additional paid-in capital	'		'		2,046	[3]	'
Retained earnings	'		'		1,100	[3]	'
Total equity	'		'		3,563	[3]	'
Total liabilities and equity	'		'		$13,904	[3]	'
[1]	Amounts revised for prior period adjustments. See Note 13 for additional information.
[2]	Amounts revised and include prior period adjustments. See Note 13 for additional information.
[3]	Reflects the reclassification of the Tropical Shipping amounts as held for sale.

Note_13_Revision_to_Prior_Peri5

Note 13 - Revision to Prior Period Financial Statements (Details) - Revisions to Condensed Consolidated Statements of Cash Flows (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Cash flows from operating activities	'		'		'
Net income	$25		$348		$229
Adjustments to reconcile net income to net cash flow provided by operating activities	'		'		'
Depreciation and amortization	104	[1]	281	[1]	309	[1]
Deferred income taxes	'		47		-32
Changes to certain assets and liabilities	'		'		'
Other, net	'		37		82
Net cash flow provided by operating activities	'		874		1,070
Scenario, Previously Reported [Member]	'		'		'
Cash flows from operating activities	'		'		'
Net income	28	[2]	'		242	[2]
Adjustments to reconcile net income to net cash flow provided by operating activities	'		'		'
Depreciation and amortization	105	[2]	'		311	[2]
Deferred income taxes	'		'		-28	[2]
Changes to certain assets and liabilities	'		'		'
Other, net	'		'		63	[2]
Net cash flow provided by operating activities	'		'		1,070	[2]
Restatement Adjustment [Member]	'		'		'
Cash flows from operating activities	'		'		'
Net income	-3		'		-13
Adjustments to reconcile net income to net cash flow provided by operating activities	'		'		'
Depreciation and amortization	-1		'		-2
Deferred income taxes	'		'		-4
Changes to certain assets and liabilities	'		'		'
Other, net	'		'		$19
[1]	Amounts revised and include prior period adjustments. See Note 13 for additional information.
[2]	Reflects the reclassification of the Tropical Shipping amounts as discontinued operations.

Note_13_Revision_to_Prior_Peri6

Note 13 - Revision to Prior Period Financial Statements (Details) - Revisions to Previously Reported Intangible Assets Disclosures (USD $)	Sep. 30, 2013
In Millions, unless otherwise specified
Scenario, Previously Reported [Member] | Customer Relationships [Member]	'
Finite-lived intangible assets, gross	$131
Finite-lived intangible assets, accumulated amortization	-12
Finite-lived intangible assets, net	119
Scenario, Previously Reported [Member] | Trade Names [Member]	'
Finite-lived intangible assets, gross	46
Finite-lived intangible assets, accumulated amortization	-5
Finite-lived intangible assets, net	41
Restatement Adjustment [Member] | Customer Relationships [Member]	'
Finite-lived intangible assets, accumulated amortization	-9
Finite-lived intangible assets, net	-9
Restatement Adjustment [Member] | Trade Names [Member]	'
Finite-lived intangible assets, accumulated amortization	1
Finite-lived intangible assets, net	1
Customer Relationships [Member]	'
Finite-lived intangible assets, gross	131
Finite-lived intangible assets, accumulated amortization	-21
Finite-lived intangible assets, net	110
Trade Names [Member]	'
Finite-lived intangible assets, gross	46
Finite-lived intangible assets, accumulated amortization	-4
Finite-lived intangible assets, net	$42