Magellan Midstream Partners (MMP) 10-Q 6 Aug 15 2015 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	6 Months Ended
	Jun. 30, 2015	Aug. 05, 2015
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q2
Entity Registrant Name	MAGELLAN MIDSTREAM PARTNERS LP
Entity Central Index Key	1,126,975
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		227,427,247

Consolidated Statements Of Inco

Consolidated Statements Of Income - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Transportation and terminals revenue	$ 374,016	$ 353,568	$ 719,616	$ 671,205
Product sales revenue	109,969	137,657	283,096	433,720
Affiliate management fee revenue	3,558	5,221	6,921	10,127
Total revenue	487,543	496,446	1,009,633	1,115,052
Costs and expenses:
Operating	131,433	124,874	229,928	198,371
Cost of product sales	94,507	109,103	230,686	307,143
Depreciation and amortization	40,440	46,897	82,137	84,408
General and administrative	37,942	39,309	73,440	74,244
Total costs and expenses	304,322	320,183	616,191	664,166
Earnings of non-controlled entities	24,542	1,955	34,132	2,421
Operating profit	207,763	178,218	427,574	453,307
Interest expense	39,756	37,265	76,363	73,681
Interest income	(334)	(406)	(683)	(797)
Interest capitalized	(2,946)	(6,843)	(5,053)	(12,153)
Debt placement fee amortization expense	640	602	1,227	1,201
Other income	(6,539)	0	(6,260)	0
Income before provision for income taxes	177,186	147,600	361,980	391,375
Provision for income taxes	(205)	1,340	953	2,561
Net income	$ 177,391	$ 146,260	$ 361,027	$ 388,814
Basic and diluted net income per limited partner unit	$ 0.78	$ 0.64	$ 1.59	$ 1.71
Weighted average number of limited partner units outstanding used for basic and diluted net income per unit calculation	227,631	227,288	227,578	227,215

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Net income		$ 177,391	$ 146,260	$ 361,027	$ 388,814
Other comprehensive income:
Net gain (loss) on cash flow hedges(1)	[1]	1,936	0	(13,529)	(3,613)
Reclassification of net loss (gain) on cash flow hedges to income(1)	[1]	388	(153)	588	(179)
Amortization of prior service credit(2)	[2]	(928)	(928)	(1,856)	(1,823)
Amortization of actuarial loss(2)	[2]	2,023	1,192	3,595	2,016
Settlement cost(2)	[2]	0	1,569	0	1,569
Total other comprehensive income (loss)		3,419	1,680	(11,202)	(2,030)
Comprehensive income		$ 180,810	$ 147,940	$ 349,825	$ 386,784
[1]	See Note 8–Derivative Financial Instruments for details of the amount of gain/loss recognized in accumulated other comprehensive loss ("AOCL") for derivative financial instruments and the amount of gain/loss reclassified from AOCL into income.
[2]	See Note 6–Employee Benefit Plans for details of the changes in employee benefit plan assets and benefit obligations recognized in AOCL.

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
ASSETS
Cash and cash equivalents	$ 29,030	$ 17,063
Trade accounts receivable (less allowance for doubtful accounts of $0 and $20 at December 31, 2014 and June 30, 2015, respectively)	84,715	84,465
Other accounts receivable	12,447	15,711
Inventory	159,920	157,762
Energy commodity derivatives contracts, net	0	87,151
Energy commodity derivatives deposits	5,696	6,184
Other current assets	40,893	34,331
Total current assets	332,701	402,667
Property, plant and equipment	5,832,338	5,533,935
Less: Accumulated depreciation	1,278,865	1,204,601
Net property, plant and equipment	4,553,473	4,329,334
Investments in non-controlled entities	666,451	613,867
Long-term receivables	25,614	28,611
Goodwill	53,260	53,260
Other intangibles (less accumulated amortization of $11,526 and $12,885 at December 31, 2014 and June 30, 2015, respectively)	3,214	4,573
Debt placement costs (less accumulated amortization of $8,952 and $10,179 at December 31, 2014 and June 30, 2015, respectively)	21,591	18,084
Tank bottoms and linefill	47,204	42,585
Other noncurrent assets	28,548	24,304
Total assets	5,732,056	5,517,285
LIABILITIES AND PARTNERS' CAPITAL
Accounts payable	95,810	97,131
Accrued payroll and benefits	33,576	48,298
Accrued interest payable	52,037	45,973
Accrued taxes other than income	46,865	47,888
Environmental liabilities	14,581	10,564
Deferred revenue	71,178	71,142
Accrued product purchases	21,629	44,355
Energy commodity derivatives contracts, net	2,860	5,413
Energy commodity derivatives deposits	0	84,463
Other current liabilities	44,669	80,928
Total current liabilities	383,205	536,155
Long-term debt	3,326,936	2,982,895
Long-term pension and benefits	79,807	75,155
Other noncurrent liabilities	23,843	29,069
Environmental liabilities	$ 21,877	$ 25,778
Commitments and contingencies
Partners’ capital:
Limited partner unitholders (227,068 units and 227,427 units outstanding at December 31, 2014 and June 30, 2015, respectively)	$ 1,989,130	$ 1,949,773
Accumulated other comprehensive loss	(92,742)	(81,540)
Total partners’ capital	1,896,388	1,868,233
Total liabilities and partners' capital	$ 5,732,056	$ 5,517,285

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Statement of Financial Position [Abstract]
Trade accounts receivable, allowance for doubtful accounts	$ 20	$ 0
Other intangibles, accumulated amortization	12,885	11,526
Debt placement costs, accumulated amortization	$ 10,179	$ 8,952
Limited partner unitholders, units outstanding	227,427,247	227,068,257

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Operating Activities:
Net income	$ 361,027	$ 388,814
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	82,137	84,408
Debt placement fee amortization expense	1,227	1,201
Loss on sale and retirement of assets	2,084	3,310
Earnings of non-controlled entities	(34,132)	(2,421)
Distributions from investments in non-controlled entities	31,243	1,713
Equity-based incentive compensation expense	10,539	12,753
Amortization of prior service credit, actuarial loss and pension settlement	1,739	1,762
Changes in operating assets and liabilities:
Trade accounts receivable and other accounts receivable	3,096	25,486
Inventory	(2,158)	(1,718)
Energy commodity derivatives contracts, net of derivatives deposits	(1,411)	(4,133)
Accounts payable	8,406	486
Accrued payroll and benefits	(14,722)	(11,434)
Accrued interest payable	6,064	1,038
Accrued taxes other than income	(1,023)	(3,679)
Accrued product purchases	(22,726)	(25,278)
Deferred revenue	36	6,174
Current and noncurrent environmental liabilities	116	(3,820)
Other current and noncurrent assets and liabilities	(16,723)	2,694
Net cash provided by operating activities	414,819	477,356
Investing Activities:
Additions to property, plant and equipment, net(1)	(275,848)	(153,250)
Proceeds from sale and disposition of assets	3,153	107
Acquisition of business	(54,678)	0
Investments in non-controlled entities	(36,443)	(285,945)
Distributions in excess of earnings of non-controlled entities	0	1,765
Net cash used by investing activities	(363,816)	(437,323)
Financing Activities:
Distributions paid	(321,239)	(271,914)
Net commercial paper borrowings (repayments)	(151,960)	220,977
Borrowings under long-term notes	499,589	257,713
Payments on notes	0	(250,000)
Debt placement costs	(4,734)	(2,887)
Net payment on financial derivatives	(42,908)	(3,613)
Settlement of tax withholdings on long-term incentive compensation	(17,784)	(14,813)
Net cash used by financing activities	(39,036)	(64,537)
Change in cash and cash equivalents	11,967	(24,504)
Cash and cash equivalents at beginning of period	17,063	25,235
Cash and cash equivalents at end of period	29,030	731
Supplemental non-cash investing and financing activities:
Contribution of property, plant and equipment to a non-controlled entity	13,252	0
Issuance of limited partner units in settlement of equity-based incentive plan awards	8,045	7,315
Additions to property, plant and equipment	(268,849)	(149,138)
Increase (Decrease) in Other Accounts Payable	(6,999)	(4,112)
Additions to property, plant and equipment	$ (275,848)	$ (153,250)

Organization, Description of Bu

Organization, Description of Business And Basis Of Presentation	6 Months Ended
	Jun. 30, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization, Description of Business and Basis of Presentation	Organization, Description of Business and Basis of Presentation Organization Unless indicated otherwise, the terms “our,” “we,” “us” and similar language refer to Magellan Midstream Partners, L.P. together with its subsidiaries. We are a Delaware limited partnership and our limited partner units are traded on the New York Stock Exchange under the ticker symbol “MMP.” Magellan GP, LLC, a wholly-owned Delaware limited liability company, serves as our general partner. Description of Business We are principally engaged in the transportation, storage and distribution of refined petroleum products and crude oil. As of June 30, 2015 , our asset portfolio, including the assets of our joint ventures, consisted of: • our refined products segment, comprised of our 9,500 -mile refined products pipeline system with 52 terminals as well as 28 independent terminals not connected to our pipeline system and our 1,100 -mile ammonia pipeline system; • our crude oil segment, comprised of approximately 1,600 miles of crude oil pipelines and storage facilities with an aggregate storage capacity of approximately 21 million barrels, of which 13 million barrels are used for leased storage; and • our marine storage segment, consisting of five marine terminals located along coastal waterways with an aggregate storage capacity of approximately 26 million barrels. Products transported, stored or distributed through our pipelines and terminals include: • refined products are the output from refineries and are primarily used as fuels by consumers. Refined products include gasoline, diesel fuel, aviation fuel, kerosene and heating oil. Collectively, diesel fuel and heating oil are referred to as distillates; • liquefied petroleum gases, or LPGs are produced as by-products of the crude oil refining process and in connection with natural gas production. LPGs include butane and propane; • blendstocks are blended with refined products to change or enhance their characteristics such as increasing a gasoline's octane or oxygen content. Blendstocks include alkylates, oxygenates and natural gasoline; • heavy oils and feedstocks are used as burner fuels or feedstocks for further processing by refineries and petrochemical facilities. Heavy oils and feedstocks include No. 6 fuel oil and vacuum gas oil; • crude oil and condensate are used as feedstocks by refineries and petrochemical facilities; • biofuels , such as ethanol and biodiesel, are increasingly required by government mandates; and • ammonia is primarily used as a nitrogen fertilizer. Except for ammonia, we use the term petroleum products to describe any, or a combination, of the above-noted products. Basis of Presentation In the opinion of management, our accompanying consolidated financial statements which are unaudited, except for the consolidated balance sheet as of December 31, 2014 which is derived from our audited financial statements, include all normal and recurring adjustments necessary to present fairly our financial position as of June 30, 2015 , the results of operations for the three and six months ended June 30, 2014 and 2015 and cash flows for the six months ended June 30, 2014 and 2015 . The results of operations for the six months ended June 30, 2015 are not necessarily indicative of the results to be expected for the full year ending December 31, 2015 as profits from our blending activities are realized largely during the first and fourth quarters of each year. Additionally, gasoline demand, which drives transportation volumes and revenues on our pipeline systems, generally trends higher during the summer driving months. Further, the volatility of commodity prices impact the profits from our commodity activities and, to a lesser extent, the volume of petroleum products we ship on our pipelines. Pursuant to the rules and regulations of the Securities and Exchange Commission, the financial statements in this report do not include all of the information and notes normally included with financial statements prepared in accordance with accounting principles generally accepted in the United States. These financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2014 . Use of Estimates The preparation of our consolidated financial statements in conformity with generally accepted accounting principles in the U.S. ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities that exist at the date of our consolidated financial statements, as well as their impact on the reported amounts of revenue and expense during the reporting periods. Actual results could differ from those estimates.

Product Sales Revenues

Product Sales Revenues	6 Months Ended
	Jun. 30, 2015
Product Sales Revenue [Abstract]
Product Sales Revenues	Product Sales Revenue The amounts reported as product sales revenue on our consolidated statements of income include revenue from the physical sale of petroleum products and from mark-to-market adjustments from New York Mercantile Exchange ("NYMEX") contracts. See Note 8 – Derivative Financial Instruments for a discussion of our commodity hedging strategies and how our NYMEX contracts impact product sales revenues. All of the petroleum products inventory we physically sell associated with our butane blending and fractionation activities as well as the barrels from product gains we obtain from our independent terminals are reported as product sales on our consolidated statements of income. The physical sale of the petroleum products inventory from product gains obtained from our pipeline operations and crude terminal activities are reported as adjustments to operating expense. For the three and six months ended June 30, 2014 and 2015 , product sales revenue included the following (in thousands): Three Months Ended Six Months Ended June 30, June 30, 2014 2015 2014 2015 Physical sale of petroleum products $ 154,310 $ 133,319 $ 447,550 $ 302,566 NYMEX contract adjustments: Change in value of NYMEX contracts that were not designated as hedging instruments associated with our butane blending and fractionation activities (16,666 ) (23,350 ) (13,843 ) (19,470 ) Other 13 — 13 — Total NYMEX contract adjustments (16,653 ) (23,350 ) (13,830 ) (19,470 ) Total product sales revenue $ 137,657 $ 109,969 $ 433,720 $ 283,096

Segment Disclosures

Segment Disclosures	6 Months Ended
	Jun. 30, 2015
Segment Reporting [Abstract]
Segment Disclosures	Segment Disclosures Our reportable segments are strategic business units that offer different products and services. Our segments are managed separately because each segment requires different marketing strategies and business knowledge. Management evaluates performance based on segment operating margin, which includes revenue from affiliates and external customers, operating expenses, cost of product sales and earnings of non-controlled entities. We believe that investors benefit from having access to the same financial measures used by management. Operating margin, which is presented in the following tables, is an important measure used by management to evaluate the economic performance of our core operations. Operating margin is not a GAAP measure, but the components of operating margin are computed using amounts that are determined in accordance with GAAP. A reconciliation of operating margin to operating profit, which is its nearest comparable GAAP financial measure, is included in the tables below. Operating profit includes depreciation and amortization expense and general and administrative ("G&A") expenses that management does not consider when evaluating the core profitability of our separate operating segments. On May 1, 2015, we acquired a refined products terminal in Atlanta, Georgia for net cash consideration of $54.7 million . As this acquired business is not significant to our consolidated operating results and financial position, pro forma financial information and the purchase price allocation of acquired assets and liabilities have not been presented. The results of the acquired operations subsequent to the acquisition date have been included in the accompanying consolidated financial statements and in the tables below in our refined products operating segment. Three Months Ended June 30, 2014 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 232,489 $ 79,556 $ 41,523 $ — $ 353,568 Product sales revenue 136,334 — 1,323 — 137,657 Affiliate management fee revenue — 4,902 319 — 5,221 Total revenue 368,823 84,458 43,165 — 496,446 Operating expenses 97,302 11,867 16,544 (839 ) 124,874 Cost of product sales 108,817 — 286 — 109,103 Earnings of non-controlled entities — (888 ) (1,067 ) — (1,955 ) Operating margin 162,704 73,479 27,402 839 264,424 Depreciation and amortization expense 32,083 6,725 7,250 839 46,897 G&A expenses 25,374 7,697 6,238 — 39,309 Operating profit $ 105,247 $ 59,057 $ 13,914 $ — $ 178,218 Three Months Ended June 30, 2015 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 233,711 $ 95,756 $ 44,549 $ — $ 374,016 Product sales revenue 109,323 — 646 — 109,969 Affiliate management fee revenue — 3,211 347 — 3,558 Total revenue 343,034 98,967 45,542 — 487,543 Operating expenses 100,475 16,014 15,881 (937 ) 131,433 Cost of product sales 94,326 — 181 — 94,507 Losses (earnings) of non-controlled entities 43 (23,905 ) (680 ) — (24,542 ) Operating margin 148,190 106,858 30,160 937 286,145 Depreciation and amortization expense 23,962 8,264 7,277 937 40,440 G&A expenses 23,893 9,031 5,018 — 37,942 Operating profit $ 100,335 $ 89,563 $ 17,865 $ — $ 207,763 Six Months Ended June 30, 2014 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 442,725 $ 147,459 $ 81,021 $ — $ 671,205 Product sales revenue 430,044 — 3,676 — 433,720 Affiliate management fee revenue — 9,497 630 — 10,127 Total revenue 872,769 156,956 85,327 — 1,115,052 Operating expenses 148,459 20,925 30,630 (1,643 ) 198,371 Cost of product sales 306,573 — 570 — 307,143 Earnings of non-controlled entities — (708 ) (1,713 ) — (2,421 ) Operating margin 417,737 136,739 55,840 1,643 611,959 Depreciation and amortization expense 55,255 13,188 14,322 1,643 84,408 G&A expenses 48,393 13,691 12,160 — 74,244 Operating profit $ 314,089 $ 109,860 $ 29,358 $ — $ 453,307 Six Months Ended June 30, 2015 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 450,488 $ 182,316 $ 86,812 $ — $ 719,616 Product sales revenue 281,962 — 1,134 — 283,096 Affiliate management fee revenue — 6,238 683 — 6,921 Total revenue 732,450 188,554 88,629 — 1,009,633 Operating expenses 170,781 29,875 31,216 (1,944 ) 229,928 Cost of product sales 229,960 — 726 — 230,686 Losses (earnings) of non-controlled entities 98 (32,829 ) (1,401 ) — (34,132 ) Operating margin 331,611 191,508 58,088 1,944 583,151 Depreciation and amortization expense 47,409 16,493 16,291 1,944 82,137 G&A expenses 46,492 17,117 9,831 — 73,440 Operating profit $ 237,710 $ 157,898 $ 31,966 $ — $ 427,574

Investments in Non-Controlled E

Investments in Non-Controlled Entities (Notes)	6 Months Ended
	Jun. 30, 2015
Equity Method Investments and Joint Ventures [Abstract]
Investments in Non-Controlled Entities	Investments in Non-Controlled Entities Recently-Formed Company Seabrook Logistics, LLC ("Seabrook") was formed in second quarter 2015 to construct, own and operate crude oil storage and pipeline infrastructure in the Houston Gulf Coast area. We hold a 50% equity ownership interest in Seabrook, with LBC Tank Terminals, LLC holding the other 50% equity ownership interest. The assets to be constructed and owned by Seabrook include over 700,000 barrels of crude oil storage located adjacent to LBC's existing terminal in Seabrook, Texas. In addition, Seabrook will construct and own an 18 -inch diameter pipeline, which will connect Seabrook's storage facilities to an existing third-party pipeline that will transport crude oil to a Houston-area refinery. Subject to the receipt of permits and regulatory approvals, the new storage facility and pipeline infrastructure are expected to be operational in the first quarter of 2017. Our investments in non-controlled entities at June 30, 2015 were comprised of: Entity Ownership Interest BridgeTex Pipeline Company, LLC ("BridgeTex") 50% Double Eagle Pipeline LLC ("Double Eagle") 50% Osage Pipe Line Company, LLC ("Osage") 50% Powder Springs Logistics, LLC ("Powder Springs") 50% Saddlehorn Pipeline Company, LLC ("Saddlehorn") 40% Seabrook Logistics, LLC 50% Texas Frontera, LLC ("Texas Frontera") 50% The management fees we have recognized or will recognize from BridgeTex, Osage, Powder Springs, Saddlehorn, Seabrook and Texas Frontera are or will be reported as affiliate management fee revenue on our consolidated statements of income. At December 31, 2014 and June 30, 2015 , we recognized liabilities of $2.2 million and $1.1 million , respectively, to BridgeTex primarily for pre-paid construction management fees. For the three and six months ended June 30, 2015 , we recognized pipeline capacity lease revenue from BridgeTex of $8.5 million and $16.9 million , respectively, which we included in transportation and terminals revenue on our consolidated statements of income. We recognized a $2.6 million receivable from BridgeTex at December 31, 2014 ( no receivable was recognized at June 30, 2015 ). We recognized throughput revenue from Double Eagle for the three months ended June 30, 2014 and 2015 of $0.8 million and $0.9 million , respectively, and for the six months ended June 30, 2014 and 2015 of $1.3 million and $1.8 million , respectively, which we included in transportation and terminals revenue. At December 31, 2014 and June 30, 2015 , respectively, we recognized a $0.3 million trade accounts receivable from Double Eagle. The financial results from Texas Frontera are included in our marine storage segment, the financial results from BridgeTex, Double Eagle, Osage, Saddlehorn and Seabrook are or will be included in our crude oil segment and the financial results from Powder Springs are included in our refined products segment as earnings/losses of non-controlled entities. A summary of our investments in non-controlled entities follows (in thousands): BridgeTex All Others Consolidated Investments at December 31, 2014 $ 489,348 $ 124,519 $ 613,867 Additional investment 16,609 33,086 49,695 Earnings of non-controlled entities: Proportionate share of earnings 31,828 3,699 35,527 Amortization of excess investment and capitalized interest (1,020 ) (375 ) (1,395 ) Earnings of non-controlled entities 30,808 3,324 34,132 Less: Distributions of earnings from investments in non-controlled entities 30,332 911 31,243 Investments at June 30, 2015 $ 506,433 $ 160,018 $ 666,451 Summarized financial information of our non-controlled entities for the three and six months ended June 30, 2014 and 2015 follows (in thousands): Three Months Ended June 30, 2014 Three Months Ended June 30, 2015 BridgeTex All Others Consolidated BridgeTex All Others Consolidated Revenue $ — $ 11,709 $ 11,709 $ 61,629 $ 11,627 $ 73,256 Net income (loss) $ (240 ) $ 4,524 $ 4,284 $ 45,619 $ 4,793 $ 50,412 Six Months Ended June 30, 2014 Six Months Ended June 30, 2015 BridgeTex All Others Consolidated BridgeTex All Others Consolidated Revenue $ — $ 18,464 $ 18,464 $ 98,765 $ 21,147 $ 119,912 Net income (loss) $ (280 ) $ 5,871 $ 5,591 $ 63,656 $ 7,374 $ 71,030

Inventory

Inventory	6 Months Ended
	Jun. 30, 2015
Inventory Disclosure [Abstract]
Inventory	Inventory Inventory at December 31, 2014 and June 30, 2015 was as follows (in thousands): December 31, 2014 June 30, Refined products $ 67,055 $ 33,862 Liquefied petroleum gases 37,642 39,942 Transmix 36,867 47,513 Crude oil 10,015 32,501 Additives 6,183 6,102 Total inventory $ 157,762 $ 159,920

Employee Benefit Plans

Employee Benefit Plans	6 Months Ended
	Jun. 30, 2015
Compensation and Retirement Disclosure [Abstract]
Employee Benefit Plans	Employee Benefit Plans We sponsor two pension plans for certain union employees and a pension plan primarily for non-union employees, a postretirement benefit plan for selected employees and a defined contribution plan. The following tables present our consolidated net periodic benefit costs related to the pension and postretirement benefit plans for the three and six months ended June 30, 2014 and 2015 (in thousands): Three Months Ended Three Months Ended June 30, 2014 June 30, 2015 Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Components of net periodic benefit costs: Service cost $ 3,352 $ 47 $ 4,975 $ 56 Interest cost 2,030 139 2,008 109 Expected return on plan assets (1,490 ) — (2,123 ) — Amortization of prior service credit — (928 ) — (928 ) Amortization of actuarial loss 930 262 1,806 217 Settlement cost 1,569 — — — Net periodic benefit cost (credit) $ 6,391 $ (480 ) $ 6,666 $ (546 ) Six Months Ended Six Months Ended June 30, 2014 June 30, 2015 Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Components of net periodic benefit costs: Service cost $ 6,704 $ 114 $ 9,445 $ 122 Interest cost 3,689 253 3,877 219 Expected return on plan assets (3,187 ) — (4,019 ) — Amortization of prior service cost (credit) 33 (1,856 ) — (1,856 ) Amortization of actuarial loss 1,559 457 3,153 442 Settlement cost 1,569 — — — Net periodic benefit cost (credit) $ 10,367 $ (1,032 ) $ 12,456 $ (1,073 ) Contributions estimated to be paid into the plans in 2015 are $21.1 million and $1.1 million for the pension and other postretirement benefit plans, respectively. We match our employees' qualifying contributions to our defined contribution plan, resulting in expense to us. Expenses related to the defined contribution plan were $2.0 million and $2.2 million , respectively, for the three months ended June 30, 2014 and 2015 , and $4.6 million and $5.0 million , respectively, for the six months ended June 30, 2014 and 2015 . Amounts Included in AOCL The changes in AOCL related to employee benefit plan assets and benefit obligations for the three and six months ended June 30, 2014 and 2015 were as follows (in thousands): Three Months Ended Three Months Ended June 30, 2014 June 30, 2015 Gains (Losses) Included in AOCL Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Beginning balance $ (35,522 ) $ 2,320 $ (61,910 ) $ (2,399 ) Amortization of prior service credit — (928 ) — (928 ) Amortization of actuarial loss 930 262 1,806 217 Settlement cost 1,569 — — — Ending balance $ (33,023 ) $ 1,654 $ (60,104 ) $ (3,110 ) Six Months Ended Six Months Ended June 30, 2014 June 30, 2015 Gains (Losses) Included in AOCL Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Beginning balance $ (36,184 ) $ 3,053 $ (63,257 ) $ (1,696 ) Amortization of prior service cost (credit) 33 (1,856 ) — (1,856 ) Amortization of actuarial loss 1,559 457 3,153 442 Settlement cost 1,569 — — — Ending balance $ (33,023 ) $ 1,654 $ (60,104 ) $ (3,110 )

Debt

Debt	6 Months Ended
	Jun. 30, 2015
Debt Disclosure [Abstract]
Debt	Debt Consolidated debt at December 31, 2014 and June 30, 2015 was as follows (in thousands, except as otherwise noted): December 31, 2014 June 30, Weighted-Average Interest Rate for the Six Months Ended June 30, 2015 (1) Commercial paper (2) $ 296,942 $ 144,982 0.5% $250.0 million of 5.65% Notes due 2016 250,758 250,546 5.7% $250.0 million of 6.40% Notes due 2018 257,280 256,248 5.4% $550.0 million of 6.55% Notes due 2019 567,868 566,006 5.7% $550.0 million of 4.25% Notes due 2021 556,304 555,837 4.0% $250.0 million of 3.20% Notes due 2025 (2) — 249,687 3.2% $250.0 million of 6.40% Notes due 2037 249,017 249,026 6.4% $250.0 million of 4.20% Notes due 2042 248,406 248,421 4.2% $550.0 million of 5.15% Notes due 2043 556,320 556,270 5.1% $250.0 million of 4.20% Notes due 2045 (2) — 249,913 4.6% Total debt $ 2,982,895 $ 3,326,936 4.8% (1) Weighted-average interest rate includes the amortization/accretion of discounts, premiums and gains/losses realized on historical cash flow and fair value hedges recognized as interest expense. (2) These borrowings were outstanding for only a portion of the six month period ending June 30, 2015 . The weighted-average interest rate for these borrowings was calculated based on the number of days the borrowings were outstanding during the noted period. All of the instruments detailed in the table above are senior indebtedness. The face value of our debt at December 31, 2014 and June 30, 2015 was $2.9 billion and $3.3 billion , respectively. The difference between the face value and carrying value of our debt outstanding is the unamortized portion of terminated fair value hedges and the unamortized discounts and premiums on debt issuances. Realized gains and losses on fair value hedges and note discounts and premiums are being amortized or accreted to the applicable notes over the respective lives of those notes. 2015 Debt Offerings In March 2015, we issued $250.0 million of our 3.20% notes due 2025 in an underwritten public offering. The notes were issued at 99.871% of par. Net proceeds from this offering were $247.6 million , after underwriting discounts and offering expenses of $2.1 million . Also in March 2015, we issued $250.0 million of our 4.20% notes due 2045 in an underwritten public offering. The notes were issued at 99.965% of par. Net proceeds from this offering were $247.3 million , after underwriting discounts and offering expenses of $2.6 million . The net proceeds from these offerings were used to repay borrowings outstanding under our commercial paper program and for general partnership purposes, including expansion capital. Other Debt Revolving Credit Facility. The total borrowing capacity under our revolving credit facility, which matures in November 2018, is $1.0 billion . Borrowings outstanding under the facility are classified as long-term debt on our consolidated balance sheets. Borrowings under the facility are unsecured and bear interest at LIBOR plus a spread ranging from 1.0% to 1.75% based on our credit ratings. Additionally, an unused commitment fee is assessed at a rate from 0.10% to 0.28% , depending on our credit ratings. The unused commitment fee was 0.125% at June 30, 2015 . Borrowings under this facility may be used for general partnership purposes, including capital expenditures. As of June 30, 2015 , there were no borrowings outstanding under this facility; however, $5.6 million was obligated for letters of credit. Amounts obligated for letters of credit are not reflected as debt on our consolidated balance sheets but decrease our borrowing capacity under the facility. Commercial Paper Program. The maturities of our commercial paper notes vary, but may not exceed 397 days from the date of issuance. The commercial paper notes are sold under customary terms in the commercial paper market and are issued at a discount from par, or alternatively, are sold at par and bear varying interest rates on a fixed or floating basis. The commercial paper we can issue is limited by the amounts available under our revolving credit facility up to an aggregate principal amount of $1.0 billion and, therefore, is classified as long-term debt.

Derivative Financial Instrument

Derivative Financial Instruments	6 Months Ended
	Jun. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Financial Instruments	Derivative Financial Instruments Interest Rate Derivatives We periodically enter into interest rate derivatives to economically hedge debt, interest or expected debt issuances, and we have historically designated these derivatives as cash flow or fair value hedges for accounting purposes. Adjustments resulting from discontinued hedges continue to be recognized in accordance with their historic hedging relationships. In first quarter 2015, we entered into a $50.0 million forward-starting interest rate swap agreement to hedge against the risk of variability of future interest payments on a portion of debt we anticipate issuing in 2016. The fair value of this contract at June 30, 2015 was recorded on our balance sheet as an other noncurrent asset of $2.9 million with an offset to other comprehensive income. We account for this agreement as a cash flow hedge. In third and fourth quarter of 2014, we entered into $250.0 million of forward-starting interest rate swap agreements to hedge against the risk of variability of future interest payments on a portion of debt we anticipated issuing in 2015. We accounted for these agreements as cash flow hedges. When we issued the $250.0 million of 4.20% notes due 2045 in first quarter 2015, we settled the associated interest rate swap agreements for a loss of $42.9 million . The loss was recorded to other comprehensive income ( $26.5 million and $16.4 million recorded in 2014 and 2015, respectively) and will be recognized into earnings as an adjustment to our periodic interest expense accruals over the life of the associated notes. This loss was also reported as a net payment on financial derivatives in the financing activities of our consolidated statements of cash flows in 2015. Commodity Derivatives Hedging Strategies Our butane blending activities produce gasoline products, and we can reasonably estimate the timing and quantities of sales of these products. We use a combination of NYMEX and forward purchase and sale contracts to help manage commodity price changes, which is intended to mitigate the risk of decline in the product margin realized from our butane blending activities that we choose to hedge. Further, certain of our other commercial operations generate petroleum products. We use NYMEX contracts to hedge against future price changes for some of these commodities. We account for the forward physical purchase and sale contracts we use in our butane blending and fractionation activities as normal purchases and sales. Forward contracts that qualify for and are elected as normal purchases and sales are accounted for using traditional accrual accounting. As of June 30, 2015 , we had commitments under these forward purchase and sale contracts as follows (in millions): Notional Value Barrels Forward purchase contracts $ 118.3 3.5 Forward sale contracts $ 11.4 0.1 The NYMEX contracts that we enter into fall into one of three hedge categories: Hedge Category Hedge Purpose Accounting Treatment Qualifies For Hedge Accounting Treatment Cash Flow Hedge To hedge the variability in cash flows related to a forecasted transaction. The effective portion of changes in the value of the hedge is recorded to accumulated other comprehensive income/loss and reclassified to earnings when the forecasted transaction occurs. Any ineffectiveness is recognized currently in earnings. Fair Value Hedge To hedge against changes in the fair value of a recognized asset or liability. The effective portion of changes in the value of the hedge is recorded as adjustments to the asset or liability being hedged. Any ineffectiveness and amounts excluded from the assessment of hedge effectiveness is recognized currently in earnings. Does Not Qualify For Hedge Accounting Treatment Economic Hedge To effectively serve as either a fair value or a cash flow hedge; however, the derivative agreement does not qualify for hedge accounting treatment under Accounting Standards Codification ("ASC") 815, Derivatives and Hedging . Changes in the fair value of these agreements are recognized currently in earnings. During the three and six months ended June 30, 2014 and 2015 , none of the commodity hedging contracts we entered into qualified for or were designated as cash flow hedges. Period changes in the fair value of NYMEX agreements that are accounted for as economic hedges (other than those economic hedges of our butane purchases and our pipeline product overages as discussed below), the effective portion of changes in the fair value of cash flow hedges that are reclassified from accumulated other comprehensive income/loss and any ineffectiveness associated with hedges related to our commodity activities are recognized currently in earnings as adjustments to product sales. We also use NYMEX contracts, which are not designated as hedges for accounting purposes, to hedge against changes in the price of butane we expect to purchase in the future. Period changes in the fair value of these agreements are recognized currently in earnings as adjustments to cost of product sales. We currently hold petroleum product inventories that we obtained from overages on our pipeline systems. We use NYMEX contracts that are not designated as hedges for accounting purposes to help manage price changes related to these overage inventory barrels. Period changes in the fair value of these agreements are recognized currently in earnings as adjustments to operating expense. Additionally, we hold crude oil barrels that we use for operational purposes which we classify as long-term assets on our balance sheet and which are reported as tank bottom and linefill assets. We use NYMEX contracts to hedge against changes in the price of these crude oil barrels. We record the effective portion of the gains or losses for those contracts that qualify as fair value hedges as adjustments to the assets being hedged and the ineffective portions as well as amounts excluded from the assessment of hedge effectiveness as adjustments to other income or expense. As outlined in the table below, our open NYMEX contracts at June 30, 2015 were as follows: Type of Contract/Accounting Methodology Product Represented by the Contract and Associated Barrels Maturity Dates NYMEX - Fair Value Hedges 0.7 million barrels of crude oil Between December 2015 and November 2016 NYMEX - Economic Hedges 5.6 million barrels of refined products and crude oil (1) Between July 2015 and December 2016 NYMEX - Economic Hedges 1.3 million barrels of future purchases of butane Between September 2015 and December 2016 (1) Of the 5.6 million barrels of products we have economically hedged at June 30, 2015 , we had open agreements which swap the pricing on 1.6 million of those barrels from New York Harbor to Platts Group 3 or Platts Gulf Coast, which are the geographic locations where these barrels will be sold. Energy Commodity Derivatives Contracts and Deposits Offsets At June 30, 2015 , we had made margin deposits of $5.7 million for our NYMEX contracts with one of our counterparties, which were recorded as a current asset under energy commodity derivatives deposits on our consolidated balance sheet. We have the right to offset the combined fair values of our open NYMEX contracts against our margin deposits under a master netting arrangement for each counterparty; however, we have elected to present the combined fair values of our open NYMEX contracts separately from the related margin deposits on our consolidated balance sheets. Additionally, we have the right to offset the fair values of our NYMEX agreements together for each counterparty, which we have elected to do, and we report the combined net balances on our consolidated balance sheets. A schedule of the derivative amounts we have offset and the deposit amounts we could offset under a master netting arrangement are provided below as of December 31, 2014 and June 30, 2015 (in thousands): December 31, 2014 Description Gross Amounts of Recognized Assets Gross Amounts of Liabilities Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet (1) Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet Net Asset Amount (3) Energy commodity derivatives $ 106,764 $ (10,622 ) $ 96,142 $ (78,279 ) $ 17,863 June 30, 2015 Description Gross Amounts of Recognized Assets Gross Amounts of Liabilities Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet (2) Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet Net Asset Amount (3) Energy commodity derivatives $ 26,262 $ (12,636 ) $ 13,626 $ 5,696 $ 19,322 (1) Net amount includes energy commodity derivative contracts classified as current assets, net, of $87,151 , current liabilities of $5,413 and noncurrent assets of $14,404 . (2) Net amount includes energy commodity derivative contracts classified as current liabilities, net, of $2,860 and noncurrent assets of $16,486 . (3) This represents the maximum amount of loss we would incur if all of our counterparties failed to perform on their derivative contracts. Impact of Derivatives on Our Financial Statements Comprehensive Income The changes in derivative activity included in AOCL for the three and six months ended June 30, 2014 and 2015 were as follows (in thousands): Three Months Ended Six Months Ended June 30, June 30, Derivative Gains (Losses) Included in AOCL 2014 2015 2014 2015 Beginning balance $ 9,988 $ (31,852 ) $ 13,627 $ (16,587 ) Net gain (loss) on interest rate contract cash flow hedges — 1,936 (3,613 ) (13,529 ) Reclassification of net loss (gain) on cash flow hedges to income (153 ) 388 (179 ) 588 Ending balance $ 9,835 $ (29,528 ) $ 9,835 $ (29,528 ) The following tables provide a summary of the effect on our consolidated statements of income for the three and six months ended June 30, 2014 and 2015 of derivatives accounted for under ASC 815-30, Derivatives and Hedging—Cash Flow Hedges , that were designated as hedging instruments (in thousands): Three Months Ended June 30, 2014 Amount of Loss Recognized in AOCL on Derivative Location of Gain (Loss) Reclassified from AOCL into Income Amount of Gain (Loss) Reclassified from AOCL into Income Derivative Instrument Effective Portion Ineffective Portion Interest rate contracts $ — Interest expense $ (30 ) $ 183 Three Months Ended June 30, 2015 Amount of Gain Recognized in AOCL on Derivative Location of Loss Reclassified from AOCL into Income Amount of Loss Reclassified from AOCL into Income Derivative Instrument Effective Portion Ineffective Portion Interest rate contracts $ 1,936 Interest expense $ (388 ) $ — Six Months Ended June 30, 2014 Amount of Loss Recognized in AOCL on Derivative Location of Gain (Loss) Reclassified from AOCL into Income Amount of Gain (Loss) Reclassified from AOCL into Income Derivative Instrument Effective Portion Ineffective Portion Interest rate contracts $ (3,613 ) Interest expense $ (4 ) $ 183 Six Months Ended June 30, 2015 Amount of Loss Recognized in AOCL on Derivative Location of Loss Reclassified from AOCL into Income Amount of Loss Reclassified from AOCL into Income Derivative Instrument Effective Portion Ineffective Portion Interest rate contracts $ (13,529 ) Interest expense $ (588 ) $ — As of June 30, 2015 , the net loss estimated to be classified to interest expense over the next twelve months from AOCL is approximately $1.5 million . Income Statement The following table provides a summary of the effect on our consolidated statements of income for the three and six months ended June 30, 2014 and 2015 of derivatives accounted for under ASC 815, Derivatives and Hedging , that were not designated as hedging instruments (in thousands): Amount of Gain (Loss) Recognized on Derivative Three Months Ended Six Months Ended Location of Gain (Loss) Recognized on Derivative June 30, June 30, Derivative Instrument 2014 2015 2014 2015 NYMEX commodity contracts Product sales revenue $ (16,653 ) $ (23,350 ) $ (13,830 ) $ (19,470 ) NYMEX commodity contracts Operating expenses (4,268 ) (8,883 ) (3,903 ) (7,580 ) NYMEX commodity contracts Cost of product sales 632 (856 ) 776 (2,080 ) Total $ (20,289 ) $ (33,089 ) $ (16,957 ) $ (29,130 ) The impact of the derivatives in the above table was reflected as cash from operations on our consolidated statements of cash flows. During 2014 and 2015 , we had open NYMEX contracts on 0.7 million barrels of crude oil that were designated as fair value hedges. Because there was no ineffectiveness recognized on these hedges, the cumulative gains at December 31, 2014 and June 30, 2015 of $13.3 million and $8.7 million , respectively, from the agreements were offset by a cumulative decrease to tank bottoms and linefill. The differential between the current spot price and forward price is excluded from the assessment of hedge effectiveness for these fair value hedges. For the three and six months ended June 30, 2015 , we recognized a gain of $6.5 million and $6.3 million , respectively, for the amounts we excluded from the assessment of effectiveness of these fair value hedges, which we reported as other income on our consolidated statements of income. Balance Sheet The following tables provide a summary of the fair value of derivatives accounted for under ASC 815, Derivatives and Hedging, which are presented on a net basis in our consolidated balance sheets, that were designated as hedging instruments as of December 31, 2014 and June 30, 2015 (in thousands): December 31, 2014 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value NYMEX commodity contracts Energy commodity derivatives contracts, net $ 360 Energy commodity derivatives contracts, net $ — NYMEX commodity contracts Other noncurrent assets 14,404 Other noncurrent liabilities — Interest rate contracts Other current assets — Other current liabilities 26,478 Total $ 14,764 Total $ 26,478 June 30, 2015 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value NYMEX commodity contracts Energy commodity derivatives contracts, net $ 316 Energy commodity derivatives contracts, net $ — NYMEX commodity contracts Other noncurrent assets 16,089 Other noncurrent liabilities — Interest rate contracts Other noncurrent assets 2,901 Other noncurrent liabilities — Total $ 19,306 Total $ — The following tables provide a summary of the fair value of derivatives accounted for under ASC 815, Derivatives and Hedging, which are presented on a net basis in our consolidated balance sheets, that were not designated as hedging instruments as of December 31, 2014 and June 30, 2015 (in thousands): December 31, 2014 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value NYMEX commodity contracts Energy commodity derivatives contracts, net $ 92,000 Energy commodity derivatives contracts, net $ 10,622 June 30, 2015 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value NYMEX commodity contracts Energy commodity derivatives contracts, net $ 9,460 Energy commodity derivatives contracts, net $ 12,636 NYMEX commodity contracts Other noncurrent assets 397 Other noncurrent liabilities — Total $ 9,857 Total $ 12,636

Commitments And Contingencies

Commitments And Contingencies	6 Months Ended
	Jun. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Environmental Liabilities Liabilities recognized for estimated environmental costs were $36.3 million and $36.5 million at December 31, 2014 and June 30, 2015 , respectively. We have classified environmental liabilities as current or noncurrent based on management’s estimates regarding the timing of actual payments. Management estimates that expenditures associated with these environmental liabilities will be paid over the next 10 years . Environmental expenditures recognized as a result of changes in our environmental liabilities are generally included in operating expenses on our consolidated statements of income. Environmental expenses for the three and six months ended June 30, 2014 were $0.1 million and $0.4 million , respectively. Environmental expenses for the three and six months ended June 30, 2015 were $2.9 million and $4.3 million , respectively. Environmental Receivables Receivables from insurance carriers and other third parties related to environmental matters at December 31, 2014 were $5.1 million , of which $1.3 million and $3.8 million were recorded to other accounts receivable and long-term receivables, respectively, on our consolidated balance sheet. Receivables from insurance carriers and other third parties related to environmental matters at June 30, 2015 were $4.9 million , of which $1.0 million and $3.9 million were recorded to other accounts receivable and long-term receivables, respectively, on our consolidated balance sheet. Other We are a party to various other claims, legal actions and complaints arising in the ordinary course of business, including without limitation those disclosed in Item 1, Legal Proceedings of Part II of this report on Form 10-Q. While the results cannot be predicted with certainty, management believes the ultimate resolution of these claims, legal actions and complaints after consideration of amounts accrued, insurance coverage or other indemnification arrangements will not have a material adverse effect on our results of operations, financial position or cash flows.

Long-Term Incentive Plan

Long-Term Incentive Plan	6 Months Ended
	Jun. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Long-Term Incentive Plan	Long-Term Incentive Plan We have a long-term incentive plan (“LTIP”) for certain of our employees and for directors of our general partner. The LTIP primarily consists of phantom units and permits the grant of awards covering an aggregate payout of 9.4 million of our limited partner units. The estimated units available under the LTIP at June 30, 2015 total 1.0 million . The compensation committee of our general partner’s board of directors administers our LTIP. Our equity-based incentive compensation expense was as follows (in thousands): Three Months Ended Six Months Ended June 30, 2014 June 30, 2014 Equity Method Liability Method Total Equity Method Liability Method Total Performance/market-based awards: 2012 awards $ 1,022 $ 1,617 $ 2,639 $ 2,044 $ 2,541 $ 4,585 2013 awards 2,195 1,305 3,500 3,376 1,853 5,229 2014 awards 1,228 — 1,228 2,132 — 2,132 Retention awards 298 — 298 807 — 807 Total $ 4,743 $ 2,922 $ 7,665 $ 8,359 $ 4,394 $ 12,753 Allocation of LTIP expense on our consolidated statements of income: G&A expense $ 7,486 $ 12,460 Operating expense 179 293 Total $ 7,665 $ 12,753 Three Months Ended Six Months Ended June 30, 2015 June 30, 2015 Equity Method Liability Method Total Equity Method Liability Method Total Performance/market-based awards: 2013 awards $ 3,054 $ 876 $ 3,930 $ 4,573 $ 1,091 $ 5,664 2014 awards 860 — 860 2,483 — 2,483 2015 awards 941 — 941 1,960 — 1,960 Retention awards 57 — 57 432 — 432 Total $ 4,912 $ 876 $ 5,788 $ 9,448 $ 1,091 $ 10,539 Allocation of LTIP expense on our consolidated statements of income: G&A expense $ 5,684 $ 10,373 Operating expense 104 166 Total $ 5,788 $ 10,539 In February 2015, 166,189 phantom unit awards were issued pursuant to our LTIP. These grants included both performance-based and retention awards and have a three -year vesting period. In January 2015, we issued 354,529 limited partner units to settle unit award grants to certain employees that vested on December 31, 2014. Further, 4,461 limited partner units were issued during 2015 to settle the equity-based retainer paid to certain members of our general partner's board of directors.

Distributions

Distributions	6 Months Ended
	Jun. 30, 2015
Distributions Made to Members or Limited Partners [Abstract]
Distributions	Distributions Distributions we paid during 2014 and 2015 were as follows (in thousands, except per unit amounts): Payment Date Per Unit Cash Distribution Amount Total Cash Distribution to Limited Partners 02/14/2014 $ 0.5850 $ 132,835 05/15/2014 0.6125 139,079 Through 06/30/2014 1.1975 271,914 08/14/2014 0.6400 145,324 11/14/2014 0.6675 151,568 Total $ 2.5050 $ 568,806 2/13/2015 $ 0.6950 $ 158,061 5/15/2015 0.7175 163,178 Through 06/30/2015 1.4125 321,239 08/14/2015 (1) 0.7400 168,296 Total $ 2.1525 $ 489,535 (1) Our general partner's board of directors declared this cash distribution on July 23, 2015 to be paid on August 14, 2015 to unitholders of record at the close of business on August 7, 2015 .

Fair Value

Fair Value	6 Months Ended
	Jun. 30, 2015
Fair Value Disclosures [Abstract]
Fair Value	Fair Value Recurring Fair Value Methods and Assumptions - Financial Assets and Liabilities. We used the following methods and assumptions in estimating fair value for our financial assets and liabilities: • Energy commodity derivatives contracts . These include NYMEX futures agreements related to petroleum products. These contracts are carried at fair value on our consolidated balance sheets and are valued based on quoted prices in active markets. See Note 8 – Derivative Financial Instruments for further disclosures regarding these contracts. • Interest rate contracts. These include forward-starting interest rate swap agreements to hedge against the risk of variability of interest payments on future debt. These contracts are carried at fair value on our consolidated balance sheets and are valued based on an assumed exchange, at the end of each period, in an orderly transaction with a market participant in the market in which the financial instrument is traded. The exchange value was calculated using present value techniques on estimated future cash flows based on forward interest rate curves. See Note 8 – Derivative Financial Instruments for further disclosures regarding these contracts. • Long-term receivables. These include lease payments receivable under a direct-financing leasing arrangement and insurance receivables. Fair value was determined by estimating the present value of future cash flows using current market rates. • Debt. The fair value of our publicly traded notes was based on the prices of those notes at December 31, 2014 and June 30, 2015 ; however, where recent observable market trades were not available, prices were determined using adjustments to the last traded value for that debt issuance or by adjustments to the prices of similar debt instruments of peer entities that are actively traded. The carrying amount of borrowings, if any, under our revolving credit facility and our commercial paper program approximates fair value due to the frequent repricing of these obligations. Fair Value Measurements - Financial Assets and Liabilities The following tables summarize the carrying amounts, fair values and recurring fair value measurements recorded or disclosed as of December 31, 2014 and June 30, 2015 , based on the three levels established by ASC 820, Fair Value Measurements and Disclosures (in thousands): As of December 31, 2014 Assets (Liabilities) Fair Value Measurements using: Carrying Amount Fair Value Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Energy commodity derivatives contracts – assets $ 96,142 $ 96,142 $ 96,142 $ — $ — Interest rate contracts – liabilities $ (26,478 ) $ (26,478 ) $ — $ (26,478 ) $ — Long-term receivables $ 28,611 $ 30,200 $ — $ — $ 30,200 Debt $ (2,982,895 ) $ (3,212,462 ) $ — $ (3,212,462 ) $ — As of June 30, 2015 Assets (Liabilities) Fair Value Measurements using: Carrying Amount Fair Value Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Energy commodity derivatives contracts – assets $ 13,626 $ 13,626 $ 13,626 $ — $ — Interest rate contracts – assets $ 2,901 $ 2,901 $ — $ 2,901 $ — Long-term receivables $ 25,614 $ 26,413 $ — $ — $ 26,413 Debt $ (3,326,936 ) $ (3,426,312 ) $ — $ (3,426,312 ) $ —

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2015
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions Barry R. Pearl is an independent member of our general partner's board of directors and is also a director of the general partner of Targa Resources Partners, L.P. ("Targa"). In the normal course of business, we purchase butane from subsidiaries of Targa. For the three months ended June 30, 2014 and 2015 , we made purchases of butane from subsidiaries of Targa of $1.6 million and $4.0 million , respectively. For the six months ended June 30, 2014 and 2015 , we made purchases of butane from subsidiaries of Targa of $13.8 million and $12.8 million , respectively. These purchases were based on the then-current index prices. We had recognized payables to Targa of $0.9 million and $0.2 million at December 31, 2014 and June 30, 2015 , respectively. Stacy P. Methvin was elected as an independent member of our general partner's board of directors on April 23, 2015 and is also a director of one of our customers. We received tariff revenue of $2.6 million from April 23, 2015 through June 30, 2015, and have recorded a $1.3 million receivable from this customer at June 30, 2015. The tariff revenue we recognized from this customer was in the normal course of business, with rates determined in accordance with published tariffs. See Note 4 – Investments in Non-Controlled Entities for a discussion of affiliate joint venture transactions we account for under the equity method.

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2015
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events Recognizable events No recognizable events occurred subsequent to June 30, 2015 . Non-recognizable events In July 2015, our general partner's board of directors declared a quarterly distribution of $0.74 per unit to be paid on August 14, 2015 to unitholders of record at the close of business on August 7, 2015 . The total cash distributions expected to be paid under this declaration are approximately $168.3 million .

Product Sales Revenues (Tables)

Product Sales Revenues (Tables)	6 Months Ended
	Jun. 30, 2015
Product Sales Revenue [Abstract]
Components of Product Sales Revenues	For the three and six months ended June 30, 2014 and 2015 , product sales revenue included the following (in thousands): Three Months Ended Six Months Ended June 30, June 30, 2014 2015 2014 2015 Physical sale of petroleum products $ 154,310 $ 133,319 $ 447,550 $ 302,566 NYMEX contract adjustments: Change in value of NYMEX contracts that were not designated as hedging instruments associated with our butane blending and fractionation activities (16,666 ) (23,350 ) (13,843 ) (19,470 ) Other 13 — 13 — Total NYMEX contract adjustments (16,653 ) (23,350 ) (13,830 ) (19,470 ) Total product sales revenue $ 137,657 $ 109,969 $ 433,720 $ 283,096

Segment Disclosures (Tables)

Segment Disclosures (Tables)	6 Months Ended
	Jun. 30, 2015
Segment Reporting [Abstract]
Schedule of Business Segment Reporting Information	A reconciliation of operating margin to operating profit, which is its nearest comparable GAAP financial measure, is included in the tables below. Operating profit includes depreciation and amortization expense and general and administrative ("G&A") expenses that management does not consider when evaluating the core profitability of our separate operating segments. On May 1, 2015, we acquired a refined products terminal in Atlanta, Georgia for net cash consideration of $54.7 million . As this acquired business is not significant to our consolidated operating results and financial position, pro forma financial information and the purchase price allocation of acquired assets and liabilities have not been presented. The results of the acquired operations subsequent to the acquisition date have been included in the accompanying consolidated financial statements and in the tables below in our refined products operating segment. Three Months Ended June 30, 2014 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 232,489 $ 79,556 $ 41,523 $ — $ 353,568 Product sales revenue 136,334 — 1,323 — 137,657 Affiliate management fee revenue — 4,902 319 — 5,221 Total revenue 368,823 84,458 43,165 — 496,446 Operating expenses 97,302 11,867 16,544 (839 ) 124,874 Cost of product sales 108,817 — 286 — 109,103 Earnings of non-controlled entities — (888 ) (1,067 ) — (1,955 ) Operating margin 162,704 73,479 27,402 839 264,424 Depreciation and amortization expense 32,083 6,725 7,250 839 46,897 G&A expenses 25,374 7,697 6,238 — 39,309 Operating profit $ 105,247 $ 59,057 $ 13,914 $ — $ 178,218 Three Months Ended June 30, 2015 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 233,711 $ 95,756 $ 44,549 $ — $ 374,016 Product sales revenue 109,323 — 646 — 109,969 Affiliate management fee revenue — 3,211 347 — 3,558 Total revenue 343,034 98,967 45,542 — 487,543 Operating expenses 100,475 16,014 15,881 (937 ) 131,433 Cost of product sales 94,326 — 181 — 94,507 Losses (earnings) of non-controlled entities 43 (23,905 ) (680 ) — (24,542 ) Operating margin 148,190 106,858 30,160 937 286,145 Depreciation and amortization expense 23,962 8,264 7,277 937 40,440 G&A expenses 23,893 9,031 5,018 — 37,942 Operating profit $ 100,335 $ 89,563 $ 17,865 $ — $ 207,763 Six Months Ended June 30, 2014 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 442,725 $ 147,459 $ 81,021 $ — $ 671,205 Product sales revenue 430,044 — 3,676 — 433,720 Affiliate management fee revenue — 9,497 630 — 10,127 Total revenue 872,769 156,956 85,327 — 1,115,052 Operating expenses 148,459 20,925 30,630 (1,643 ) 198,371 Cost of product sales 306,573 — 570 — 307,143 Earnings of non-controlled entities — (708 ) (1,713 ) — (2,421 ) Operating margin 417,737 136,739 55,840 1,643 611,959 Depreciation and amortization expense 55,255 13,188 14,322 1,643 84,408 G&A expenses 48,393 13,691 12,160 — 74,244 Operating profit $ 314,089 $ 109,860 $ 29,358 $ — $ 453,307 Six Months Ended June 30, 2015 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 450,488 $ 182,316 $ 86,812 $ — $ 719,616 Product sales revenue 281,962 — 1,134 — 283,096 Affiliate management fee revenue — 6,238 683 — 6,921 Total revenue 732,450 188,554 88,629 — 1,009,633 Operating expenses 170,781 29,875 31,216 (1,944 ) 229,928 Cost of product sales 229,960 — 726 — 230,686 Losses (earnings) of non-controlled entities 98 (32,829 ) (1,401 ) — (34,132 ) Operating margin 331,611 191,508 58,088 1,944 583,151 Depreciation and amortization expense 47,409 16,493 16,291 1,944 82,137 G&A expenses 46,492 17,117 9,831 — 73,440 Operating profit $ 237,710 $ 157,898 $ 31,966 $ — $ 427,574

Investments in Non-Controlled23

Investments in Non-Controlled Entities (Tables)	6 Months Ended
	Jun. 30, 2015
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Our investments in non-controlled entities at June 30, 2015 were comprised of: Entity Ownership Interest BridgeTex Pipeline Company, LLC ("BridgeTex") 50% Double Eagle Pipeline LLC ("Double Eagle") 50% Osage Pipe Line Company, LLC ("Osage") 50% Powder Springs Logistics, LLC ("Powder Springs") 50% Saddlehorn Pipeline Company, LLC ("Saddlehorn") 40% Seabrook Logistics, LLC 50% Texas Frontera, LLC ("Texas Frontera") 50% The management fees we have recognized or will recognize from BridgeTex, Osage, Powder Springs, Saddlehorn, Seabrook and Texas Frontera are or will be reported as affiliate management fee revenue on our consolidated statements of income. At December 31, 2014 and June 30, 2015 , we recognized liabilities of $2.2 million and $1.1 million , respectively, to BridgeTex primarily for pre-paid construction management fees. For the three and six months ended June 30, 2015 , we recognized pipeline capacity lease revenue from BridgeTex of $8.5 million and $16.9 million , respectively, which we included in transportation and terminals revenue on our consolidated statements of income. We recognized a $2.6 million receivable from BridgeTex at December 31, 2014 ( no receivable was recognized at June 30, 2015 ). We recognized throughput revenue from Double Eagle for the three months ended June 30, 2014 and 2015 of $0.8 million and $0.9 million , respectively, and for the six months ended June 30, 2014 and 2015 of $1.3 million and $1.8 million , respectively, which we included in transportation and terminals revenue. At December 31, 2014 and June 30, 2015 , respectively, we recognized a $0.3 million trade accounts receivable from Double Eagle. The financial results from Texas Frontera are included in our marine storage segment, the financial results from BridgeTex, Double Eagle, Osage, Saddlehorn and Seabrook are or will be included in our crude oil segment and the financial results from Powder Springs are included in our refined products segment as earnings/losses of non-controlled entities. A summary of our investments in non-controlled entities follows (in thousands): BridgeTex All Others Consolidated Investments at December 31, 2014 $ 489,348 $ 124,519 $ 613,867 Additional investment 16,609 33,086 49,695 Earnings of non-controlled entities: Proportionate share of earnings 31,828 3,699 35,527 Amortization of excess investment and capitalized interest (1,020 ) (375 ) (1,395 ) Earnings of non-controlled entities 30,808 3,324 34,132 Less: Distributions of earnings from investments in non-controlled entities 30,332 911 31,243 Investments at June 30, 2015 $ 506,433 $ 160,018 $ 666,451 Summarized financial information of our non-controlled entities for the three and six months ended June 30, 2014 and 2015 follows (in thousands): Three Months Ended June 30, 2014 Three Months Ended June 30, 2015 BridgeTex All Others Consolidated BridgeTex All Others Consolidated Revenue $ — $ 11,709 $ 11,709 $ 61,629 $ 11,627 $ 73,256 Net income (loss) $ (240 ) $ 4,524 $ 4,284 $ 45,619 $ 4,793 $ 50,412 Six Months Ended June 30, 2014 Six Months Ended June 30, 2015 BridgeTex All Others Consolidated BridgeTex All Others Consolidated Revenue $ — $ 18,464 $ 18,464 $ 98,765 $ 21,147 $ 119,912 Net income (loss) $ (280 ) $ 5,871 $ 5,591 $ 63,656 $ 7,374 $ 71,030

Inventory (Tables)

Inventory (Tables)	6 Months Ended
	Jun. 30, 2015
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventory at December 31, 2014 and June 30, 2015 was as follows (in thousands): December 31, 2014 June 30, Refined products $ 67,055 $ 33,862 Liquefied petroleum gases 37,642 39,942 Transmix 36,867 47,513 Crude oil 10,015 32,501 Additives 6,183 6,102 Total inventory $ 157,762 $ 159,920

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	6 Months Ended
	Jun. 30, 2015
Compensation and Retirement Disclosure [Abstract]
Schedule Of Consolidated Net Periodic Benefit Costs	The following tables present our consolidated net periodic benefit costs related to the pension and postretirement benefit plans for the three and six months ended June 30, 2014 and 2015 (in thousands): Three Months Ended Three Months Ended June 30, 2014 June 30, 2015 Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Components of net periodic benefit costs: Service cost $ 3,352 $ 47 $ 4,975 $ 56 Interest cost 2,030 139 2,008 109 Expected return on plan assets (1,490 ) — (2,123 ) — Amortization of prior service credit — (928 ) — (928 ) Amortization of actuarial loss 930 262 1,806 217 Settlement cost 1,569 — — — Net periodic benefit cost (credit) $ 6,391 $ (480 ) $ 6,666 $ (546 ) Six Months Ended Six Months Ended June 30, 2014 June 30, 2015 Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Components of net periodic benefit costs: Service cost $ 6,704 $ 114 $ 9,445 $ 122 Interest cost 3,689 253 3,877 219 Expected return on plan assets (3,187 ) — (4,019 ) — Amortization of prior service cost (credit) 33 (1,856 ) — (1,856 ) Amortization of actuarial loss 1,559 457 3,153 442 Settlement cost 1,569 — — — Net periodic benefit cost (credit) $ 10,367 $ (1,032 ) $ 12,456 $ (1,073 )
Schedule of Amounts Recognized in Other Comprehensive Income (Loss)	The changes in AOCL related to employee benefit plan assets and benefit obligations for the three and six months ended June 30, 2014 and 2015 were as follows (in thousands): Three Months Ended Three Months Ended June 30, 2014 June 30, 2015 Gains (Losses) Included in AOCL Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Beginning balance $ (35,522 ) $ 2,320 $ (61,910 ) $ (2,399 ) Amortization of prior service credit — (928 ) — (928 ) Amortization of actuarial loss 930 262 1,806 217 Settlement cost 1,569 — — — Ending balance $ (33,023 ) $ 1,654 $ (60,104 ) $ (3,110 ) Six Months Ended Six Months Ended June 30, 2014 June 30, 2015 Gains (Losses) Included in AOCL Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Beginning balance $ (36,184 ) $ 3,053 $ (63,257 ) $ (1,696 ) Amortization of prior service cost (credit) 33 (1,856 ) — (1,856 ) Amortization of actuarial loss 1,559 457 3,153 442 Settlement cost 1,569 — — — Ending balance $ (33,023 ) $ 1,654 $ (60,104 ) $ (3,110 )

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2015
Debt Disclosure [Abstract]
Consolidated Debt	Consolidated debt at December 31, 2014 and June 30, 2015 was as follows (in thousands, except as otherwise noted): December 31, 2014 June 30, Weighted-Average Interest Rate for the Six Months Ended June 30, 2015 (1) Commercial paper (2) $ 296,942 $ 144,982 0.5% $250.0 million of 5.65% Notes due 2016 250,758 250,546 5.7% $250.0 million of 6.40% Notes due 2018 257,280 256,248 5.4% $550.0 million of 6.55% Notes due 2019 567,868 566,006 5.7% $550.0 million of 4.25% Notes due 2021 556,304 555,837 4.0% $250.0 million of 3.20% Notes due 2025 (2) — 249,687 3.2% $250.0 million of 6.40% Notes due 2037 249,017 249,026 6.4% $250.0 million of 4.20% Notes due 2042 248,406 248,421 4.2% $550.0 million of 5.15% Notes due 2043 556,320 556,270 5.1% $250.0 million of 4.20% Notes due 2045 (2) — 249,913 4.6% Total debt $ 2,982,895 $ 3,326,936 4.8% (1) Weighted-average interest rate includes the amortization/accretion of discounts, premiums and gains/losses realized on historical cash flow and fair value hedges recognized as interest expense. (2) These borrowings were outstanding for only a portion of the six month period ending June 30, 2015 . The weighted-average interest rate for these borrowings was calculated based on the number of days the borrowings were outstanding during the noted period.

Derivative Financial Instrume27

Derivative Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule Of Forward Purchase And Sales Contracts	As of June 30, 2015 , we had commitments under these forward purchase and sale contracts as follows (in millions): Notional Value Barrels Forward purchase contracts $ 118.3 3.5 Forward sale contracts $ 11.4 0.1
Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements	As outlined in the table below, our open NYMEX contracts at June 30, 2015 were as follows: Type of Contract/Accounting Methodology Product Represented by the Contract and Associated Barrels Maturity Dates NYMEX - Fair Value Hedges 0.7 million barrels of crude oil Between December 2015 and November 2016 NYMEX - Economic Hedges 5.6 million barrels of refined products and crude oil (1) Between July 2015 and December 2016 NYMEX - Economic Hedges 1.3 million barrels of future purchases of butane Between September 2015 and December 2016 (1) Of the 5.6 million barrels of products we have economically hedged at June 30, 2015 , we had open agreements which swap the pricing on 1.6 million of those barrels from New York Harbor to Platts Group 3 or Platts Gulf Coast, which are the geographic locations where these barrels will be sold.
Derivatives and Offset Amounts [Table Text Block]	A schedule of the derivative amounts we have offset and the deposit amounts we could offset under a master netting arrangement are provided below as of December 31, 2014 and June 30, 2015 (in thousands): December 31, 2014 Description Gross Amounts of Recognized Assets Gross Amounts of Liabilities Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet (1) Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet Net Asset Amount (3) Energy commodity derivatives $ 106,764 $ (10,622 ) $ 96,142 $ (78,279 ) $ 17,863 June 30, 2015 Description Gross Amounts of Recognized Assets Gross Amounts of Liabilities Offset in the Consolidated Balance Sheet Net Amounts of Assets Presented in the Consolidated Balance Sheet (2) Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet Net Asset Amount (3) Energy commodity derivatives $ 26,262 $ (12,636 ) $ 13,626 $ 5,696 $ 19,322 (1) Net amount includes energy commodity derivative contracts classified as current assets, net, of $87,151 , current liabilities of $5,413 and noncurrent assets of $14,404 . (2) Net amount includes energy commodity derivative contracts classified as current liabilities, net, of $2,860 and noncurrent assets of $16,486 . (3) This represents the maximum amount of loss we would incur if all of our counterparties failed to perform on their derivative contracts.
Derivative Gains Included In Accumulated Other Comprehensive Loss (AOCL)	The changes in derivative activity included in AOCL for the three and six months ended June 30, 2014 and 2015 were as follows (in thousands): Three Months Ended Six Months Ended June 30, June 30, Derivative Gains (Losses) Included in AOCL 2014 2015 2014 2015 Beginning balance $ 9,988 $ (31,852 ) $ 13,627 $ (16,587 ) Net gain (loss) on interest rate contract cash flow hedges — 1,936 (3,613 ) (13,529 ) Reclassification of net loss (gain) on cash flow hedges to income (153 ) 388 (179 ) 588 Ending balance $ 9,835 $ (29,528 ) $ 9,835 $ (29,528 )
Derivatives And Hedging-Cash Flow Hedges	The following tables provide a summary of the effect on our consolidated statements of income for the three and six months ended June 30, 2014 and 2015 of derivatives accounted for under ASC 815-30, Derivatives and Hedging—Cash Flow Hedges , that were designated as hedging instruments (in thousands): Three Months Ended June 30, 2014 Amount of Loss Recognized in AOCL on Derivative Location of Gain (Loss) Reclassified from AOCL into Income Amount of Gain (Loss) Reclassified from AOCL into Income Derivative Instrument Effective Portion Ineffective Portion Interest rate contracts $ — Interest expense $ (30 ) $ 183 Three Months Ended June 30, 2015 Amount of Gain Recognized in AOCL on Derivative Location of Loss Reclassified from AOCL into Income Amount of Loss Reclassified from AOCL into Income Derivative Instrument Effective Portion Ineffective Portion Interest rate contracts $ 1,936 Interest expense $ (388 ) $ —
Derivatives And Hedging-Overall-Subsequent Measurement	The following table provides a summary of the effect on our consolidated statements of income for the three and six months ended June 30, 2014 and 2015 of derivatives accounted for under ASC 815, Derivatives and Hedging , that were not designated as hedging instruments (in thousands): Amount of Gain (Loss) Recognized on Derivative Three Months Ended Six Months Ended Location of Gain (Loss) Recognized on Derivative June 30, June 30, Derivative Instrument 2014 2015 2014 2015 NYMEX commodity contracts Product sales revenue $ (16,653 ) $ (23,350 ) $ (13,830 ) $ (19,470 ) NYMEX commodity contracts Operating expenses (4,268 ) (8,883 ) (3,903 ) (7,580 ) NYMEX commodity contracts Cost of product sales 632 (856 ) 776 (2,080 ) Total $ (20,289 ) $ (33,089 ) $ (16,957 ) $ (29,130 )
Derivatives And Hedging-Designated	The following tables provide a summary of the fair value of derivatives accounted for under ASC 815, Derivatives and Hedging, which are presented on a net basis in our consolidated balance sheets, that were designated as hedging instruments as of December 31, 2014 and June 30, 2015 (in thousands): December 31, 2014 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value NYMEX commodity contracts Energy commodity derivatives contracts, net $ 360 Energy commodity derivatives contracts, net $ — NYMEX commodity contracts Other noncurrent assets 14,404 Other noncurrent liabilities — Interest rate contracts Other current assets — Other current liabilities 26,478 Total $ 14,764 Total $ 26,478 June 30, 2015 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value NYMEX commodity contracts Energy commodity derivatives contracts, net $ 316 Energy commodity derivatives contracts, net $ — NYMEX commodity contracts Other noncurrent assets 16,089 Other noncurrent liabilities — Interest rate contracts Other noncurrent assets 2,901 Other noncurrent liabilities — Total $ 19,306 Total $ — The following tables provide a summary of the fair value of derivatives accounted for under ASC 815, Derivatives and Hedging, which are presented on a net basis in our consolidated balance sheets, that were not designated as hedging instruments as of December 31, 2014 and June 30, 2015 (in thousands): December 31, 2014 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value NYMEX commodity contracts Energy commodity derivatives contracts, net $ 92,000 Energy commodity derivatives contracts, net $ 10,622 June 30, 2015 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value NYMEX commodity contracts Energy commodity derivatives contracts, net $ 9,460 Energy commodity derivatives contracts, net $ 12,636 NYMEX commodity contracts Other noncurrent assets 397 Other noncurrent liabilities — Total $ 9,857 Total $ 12,636

Long-Term Incentive Plan (Table

Long-Term Incentive Plan (Tables)	6 Months Ended
	Jun. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Equity-Based Incentive Compensation Expense	Our equity-based incentive compensation expense was as follows (in thousands): Three Months Ended Six Months Ended June 30, 2014 June 30, 2014 Equity Method Liability Method Total Equity Method Liability Method Total Performance/market-based awards: 2012 awards $ 1,022 $ 1,617 $ 2,639 $ 2,044 $ 2,541 $ 4,585 2013 awards 2,195 1,305 3,500 3,376 1,853 5,229 2014 awards 1,228 — 1,228 2,132 — 2,132 Retention awards 298 — 298 807 — 807 Total $ 4,743 $ 2,922 $ 7,665 $ 8,359 $ 4,394 $ 12,753 Allocation of LTIP expense on our consolidated statements of income: G&A expense $ 7,486 $ 12,460 Operating expense 179 293 Total $ 7,665 $ 12,753 Three Months Ended Six Months Ended June 30, 2015 June 30, 2015 Equity Method Liability Method Total Equity Method Liability Method Total Performance/market-based awards: 2013 awards $ 3,054 $ 876 $ 3,930 $ 4,573 $ 1,091 $ 5,664 2014 awards 860 — 860 2,483 — 2,483 2015 awards 941 — 941 1,960 — 1,960 Retention awards 57 — 57 432 — 432 Total $ 4,912 $ 876 $ 5,788 $ 9,448 $ 1,091 $ 10,539 Allocation of LTIP expense on our consolidated statements of income: G&A expense $ 5,684 $ 10,373 Operating expense 104 166 Total $ 5,788 $ 10,539

Distributions (Tables)

Distributions (Tables)	6 Months Ended
	Jun. 30, 2015
Distributions Made to Members or Limited Partners [Abstract]
Schedule Of Distributions	Distributions we paid during 2014 and 2015 were as follows (in thousands, except per unit amounts): Payment Date Per Unit Cash Distribution Amount Total Cash Distribution to Limited Partners 02/14/2014 $ 0.5850 $ 132,835 05/15/2014 0.6125 139,079 Through 06/30/2014 1.1975 271,914 08/14/2014 0.6400 145,324 11/14/2014 0.6675 151,568 Total $ 2.5050 $ 568,806 2/13/2015 $ 0.6950 $ 158,061 5/15/2015 0.7175 163,178 Through 06/30/2015 1.4125 321,239 08/14/2015 (1) 0.7400 168,296 Total $ 2.1525 $ 489,535 (1) Our general partner's board of directors declared this cash distribution on July 23, 2015 to be paid on August 14, 2015 to unitholders of record at the close of business on August 7, 2015 .

Fair Value (Tables)

Fair Value (Tables)	6 Months Ended
	Jun. 30, 2015
Fair Value Disclosures [Abstract]
Schedule Of Fair Value, Assets and Liabilities Measured on Recurring Basis	The following tables summarize the carrying amounts, fair values and recurring fair value measurements recorded or disclosed as of December 31, 2014 and June 30, 2015 , based on the three levels established by ASC 820, Fair Value Measurements and Disclosures (in thousands): As of December 31, 2014 Assets (Liabilities) Fair Value Measurements using: Carrying Amount Fair Value Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Energy commodity derivatives contracts – assets $ 96,142 $ 96,142 $ 96,142 $ — $ — Interest rate contracts – liabilities $ (26,478 ) $ (26,478 ) $ — $ (26,478 ) $ — Long-term receivables $ 28,611 $ 30,200 $ — $ — $ 30,200 Debt $ (2,982,895 ) $ (3,212,462 ) $ — $ (3,212,462 ) $ — As of June 30, 2015 Assets (Liabilities) Fair Value Measurements using: Carrying Amount Fair Value Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Energy commodity derivatives contracts – assets $ 13,626 $ 13,626 $ 13,626 $ — $ — Interest rate contracts – assets $ 2,901 $ 2,901 $ — $ 2,901 $ — Long-term receivables $ 25,614 $ 26,413 $ — $ — $ 26,413 Debt $ (3,326,936 ) $ (3,426,312 ) $ — $ (3,426,312 ) $ —

Organization, Description of 31

Organization, Description of Business and Basis of Presentation (Narrative) (Details) - Jun. 30, 2015 bbl in Millions	Terminalbblmi
Refined Products [Member]
Organization and Description of Business [Line Items]
Number of Pipeline Terminals	52
Number of Independent Terminals	28
Refined Products [Member] | Refined Products Transportation Services [Member]
Organization and Description of Business [Line Items]
Pipeline Length | mi	9,500
Refined Products [Member] | Ammonia Transportation Services [Member]
Organization and Description of Business [Line Items]
Pipeline Length | mi	1,100
Crude Oil Pipeline and Terminals [Member]
Organization and Description of Business [Line Items]
Pipeline Length | mi	1,600
Storage Capacity | bbl	21
Leaseable Storage Capacity | bbl	13
Marine Storage [Member]
Organization and Description of Business [Line Items]
Number of Independent Terminals	5
Storage Capacity | bbl	26

Product Sales Revenues (Compone

Product Sales Revenues (Components Of Product Sales Revenues) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Product Sales Revenue [Line Items]
Physical sale of petroleum products	$ 133,319	$ 154,310	$ 302,566	$ 447,550
NYMEX Adjustments Included in Product Sales	(23,350)	(16,653)	(19,470)	(13,830)
Sales Revenue from Energy Commodities and Services	109,969	137,657	283,096	433,720
Other Product Sale Revenue [Member]
Product Sales Revenue [Line Items]
NYMEX Adjustments Included in Product Sales	0	13	0	13
Butane Blending And Fractionation Activities [Member]
Product Sales Revenue [Line Items]
NYMEX Adjustments Included in Product Sales	$ (23,350)	$ (16,666)	$ (19,470)	$ (13,843)

Segment Disclosures (Schedule O

Segment Disclosures (Schedule Of Business Segment Reporting Information) (Details) - USD ($) $ in Thousands	May. 01, 2015	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Segment Reporting Information [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired				$ 54,678	$ 0
Transportation and terminals revenue		$ 374,016	$ 353,568	719,616	671,205
Product sales revenue		109,969	137,657	283,096	433,720
Affiliate management fee revenue		3,558	5,221	6,921	10,127
Total revenue		487,543	496,446	1,009,633	1,115,052
Operating expenses		131,433	124,874	229,928	198,371
Cost of product sales		94,507	109,103	230,686	307,143
Earnings of non-controlled entities		(24,542)	(1,955)	(34,132)	(2,421)
Operating margin		286,145	264,424	583,151	611,959
Depreciation and amortization expense		40,440	46,897	82,137	84,408
G&A expenses		37,942	39,309	73,440	74,244
Operating profit		207,763	178,218	427,574	453,307
Operating Segments [Member] | Refined Products [Member]
Segment Reporting Information [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired	$ 54,678
Transportation and terminals revenue		233,711	232,489	450,488	442,725
Product sales revenue		109,323	136,334	281,962	430,044
Affiliate management fee revenue		0	0	0	0
Total revenue		343,034	368,823	732,450	872,769
Operating expenses		100,475	97,302	170,781	148,459
Cost of product sales		94,326	108,817	229,960	306,573
Earnings of non-controlled entities		43	0	98	0
Operating margin		148,190	162,704	331,611	417,737
Depreciation and amortization expense		23,962	32,083	47,409	55,255
G&A expenses		23,893	25,374	46,492	48,393
Operating profit		100,335	105,247	237,710	314,089
Operating Segments [Member] | Crude Oil Pipeline and Terminals [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue		95,756	79,556	182,316	147,459
Product sales revenue		0	0	0	0
Affiliate management fee revenue		3,211	4,902	6,238	9,497
Total revenue		98,967	84,458	188,554	156,956
Operating expenses		16,014	11,867	29,875	20,925
Cost of product sales		0	0	0	0
Earnings of non-controlled entities		(23,905)	(888)	(32,829)	(708)
Operating margin		106,858	73,479	191,508	136,739
Depreciation and amortization expense		8,264	6,725	16,493	13,188
G&A expenses		9,031	7,697	17,117	13,691
Operating profit		89,563	59,057	157,898	109,860
Operating Segments [Member] | Marine Storage [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue		44,549	41,523	86,812	81,021
Product sales revenue		646	1,323	1,134	3,676
Affiliate management fee revenue		347	319	683	630
Total revenue		45,542	43,165	88,629	85,327
Operating expenses		15,881	16,544	31,216	30,630
Cost of product sales		181	286	726	570
Earnings of non-controlled entities		(680)	(1,067)	(1,401)	(1,713)
Operating margin		30,160	27,402	58,088	55,840
Depreciation and amortization expense		7,277	7,250	16,291	14,322
G&A expenses		5,018	6,238	9,831	12,160
Operating profit		17,865	13,914	31,966	29,358
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue		0	0	0	0
Product sales revenue		0	0	0	0
Affiliate management fee revenue		0	0	0	0
Total revenue		0	0	0	0
Operating expenses		(937)	(839)	(1,944)	(1,643)
Cost of product sales		0	0	0	0
Earnings of non-controlled entities		0	0	0	0
Operating margin		937	839	1,944	1,643
Depreciation and amortization expense		937	839	1,944	1,643
G&A expenses		0	0	0	0
Operating profit		$ 0	$ 0	$ 0	$ 0

Investments in Non-Controlled34

Investments in Non-Controlled Entities (Details) bbl in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015USD ($)bblin	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)bblin	Jun. 30, 2014USD ($)	Dec. 31, 2014USD ($)
Change in Equity Method Investments [Roll Forward]
Investments at December 31, 2014			$ 613,867,000
Additional Investment in NonControlled Entities			49,695,000
Proportionate share of earnings			35,527,000
Amortization of excess investment and capitalized interest			(1,395,000)
Earnings of non-controlled entities	$ 24,542,000	$ 1,955,000	34,132,000	$ 2,421,000
Distributions of earnings from investments in non-controlled entities			31,243,000	1,713,000
Investments at March 31, 2015	666,451,000		666,451,000
Equity Method Investment, Summarized Financial Information, Revenue	73,256,000	11,709,000	119,912,000	18,464,000
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	$ 50,412,000	4,284,000	$ 71,030,000	5,591,000
Texas Frontera Llc [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%		50.00%
Powder Springs Logistics, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%		50.00%
Saddlehorn Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	40.00%		40.00%
Seabrook Logistics, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%		50.00%
Joint Venture Partner One, Ownership Interest	50.00%		50.00%
Storage Capacity | bbl	0.7		0.7
Pipeline Width | in	18		18
Osage Pipeline Co [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%		50.00%
Double Eagle Pipeline Llc [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%		50.00%
BridgeTex [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%		50.00%
Change in Equity Method Investments [Roll Forward]
Investments at December 31, 2014			$ 489,348,000
Additional Investment in NonControlled Entities			16,609,000
Proportionate share of earnings			31,828,000
Amortization of excess investment and capitalized interest			(1,020,000)
Earnings of non-controlled entities			30,808,000
Distributions of earnings from investments in non-controlled entities			30,332,000
Investments at March 31, 2015	$ 506,433,000		506,433,000
Equity Method Investment, Summarized Financial Information, Revenue	61,629,000	0	98,765,000	0
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	45,619,000	(240,000)	63,656,000	(280,000)
All Other Equity Investments [Member]
Change in Equity Method Investments [Roll Forward]
Investments at December 31, 2014			124,519,000
Additional Investment in NonControlled Entities			33,086,000
Proportionate share of earnings			3,699,000
Amortization of excess investment and capitalized interest			(375,000)
Earnings of non-controlled entities			3,324,000
Distributions of earnings from investments in non-controlled entities			911,000
Investments at March 31, 2015	160,018,000		160,018,000
Equity Method Investment, Summarized Financial Information, Revenue	11,627,000	11,709,000	21,147,000	18,464,000
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	4,793,000	4,524,000	7,374,000	5,871,000
Equity Method Investee [Member] | Double Eagle Pipeline Llc [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party	900,000	$ 800,000	1,800,000	$ 1,300,000
Accounts Receivable, Related Parties, Current	300,000		300,000		$ 300,000
Equity Method Investee [Member] | BridgeTex [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party	8,500,000		16,900,000
Accounts Receivable, Related Parties, Current	0		0		2,600,000
Accounts Payable, Related Parties, Current	$ 1,100,000		$ 1,100,000		$ 2,200,000

Inventory (Details)

Inventory (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Inventory Disclosure [Abstract]
Refined products	$ 33,862	$ 67,055
Liquefied petroleum gases	39,942	37,642
Transmix	47,513	36,867
Crude oil	32,501	10,015
Additives	6,102	6,183
Total inventory	$ 159,920	$ 157,762

Schedule Of Consolidated Net Pe

Schedule Of Consolidated Net Periodic Benefit Costs (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)pension_plan	Jun. 30, 2014USD ($)
Defined Benefit Plan Disclosure [Line Items]
Number of Union Pension Plans | pension_plan			2
Defined Contribution Plan, Cost Recognized	$ 2,200	$ 2,000	$ 5,000	$ 4,600
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year			21,100
Components of net periodic benefit costs:
Service cost	4,975	3,352	9,445	6,704
Interest cost	2,008	2,030	3,877	3,689
Expected return on plan assets	(2,123)	(1,490)	(4,019)	(3,187)
Amortization of prior service credit	0	0	0	33
Amortization of actuarial loss	1,806	930	3,153	1,559
Settlement cost	0	1,569	0	1,569
Net periodic benefit cost (credit)	6,666	6,391	12,456	10,367
Other Postretirement Benefit Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year			1,100
Components of net periodic benefit costs:
Service cost	56	47	122	114
Interest cost	109	139	219	253
Expected return on plan assets	0	0	0	0
Amortization of prior service credit	(928)	(928)	(1,856)	(1,856)
Amortization of actuarial loss	217	262	442	457
Settlement cost	0	0	0	0
Net periodic benefit cost (credit)	$ (546)	$ (480)	$ (1,073)	$ (1,032)

Employee Benefit Plans Schedule

Employee Benefit Plans Schedule of Amounts Recognized in Other Comprehensive Income (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Changes in AOCL [Roll Forward]
Accumulated other comprehensive loss (Beginning Bal)				$ (81,540)
Amortization of prior service credit	[1]	$ (928)	$ (928)	(1,856)	$ (1,823)
Amortization of actuarial loss	[1]	2,023	1,192	3,595	2,016
Settlement cost	[1]	0	1,569	0	1,569
Accumulated other comprehensive loss (Ending Bal)		(92,742)		(92,742)
Pension Plan [Member]
Changes in AOCL [Roll Forward]
Accumulated other comprehensive loss (Beginning Bal)		(61,910)	(35,522)	(63,257)	(36,184)
Amortization of prior service credit		0	0	0	33
Amortization of actuarial loss		1,806	930	3,153	1,559
Settlement cost		0	1,569	0	1,569
Accumulated other comprehensive loss (Ending Bal)		(60,104)	(33,023)	(60,104)	(33,023)
Other Postretirement Benefit Plan [Member]
Changes in AOCL [Roll Forward]
Accumulated other comprehensive loss (Beginning Bal)		(2,399)	2,320	(1,696)	3,053
Amortization of prior service credit		(928)	(928)	(1,856)	(1,856)
Amortization of actuarial loss		217	262	442	457
Settlement cost		0	0	0	0
Accumulated other comprehensive loss (Ending Bal)		$ (3,110)	$ 1,654	$ (3,110)	$ 1,654
[1]	See Note 6–Employee Benefit Plans for details of the changes in employee benefit plan assets and benefit obligations recognized in AOCL.

Debt (Consolidated Debt) (Detai

Debt (Consolidated Debt) (Details) - USD ($)		Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Total debt		$ 3,326,936,000		$ 2,982,895,000
Weighted-Average Interest Rate	[1]	4.80%
Debt Instrument, Face Amount		$ 3,300,000,000		2,900,000,000
Commercial Paper [Member]
Debt Instrument [Line Items]
Total debt		$ 144,982,000		296,942,000
Weighted-Average Interest Rate	[1],[2]	0.50%
Senior Notes [Member] | 5.65% Notes Due 2016 [Member]
Debt Instrument [Line Items]
Total debt		$ 250,546,000		250,758,000
Weighted-Average Interest Rate	[1]	5.70%
Debt Instrument, Face Amount		$ 250,000,000		$ 250,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.65%		5.65%
Senior Notes [Member] | 6.40% Notes Due 2018 [Member]
Debt Instrument [Line Items]
Total debt		$ 256,248,000		$ 257,280,000
Weighted-Average Interest Rate	[1]	5.40%
Debt Instrument, Face Amount		$ 250,000,000		$ 250,000,000
Debt Instrument, Interest Rate, Stated Percentage		6.40%		6.40%
Senior Notes [Member] | 6.55% Notes Due 2019 [Member]
Debt Instrument [Line Items]
Total debt		$ 566,006,000		$ 567,868,000
Weighted-Average Interest Rate	[1]	5.70%
Debt Instrument, Face Amount		$ 550,000,000		$ 550,000,000
Debt Instrument, Interest Rate, Stated Percentage		6.55%		6.55%
Senior Notes [Member] | 4.25% Notes Due 2021 [Member]
Debt Instrument [Line Items]
Total debt		$ 555,837,000		$ 556,304,000
Weighted-Average Interest Rate	[1]	4.00%
Debt Instrument, Face Amount		$ 550,000,000		$ 550,000,000
Debt Instrument, Interest Rate, Stated Percentage		4.25%		4.25%
Senior Notes [Member] | 3.20% Notes Due 2025 [Member]
Debt Instrument [Line Items]
Total debt		$ 249,687,000		$ 0
Weighted-Average Interest Rate	[1],[2]	3.20%
Debt Instrument, Face Amount		$ 250,000,000	$ 250,000,000	$ 0
Debt Instrument, Interest Rate, Stated Percentage		3.20%	3.20%	0.00%
Senior Notes [Member] | 6.40% Notes Due 2037 [Member]
Debt Instrument [Line Items]
Total debt		$ 249,026,000		$ 249,017,000
Weighted-Average Interest Rate	[1]	6.40%
Debt Instrument, Face Amount		$ 250,000,000		$ 250,000,000
Debt Instrument, Interest Rate, Stated Percentage		6.40%		6.40%
Senior Notes [Member] | 4.20% Notes Due 2042 [Member]
Debt Instrument [Line Items]
Total debt		$ 248,421,000		$ 248,406,000
Weighted-Average Interest Rate	[1]	4.20%
Debt Instrument, Face Amount		$ 250,000,000		$ 250,000,000
Debt Instrument, Interest Rate, Stated Percentage		4.20%		4.20%
Senior Notes [Member] | 5.15% Notes Due 2043 [Member]
Debt Instrument [Line Items]
Total debt		$ 556,270,000		$ 556,320,000
Weighted-Average Interest Rate	[1]	5.10%
Debt Instrument, Face Amount		$ 550,000,000		$ 550,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.15%		5.15%
Senior Notes [Member] | 4.20% Notes Due 2045 [Member]
Debt Instrument [Line Items]
Total debt		$ 249,913,000		$ 0
Weighted-Average Interest Rate	[1],[2]	4.60%
Debt Instrument, Face Amount		$ 250,000,000	$ 250,000,000	$ 0
Debt Instrument, Interest Rate, Stated Percentage		4.20%	4.20%	0.00%
[1]	Weighted-average interest rate includes the amortization/accretion of discounts, premiums and gains/losses realized on historical cash flow and fair value hedges recognized as interest expense.
[2]	These borrowings were outstanding for only a portion of the six month period ending June 30, 2015. The weighted-average interest rate for these borrowings was calculated based on the number of days the borrowings were outstanding during the noted period.

Debt (Narrative) (Details)

Debt (Narrative) (Details) - USD ($)	3 Months Ended	6 Months Ended
	Mar. 31, 2015	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 3,300,000,000		$ 2,900,000,000
Debt placement costs		4,734,000	$ 2,887,000
Long-term Debt		3,326,936,000		2,982,895,000
Commercial Paper [Member]
Debt Instrument [Line Items]
Borrowing capacity		1,000,000,000
Long-term Debt		$ 144,982,000		296,942,000
Commercial Paper [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Term		397 days
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Borrowing capacity		$ 1,000,000,000
Unused commitment fee		0.125%
Long-term Debt		$ 0
Obligation for letters of credit		$ 5,600,000
Revolving Credit Facility [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.00%
Unused commitment fee		0.10%
Revolving Credit Facility [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.75%
Unused commitment fee		0.28%
Senior Notes [Member] | 3.20% Notes Due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 250,000,000	$ 250,000,000		$ 0
Debt Instrument, Interest Rate, Stated Percentage	3.20%	3.20%		0.00%
Notes At Price	99.871%
After Underwriting Discounts	$ 247,600,000
Debt placement costs	2,100,000
Long-term Debt		$ 249,687,000		$ 0
Senior Notes [Member] | 4.20% Notes Due 2045 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 250,000,000	$ 250,000,000		$ 0
Debt Instrument, Interest Rate, Stated Percentage	4.20%	4.20%		0.00%
Notes At Price	99.965%
After Underwriting Discounts	$ 247,300,000
Debt placement costs	$ 2,600,000
Long-term Debt		$ 249,913,000		$ 0

Derivative Financial Instrume40

Derivative Financial Instruments (Narrative) (Details) - Balance Sheet Location [Domain] bbl in Millions		3 Months Ended			6 Months Ended		12 Months Ended
		Jun. 30, 2015USD ($)bbl	Mar. 31, 2015USD ($)	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)bbl	Jun. 30, 2014USD ($)	Dec. 31, 2014USD ($)bbl
Derivative [Line Items]
Debt Instrument, Face Amount		$ 3,300,000,000			$ 3,300,000,000		$ 2,900,000,000
Net payment on financial derivatives					42,908,000	$ 3,613,000
Net gain (loss) on cash flow hedges(1)	[1]	1,936,000		$ 0	(13,529,000)	$ (3,613,000)
Energy commodity derivatives deposits (asset)		5,696,000			5,696,000		6,184,000
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months					(1,500,000)
Tank bottoms and linefill		$ 47,204,000			$ 47,204,000		$ 42,585,000
Fair Value Hedging [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl		0.7			0.7
Fair Value Hedging [Member] | NYMEX Commodity Contracts [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl		0.7			0.7		0.7
Tank bottoms and linefill		$ (8,700,000)			$ (8,700,000)		$ (13,300,000)
Gain (Loss) from Components Excluded from Assessment of Fair Value Hedge Effectiveness, Net		6,500,000			6,300,000
Two Thousand Fifteen Interest Rate Swaps [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Notional Amount		50,000,000			50,000,000
Derivative Asset, Fair Value, Gross Asset		2,900,000			2,900,000
Two Thousand Fourteen Interest Rate Swaps [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Notional Amount			$ 250,000,000
Net payment on financial derivatives			(42,908,000)
Net gain (loss) on cash flow hedges(1)			(16,400,000)				(26,500,000)
Senior Notes [Member] | 4.20% Notes Due 2045 [Member]
Derivative [Line Items]
Debt Instrument, Face Amount		$ 250,000,000	$ 250,000,000		$ 250,000,000		$ 0
Debt Instrument, Interest Rate, Stated Percentage		4.20%	4.20%		4.20%		0.00%
[1]	See Note 8–Derivative Financial Instruments for details of the amount of gain/loss recognized in accumulated other comprehensive loss ("AOCL") for derivative financial instruments and the amount of gain/loss reclassified from AOCL into income.

Derivative Financial Instrume41

Derivative Financial Instruments (Schedule Of Forward Purchase And Sales Contracts) (Details) - Jun. 30, 2015 - Forward Contracts [Member] bbl in Millions, $ in Millions	USD ($)bbl
Derivative [Line Items]
Forward purchase contracts, Amount | $	$ 118.3
Forward purchase contracts, Barrels	3.5
Forward sale contracts, Amount | $	$ 11.4
Forward sale contracts, Barrels	0.1

Derivative Financial Instrume42

Derivative Financial Instruments (Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements) (Details) bbl in Millions		Jun. 30, 2015bbl
Fair Value Hedging [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount		0.7
Economic Hedges [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	[1]	5.6
Economic Hedges Futures [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount		1.3
Basis Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount		1.6
[1]	Of the 5.6 million barrels of products we have economically hedged at June 30, 2015, we had open agreements which swap the pricing on 1.6 million of those barrels from New York Harbor to Platts Group 3 or Platts Gulf Coast, which are the geographic locations where these barrels will be sold.

Derivative Financial Instrume43

Derivative Financial Instruments Schedule of Derivative Offset Amounts (Details) - USD ($) $ in Thousands		Jun. 30, 2015		Dec. 31, 2014
Derivative [Line Items]
Energy commodity derivatives deposits		$ 5,696		$ 6,184
Exchange Traded [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset		26,262		106,764
Derivative Liability, Fair Value, Gross Liability		(12,636)		(10,622)
Derivative Asset, Fair Value, Amount Not Offset Against Collateral		13,626	[1]	96,142	[2]
Derivative, Collateral, Obligation to Return Cash				(78,279)
Energy commodity derivatives deposits		5,696
Amount After Offset	[3]	19,322		17,863
Other Current Liabilities [Member] | Exchange Traded [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral				(5,413)
Other Noncurrent Assets [Member] | Exchange Traded [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral		16,486		14,404
Other Current Assets [Member] | Exchange Traded [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral		$ (2,860)		$ 87,151
[1]	Net amount includes energy commodity derivative contracts classified as current liabilities, net, of $2,860 and noncurrent assets of $16,486.
[2]	Net amount includes energy commodity derivative contracts classified as current assets, net, of $87,151, current liabilities of $5,413 and noncurrent assets of $14,404.
[3]	This represents the maximum amount of loss we would incur if all of our counterparties failed to perform on their derivative contracts.

Derivative Financial Instrume44

Derivative Financial Instruments (Derivative Gains Included In Accumulated Other Comprehensive Loss (AOCL) (Details) - USD ($) $ in Thousands		3 Months Ended			6 Months Ended		12 Months Ended
		Jun. 30, 2015	Mar. 31, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Derivative Gains Included in AOCI [Roll Forward]
Beginning balance		$ (31,852)	$ (16,587)	$ 9,988	$ (16,587)	$ 13,627	$ 13,627
Net gain (loss) on cash flow hedges	[1]	1,936		0	(13,529)	(3,613)
Reclassification of net loss (gain) on cash flow hedges to income	[1]	388		(153)	588	(179)
Ending balance		$ (29,528)	$ (31,852)	$ 9,835	$ (29,528)	$ 9,835	$ (16,587)
[1]	See Note 8–Derivative Financial Instruments for details of the amount of gain/loss recognized in accumulated other comprehensive loss ("AOCL") for derivative financial instruments and the amount of gain/loss reclassified from AOCL into income.

Derivative Financial Instrume45

Derivative Financial Instruments (Derivatives And Hedging-Cash Flow Hedges) (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on cash flow hedges	[1]	$ 1,936	$ 0	$ (13,529)	$ (3,613)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on cash flow hedges		1,936	0	(13,529)	(3,613)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Interest Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net		(388)	(30)	(588)	(4)
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net		$ 0	$ 183	$ 0	$ 183
[1]	See Note 8–Derivative Financial Instruments for details of the amount of gain/loss recognized in accumulated other comprehensive loss ("AOCL") for derivative financial instruments and the amount of gain/loss reclassified from AOCL into income.

Derivative Financial Instrume46

Derivative Financial Instruments (Derivatives And Hedging-Overall-Subsequent Measurement) (Details) - Not Designated as Hedging Instrument [Member] - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ (33,089)	$ (20,289)	$ (29,130)	$ (16,957)
NYMEX Commodity Contracts [Member] | Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(23,350)	(16,653)	(19,470)	(13,830)
NYMEX Commodity Contracts [Member] | Operating Expenses [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(8,883)	(4,268)	(7,580)	(3,903)
NYMEX Commodity Contracts [Member] | Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ (856)	$ 632	$ (2,080)	$ 776

Derivative Financial Instrume47

Derivative Financial Instruments (Derivatives and Hedging - Designated) (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 19,306	$ 14,764
Derivative Liability, Fair Value, Gross Liability	0	26,478
Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	316	360
Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	0	0
Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	16,089	14,404
Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	0	0
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		0
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability		26,478
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	2,901
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	0
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	9,857
Derivative Liability, Fair Value, Gross Liability	12,636
Not Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	9,460	92,000
Not Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	12,636	$ 10,622
Not Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	397
Not Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	$ 0

Commitments And Contingencies (

Commitments And Contingencies (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Loss Contingencies [Line Items]
Liabilities recognized for estimated environmental costs	$ 36.5		$ 36.5		$ 36.3
Estimated environmental liabilities, years			10 years
Environmental expenses	2.9	$ 0.1	$ 4.3	$ 0.4
Receivables from insurance carriers related to environmental matters	4.9		4.9		5.1
Accounts Receivable [Member]
Loss Contingencies [Line Items]
Receivables from insurance carriers related to environmental matters	1		1		1.3
Other Noncurrent Assets [Member]
Loss Contingencies [Line Items]
Receivables from insurance carriers related to environmental matters	$ 3.9		$ 3.9		$ 3.8

Long-Term Incentive Plan (Narra

Long-Term Incentive Plan (Narrative) (Details) - shares	1 Months Ended		6 Months Ended
	Feb. 28, 2015	Jan. 31, 2015	Jun. 30, 2015
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Limited partners' capital account, units authorized for issuance			9,400,000
Limited partner unitholders, units remaining available			1,000,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	166,189
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Management [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Partners' Capital Account, Units, Unit-based Compensation		354,529
Director [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Partners' Capital Account, Units, Unit-based Compensation			4,461

Long-Term Incentive Plan (Equit

Long-Term Incentive Plan (Equity-Based Incentive Compensation Expense) (Details) - Management [Member] - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	$ 5,788	$ 7,665	$ 10,539	$ 12,753
G&A Expense [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	5,684	7,486	10,373	12,460
Operating Expenses [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	104	179	166	293
Equity Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	4,912	4,743	9,448	8,359
Liability Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	876	2,922	1,091	4,394
Performance Based Awards [Member] | Two Thousand Twelve Awards [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income		2,639		4,585
Performance Based Awards [Member] | Two Thousand Twelve Awards [Member] | Equity Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income		1,022		2,044
Performance Based Awards [Member] | Two Thousand Twelve Awards [Member] | Liability Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income		1,617		2,541
Performance Based Awards [Member] | Two Thousand Thirteen Awards [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	3,930	3,500	5,664	5,229
Performance Based Awards [Member] | Two Thousand Thirteen Awards [Member] | Equity Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	3,054	2,195	4,573	3,376
Performance Based Awards [Member] | Two Thousand Thirteen Awards [Member] | Liability Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	876	1,305	1,091	1,853
Performance Based Awards [Member] | Two Thousand Fourteen Awards [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	860	1,228	2,483	2,132
Performance Based Awards [Member] | Two Thousand Fourteen Awards [Member] | Equity Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	860	1,228	2,483	2,132
Performance Based Awards [Member] | Two Thousand Fourteen Awards [Member] | Liability Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	0	0	0	0
Performance Based Awards [Member] | Two Thousand Fifteen Awards [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	941		1,960
Performance Based Awards [Member] | Two Thousand Fifteen Awards [Member] | Equity Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	941		1,960
Performance Based Awards [Member] | Two Thousand Fifteen Awards [Member] | Liability Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	0		0
Retention Awards [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	57	298	432	807
Retention Awards [Member] | Equity Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	57	298	432	807
Retention Awards [Member] | Liability Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	$ 0	$ 0	$ 0	$ 0

Distributions (Schedule Of Dist

Distributions (Schedule Of Distributions) (Details) - USD ($) $ / shares in Units, $ in Thousands	Aug. 14, 2015	[1]	May. 15, 2015	Feb. 13, 2015	Nov. 14, 2014	Aug. 14, 2014	May. 15, 2014	Feb. 14, 2014	Jun. 30, 2015	Jun. 30, 2014	Sep. 30, 2015	Dec. 31, 2014
Per Unit Cash Distribution Amount			$ 0.7175	$ 0.6950	$ 0.6675	$ 0.64	$ 0.6125	$ 0.585	$ 1.4125	$ 1.1975		$ 2.505
Total Cash Distribution to Limited Partners			$ 163,178	$ 158,061	$ 151,568	$ 145,324	$ 139,079	$ 132,835	$ 321,239	$ 271,914		$ 568,806
Scenario, Forecast
Per Unit Cash Distribution Amount	$ 0.7400										$ 2.1525
Total Cash Distribution to Limited Partners	$ 168,296										$ 489,535
[1]	Our general partner's board of directors declared this cash distribution on July 23, 2015 to be paid on August 14, 2015 to unitholders of record at the close of business on August 7, 2015.

Fair Value (Schedule Of Carryin

Fair Value (Schedule Of Carrying Amounts And Fair Values Of Financial Assets/Liabilities) (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | NYMEX Commodity Contracts [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	$ 13,626	$ 96,142
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt	(3,426,312)	(3,212,462)
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member] | Interest Rate Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	2,901
Derivative liability		(26,478)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivables	26,413	30,200
Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivables	26,413	30,200
Debt	(3,426,312)	(3,212,462)
Estimate of Fair Value Measurement [Member] | NYMEX Commodity Contracts [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	13,626	96,142
Estimate of Fair Value Measurement [Member] | Interest Rate Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	2,901
Derivative liability		(26,478)
Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivables	25,614	28,611
Debt	(3,326,936)	(2,982,895)
Reported Value Measurement [Member] | NYMEX Commodity Contracts [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	13,626	96,142
Reported Value Measurement [Member] | Interest Rate Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	$ 2,901
Derivative liability		$ (26,478)

Related Party Transactions (Det

Related Party Transactions (Details) - Director [Member] - USD ($) $ in Millions	2 Months Ended	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Targa Resource Partners L P [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party		$ 4	$ 1.6	$ 12.8	$ 13.8
Accounts Payable, Related Parties	$ 0.2	0.2		0.2		$ 0.9
Methvin Company [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party	2.6
Accounts Receivable, Related Parties, Current	$ 1.3	$ 1.3		$ 1.3

Subsequent Events (Details)

Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Thousands	Aug. 14, 2015	[1]	May. 15, 2015	Feb. 13, 2015	Nov. 14, 2014	Aug. 14, 2014	May. 15, 2014	Feb. 14, 2014	Jun. 30, 2015	Jun. 30, 2014	Sep. 30, 2015	Dec. 31, 2014
Subsequent Event [Line Items]
Cash distribution per unit			$ 0.7175	$ 0.6950	$ 0.6675	$ 0.64	$ 0.6125	$ 0.585	$ 1.4125	$ 1.1975		$ 2.505
Total cash distributions			$ 163,178	$ 158,061	$ 151,568	$ 145,324	$ 139,079	$ 132,835	$ 321,239	$ 271,914		$ 568,806
Scenario, Forecast
Subsequent Event [Line Items]
Cash distribution per unit	$ 0.7400										$ 2.1525
Total cash distributions	$ 168,296										$ 489,535
[1]	Our general partner's board of directors declared this cash distribution on July 23, 2015 to be paid on August 14, 2015 to unitholders of record at the close of business on August 7, 2015.