Magellan Midstream Partners (MMP) 10-Q 2 Aug 16 2016 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	6 Months Ended
	Jun. 30, 2016	Aug. 01, 2016
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2,016
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		227,783,916

Consolidated Statements Of Inco

Consolidated Statements Of Income - USD ($) shares in Thousands, $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Income Statement [Abstract]
Transportation and terminals revenue		$ 392,240	$ 384,901	$ 762,315	$ 738,713
Product sales revenue	[1]	123,689	109,969	270,251	283,096
Affiliate management fee revenue		2,968	3,558	6,147	6,921
Total revenue		518,897	498,428	1,038,713	1,028,730
Costs and expenses:
Operating		134,162	142,318	257,395	249,025
Cost of product sales	[1]	95,703	94,507	209,288	230,686
Depreciation and amortization		43,302	40,440	87,056	82,137
General and administrative		34,542	37,942	75,416	73,440
Total costs and expenses		307,709	315,207	629,155	635,288
Earnings of non-controlled entities		15,339	24,542	32,967	34,132
Operating profit		226,527	207,763	442,525	427,574
Interest expense		48,686	40,396	92,410	77,590
Interest income		(404)	(334)	(765)	(683)
Interest capitalized		(7,130)	(2,946)	(13,266)	(5,053)
Gain on exchange of interest in non-controlled entity		(1,244)	0	(28,144)	0
Other income		(1,925)	(6,539)	(4,195)	(6,260)
Income before provision for income taxes		188,544	177,186	396,485	361,980
Provision for income taxes		685	(205)	1,556	953
Net income		$ 187,859	$ 177,391	$ 394,929	$ 361,027
Basic net income per limited partner unit		$ 0.82	$ 0.78	$ 1.73	$ 1.59
Diluted net income per limited partner unit		$ 0.82	$ 0.78	$ 1.73	$ 1.59
Weighted average number of limited partner units outstanding used for basic net income per unit calculation(1)	[2]	227,952	227,631	227,889	227,578
Weighted average number of limited partner units outstanding used for diluted net income per unit calculation(1)	[2]	227,983	227,631	227,921	227,578
[1]	Includes gains (losses) on related NYMEX contracts. See Note 8–Derivative Financial Instruments.
[2]	See Note 10–Long-Term Incentive Plan for additional information regarding our weighted average unit calculations.

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Statement of Comprehensive Income [Abstract]
Net income		$ 187,859	$ 177,391	$ 394,929	$ 361,027
Other comprehensive income:
Net gain (loss) on cash flow hedges(1)	[1]	(8,631)	1,936	(21,109)	(13,529)
Reclassification of net loss on cash flow hedges to income(1)	[1]	388	388	776	588
Amortization of prior service credit(2)	[2]	(974)	(928)	(1,947)	(1,856)
Amortization of actuarial loss(2)	[2]	1,292	2,023	2,693	3,595
Total other comprehensive income (loss)		(7,925)	3,419	(19,587)	(11,202)
Comprehensive income		$ 179,934	$ 180,810	$ 375,342	$ 349,825
[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, 2016	Dec. 31, 2015
ASSETS
Cash and cash equivalents		$ 34,263	$ 28,731
Trade accounts receivable		93,329	83,893
Other accounts receivable		19,368	12,701
Inventory		156,430	130,868
Energy commodity derivatives contracts, net		7,359	39,243
Energy commodity derivatives deposits		28,528	0
Other current assets		46,305	43,418
Total current assets		385,582	338,854
Property, plant and equipment		6,470,356	6,166,766
Less: Accumulated depreciation		1,428,426	1,347,537
Net property, plant and equipment		5,041,930	4,819,229
Investments in non-controlled entities		850,401	765,628
Long-term receivables		18,134	20,374
Goodwill		53,260	53,260
Other intangibles (less accumulated amortization of $13,709 and $5,676 at December 31, 2015 and June 30, 2016, respectively)		52,337	1,856
Tank bottoms		35,492	27,533
Other noncurrent assets		11,068	14,833
Total assets		6,448,204	6,041,567
LIABILITIES AND PARTNERS’ CAPITAL
Accounts payable		118,484	104,094
Accrued payroll and benefits		36,827	51,764
Accrued interest payable		62,294	51,296
Accrued taxes other than income		45,124	51,587
Environmental liabilities		15,572	15,679
Deferred revenue		98,562	81,627
Accrued product purchases		22,481	31,339
Energy commodity derivatives deposits		0	24,252
Current portion of long-term debt, net		250,083	250,335
Other current liabilities		64,235	51,099
Total current liabilities		713,662	713,072
Long-term debt, net	[1]	3,574,898	3,189,287
Long-term pension and benefits		81,863	77,551
Other noncurrent liabilities		26,412	24,162
Environmental liabilities		13,171	15,759
Commitments and contingencies
Partners’ capital:
Limited partner unitholders (227,427 units and 227,784 units outstanding at December 31, 2015 and June 30, 2016, respectively)		2,154,135	2,118,086
Accumulated other comprehensive loss		(115,937)	(96,350)
Total partners’ capital		2,038,198	2,021,736
Total liabilities and partners’ capital		$ 6,448,204	$ 6,041,567
[1]	ong-term debt is presented net of unamortized debt issuance costs of $18.7 million and $22.9 million at December 31, 2015 and June 30, 2016, respectively.

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Statement of Financial Position [Abstract]
Other intangibles, accumulated amortization	$ 5,676	$ 13,709
Limited partner unitholders, units outstanding	227,783,916	227,427,247

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Operating Activities:
Net income	$ 394,929	$ 361,027
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	87,056	82,137
Loss on sale and retirement of assets	3,263	2,084
Earnings of non-controlled entities	(32,967)	(34,132)
Distributions of earnings from investments in non-controlled entities	31,080	31,243
Equity-based incentive compensation expense	10,059	10,539
Amortization of prior service credit and actuarial loss	746	1,739
Gain on exchange of interest in non-controlled entity	(28,144)	0
Changes in operating assets and liabilities:
Trade accounts receivable and other accounts receivable	(10,703)	3,096
Inventory	(25,562)	(2,158)
Energy commodity derivatives contracts, net of derivatives deposits	(17,121)	(1,411)
Accounts payable	9,125	8,406
Accrued payroll and benefits	(14,937)	(14,722)
Accrued interest payable	10,998	6,064
Accrued taxes other than income	(6,463)	(1,023)
Accrued product purchases	(8,858)	(22,726)
Deferred revenue	16,935	36
Current and noncurrent environmental liabilities	(2,695)	116
Other current and noncurrent assets and liabilities	(9,673)	(15,496)
Net cash provided by operating activities	407,068	414,819
Investing Activities:
Additions to property, plant and equipment, net(1)	(310,133)	(275,848)
Proceeds from sale and disposition of assets	4,756	3,153
Acquisition of business	0	(54,678)
Investments in non-controlled entities	(109,933)	(36,443)
Distributions in excess of earnings of non-controlled entities	1,942	0
Net cash used by investing activities	(413,368)	(363,816)
Financing Activities:
Distributions paid	(361,605)	(321,239)
Net commercial paper repayments	(255,966)	(151,960)
Borrowings under long-term notes	649,187	499,589
Debt placement costs	(5,408)	(4,734)
Net payment on financial derivatives	0	(42,908)
Settlement of tax withholdings on long-term incentive compensation	(14,376)	(17,784)
Net cash provided (used) by financing activities	11,832	(39,036)
Change in cash and cash equivalents	5,532	11,967
Cash and cash equivalents at beginning of period	28,731	17,063
Cash and cash equivalents at end of period	34,263	29,030
Supplemental non-cash investing and financing activities:
Contribution of property, plant and equipment to a non-controlled entity	0	13,252
Issuance of limited partner units in settlement of equity-based incentive plan awards	7,092	8,045
(1) Additions to property, plant and equipment	(321,085)	(268,849)
Changes in accounts payable and other current liabilities related to capital expenditures	10,952	(6,999)
Additions to property, plant and equipment, net	$ (310,133)	$ (275,848)

Organization, Description of Bu

Organization, Description of Business And Basis Of Presentation	6 Months Ended
	Jun. 30, 2016
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, 2016 , our asset portfolio, including the assets of our joint ventures, consisted of: • our refined products segment, comprised of our 9,700 -mile refined products pipeline system with 54 terminals as well as 26 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 22 million barrels, of which approximately 15 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. Terminology common in our industry includes the following terms, which describe products that we transport, store and distribute through our pipelines and terminals: • 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, 2015 , 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, 2016 , the results of operations for the three and six months ended June 30, 2015 and 2016 and cash flows for the six months ended June 30, 2015 and 2016 . The results of operations for the six months ended June 30, 2016 are not necessarily indicative of the results to be expected for the full year ending December 31, 2016 as profits from our butane 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 impacts 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 U.S. generally accepted accounting principles (“GAAP”). 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, 2015 . Use of Estimates The preparation of our consolidated financial statements in conformity with 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. New Accounting Pronouncements In March 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2016-09, Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting , which is part of the FASB’s initiative to simplify accounting standards. The guidance requires an entity to make an entity-wide accounting policy election to either estimate the number of awards that are expected to vest or account for forfeitures when they occur, and allows equity classification for awards where employees elect to withhold the maximum statutory tax rates in the applicable jurisdictions. The new standard also requires cash paid by employers when directly withholding shares for tax withholding purposes to be classified as a financing activity in the statement of cash flows. We elected to early adopt ASU 2016-09 during the first quarter of 2016, and this adoption did not have a material impact on our consolidated financial statements. In conjunction with our adoption of this new accounting standard, we have elected to account for equity-based compensation forfeitures as they occur. Additionally, and consistent with our prior accounting policy, we continue to show cash paid when directly withholding shares for tax withholding purposes as a financing activity in our statements of cash flows. In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) . This standard requires companies that lease valuable assets like aircraft, real estate, and heavy equipment to recognize on their balance sheets the assets and liabilities generated by contracts longer than a year. The new accounting model for lessors remains largely the same, although some changes have been made to align it with the new lessee model and the new revenue recognition guidance. This update also requires companies to disclose in the footnotes to their financial statements information about the amount, timing and uncertainty for the payments they make for the lease arrangements. Public companies will have to begin applying the standard for fiscal years and quarters that start after December 15, 2018, although early adoption is permitted. We are currently in the process of evaluating the impact this new standard will have on our financial statements. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers, which eliminates the industry-specific guidance in U.S. GAAP and produces a single, principles-based method for companies to report revenue in their financial statements. This standard requires companies to make more estimates and use more judgment than under current guidance. In addition, all companies must compile more extensive footnote disclosures about how the revenue numbers were derived. This ASU requires full retrospective, modified retrospective or use of the cumulative effect method during the period of adoption. In July 2015, the FASB extended the effective date of this standard from January 1, 2017 to January 1, 2018. We are currently in the process of evaluating the impact this new standard will have on our financial statements.

Product Sales Revenues

Product Sales Revenues	6 Months Ended
	Jun. 30, 2016
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 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 revenue. 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 operations, are reported as product sales revenue on our consolidated statements of income. For the three and six months ended June 30, 2015 and 2016 , product sales revenue included the following (in thousands): Three Months Ended Six Months Ended June 30, June 30, 2015 2016 2015 2016 Physical sale of petroleum products $ 133,319 $ 135,459 $ 302,566 $ 266,039 Change in value of NYMEX contracts (23,350 ) (11,770 ) (19,470 ) 4,212 Total product sales revenue $ 109,969 $ 123,689 $ 283,096 $ 270,251

Segment Disclosures

Segment Disclosures	6 Months Ended
	Jun. 30, 2016
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 as 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”) expense that management does not consider when evaluating the core profitability of our separate operating segments. Three Months Ended June 30, 2015 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 238,317 $ 102,035 $ 44,549 $ — $ 384,901 Product sales revenue (1) 109,323 — 646 — 109,969 Affiliate management fee revenue — 3,211 347 — 3,558 Total revenue 347,640 105,246 45,542 — 498,428 Operating expenses 105,081 22,293 15,881 (937 ) 142,318 Cost of product sales (1) 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 Three Months Ended June 30, 2016 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 247,842 $ 101,340 $ 43,058 $ — $ 392,240 Product sales revenue (1) 122,311 (28 ) 1,406 — 123,689 Affiliate management fee revenue 124 2,486 358 — 2,968 Total revenue 370,277 103,798 44,822 — 518,897 Operating expenses 98,500 20,550 16,275 (1,163 ) 134,162 Cost of product sales (1) 94,392 1,016 295 — 95,703 Losses (earnings) of non-controlled entities 38 (14,711 ) (666 ) — (15,339 ) Operating margin 177,347 96,943 28,918 1,163 304,371 Depreciation and amortization expense 24,971 9,062 8,106 1,163 43,302 G&A expenses 20,498 9,146 4,898 — 34,542 Operating profit $ 131,878 $ 78,735 $ 15,914 $ — $ 226,527 Six Months Ended June 30, 2015 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 459,000 $ 192,901 $ 86,812 $ — $ 738,713 Product sales revenue (1) 281,962 — 1,134 — 283,096 Affiliate management fee revenue — 6,238 683 — 6,921 Total revenue 740,962 199,139 88,629 — 1,028,730 Operating expenses 179,293 40,460 31,216 (1,944 ) 249,025 Cost of product sales (1) 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 Six Months Ended June 30, 2016 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 472,592 $ 203,068 $ 86,655 $ — $ 762,315 Product sales revenue (1) 266,227 1,715 2,309 — 270,251 Affiliate management fee revenue 204 5,270 673 — 6,147 Total revenue 739,023 210,053 89,637 — 1,038,713 Operating expenses 184,485 41,742 33,523 (2,355 ) 257,395 Cost of product sales (1) 206,248 2,361 679 — 209,288 Losses (earnings) of non-controlled entities 80 (31,690 ) (1,357 ) — (32,967 ) Operating margin 348,210 197,640 56,792 2,355 604,997 Depreciation and amortization expense 50,091 18,931 15,679 2,355 87,056 G&A expenses 45,859 18,926 10,631 — 75,416 Operating profit $ 252,260 $ 159,783 $ 30,482 $ — $ 442,525 (1) Includes gains (losses) on related NYMEX contracts. See Note 8– Derivative Financial Instruments.

Investments in Non-Controlled E

Investments in Non-Controlled Entities (Notes)	6 Months Ended
	Jun. 30, 2016
Equity Method Investments and Joint Ventures [Abstract]
Investments in Non-Controlled Entities	Investments in Non-Controlled Entities Our investments in non-controlled entities at June 30, 2016 were comprised of: Entity Ownership Interest BridgeTex Pipeline Company, LLC (“BridgeTex”) 50% Double Eagle Pipeline LLC (“Double Eagle”) 50% HoustonLink Pipeline Company, LLC (“HoustonLink”) 50% Powder Springs Logistics, LLC (“Powder Springs”) 50% Saddlehorn Pipeline Company, LLC (“Saddlehorn”) 40% Seabrook Logistics, LLC (“Seabrook”) 50% Texas Frontera, LLC (“Texas Frontera”) 50% In February 2016, we transferred our 50% membership interest in Osage Pipe Line Company, LLC (“Osage”) to an affiliate of HollyFrontier Corporation. In conjunction with this transaction, we entered into several commercial agreements with affiliates of HollyFrontier Corporation. We recorded these commercial agreements as $43.7 million of intangible assets and $8.3 million of other receivables in our consolidated balance sheets. The intangible assets will be amortized over the 20 -year life of the contracts received. The total gain recorded was $28.1 million , which includes $26.9 million recorded in the first quarter of 2016 and an additional $1.2 million recorded in the second quarter of 2016 for proceeds received for a working capital settlement related to the transaction. The management fees we have recognized from BridgeTex, Osage, Powder Springs, Saddlehorn and Texas Frontera are reported as affiliate management fee revenue on our consolidated statements of income. In addition, we receive reimbursement from certain of our joint ventures for costs incurred during construction, which we included as reductions to costs and expenses on our consolidated statements of income. During the second quarter of 2016, we received construction cost reimbursements of $0.8 million from Saddlehorn, $0.1 million from Powder Springs, $0.1 million from HoustonLink and $0.1 million from Seabrook. During the six months ended June 2016, we received construction cost reimbursements of $1.2 million from Saddlehorn, $0.1 million from Powder Springs, $0.1 million from HoustonLink and $0.1 million from Seabrook. We recognized pipeline capacity lease revenue from BridgeTex of $8.5 million and $8.8 million for the three months ended June 30, 2015 and 2016 , respectively, and $16.9 million and $17.7 million for the six months ended June 30, 2015 and 2016 , respectively, which we included in transportation and terminals revenue on our consolidated statements of income. We recognized throughput revenue from Double Eagle of $0.9 million and $0.9 million for the three months ended June 30, 2015 and 2016 , respectively, and $1.8 million and $1.6 million for the six months ended June 30, 2015 and 2016 , respectively, which we included in transportation and terminals revenue on our consolidated statements of income. At December 31, 2015 and June 30, 2016 , respectively, we recognized a $0.2 million and $0.4 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, HoustonLink, Osage, Saddlehorn and Seabrook are included in our crude oil segment and the financial results from Powder Springs are included in our refined products segment, each 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, 2015 $ 495,267 $ 270,361 $ 765,628 Additional investment 7,003 102,930 109,933 Exchange of investment in non-controlled entity — (25,105 ) (25,105 ) Earnings of non-controlled entities: Proportionate share of earnings 29,234 4,890 34,124 Amortization of excess investment and capitalized interest (1,019 ) (138 ) (1,157 ) Earnings of non-controlled entities 28,215 4,752 32,967 Less: Distributions of earnings from investments in non-controlled entities 28,215 2,865 31,080 Distributions in excess of earnings of non-controlled entities 899 1,043 1,942 Investments at June 30, 2016 $ 501,371 $ 349,030 $ 850,401 Summarized financial information of our non-controlled entities for the three and six months ended June 30, 2015 and 2016 follows (in thousands): Three Months Ended June 30, 2015 Three Months Ended June 30, 2016 BridgeTex All Others Consolidated BridgeTex All Others Consolidated Revenue $ 61,629 $ 11,627 $ 73,256 $ 48,426 $ 10,020 $ 58,446 Net income $ 45,619 $ 4,793 $ 50,412 $ 27,219 $ 4,492 $ 31,711 Six Months Ended June 30, 2015 Six Months Ended June 30, 2016 BridgeTex All Others Consolidated BridgeTex All Others Consolidated Revenue $ 98,765 $ 21,147 $ 119,912 $ 99,224 $ 21,429 $ 120,653 Net income $ 63,656 $ 7,374 $ 71,030 $ 58,467 $ 9,758 $ 68,225

Inventory

Inventory	6 Months Ended
	Jun. 30, 2016
Inventory Disclosure [Abstract]
Inventory	Inventory Inventory at December 31, 2015 and June 30, 2016 was as follows (in thousands): December 31, 2015 June 30, Refined products $ 57,455 $ 44,809 Crude oil 28,385 43,767 Transmix 21,297 23,195 Liquefied petroleum gases 17,954 38,846 Additives 5,777 5,813 Total inventory $ 130,868 $ 156,430

Employee Benefit Plans

Employee Benefit Plans	6 Months Ended
	Jun. 30, 2016
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, 2015 and 2016 (in thousands): Three Months Ended Three Months Ended June 30, 2015 June 30, 2016 Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Components of net periodic benefit costs: Service cost $ 4,975 $ 56 $ 4,405 $ 62 Interest cost 2,008 109 1,933 110 Expected return on plan assets (2,123 ) — (2,331 ) — Amortization of prior service credit — (928 ) (45 ) (929 ) Amortization of actuarial loss 1,806 217 1,107 185 Net periodic benefit cost (credit) $ 6,666 $ (546 ) $ 5,069 $ (572 ) Six Months Ended Six Months Ended June 30, 2015 June 30, 2016 Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Components of net periodic benefit costs: Service cost $ 9,445 $ 122 $ 9,093 $ 123 Interest cost 3,877 219 3,978 220 Expected return on plan assets (4,019 ) — (4,459 ) — Amortization of prior service credit — (1,856 ) (90 ) (1,857 ) Amortization of actuarial loss 3,153 442 2,324 369 Net periodic benefit cost (credit) $ 12,456 $ (1,073 ) $ 10,846 $ (1,145 ) Contributions estimated to be paid into the plans in 2016 are $22.9 million and $0.6 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 $2.2 million and $2.4 million , respectively, for the three months ended June 30, 2015 and 2016 and $5.0 million and $5.4 million , respectively, for the six months ended June 30, 2015 and 2016 . 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, 2015 and 2016 were as follows (in thousands): Three Months Ended Three Months Ended June 30, 2015 June 30, 2016 Gains (Losses) Included in AOCL Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Beginning balance $ (61,910 ) $ (2,399 ) $ (61,107 ) $ (4,689 ) Amortization of prior service credit — (928 ) (45 ) (929 ) Amortization of actuarial loss 1,806 217 1,107 185 Ending balance $ (60,104 ) $ (3,110 ) $ (60,045 ) $ (5,433 ) Six Months Ended Six Months Ended June 30, 2015 June 30, 2016 Gains (Losses) Included in AOCL Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Beginning balance $ (63,257 ) $ (1,696 ) $ (62,279 ) $ (3,945 ) Amortization of prior service credit — (1,856 ) (90 ) (1,857 ) Amortization of actuarial loss 3,153 442 2,324 369 Ending balance $ (60,104 ) $ (3,110 ) $ (60,045 ) $ (5,433 )

Debt

Debt	6 Months Ended
	Jun. 30, 2016
Debt Disclosure [Abstract]
Debt	Debt The carrying amount of our consolidated debt at December 31, 2015 and June 30, 2016 was as follows (in thousands, except as otherwise noted): December 31, 2015 June 30, Weighted-Average Interest Rate for the Six Months Ended June 30, 2016 (1) Commercial paper (2) $ 279,801 $ 23,863 0.7% $250.0 million of 5.65% Notes due 2016 (3) 250,208 250,083 5.7% $250.0 million of 6.40% Notes due 2018 254,694 253,763 5.5% $550.0 million of 6.55% Notes due 2019 562,600 560,902 5.7% $550.0 million of 4.25% Notes due 2021 553,002 552,750 4.0% $250.0 million of 3.20% Notes due 2025 247,788 247,907 3.2% $650.0 million of 5.00% Notes due 2026 (2) — 643,978 5.0% $250.0 million of 6.40% Notes due 2037 247,230 247,286 6.4% $250.0 million of 4.20% Notes due 2042 246,142 246,201 4.2% $550.0 million of 5.15% Notes due 2043 550,819 550,863 5.1% $250.0 million of 4.20% Notes due 2045 247,338 247,385 4.6% Total debt 3,439,622 3,824,981 4.8% Less: current portion of long-term debt, net 250,335 250,083 Long-term debt, net (4) $ 3,189,287 $ 3,574,898 (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, 2016 . The weighted-average interest rate for these borrowings was calculated based on the number of days the borrowings were outstanding during the noted period. (3) These borrowings will mature in October 2016 and are reflected in current debt on our consolidated balance sheets at December 31, 2015 and June 30, 2016 . (4) Long-term debt is presented net of unamortized debt issuance costs of $18.7 million and $22.9 million at December 31, 2015 and June 30, 2016 , respectively. All of the instruments detailed in the table above are senior indebtedness. The face value of our debt at December 31, 2015 and June 30, 2016 was $3.4 billion and $3.8 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. 2016 Debt Offering In February 2016, we issued $650.0 million of our 5.00% notes due 2026 in an underwritten public offering. The notes were issued at 99.875% of par. Net proceeds from this offering were approximately $643.8 million , after underwriting discounts and offering expenses of $5.4 million . The net proceeds from this offering were used to repay borrowings outstanding under our commercial paper program and for general partnership purposes, including expansion capital. Other Debt Revolving Credit Facilities. At June 30, 2016 , the total borrowing capacity under our revolving credit facility with a maturity date of October 27, 2020 was $1.0 billion . Any borrowings outstanding under this facility are classified as long-term debt on our consolidated balance sheets. Borrowings under this facility are unsecured and bear interest at LIBOR plus a spread ranging from 1.000% to 1.625% based on our credit ratings. Additionally, an unused commitment fee is assessed at a rate between 0.100% and 0.275% depending on our credit ratings. The unused commitment fee was 0.125% at June 30, 2016 . Borrowings under this facility may be used for general partnership purposes, including capital expenditures. As of December 31, 2015 and June 30, 2016 , respectively, there were no borrowings outstanding under this facility, with $6.3 million 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 this facility. At June 30, 2016 , the total borrowing capacity under our 364 -day credit facility was $250.0 million . This credit facility matures on October 25, 2016, subject to a term-out option. We may exercise the term-out option no later than 30 days prior to October 25, 2016 and elect to have all outstanding borrowings converted into a term loan due and payable on October 25, 2018, subject to the payment of a term-out fee. Any borrowings under this credit facility are classified as current debt on our consolidated balance sheets. Borrowings under this facility are unsecured and bear interest at LIBOR plus a spread ranging from 1.000% to 1.625% based on our credit ratings. Additionally, an unused commitment fee is assessed at a rate between 0.080% and 0.225% depending on our credit ratings. The unused commitment fee was 0.100% at June 30, 2016 . Borrowings under this facility may be used for general partnership purposes, including capital expenditures. As of December 31, 2015 and June 30, 2016 , respectively, there were no borrowings outstanding under this 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 is classified as long-term debt.

Derivative Financial Instrument

Derivative Financial Instruments	6 Months Ended
	Jun. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Financial Instruments	Derivative Financial Instruments Interest Rate Derivatives We periodically enter into interest rate derivatives to hedge the fair value of our debt or interest on 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. As of June 30, 2016 , we had 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 anticipate issuing in 2016. The fair value of these contracts at June 30, 2016 was recorded on our consolidated balance sheets as an other current liability of $18.6 million , with the offset recorded to other comprehensive income. We account for these agreements as cash flow hedges. During second quarter 2016, we entered into $100.0 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 anticipate issuing in 2018. The fair values of these contracts at June 30, 2016 were recorded on our balance sheets as an other noncurrent liability of $1.4 million and an other noncurrent asset of $0.4 million , with the net offset recorded to other comprehensive income. We account for these agreements as cash flow hedges. 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. 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 fair 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 fair 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 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, 2015 and 2016 , 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 AOCL 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 hold petroleum product inventories that we obtain 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 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 a long-term asset on our consolidated balance sheets as tank bottoms. 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, 2016 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 November 2017 NYMEX - Economic Hedges 5.8 million barrels of refined products and crude oil Between July 2016 and April 2017 NYMEX - Economic Hedges 1.2 million barrels of future purchases of butane Between July 2016 and April 2017 Energy Commodity Derivatives Contracts and Deposits Offsets At June 30, 2016 , we had made margin deposits of $28.5 million for our NYMEX contracts with our counterparties, which were recorded as a current asset under energy commodity derivatives deposits on our consolidated balance sheets. 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, 2015 and June 30, 2016 (in thousands): December 31, 2015 Description Gross Amounts of Recognized Assets Gross Amounts of Liabilities Offset in the Consolidated Balance Sheets Net Amounts of Assets Presented in the Consolidated Balance Sheets (1) Margin Deposit Amounts Not Offset in the Consolidated Balance Sheets Net Asset Amount (3) Energy commodity derivatives $ 48,367 $ (5,646 ) $ 42,721 $ (24,252 ) $ 18,469 June 30, 2016 Description Gross Amounts of Recognized Assets Gross Amounts of Liabilities Offset in the Consolidated Balance Sheets Net Amounts of Assets Presented in the Consolidated Balance Sheets (2) Margin Deposit Amounts Not Offset in the Consolidated Balance Sheets Net Asset Amount (3) Energy commodity derivatives $ 9,615 $ (2,543 ) $ 7,072 $ 28,528 $ 35,600 (1) Net amount includes energy commodity derivative contracts classified as current assets, net, of $39,243 and noncurrent assets of $3,478 . (2) Net amount includes energy commodity derivative contracts classified as current assets, net, of $7,359 and noncurrent liabilities of $287 . (3) Amount represents the maximum 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, 2015 and 2016 were as follows (in thousands): Three Months Ended Six Months Ended June 30, June 30, Derivative Losses Included in AOCL 2015 2016 2015 2016 Beginning balance $ (31,852 ) $ (42,216 ) $ (16,587 ) $ (30,126 ) Net gain (loss) on interest rate contract cash flow hedges 1,936 (8,631 ) (13,529 ) (21,109 ) Reclassification of net loss on cash flow hedges to income 388 388 588 776 Ending balance $ (29,528 ) $ (50,459 ) $ (29,528 ) $ (50,459 ) Income Statements The following tables provide a summary of the effect on our consolidated statements of income for the three and six months ended June 30, 2015 and 2016 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, 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 ) $ — Three Months Ended June 30, 2016 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 $ (8,631 ) Interest expense $ (388 ) $ — 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 ) $ — Six Months Ended June 30, 2016 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 $ (21,109 ) Interest expense $ (776 ) $ — As of June 30, 2016 , the net loss estimated to be classified to interest expense over the next twelve months from AOCL is approximately $1.2 million . During 2015 and 2016 , 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, 2015 and June 30, 2016 of $27.9 million and $17.5 million , respectively, from these agreements were offset by a cumulative decrease to tank bottoms. 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 months ended June 30, 2015 and 2016 , we recognized a gain of $6.5 million and $1.9 million , respectively, and for the six months ended June 30, 2015 and 2016 , we recognized a gain of $6.3 million and $4.2 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. The following table provides a summary of the effect on our consolidated statements of income for the three and six months ended June 30, 2015 and 2016 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 Derivatives Three Months Ended Six Months Ended Location of Gain (Loss) Recognized on Derivatives June 30, June 30, Derivative Instrument 2015 2016 2015 2016 NYMEX commodity contracts Product sales revenue $ (23,350 ) $ (11,770 ) $ (19,470 ) $ 4,212 NYMEX commodity contracts Operating expenses (8,883 ) (8,003 ) (7,580 ) (5,404 ) NYMEX commodity contracts Cost of product sales (856 ) 3,240 (2,080 ) 2,812 Total $ (33,089 ) $ (16,533 ) $ (29,130 ) $ 1,620 The impact of the derivatives in the above table was reflected as cash from operations on our consolidated statements of cash flows. Balance Sheets 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, 2015 and June 30, 2016 (in thousands): December 31, 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 $ 60 Energy commodity derivatives contracts, net $ — NYMEX commodity contracts Other noncurrent assets 3,478 Other noncurrent liabilities — Interest rate contracts Other current assets 2,179 Other current liabilities 653 Total $ 5,717 Total $ 653 June 30, 2016 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value NYMEX commodity contracts Other noncurrent assets $ — Other noncurrent liabilities $ 287 Interest rate contracts Other current assets — Other current liabilities 18,595 Interest rate contracts Other noncurrent assets 391 Other noncurrent liabilities 1,379 Total $ 391 Total $ 20,261 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, 2015 and June 30, 2016 (in thousands): December 31, 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 $ 44,829 Energy commodity derivatives contracts, net $ 5,646 June 30, 2016 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value NYMEX commodity contracts Energy commodity derivatives contracts, net $ 9,615 Energy commodity derivatives contracts, net $ 2,256

Commitments And Contingencies

Commitments And Contingencies	6 Months Ended
	Jun. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Environmental Liabilities Liabilities recognized for estimated environmental costs were $31.4 million and $28.7 million at December 31, 2015 and June 30, 2016 , 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 9 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 were $2.9 million and $0.8 million for the three months ended June 30, 2015 and 2016 , respectively, and $4.3 million and $4.3 million for the six months ended June 30, 2015 and 2016 , respectively. Environmental Receivables Receivables from insurance carriers and other third parties related to environmental matters were $2.6 million at December 31, 2015 , of which $0.7 million and $1.9 million were recorded to other accounts receivable and long-term receivables, respectively, on our consolidated balance sheets. Receivables from insurance carriers and other third parties related to environmental matters were $1.9 million at June 30, 2016 , of which $0.8 million and $1.1 million were recorded to other accounts receivable and long-term receivables, respectively, on our consolidated balance sheets. 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, 2016
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 directors of our general partner. The LTIP primarily consists of phantom units and permits the grant of awards covering an aggregate payout of 11.9 million of our limited partner units. The compensation committee of our general partner’s board of directors administers our LTIP. The estimated units remaining available under the LTIP at June 30, 2016 total 3.0 million . Our equity-based incentive compensation expense was as follows (in thousands): Three Months Ended Six Months Ended June 30, 2015 June 30, 2015 Equity Method Liability Method Total Equity Method Liability Method Total Performance-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 Time-based 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 Three Months Ended Six Months Ended June 30, 2016 June 30, 2016 Equity Method Liability Method Total Equity Method Liability Method Total Performance-based awards: 2014 awards $ 979 $ — $ 979 $ 4,388 $ — $ 4,388 2015 awards 926 — 926 2,471 — 2,471 2016 awards 1,023 — 1,023 2,143 — 2,143 Time-based awards 481 — 481 1,057 — 1,057 Total $ 3,409 $ — $ 3,409 $ 10,059 $ — $ 10,059 Allocation of LTIP expense on our consolidated statements of income: G&A expense $ 3,378 $ 9,986 Operating expense 31 73 Total $ 3,409 $ 10,059 In February 2016, 218,046 phantom unit awards were issued pursuant to our LTIP. These grants included both performance-based and time-based phantom unit awards and have a three -year vesting period that will end on December 31, 2018. In February 2016, we issued 350,552 limited partner units to settle unit award grants to certain employees that vested on December 31, 2015. Further, 6,117 limited partner units were issued during 2016 to settle the equity-based retainers paid to the directors of our general partner. Basic and Diluted Net Income Per Limited Partner Unit The difference between our actual limited partner units outstanding and our weighted-average number of limited partner units outstanding used to calculate basic net income per unit is due to the impact of: (i) the phantom units issued to non-employee directors and (ii) the weighted average effect of units actually issued during a period. The difference between the weighted-average number of limited partner units outstanding used for basic and diluted net income per unit calculations on our consolidated statements of income is primarily the dilutive effect of phantom unit grants associated with our LTIP that have not yet vested.

Distributions

Distributions	6 Months Ended
	Jun. 30, 2016
Distributions Made to Members or Limited Partners [Abstract]
Distributions	Distributions Distributions we paid during 2015 and 2016 were as follows (in thousands, except per unit amounts): Payment Date Per Unit Cash Distribution Amount Total Cash Distribution to Limited Partners 02/13/2015 $ 0.6950 $ 158,061 05/15/2015 0.7175 163,178 Through 06/30/2015 1.4125 321,239 08/14/2015 0.7400 168,296 11/13/2015 0.7625 173,413 Total $ 2.9150 $ 662,948 2/12/2016 $ 0.7850 $ 178,808 5/13/2016 0.8025 182,797 Through 06/30/2016 1.5875 361,605 08/12/2016 (1) 0.8200 186,783 Total $ 2.4075 $ 548,388 (1) Our general partner’s board of directors declared this cash distribution in July 2016 to be paid on August 12, 2016 to unitholders of record at the close of business on August 1, 2016 .

Fair Value

Fair Value	6 Months Ended
	Jun. 30, 2016
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 of 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 primarily include lease payments receivable under a direct-financing leasing arrangement. 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, 2015 and June 30, 2016 ; 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, 2015 and June 30, 2016 based on the three levels established by ASC 820, Fair Value Measurements and Disclosures (in thousands): December 31, 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 $ 42,721 $ 42,721 $ 42,721 $ — $ — Interest rate contracts $ 1,526 $ 1,526 $ — $ 1,526 $ — Long-term receivables $ 20,374 $ 20,021 $ — $ — $ 20,021 Debt $ (3,439,622 ) $ (3,284,791 ) $ — $ (3,284,791 ) $ — June 30, 2016 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 $ 7,072 $ 7,072 $ 7,072 $ — $ — Interest rate contracts $ (19,583 ) $ (19,583 ) $ — $ (19,583 ) $ — Long-term receivables $ 18,134 $ 19,708 $ — $ — $ 19,708 Debt $ (3,824,981 ) $ (4,161,568 ) $ — $ (4,161,568 ) $ —

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2016
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 was also a director of the general partner of Targa Resources Partners, L.P. (“Targa”) through February 29, 2016. In the normal course of business, we purchase butane from subsidiaries of Targa. During Mr. Pearl’s tenure as a director of the general partner of Targa, we made purchases of butane from subsidiaries of Targa of $4.0 million and $12.8 million , respectively, for the three and six month periods ending June 30, 2015 , and $4.7 million for the period from January 1, 2016 through February 29, 2016. These purchases were based on the then-current index prices. We had recognized payables to Targa of $2.0 million at December 31, 2015 . 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 from this customer of $2.6 million from April 23, 2015 through June 30, 2015 and $4.7 million and $7.7 million , respectively, for the three and six months ended June 30, 2016 . We recorded receivables of $1.3 million and $1.3 million from this customer at December 31, 2015 and June 30, 2016 , respectively. 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, 2016
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events Recognizable events No recognizable events occurred subsequent to June 30, 2016 . Non-recognizable events Cash Distribution. In July 2016, our general partner’s board of directors declared a quarterly distribution of $0.82 per unit to be paid on August 12, 2016 to unitholders of record at the close of business on August 1, 2016 . The total cash distributions expected to be paid under this declaration are approximately $186.8 million .

Organization, Description of 21

Organization, Description of Business And Basis Of Presentation (Accounting Policies) (Policies)	6 Months Ended
	Jun. 30, 2016
Accounting Policies [Abstract]
New Accounting Pronouncements	New Accounting Pronouncements In March 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2016-09, Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting , which is part of the FASB’s initiative to simplify accounting standards. The guidance requires an entity to make an entity-wide accounting policy election to either estimate the number of awards that are expected to vest or account for forfeitures when they occur, and allows equity classification for awards where employees elect to withhold the maximum statutory tax rates in the applicable jurisdictions. The new standard also requires cash paid by employers when directly withholding shares for tax withholding purposes to be classified as a financing activity in the statement of cash flows. We elected to early adopt ASU 2016-09 during the first quarter of 2016, and this adoption did not have a material impact on our consolidated financial statements. In conjunction with our adoption of this new accounting standard, we have elected to account for equity-based compensation forfeitures as they occur. Additionally, and consistent with our prior accounting policy, we continue to show cash paid when directly withholding shares for tax withholding purposes as a financing activity in our statements of cash flows. In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) . This standard requires companies that lease valuable assets like aircraft, real estate, and heavy equipment to recognize on their balance sheets the assets and liabilities generated by contracts longer than a year. The new accounting model for lessors remains largely the same, although some changes have been made to align it with the new lessee model and the new revenue recognition guidance. This update also requires companies to disclose in the footnotes to their financial statements information about the amount, timing and uncertainty for the payments they make for the lease arrangements. Public companies will have to begin applying the standard for fiscal years and quarters that start after December 15, 2018, although early adoption is permitted. We are currently in the process of evaluating the impact this new standard will have on our financial statements. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers, which eliminates the industry-specific guidance in U.S. GAAP and produces a single, principles-based method for companies to report revenue in their financial statements. This standard requires companies to make more estimates and use more judgment than under current guidance. In addition, all companies must compile more extensive footnote disclosures about how the revenue numbers were derived. This ASU requires full retrospective, modified retrospective or use of the cumulative effect method during the period of adoption. In July 2015, the FASB extended the effective date of this standard from January 1, 2017 to January 1, 2018. We are currently in the process of evaluating the impact this new standard will have on our financial statements.

Product Sales Revenues (Tables)

Product Sales Revenues (Tables)	6 Months Ended
	Jun. 30, 2016
Product Sales Revenue [Abstract]
Components of Product Sales Revenues	For the three and six months ended June 30, 2015 and 2016 , product sales revenue included the following (in thousands): Three Months Ended Six Months Ended June 30, June 30, 2015 2016 2015 2016 Physical sale of petroleum products $ 133,319 $ 135,459 $ 302,566 $ 266,039 Change in value of NYMEX contracts (23,350 ) (11,770 ) (19,470 ) 4,212 Total product sales revenue $ 109,969 $ 123,689 $ 283,096 $ 270,251

Segment Disclosures (Tables)

Segment Disclosures (Tables)	6 Months Ended
	Jun. 30, 2016
Segment Reporting [Abstract]
Schedule of Business Segment Reporting Information	Three Months Ended June 30, 2015 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 238,317 $ 102,035 $ 44,549 $ — $ 384,901 Product sales revenue (1) 109,323 — 646 — 109,969 Affiliate management fee revenue — 3,211 347 — 3,558 Total revenue 347,640 105,246 45,542 — 498,428 Operating expenses 105,081 22,293 15,881 (937 ) 142,318 Cost of product sales (1) 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 Three Months Ended June 30, 2016 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 247,842 $ 101,340 $ 43,058 $ — $ 392,240 Product sales revenue (1) 122,311 (28 ) 1,406 — 123,689 Affiliate management fee revenue 124 2,486 358 — 2,968 Total revenue 370,277 103,798 44,822 — 518,897 Operating expenses 98,500 20,550 16,275 (1,163 ) 134,162 Cost of product sales (1) 94,392 1,016 295 — 95,703 Losses (earnings) of non-controlled entities 38 (14,711 ) (666 ) — (15,339 ) Operating margin 177,347 96,943 28,918 1,163 304,371 Depreciation and amortization expense 24,971 9,062 8,106 1,163 43,302 G&A expenses 20,498 9,146 4,898 — 34,542 Operating profit $ 131,878 $ 78,735 $ 15,914 $ — $ 226,527 Six Months Ended June 30, 2015 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 459,000 $ 192,901 $ 86,812 $ — $ 738,713 Product sales revenue (1) 281,962 — 1,134 — 283,096 Affiliate management fee revenue — 6,238 683 — 6,921 Total revenue 740,962 199,139 88,629 — 1,028,730 Operating expenses 179,293 40,460 31,216 (1,944 ) 249,025 Cost of product sales (1) 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 Six Months Ended June 30, 2016 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 472,592 $ 203,068 $ 86,655 $ — $ 762,315 Product sales revenue (1) 266,227 1,715 2,309 — 270,251 Affiliate management fee revenue 204 5,270 673 — 6,147 Total revenue 739,023 210,053 89,637 — 1,038,713 Operating expenses 184,485 41,742 33,523 (2,355 ) 257,395 Cost of product sales (1) 206,248 2,361 679 — 209,288 Losses (earnings) of non-controlled entities 80 (31,690 ) (1,357 ) — (32,967 ) Operating margin 348,210 197,640 56,792 2,355 604,997 Depreciation and amortization expense 50,091 18,931 15,679 2,355 87,056 G&A expenses 45,859 18,926 10,631 — 75,416 Operating profit $ 252,260 $ 159,783 $ 30,482 $ — $ 442,525 (1) Includes gains (losses) on related NYMEX contracts. See Note 8– Derivative Financial Instruments.

Investments in Non-Controlled24

Investments in Non-Controlled Entities (Tables)	6 Months Ended
	Jun. 30, 2016
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Our investments in non-controlled entities at June 30, 2016 were comprised of: Entity Ownership Interest BridgeTex Pipeline Company, LLC (“BridgeTex”) 50% Double Eagle Pipeline LLC (“Double Eagle”) 50% HoustonLink Pipeline Company, LLC (“HoustonLink”) 50% Powder Springs Logistics, LLC (“Powder Springs”) 50% Saddlehorn Pipeline Company, LLC (“Saddlehorn”) 40% Seabrook Logistics, LLC (“Seabrook”) 50% Texas Frontera, LLC (“Texas Frontera”) 50% In February 2016, we transferred our 50% membership interest in Osage Pipe Line Company, LLC (“Osage”) to an affiliate of HollyFrontier Corporation. In conjunction with this transaction, we entered into several commercial agreements with affiliates of HollyFrontier Corporation. We recorded these commercial agreements as $43.7 million of intangible assets and $8.3 million of other receivables in our consolidated balance sheets. The intangible assets will be amortized over the 20 -year life of the contracts received. The total gain recorded was $28.1 million , which includes $26.9 million recorded in the first quarter of 2016 and an additional $1.2 million recorded in the second quarter of 2016 for proceeds received for a working capital settlement related to the transaction. The management fees we have recognized from BridgeTex, Osage, Powder Springs, Saddlehorn and Texas Frontera are reported as affiliate management fee revenue on our consolidated statements of income. In addition, we receive reimbursement from certain of our joint ventures for costs incurred during construction, which we included as reductions to costs and expenses on our consolidated statements of income. During the second quarter of 2016, we received construction cost reimbursements of $0.8 million from Saddlehorn, $0.1 million from Powder Springs, $0.1 million from HoustonLink and $0.1 million from Seabrook. During the six months ended June 2016, we received construction cost reimbursements of $1.2 million from Saddlehorn, $0.1 million from Powder Springs, $0.1 million from HoustonLink and $0.1 million from Seabrook. We recognized pipeline capacity lease revenue from BridgeTex of $8.5 million and $8.8 million for the three months ended June 30, 2015 and 2016 , respectively, and $16.9 million and $17.7 million for the six months ended June 30, 2015 and 2016 , respectively, which we included in transportation and terminals revenue on our consolidated statements of income. We recognized throughput revenue from Double Eagle of $0.9 million and $0.9 million for the three months ended June 30, 2015 and 2016 , respectively, and $1.8 million and $1.6 million for the six months ended June 30, 2015 and 2016 , respectively, which we included in transportation and terminals revenue on our consolidated statements of income. At December 31, 2015 and June 30, 2016 , respectively, we recognized a $0.2 million and $0.4 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, HoustonLink, Osage, Saddlehorn and Seabrook are included in our crude oil segment and the financial results from Powder Springs are included in our refined products segment, each 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, 2015 $ 495,267 $ 270,361 $ 765,628 Additional investment 7,003 102,930 109,933 Exchange of investment in non-controlled entity — (25,105 ) (25,105 ) Earnings of non-controlled entities: Proportionate share of earnings 29,234 4,890 34,124 Amortization of excess investment and capitalized interest (1,019 ) (138 ) (1,157 ) Earnings of non-controlled entities 28,215 4,752 32,967 Less: Distributions of earnings from investments in non-controlled entities 28,215 2,865 31,080 Distributions in excess of earnings of non-controlled entities 899 1,043 1,942 Investments at June 30, 2016 $ 501,371 $ 349,030 $ 850,401 Summarized financial information of our non-controlled entities for the three and six months ended June 30, 2015 and 2016 follows (in thousands): Three Months Ended June 30, 2015 Three Months Ended June 30, 2016 BridgeTex All Others Consolidated BridgeTex All Others Consolidated Revenue $ 61,629 $ 11,627 $ 73,256 $ 48,426 $ 10,020 $ 58,446 Net income $ 45,619 $ 4,793 $ 50,412 $ 27,219 $ 4,492 $ 31,711 Six Months Ended June 30, 2015 Six Months Ended June 30, 2016 BridgeTex All Others Consolidated BridgeTex All Others Consolidated Revenue $ 98,765 $ 21,147 $ 119,912 $ 99,224 $ 21,429 $ 120,653 Net income $ 63,656 $ 7,374 $ 71,030 $ 58,467 $ 9,758 $ 68,225

Inventory (Tables)

Inventory (Tables)	6 Months Ended
	Jun. 30, 2016
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventory at December 31, 2015 and June 30, 2016 was as follows (in thousands): December 31, 2015 June 30, Refined products $ 57,455 $ 44,809 Crude oil 28,385 43,767 Transmix 21,297 23,195 Liquefied petroleum gases 17,954 38,846 Additives 5,777 5,813 Total inventory $ 130,868 $ 156,430

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	6 Months Ended
	Jun. 30, 2016
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, 2015 and 2016 (in thousands): Three Months Ended Three Months Ended June 30, 2015 June 30, 2016 Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Components of net periodic benefit costs: Service cost $ 4,975 $ 56 $ 4,405 $ 62 Interest cost 2,008 109 1,933 110 Expected return on plan assets (2,123 ) — (2,331 ) — Amortization of prior service credit — (928 ) (45 ) (929 ) Amortization of actuarial loss 1,806 217 1,107 185 Net periodic benefit cost (credit) $ 6,666 $ (546 ) $ 5,069 $ (572 ) Six Months Ended Six Months Ended June 30, 2015 June 30, 2016 Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Components of net periodic benefit costs: Service cost $ 9,445 $ 122 $ 9,093 $ 123 Interest cost 3,877 219 3,978 220 Expected return on plan assets (4,019 ) — (4,459 ) — Amortization of prior service credit — (1,856 ) (90 ) (1,857 ) Amortization of actuarial loss 3,153 442 2,324 369 Net periodic benefit cost (credit) $ 12,456 $ (1,073 ) $ 10,846 $ (1,145 )
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, 2015 and 2016 were as follows (in thousands): Three Months Ended Three Months Ended June 30, 2015 June 30, 2016 Gains (Losses) Included in AOCL Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Beginning balance $ (61,910 ) $ (2,399 ) $ (61,107 ) $ (4,689 ) Amortization of prior service credit — (928 ) (45 ) (929 ) Amortization of actuarial loss 1,806 217 1,107 185 Ending balance $ (60,104 ) $ (3,110 ) $ (60,045 ) $ (5,433 ) Six Months Ended Six Months Ended June 30, 2015 June 30, 2016 Gains (Losses) Included in AOCL Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Beginning balance $ (63,257 ) $ (1,696 ) $ (62,279 ) $ (3,945 ) Amortization of prior service credit — (1,856 ) (90 ) (1,857 ) Amortization of actuarial loss 3,153 442 2,324 369 Ending balance $ (60,104 ) $ (3,110 ) $ (60,045 ) $ (5,433 )

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2016
Debt Disclosure [Abstract]
Consolidated Debt	onsolidated debt at December 31, 2015 and June 30, 2016 was as follows (in thousands, except as otherwise noted): December 31, 2015 June 30, Weighted-Average Interest Rate for the Six Months Ended June 30, 2016 (1) Commercial paper (2) $ 279,801 $ 23,863 0.7% $250.0 million of 5.65% Notes due 2016 (3) 250,208 250,083 5.7% $250.0 million of 6.40% Notes due 2018 254,694 253,763 5.5% $550.0 million of 6.55% Notes due 2019 562,600 560,902 5.7% $550.0 million of 4.25% Notes due 2021 553,002 552,750 4.0% $250.0 million of 3.20% Notes due 2025 247,788 247,907 3.2% $650.0 million of 5.00% Notes due 2026 (2) — 643,978 5.0% $250.0 million of 6.40% Notes due 2037 247,230 247,286 6.4% $250.0 million of 4.20% Notes due 2042 246,142 246,201 4.2% $550.0 million of 5.15% Notes due 2043 550,819 550,863 5.1% $250.0 million of 4.20% Notes due 2045 247,338 247,385 4.6% Total debt 3,439,622 3,824,981 4.8% Less: current portion of long-term debt, net 250,335 250,083 Long-term debt, net (4) $ 3,189,287 $ 3,574,898 (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, 2016 . The weighted-average interest rate for these borrowings was calculated based on the number of days the borrowings were outstanding during the noted period. (3) These borrowings will mature in October 2016 and are reflected in current debt on our consolidated balance sheets at December 31, 2015 and June 30, 2016 . (4) Long-term debt is presented net of unamortized debt issuance costs of $18.7 million and $22.9 million at December 31, 2015 and June 30, 2016 , respectively.

Derivative Financial Instrume28

Derivative Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements	As outlined in the table below, our open NYMEX contracts at June 30, 2016 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 November 2017 NYMEX - Economic Hedges 5.8 million barrels of refined products and crude oil Between July 2016 and April 2017 NYMEX - Economic Hedges 1.2 million barrels of future purchases of butane Between July 2016 and April 2017
Derivatives and Offset Amounts	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, 2015 and June 30, 2016 (in thousands): December 31, 2015 Description Gross Amounts of Recognized Assets Gross Amounts of Liabilities Offset in the Consolidated Balance Sheets Net Amounts of Assets Presented in the Consolidated Balance Sheets (1) Margin Deposit Amounts Not Offset in the Consolidated Balance Sheets Net Asset Amount (3) Energy commodity derivatives $ 48,367 $ (5,646 ) $ 42,721 $ (24,252 ) $ 18,469 June 30, 2016 Description Gross Amounts of Recognized Assets Gross Amounts of Liabilities Offset in the Consolidated Balance Sheets Net Amounts of Assets Presented in the Consolidated Balance Sheets (2) Margin Deposit Amounts Not Offset in the Consolidated Balance Sheets Net Asset Amount (3) Energy commodity derivatives $ 9,615 $ (2,543 ) $ 7,072 $ 28,528 $ 35,600 (1) Net amount includes energy commodity derivative contracts classified as current assets, net, of $39,243 and noncurrent assets of $3,478 . (2) Net amount includes energy commodity derivative contracts classified as current assets, net, of $7,359 and noncurrent liabilities of $287 . (3) Amount represents the maximum 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, 2015 and 2016 were as follows (in thousands): Three Months Ended Six Months Ended June 30, June 30, Derivative Losses Included in AOCL 2015 2016 2015 2016 Beginning balance $ (31,852 ) $ (42,216 ) $ (16,587 ) $ (30,126 ) Net gain (loss) on interest rate contract cash flow hedges 1,936 (8,631 ) (13,529 ) (21,109 ) Reclassification of net loss on cash flow hedges to income 388 388 588 776 Ending balance $ (29,528 ) $ (50,459 ) $ (29,528 ) $ (50,459 )
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, 2015 and 2016 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, 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 ) $ — Three Months Ended June 30, 2016 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 $ (8,631 ) Interest expense $ (388 ) $ — 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 ) $ — Six Months Ended June 30, 2016 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 $ (21,109 ) Interest expense $ (776 ) $ —
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, 2015 and 2016 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 Derivatives Three Months Ended Six Months Ended Location of Gain (Loss) Recognized on Derivatives June 30, June 30, Derivative Instrument 2015 2016 2015 2016 NYMEX commodity contracts Product sales revenue $ (23,350 ) $ (11,770 ) $ (19,470 ) $ 4,212 NYMEX commodity contracts Operating expenses (8,883 ) (8,003 ) (7,580 ) (5,404 ) NYMEX commodity contracts Cost of product sales (856 ) 3,240 (2,080 ) 2,812 Total $ (33,089 ) $ (16,533 ) $ (29,130 ) $ 1,620
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, 2015 and June 30, 2016 (in thousands): December 31, 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 $ 60 Energy commodity derivatives contracts, net $ — NYMEX commodity contracts Other noncurrent assets 3,478 Other noncurrent liabilities — Interest rate contracts Other current assets 2,179 Other current liabilities 653 Total $ 5,717 Total $ 653 June 30, 2016 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value NYMEX commodity contracts Other noncurrent assets $ — Other noncurrent liabilities $ 287 Interest rate contracts Other current assets — Other current liabilities 18,595 Interest rate contracts Other noncurrent assets 391 Other noncurrent liabilities 1,379 Total $ 391 Total $ 20,261 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, 2015 and June 30, 2016 (in thousands): December 31, 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 $ 44,829 Energy commodity derivatives contracts, net $ 5,646 June 30, 2016 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value NYMEX commodity contracts Energy commodity derivatives contracts, net $ 9,615 Energy commodity derivatives contracts, net $ 2,256

Long-Term Incentive Plan (Table

Long-Term Incentive Plan (Tables)	6 Months Ended
	Jun. 30, 2016
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, 2015 June 30, 2015 Equity Method Liability Method Total Equity Method Liability Method Total Performance-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 Time-based 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 Three Months Ended Six Months Ended June 30, 2016 June 30, 2016 Equity Method Liability Method Total Equity Method Liability Method Total Performance-based awards: 2014 awards $ 979 $ — $ 979 $ 4,388 $ — $ 4,388 2015 awards 926 — 926 2,471 — 2,471 2016 awards 1,023 — 1,023 2,143 — 2,143 Time-based awards 481 — 481 1,057 — 1,057 Total $ 3,409 $ — $ 3,409 $ 10,059 $ — $ 10,059 Allocation of LTIP expense on our consolidated statements of income: G&A expense $ 3,378 $ 9,986 Operating expense 31 73 Total $ 3,409 $ 10,059

Distributions (Tables)

Distributions (Tables)	6 Months Ended
	Jun. 30, 2016
Distributions Made to Members or Limited Partners [Abstract]
Schedule Of Distributions	Distributions we paid during 2015 and 2016 were as follows (in thousands, except per unit amounts): Payment Date Per Unit Cash Distribution Amount Total Cash Distribution to Limited Partners 02/13/2015 $ 0.6950 $ 158,061 05/15/2015 0.7175 163,178 Through 06/30/2015 1.4125 321,239 08/14/2015 0.7400 168,296 11/13/2015 0.7625 173,413 Total $ 2.9150 $ 662,948 2/12/2016 $ 0.7850 $ 178,808 5/13/2016 0.8025 182,797 Through 06/30/2016 1.5875 361,605 08/12/2016 (1) 0.8200 186,783 Total $ 2.4075 $ 548,388 (1) Our general partner’s board of directors declared this cash distribution in July 2016 to be paid on August 12, 2016 to unitholders of record at the close of business on August 1, 2016 .

Fair Value (Tables)

Fair Value (Tables)	6 Months Ended
	Jun. 30, 2016
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, 2015 and June 30, 2016 based on the three levels established by ASC 820, Fair Value Measurements and Disclosures (in thousands): December 31, 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 $ 42,721 $ 42,721 $ 42,721 $ — $ — Interest rate contracts $ 1,526 $ 1,526 $ — $ 1,526 $ — Long-term receivables $ 20,374 $ 20,021 $ — $ — $ 20,021 Debt $ (3,439,622 ) $ (3,284,791 ) $ — $ (3,284,791 ) $ — June 30, 2016 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 $ 7,072 $ 7,072 $ 7,072 $ — $ — Interest rate contracts $ (19,583 ) $ (19,583 ) $ — $ (19,583 ) $ — Long-term receivables $ 18,134 $ 19,708 $ — $ — $ 19,708 Debt $ (3,824,981 ) $ (4,161,568 ) $ — $ (4,161,568 ) $ —

Organization, Description of 32

Organization, Description of Business and Basis of Presentation (Narrative) (Details) bbl in Millions	Jun. 30, 2016Terminalbblmi
Refined Products [Member]
Organization and Description of Business [Line Items]
Number of Pipeline Terminals | Terminal	54
Number of Independent Terminals | Terminal	26
Refined Products [Member] | Refined Products Transportation Services [Member]
Organization and Description of Business [Line Items]
Pipeline Length | mi	9,700
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	22
Leasable Storage Capacity | bbl	15
Marine Storage [Member]
Organization and Description of Business [Line Items]
Number of Independent Terminals | Terminal	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, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Product Sales Revenue [Abstract]
Physical sale of petroleum products		$ 135,459	$ 133,319	$ 266,039	$ 302,566
Change in value of NYMEX contracts		(11,770)	(23,350)	4,212	(19,470)
Total product sales revenue	[1]	$ 123,689	$ 109,969	$ 270,251	$ 283,096
[1]	Includes gains (losses) on related NYMEX contracts. See Note 8–Derivative Financial Instruments.

Segment Disclosures (Schedule O

Segment Disclosures (Schedule Of Business Segment Reporting Information) (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Segment Reporting Information [Line Items]
Transportation and terminals revenue		$ 392,240	$ 384,901	$ 762,315	$ 738,713
Product sales revenue	[1]	123,689	109,969	270,251	283,096
Affiliate management fee revenue		2,968	3,558	6,147	6,921
Total revenue		518,897	498,428	1,038,713	1,028,730
Operating expenses		134,162	142,318	257,395	249,025
Cost of product sales	[1]	95,703	94,507	209,288	230,686
Earnings of non-controlled entities		(15,339)	(24,542)	(32,967)	(34,132)
Operating margin		304,371	286,145	604,997	583,151
Depreciation and amortization expense		43,302	40,440	87,056	82,137
G&A expenses		34,542	37,942	75,416	73,440
Operating profit		226,527	207,763	442,525	427,574
Operating Segments [Member] | Refined Products [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue		247,842	238,317	472,592	459,000
Product sales revenue	[1]	122,311	109,323	266,227	281,962
Affiliate management fee revenue		124	0	204	0
Total revenue		370,277	347,640	739,023	740,962
Operating expenses		98,500	105,081	184,485	179,293
Cost of product sales	[1]	94,392	94,326	206,248	229,960
Earnings of non-controlled entities		38	43	80	98
Operating margin		177,347	148,190	348,210	331,611
Depreciation and amortization expense		24,971	23,962	50,091	47,409
G&A expenses		20,498	23,893	45,859	46,492
Operating profit		131,878	100,335	252,260	237,710
Operating Segments [Member] | Crude Oil Pipeline and Terminals [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue		101,340	102,035	203,068	192,901
Product sales revenue	[1]	(28)	0	1,715	0
Affiliate management fee revenue		2,486	3,211	5,270	6,238
Total revenue		103,798	105,246	210,053	199,139
Operating expenses		20,550	22,293	41,742	40,460
Cost of product sales	[1]	1,016	0	2,361	0
Earnings of non-controlled entities		(14,711)	(23,905)	(31,690)	(32,829)
Operating margin		96,943	106,858	197,640	191,508
Depreciation and amortization expense		9,062	8,264	18,931	16,493
G&A expenses		9,146	9,031	18,926	17,117
Operating profit		78,735	89,563	159,783	157,898
Operating Segments [Member] | Marine Storage [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue		43,058	44,549	86,655	86,812
Product sales revenue	[1]	1,406	646	2,309	1,134
Affiliate management fee revenue		358	347	673	683
Total revenue		44,822	45,542	89,637	88,629
Operating expenses		16,275	15,881	33,523	31,216
Cost of product sales	[1]	295	181	679	726
Earnings of non-controlled entities		(666)	(680)	(1,357)	(1,401)
Operating margin		28,918	30,160	56,792	58,088
Depreciation and amortization expense		8,106	7,277	15,679	16,291
G&A expenses		4,898	5,018	10,631	9,831
Operating profit		15,914	17,865	30,482	31,966
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue		0	0	0	0
Product sales revenue	[1]	0	0	0	0
Affiliate management fee revenue		0	0	0	0
Total revenue		0	0	0	0
Operating expenses		(1,163)	(937)	(2,355)	(1,944)
Cost of product sales	[1]	0	0	0	0
Earnings of non-controlled entities		0	0	0	0
Operating margin		1,163	937	2,355	1,944
Depreciation and amortization expense		1,163	937	2,355	1,944
G&A expenses		0	0	0	0
Operating profit		$ 0	$ 0	$ 0	$ 0
[1]	Includes gains (losses) on related NYMEX contracts. See Note 8–Derivative Financial Instruments.

Investments in Non-Controlled35

Investments in Non-Controlled Entities (Details) - USD ($) $ in Thousands	Feb. 29, 2016	Jun. 30, 2016	Mar. 31, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Intangible Assets, Net (Excluding Goodwill)		$ 52,337			$ 52,337		$ 1,856
Equity Method Investment, Realized Gain (Loss) on Disposal		1,244		$ 0	28,144	$ 0
Change in Equity Method Investments [Roll Forward]
Investments at December 31, 2015			$ 765,628		765,628
Additional investment					109,933
Exchange of investment in non-controlled entity					(25,105)
Proportionate share of earnings					34,124
Amortization of excess investment and capitalized interest					(1,157)
Earnings of non-controlled entities		15,339		24,542	32,967	34,132
Distributions of earnings from investments in non-controlled entities					31,080	31,243
Distributions in excess of earnings of non-controlled entities					1,942	0
Investments at March 31, 2016		850,401			850,401
Equity Method Investment, Summarized Financial Information, Revenue		58,446		73,256	120,653	119,912
Equity Method Investment, Summarized Financial Information, Net Income (Loss)		$ 31,711		50,412	$ 68,225	71,030
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, 2015			495,267		$ 495,267
Additional investment					7,003
Exchange of investment in non-controlled entity					0
Proportionate share of earnings					29,234
Amortization of excess investment and capitalized interest					(1,019)
Earnings of non-controlled entities					28,215
Distributions of earnings from investments in non-controlled entities					28,215
Distributions in excess of earnings of non-controlled entities					899
Investments at March 31, 2016		$ 501,371			501,371
Equity Method Investment, Summarized Financial Information, Revenue		48,426		61,629	99,224	98,765
Equity Method Investment, Summarized Financial Information, Net Income (Loss)		$ 27,219		45,619	$ 58,467	63,656
Double Eagle Pipeline Llc [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment		50.00%			50.00%
HoustonLink Pipeline Company 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%
Texas Frontera Llc [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment		50.00%			50.00%
Osage Pipeline Co [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%
Intangible Assets, Net (Excluding Goodwill)	$ 43,700
Nontrade Receivables	$ 8,300
Finite-Lived Intangible Asset, Useful Life	20 years
Equity Method Investment, Realized Gain (Loss) on Disposal		$ 1,200	26,900		$ 28,100
All Other Equity Investments [Member]
Change in Equity Method Investments [Roll Forward]
Investments at December 31, 2015			$ 270,361		270,361
Additional investment					102,930
Exchange of investment in non-controlled entity					(25,105)
Proportionate share of earnings					4,890
Amortization of excess investment and capitalized interest					(138)
Earnings of non-controlled entities					4,752
Distributions of earnings from investments in non-controlled entities					2,865
Distributions in excess of earnings of non-controlled entities					1,043
Investments at March 31, 2016		349,030			349,030
Equity Method Investment, Summarized Financial Information, Revenue		10,020		11,627	21,429	21,147
Equity Method Investment, Summarized Financial Information, Net Income (Loss)		4,492		4,793	9,758	7,374
Equity Method Investee [Member] | BridgeTex [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party		8,800		8,500	17,700	16,900
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		$ 900	1,600	$ 1,800
Accounts Receivable, Related Parties, Current		400			400		$ 200
Equity Method Investee [Member] | HoustonLink Pipeline Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party		100			100
Equity Method Investee [Member] | Powder Springs Logistics, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party		100			100
Equity Method Investee [Member] | Saddlehorn Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party		800			1,200
Equity Method Investee [Member] | Seabrook Logistics, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party		$ 100			$ 100

Inventory (Details)

Inventory (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Inventory Disclosure [Abstract]
Refined products	$ 44,809	$ 57,455
Crude oil	43,767	28,385
Transmix	23,195	21,297
Liquefied petroleum gases	38,846	17,954
Additives	5,813	5,777
Total inventory	$ 156,430	$ 130,868

Schedule Of Consolidated Net Pe

Schedule Of Consolidated Net Periodic Benefit Costs (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2016USD ($)pension_plan	Jun. 30, 2015USD ($)
Defined Benefit Plan Disclosure [Line Items]
Number of Union Pension Plans | pension_plan			2
Defined Contribution Plan, Cost Recognized	$ 2,400	$ 2,200	$ 5,400	$ 5,000
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year			22,900
Components of net periodic benefit costs:
Service cost	4,405	4,975	9,093	9,445
Interest cost	1,933	2,008	3,978	3,877
Expected return on plan assets	(2,331)	(2,123)	(4,459)	(4,019)
Amortization of prior service credit	(45)	0	(90)	0
Amortization of actuarial loss	1,107	1,806	2,324	3,153
Net periodic benefit cost (credit)	5,069	6,666	10,846	12,456
Other Postretirement Benefit Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year			600
Components of net periodic benefit costs:
Service cost	62	56	123	122
Interest cost	110	109	220	219
Expected return on plan assets	0	0	0	0
Amortization of prior service credit	(929)	(928)	(1,857)	(1,856)
Amortization of actuarial loss	185	217	369	442
Net periodic benefit cost (credit)	$ (572)	$ (546)	$ (1,145)	$ (1,073)

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, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Changes in AOCL [Roll Forward]
Accumulated other comprehensive loss (Beginning Bal)				$ (96,350)
Amortization of prior service credit	[1]	$ (974)	$ (928)	(1,947)	$ (1,856)
Amortization of actuarial loss	[1]	1,292	2,023	2,693	3,595
Accumulated other comprehensive loss (Ending Bal)		(115,937)		(115,937)
Pension Plan [Member]
Changes in AOCL [Roll Forward]
Accumulated other comprehensive loss (Beginning Bal)		(61,107)	(61,910)	(62,279)	(63,257)
Amortization of prior service credit		(45)	0	(90)	0
Amortization of actuarial loss		1,107	1,806	2,324	3,153
Accumulated other comprehensive loss (Ending Bal)		(60,045)	(60,104)	(60,045)	(60,104)
Other Postretirement Benefit Plan [Member]
Changes in AOCL [Roll Forward]
Accumulated other comprehensive loss (Beginning Bal)		(4,689)	(2,399)	(3,945)	(1,696)
Amortization of prior service credit		(929)	(928)	(1,857)	(1,856)
Amortization of actuarial loss		185	217	369	442
Accumulated other comprehensive loss (Ending Bal)		$ (5,433)	$ (3,110)	$ (5,433)	$ (3,110)
[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, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long term debt		$ 3,824,981,000	$ 3,439,622,000
Weighted-Average Interest Rate	[1]	4.80%
Debt Instrument, Face Amount		$ 3,800,000,000	3,400,000,000
Current portion of long-term debt, net		250,083,000	250,335,000
Long-term debt, net	[2]	3,574,898,000	3,189,287,000
Unamortized Debt Acquisition Costs - Contra Liability		22,900,000	18,700,000
Senior Notes [Member] | 5.65% Notes Due 2016 [Member]
Debt Instrument [Line Items]
Long term debt	[3]	$ 250,083,000	250,208,000
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]
Long term debt		$ 253,763,000	$ 254,694,000
Weighted-Average Interest Rate	[1]	5.50%
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]
Long term debt		$ 560,902,000	$ 562,600,000
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]
Long term debt		$ 552,750,000	$ 553,002,000
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]
Long term debt		$ 247,907,000	$ 247,788,000
Weighted-Average Interest Rate	[1]	3.20%
Debt Instrument, Face Amount		$ 250,000,000	$ 250,000,000
Debt Instrument, Interest Rate, Stated Percentage		3.20%	3.20%
Senior Notes [Member] | 5.00% Notes Due 2026 [Member]
Debt Instrument [Line Items]
Long term debt		$ 643,978,000	$ 0
Weighted-Average Interest Rate	[1],[4]	5.00%
Debt Instrument, Face Amount		$ 650,000,000	$ 0
Debt Instrument, Interest Rate, Stated Percentage		5.00%	0.00%
Senior Notes [Member] | 6.40% Notes Due 2037 [Member]
Debt Instrument [Line Items]
Long term debt		$ 247,286,000	$ 247,230,000
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]
Long term debt		$ 246,201,000	$ 246,142,000
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]
Long term debt		$ 550,863,000	$ 550,819,000
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]
Long term debt		$ 247,385,000	$ 247,338,000
Weighted-Average Interest Rate	[1]	4.60%
Debt Instrument, Face Amount		$ 250,000,000	$ 250,000,000
Debt Instrument, Interest Rate, Stated Percentage		4.20%	4.20%
Commercial Paper [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Long term debt		$ 23,863,000	$ 279,801,000
Weighted-Average Interest Rate	[1],[4]	0.70%
[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]	ong-term debt is presented net of unamortized debt issuance costs of $18.7 million and $22.9 million at December 31, 2015 and June 30, 2016, respectively.
[3]	These borrowings will mature in October 2016 and are reflected in current debt on our consolidated balance sheets at December 31, 2015 and June 30, 2016.
[4]	These borrowings were outstanding for only a portion of the six-month period ending June 30, 2016. 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 ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 3,800,000,000		$ 3,400,000,000
Debt placement costs	5,408,000	$ 4,734,000
Long term debt	3,824,981,000		3,439,622,000
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Short-term Debt	0		0
Revolving Credit Facility [Member] | Notes Payable to Banks [Member]
Debt Instrument [Line Items]
Borrowing capacity	$ 250,000,000
Unused commitment fee	0.10%
Debt Instrument, Term	364 days
Revolving Credit Facility [Member] | Minimum [Member] | Notes Payable to Banks [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.00%
Unused commitment fee	0.08%
Revolving Credit Facility [Member] | Maximum [Member] | Notes Payable to Banks [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.625%
Unused commitment fee	0.225%
Senior Notes [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Borrowing capacity	$ 1,000,000,000
Unused commitment fee	0.125%
Long term debt	$ 0		0
Obligation for letters of credit	$ 6,300,000		6,300,000
Senior Notes [Member] | Revolving Credit Facility [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.00%
Unused commitment fee	0.10%
Senior Notes [Member] | Revolving Credit Facility [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.625%
Unused commitment fee	0.275%
Senior Notes [Member] | Commercial Paper [Member]
Debt Instrument [Line Items]
Borrowing capacity	$ 1,000,000,000
Long term debt	$ 23,863,000		279,801,000
Senior Notes [Member] | Commercial Paper [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Term	397 days
5.00% Notes Due 2026 [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 650,000,000		$ 0
Debt Instrument, Interest Rate, Stated Percentage	5.00%		0.00%
Notes At Price	99.875%
After Underwriting Discounts	$ 643,800,000
Debt placement costs	5,400,000
Long term debt	$ 643,978,000		$ 0

Derivative Financial Instrume41

Derivative Financial Instruments (Narrative) (Details) $ in Thousands, bbl in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016USD ($)bbl	Jun. 30, 2015USD ($)	Jun. 30, 2016USD ($)bbl	Jun. 30, 2015USD ($)	Dec. 31, 2015USD ($)bbl
Derivative [Line Items]
Energy commodity derivatives deposits, current asset	$ 28,528		$ 28,528		$ 0
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months			(1,200)
Tank bottoms	35,492		35,492		$ 27,533
Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Other Current Liabilities [Member]
Derivative [Line Items]
Derivative, Notional Amount	250,000		250,000
Derivative Liability, Fair Value, Gross Liability	18,600		18,600
Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Other Noncurrent Liabilities [Member]
Derivative [Line Items]
Derivative, Notional Amount	100,000		100,000
Derivative Liability, Fair Value, Gross Liability	1,400		1,400
Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Other Noncurrent Assets [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 400		$ 400
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	$ (17,500)		$ (17,500)		$ (27,900)
Gain (Loss) from Components Excluded from Assessment of Fair Value Hedge Effectiveness, Net	$ 1,900	$ 6,500	$ 4,200	$ 6,300

Derivative Financial Instrume42

Derivative Financial Instruments (Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements) (Details) bbl in Millions	Jun. 30, 2016bbl
Fair Value Hedging [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	0.7
Economic Hedges [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	5.8
Economic Hedges Futures [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	1.2

Derivative Financial Instrume43

Derivative Financial Instruments (Schedule of Derivative Offset Amounts) (Details) - Exchange Traded [Member] - USD ($) $ in Thousands		Jun. 30, 2016		Dec. 31, 2015
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset		$ 9,615		$ 48,367
Derivative Liability, Fair Value, Gross Liability		(2,543)		(5,646)
Derivative Asset, Fair Value, Amount Not Offset Against Collateral		7,072	[1]	42,721	[2]
Derivative, Collateral, Obligation to Return Cash				(24,252)
Derivative, Collateral, Right to Reclaim Cash		28,528
Amount After Offset	[3]	35,600		18,469
Other Noncurrent Assets [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral				3,478
Other Current Assets [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral		7,359		$ 39,243
Other Noncurrent Liabilities [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral		$ (287)
[1]	Net amount includes energy commodity derivative contracts classified as current assets, net, of $7,359 and noncurrent liabilities of $287.
[2]	Net amount includes energy commodity derivative contracts classified as current assets, net, of $39,243 and noncurrent assets of $3,478.
[3]	Amount represents the maximum 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
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Derivative Gains Included in AOCI [Roll Forward]
Beginning balance		$ (42,216)	$ (31,852)	$ (30,126)	$ (16,587)
Net gain (loss) on cash flow hedges	[1]	(8,631)	1,936	(21,109)	(13,529)
Reclassification of net loss (gain) on cash flow hedges to income	[1]	388	388	776	588
Ending balance		$ (50,459)	$ (29,528)	$ (50,459)	$ (29,528)
[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, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on cash flow hedges	[1]	$ (8,631)	$ 1,936	$ (21,109)	$ (13,529)
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		(8,631)	1,936	(21,109)	(13,529)
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)	(388)	(776)	(588)
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net		$ 0	$ 0	$ 0	$ 0
[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, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ (16,533)	$ (33,089)	$ 1,620	$ (29,130)
NYMEX Commodity Contracts [Member] | Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(11,770)	(23,350)	4,212	(19,470)
NYMEX Commodity Contracts [Member] | Operating Expenses [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(8,003)	(8,883)	(5,404)	(7,580)
NYMEX Commodity Contracts [Member] | Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 3,240	$ (856)	$ 2,812	$ (2,080)

Derivative Financial Instrume47

Derivative Financial Instruments (Derivatives and Hedging - Designated) (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 391	$ 5,717
Derivative Liability, Fair Value, Gross Liability	20,261	653
Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		60
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
Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	3,478
Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	287	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	2,179
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	18,595	653
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	391
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	1,379
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	9,615	44,829
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	$ 2,256	$ 5,646

Commitments And Contingencies (

Commitments And Contingencies (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Loss Contingencies [Line Items]
Liabilities recognized for estimated environmental costs	$ 28.7		$ 28.7		$ 31.4
Estimated environmental liabilities, years			9 years
Environmental expenses	0.8	$ 2.9	$ 4.3	$ 4.3
Receivables from insurance carriers related to environmental matters	1.9		1.9		2.6
Accounts Receivable [Member]
Loss Contingencies [Line Items]
Receivables from insurance carriers related to environmental matters	0.8		0.8		0.7
Other Noncurrent Assets [Member]
Loss Contingencies [Line Items]
Receivables from insurance carriers related to environmental matters	$ 1.1		$ 1.1		$ 1.9

Long-Term Incentive Plan (Narra

Long-Term Incentive Plan (Narrative) (Details) - shares	1 Months Ended	6 Months Ended
	Feb. 29, 2016	Jun. 30, 2016
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Limited partners' capital account, units authorized for issuance		11,900,000
Limited partner unitholders, units remaining available		3,000,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	218,046
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	350,552
Director [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Partners' Capital Account, Units, Unit-based Compensation		6,117

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, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	$ 3,409	$ 5,788	$ 10,059	$ 10,539
G&A Expense [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	3,378	5,684	9,986	10,373
Operating Expenses [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	31	104	73	166
Equity Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	3,409	4,912	10,059	9,448
Liability Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	0	876	0	1,091
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		5,664
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		4,573
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		1,091
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	979	860	4,388	2,483
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	979	860	4,388	2,483
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	926	941	2,471	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	926	941	2,471	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	0	0
Performance Based Awards [Member] | Two Thousand Sixteen Awards [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	1,023		2,143
Performance Based Awards [Member] | Two Thousand Sixteen 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	1,023		2,143
Performance Based Awards [Member] | Two Thousand Sixteen 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	481	57	1,057	432
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	481	57	1,057	432
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. 12, 2016	May 13, 2016	Feb. 12, 2016	Nov. 13, 2015	Aug. 14, 2015	May 15, 2015	Feb. 13, 2015	Jun. 30, 2016	Jun. 30, 2015	Sep. 30, 2016	Dec. 31, 2015
Per Unit Cash Distribution Amount		$ 0.8025	$ 0.785	$ 0.7625	$ 0.7400	$ 0.7175	$ 0.6950	$ 1.5875	$ 1.4125		$ 2.915
Total Cash Distribution to Limited Partners		$ 182,797	$ 178,808	$ 173,413	$ 168,296	$ 163,178	$ 158,061	$ 361,605	$ 321,239		$ 662,948
Scenario, Forecast
Per Unit Cash Distribution Amount	$ 0.82									$ 2.4075
Total Cash Distribution to Limited Partners	$ 186,783									$ 548,388

Fair Value (Schedule Of Carryin

Fair Value (Schedule Of Carrying Amounts And Fair Values Of Financial Assets/Liabilities) (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
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	$ 7,072	$ 42,721
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt	(4,161,568)	(3,284,791)
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		1,526
Derivative Liability	(19,583)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivables	19,708	20,021
Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivables	19,708	20,021
Debt	(4,161,568)	(3,284,791)
Estimate of Fair Value Measurement [Member] | NYMEX Commodity Contracts [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	7,072	42,721
Estimate of Fair Value Measurement [Member] | Interest Rate Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset		1,526
Derivative Liability	(19,583)
Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivables	18,134	20,374
Debt	(3,824,981)	(3,439,622)
Reported Value Measurement [Member] | NYMEX Commodity Contracts [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	7,072	42,721
Reported Value Measurement [Member] | Interest Rate Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset		$ 1,526
Derivative Liability	$ (19,583)

Related Party Transactions (Det

Related Party Transactions (Details) - Director [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Targa Resource Partners L P [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party		$ 4	$ 4.7	$ 12.8
Accounts Payable, Related Parties					$ 2
Methvin Company [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party	$ 4.7	$ 2.6	7.7
Accounts Receivable, Related Parties, Current	$ 1.3		$ 1.3		$ 1.3

Subsequent Events (Details)

Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Thousands	Aug. 12, 2016	May 13, 2016	Feb. 12, 2016	Nov. 13, 2015	Aug. 14, 2015	May 15, 2015	Feb. 13, 2015	Jun. 30, 2016	Jun. 30, 2015	Sep. 30, 2016	Dec. 31, 2015
Subsequent Event [Line Items]
Cash distribution per unit		$ 0.8025	$ 0.785	$ 0.7625	$ 0.7400	$ 0.7175	$ 0.6950	$ 1.5875	$ 1.4125		$ 2.915
Total cash distributions		$ 182,797	$ 178,808	$ 173,413	$ 168,296	$ 163,178	$ 158,061	$ 361,605	$ 321,239		$ 662,948
Scenario, Forecast
Subsequent Event [Line Items]
Cash distribution per unit	$ 0.82									$ 2.4075
Total cash distributions	$ 186,783									$ 548,388