Genesis Energy (GEL) 8-K 2 Jul 15 2014 FY Other Events Financial data

Document And Entity Information

Document And Entity Information	12 Months Ended
	Dec. 31, 2014
Document Type	8-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2014
Document Fiscal Year Focus	2,014
Document Fiscal Period Focus	FY
Entity Registrant Name	GENESIS ENERGY LP
Entity Central Index Key	1,022,321
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2014	Dec. 31, 2013
CURRENT ASSETS:
Cash and cash equivalents	$ 9,462	$ 8,866
Accounts receivable—trade, net	271,529	368,033
Inventories	46,829	85,330
Other	27,546	72,994
Total current assets	355,366	535,223
FIXED ASSETS, at cost	1,899,058	1,327,974
Less: Accumulated depreciation	(268,057)	(199,230)
Net fixed assets	1,631,001	1,128,744
NET INVESTMENT IN DIRECT FINANCING LEASES, net of unearned income	145,959	151,903
EQUITY INVESTEES	628,780	620,247
INTANGIBLE ASSETS, net of amortization	82,931	62,928
GOODWILL	325,046	325,046
OTHER ASSETS, net of amortization	61,291	38,111
TOTAL ASSETS	3,230,374	2,862,202
CURRENT LIABILITIES:
Accounts payable—trade	245,405	316,204
Accrued liabilities	117,740	130,349
Total current liabilities	363,145	446,553
SENIOR SECURED CREDIT FACILITY	550,400	582,800
SENIOR UNSECURED NOTES	1,050,639	700,772
DEFERRED TAX LIABILITIES	18,754	15,944
OTHER LONG-TERM LIABILITIES	$ 18,233	$ 18,396
COMMITMENTS AND CONTINGENCIES (Note 19)
PARTNERS’ CAPITAL:
Common unitholders, 95,029,218 and 88,690,985 units issued and outstanding at December 31, 2014 and 2013, respectively	$ 1,229,203	$ 1,097,737
TOTAL LIABILITIES AND PARTNERS’ CAPITAL	$ 3,230,374	$ 2,862,202

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - shares	Dec. 31, 2014	Sep. 26, 2014	Dec. 31, 2013	Sep. 16, 2013
Common units, issued	95,029,218	4,600,000	88,690,985	5,750,000
Common units, outstanding	95,029,218		88,690,985

Consolidated Statements Of Oper

Consolidated Statements Of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Revenues [Abstract]
Pipeline Transportation Services Revenues	$ 86,453	$ 86,508	$ 76,290
Refinery Services Revenues	207,401	205,985	196,017
Marine Transportation Revenues	229,282	152,542	118,204
Supply And Logistics Revenues	3,323,028	3,689,795	2,976,850
Revenues	3,846,164	4,134,830	3,367,361
COSTS AND EXPENSES:
Supply and logistics product costs	3,166,336	3,547,141	2,840,970
Supply and logistics operating costs	110,716	102,187	82,776
Marine transportation operating costs	142,793	104,676	80,547
Refinery services operating costs	121,401	131,289	123,477
Pipeline transportation operating costs	30,767	27,206	21,894
General and administrative	50,692	46,790	41,837
Depreciation and amortization	90,908	64,784	61,150
Total costs and expenses	3,713,613	4,024,073	3,252,651
OPERATING INCOME	132,551	110,757	114,710
Equity in earnings of equity investees	43,135	22,675	14,345
Interest income (expense), net	(66,639)	(48,583)	(40,923)
Income from continuing operations before income taxes	109,047	84,849	88,132
Income tax (expense) benefit	(2,845)	(845)	9,205	[1]
Income from continuing operations	106,202	84,004	97,337
Income (loss) from discontinued operations	0	2,105	(1,018)
NET INCOME	$ 106,202	$ 86,109	$ 96,319
GENESIS ENERGY, L.P. PER COMMON UNIT:
Continuing operations (in dollars per unit)	$ 1.18	$ 1	$ 1.24
Discontinued operations (in dollars per unit)	0	0.03	(0.01)
Net income per common unit (in dollars per unit)	$ 1.18	$ 1.03	$ 1.23
WEIGHTED AVERAGE OUTSTANDING COMMON UNITS:
Basic and Diluted (in units)	90,060	83,957	78,363
[1]	(1)Our discontinued operations had no income tax benefit or expense in any period presented.

Consolidated Statements Of Part

Consolidated Statements Of Partners' Capital - USD ($) $ in Thousands	Total	Number Of Common Units [Member]
Partners' capital, value at Dec. 31, 2011	$ 792,638
Partners' capital, shares at Dec. 31, 2011		71,965,000
Net income (loss)	96,319	$ 0
Cash distributions	(142,383)	$ 0
Issuance of units for cash, shares		5,750,000
Partners' Capital Account, Sale of Units	169,421
Partners' Capital Account, Units, Converted		3,476,000
Partners' Capital Account, Exchanges and Conversions	0
Partners' capital, Other	500	$ 12
Partners' capital, value at Dec. 31, 2012	916,495
Partners' capital, shares at Dec. 31, 2012		81,203,000
Net income (loss)	86,109	$ 0
Cash distributions	(168,441)	$ 0
Issuance of units for cash, shares		5,750,000
Partners' Capital Account, Sale of Units	263,574
Partners' Capital Account, Units, Converted		1,738,000
Partners' Capital Account, Exchanges and Conversions	0
Partners' capital, value at Dec. 31, 2013	$ 1,097,737
Partners' capital, shares at Dec. 31, 2013	88,690,985	88,691,000
Net income (loss)	$ 106,202	$ 0
Cash distributions	(200,461)	$ 0
Issuance of units for cash, shares		4,600,000
Partners' Capital Account, Sale of Units	225,725
Partners' Capital Account, Units, Converted		1,738,000
Partners' Capital Account, Exchanges and Conversions	0
Partners' capital, value at Dec. 31, 2014	$ 1,229,203
Partners' capital, shares at Dec. 31, 2014	95,029,218	95,029,000

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$ 106,202	$ 86,109	$ 96,319
Adjustments to reconcile net income to net cash provided by operating activities -
Amortization and write-off of debt issuance costs and premium	4,785	4,339	4,037
Amortization of unearned income and initial direct costs on direct financing leases	(15,706)	(16,152)	(16,788)
Payments received under direct financing leases	21,235	21,262	21,804
Equity in earnings of investments in equity investees	(43,135)	(22,675)	(14,345)
Cash distributions of earnings of equity investees	57,165	34,132	23,900
Non-cash effect of equity-based compensation plans	4,494	12,473	7,197
Deferred and other tax benefits	1,745	(152)	(9,222)
Unrealized (gains) losses on derivative transactions	(17,984)	1,313	86
Other, net	3,391	(873)	2,085
Net changes in components of operating assets and liabilities, net of acquisitions (See Note 14)	77,954	(46,186)	13,065
Net cash provided by operating activities	291,054	138,386	189,304
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	(443,482)	(343,119)	(146,456)
Cash distributions received from equity investees—return of investment	18,363	12,432	14,909
Investments in equity investees	(40,926)	(94,551)	(63,749)
Acquisitions	(157,000)	(230,880)	(205,576)
Proceeds from asset sales and discontinued operations	272	1,910	773
Other, net	(1,214)	(1,622)	(1,508)
Net cash used in investing activities	(623,987)	(655,830)	(401,607)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	1,839,900	1,593,300	1,674,400
Repayments on senior secured credit facility	(1,872,300)	(1,510,500)	(1,583,700)
Proceeds from issuance of senior unsecured notes, including premium	350,000	350,000	101,000
Debt issuance costs	(11,896)	(8,157)	(7,105)
Issuance of common units for cash, net	225,725	263,574	169,421
Distributions to common unitholders	(200,461)	(168,441)	(142,383)
Other, net	2,561	(4,748)	1,135
Net cash provided by financing activities	333,529	515,028	212,768
Net increase (decrease) in cash and cash equivalents	596	(2,416)	465
Cash and cash equivalents at beginning of period	8,866	11,282	10,817
Cash and cash equivalents at end of period	9,462	8,866	11,282
DepreciationDepletionAndAmortizationIncludingDiscOps	$ 90,908	$ 64,796	$ 61,166

Organization

Organization	12 Months Ended
	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization	1. Organization We are a limited partnership focused on the midstream segment of the oil and gas industry in the Gulf Coast region of the United States, primarily Texas, Louisiana, Arkansas, Mississippi, Alabama, Florida, Wyoming and in the Gulf of Mexico. We have a diverse portfolio of assets, including pipelines, refinery-related plants, storage tanks and terminals, railcars, rail loading and unloading facilities, barges and trucks. We were formed in 1996 and are owned 100% by our limited partners. Genesis Energy, LLC, our general partner, is a wholly-owned subsidiary. Our general partner has sole responsibility for conducting our business and managing our operations. We conduct our operations and own our operating assets through our subsidiaries and joint ventures. In the fourth quarter of 2014, we reorganized our operating segments as a result of a change in the way our Chief Executive Officer, who is our chief operating decision maker, evaluates the performance of operations, develops strategy and allocates resources. The results of our marine transportation activities, formerly reported in the Supply and Logistics Segment, are now reported in our Marine Transportation Segment. In addition, the results of our offshore and onshore pipeline transportation activities, formerly reported in the Pipeline Transportation Segment, are now reported separately in our Onshore Pipeline Transportation Segment and Offshore Pipeline Transportation Segments. As a result of the above changes, we currently manage our businesses through five divisions that constitute our reportable segments – Onshore Pipeline Transportation, Offshore Pipeline Transportation, Refinery Services, Marine Transportation and Supply and Logistics. Our disclosures related to prior periods have been recast to reflect our reorganized segments. These five divisions that constitute our reportable segments consist of the following: • Onshore pipeline transportation of crude oil and, to a lesser extent, carbon dioxide (or “CO2”); • Offshore pipeline transportation of crude oil in the Gulf of Mexico; • Refinery services involving processing of high sulfur (or “sour”) gas streams for refineries to remove the sulfur, and selling the related by-product, sodium hydrosulfide (or “NaHS”, commonly pronounced "nash"); • Marine transportation to provide waterborne transportation of petroleum products and crude oil throughout North America; and • Supply and logistics services, which include terminaling, blending, storing, marketing, and transporting crude oil and petroleum products and, on a smaller scale, CO2.

Summary Of Significant Accounti

Summary Of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Summary Of Significant Accounting Policies	2. Summary of Significant Accounting Policies Basis of Consolidation and Presentation The accompanying financial statements and related notes present our consolidated financial position as of December 31, 2014 and 2013 and our results of operations, changes in partners’ capital and cash flows for the years ended December 31, 2014 , 2013 and 2012 . All intercompany balances and transactions have been eliminated. The accompanying Consolidated Financial Statements include Genesis Energy, L.P. and its subsidiaries. Except per unit amounts, or as noted within the context of each footnote disclosure, the dollar amounts presented in the tabular data within these footnote disclosures are stated in thousands of dollars. Joint Ventures We participate in several joint ventures, including a 50% interest in Cameron Highway Oil Pipeline Company (or “CHOPS”), a 50% interest in Southeast Keathley Canyon Pipeline Company, LLC (or “SEKCO”), a 28% interest in Poseidon Oil Pipeline Company, L.L.C. (or "Poseidon") and a 29% interest in Odyssey Pipeline L.L.C. (or "Odyssey"). We account for our investments in these joint ventures by the equity method of accounting. See Notes 3 and 8 . Use of Estimates The preparation of our Consolidated Financial Statements requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities, if any, at the date of the Consolidated Financial Statements and the reported amounts of revenues and expenses during the reporting period. We based these estimates and assumptions on historical experience and other information that we believed to be reasonable under the circumstances. Significant estimates that we make include: (1) liability and contingency accruals, (2) estimated fair value of assets and liabilities acquired and identification of associated goodwill and intangible assets, (3) estimates of future net cash flows from assets for purposes of determining whether impairment of those assets has occurred, and (4) estimates of future asset retirement obligations. Additionally, for purposes of the calculation of the fair value of awards under equity-based compensation plans, we make estimates regarding the expected life of the rights, expected forfeiture rates of the rights, volatility of our unit price and expected future distribution yield on our units. While we believe these estimates are reasonable, actual results could differ from these estimates. Changes in facts and circumstances may result in revised estimates. Cash and Cash Equivalents Cash and cash equivalents consist of all demand deposits and funds invested in highly liquid instruments with original maturities of three months or less. We have no requirement for compensating balances or restrictions on cash. We periodically assess the financial condition of the institutions where these funds are held and believe that our credit risk is minimal. Accounts Receivable We review our outstanding accounts receivable balances on a regular basis and record an allowance for amounts that we expect will not be fully recovered. Actual balances are not applied against the reserve until substantially all collection efforts have been exhausted. Inventories Our inventories are valued at the lower of cost or market. Cost is determined principally under the average cost method within specific inventory pools. Fixed Assets Property and equipment are carried at cost. Depreciation of property and equipment is provided using the straight-line method over the respective estimated useful lives of the assets. Asset lives are 5 to 40 years for pipelines and related assets, 20 to 30 years for marine vessels, 10 to 20 years for machinery and equipment, 3 to 7 years for transportation equipment, and 3 to 10 years for buildings and improvements, office equipment, furniture and fixtures and other equipment. Interest is capitalized in connection with the construction of major facilities. The capitalized interest is recorded as part of the asset to which it relates and is amortized over the asset’s estimated useful life. Maintenance and repair costs are charged to expense as incurred. Costs incurred for major replacements and upgrades are capitalized and depreciated over the remaining useful life of the asset. Certain volumes of crude oil and refined products are classified in fixed assets, as they are necessary to ensure efficient and uninterrupted operations of the gathering businesses. These crude oil and refined products volumes are carried at their weighted average cost. Long-lived assets are reviewed for impairment. An asset is tested for impairment when events or circumstances indicate that its carrying value may not be recoverable. The carrying value of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to be generated from the use and ultimate disposal of the asset. If the carrying value is determined to not be recoverable under this method, an impairment charge equal to the amount the carrying value exceeds the fair value is recognized. Fair value is generally determined from estimated discounted future net cash flows. Deferred Charges on Marine Transportation Assets Our marine vessels are required by US Coast Guard regulations to be re-certified after a certain period of time, usually every five years. The US Coast Guard states that vessels must meet specified "seaworthiness" standards to maintain required operating certificates. To meet such standards, vessels must undergo regular inspection, monitoring, and maintenance, referred to as "dry-docking." Typical dry-docking costs include costs incurred to comply with regulatory and vessel classification inspection requirements, blasting and steel coating, and steel replacement. We defer and amortize these costs to maintenance and repair expense over the length of time that the certification is supposed to last. Asset Retirement Obligations Some of our assets have contractual or regulatory obligations to perform dismantlement and removal activities, and in some instances remediation, when the assets are abandoned. In general, our future asset retirement obligations relate to future costs associated with the removal of our oil and CO 2 pipelines, barge decommissioning, removal of equipment and facilities from leased acreage and land restoration. The fair value of a liability for an asset retirement obligation is recorded in the period in which it is incurred, discounted to its present value using our credit adjusted risk-free interest rate, and a corresponding amount capitalized by increasing the carrying amount of the related long-lived asset. The capitalized cost is depreciated over the useful life of the related asset. Accretion of the discount increases the liability and is recorded to expense. See Note 6 . Direct Financing Leasing Arrangements For our direct financing leases, we record the gross finance receivable, unearned income and the estimated residual value of the leased pipelines. Unearned income represents the excess of the gross receivable plus the estimated residual value over the costs of the pipelines. Unearned income is recognized as financing income using the interest method over the term of the transaction and is included in pipeline transportation services revenue in the Consolidated Statements of Operations. The pipeline cost is not included in fixed assets. We review our direct financing lease arrangements for credit risk. Such review includes consideration of the credit rating and financial position of the lessee. See Note 7 . CO 2 Assets Our CO 2 assets include three volumetric production payments, which are amortized on a units-of-production method. These assets are included in Other Assets in our Consolidated Balance Sheets. See Note 9 . Intangible and Other Assets Intangible assets with finite useful lives are amortized over their respective estimated useful lives. If an intangible asset has a finite useful life, but the precise length of that life is not known, that intangible asset shall be amortized over the best estimate of its useful life. At a minimum, we will assess the useful lives and residual values of all intangible assets on an annual basis to determine if adjustments are required. We are amortizing our customer and supplier relationships, contract agreements, licensing agreements and trade name based on the period over which the asset is expected to contribute to our future cash flows. Generally, the contribution of these assets to our cash flows is expected to decline over time, such that greater value is attributable to the periods shortly after the acquisition was made. Intangible assets associated with lease or other items are being amortized on a straight-line basis. We test intangible assets periodically to determine if impairment has occurred. An impairment loss is recognized for intangibles if the carrying amount of an intangible asset is not recoverable and its carrying amount exceeds its fair value. No impairment has occurred of intangible assets in any of the periods presented. Costs incurred in connection with the issuance of long-term debt and certain amendments to our credit facilities are capitalized and amortized using the straight-line method over the term of the related debt. Use of the straight-line method does not differ materially from the “effective interest” method of amortization. Goodwill Goodwill represents the excess of purchase price over fair value of net assets acquired. We evaluate, and test if necessary, goodwill for impairment annually at October 1, and more frequently if indicators of impairment are present. During evaluation, we perform a qualitative assessment of relevant events and circumstances to determine the likelihood of goodwill impairment. If it is deemed more likely than not that the fair value of the reporting unit is less than its carrying amount, we calculate the fair value of the reporting unit. Otherwise, further testing is not necessary. If the calculated fair value of the reporting unit exceeds its book value including associated goodwill amounts, the goodwill is considered to be unimpaired and no impairment charge is required. If the fair value of the reporting unit is less than its book value including associated goodwill amounts, a charge to earnings may be necessary to reduce the carrying value of the goodwill to its implied fair value. In the event that we determine that goodwill has become impaired, we will incur a charge for the amount of impairment during the period in which the determination is made. No goodwill impairment has occurred in any of the periods presented. See Note 9 for further information. Environmental Liabilities We provide for the estimated costs of environmental contingencies when liabilities are probable to occur and a reasonable estimate of the associated costs can be made. Ongoing environmental compliance costs, including maintenance and monitoring costs, are charged to expense as incurred. Equity-Based Compensation Our stock appreciation rights plan and phantom units issued under our 2010 Long-Term Incentive Plan result in the payment of cash to our employees or directors of our general partner upon exercise or vesting of the related award. The fair values of our equity-based awards are re-measured at the end of each reporting period and are recorded as liabilities. The liability and related compensation cost for our stock appreciation rights are calculated using a Black-Scholes option pricing model that takes into consideration the expected future value of the rights at their expected exercise dates and management’s assumptions about expectation of forfeitures prior to vesting. The fair value of our phantom units is equal to the market price of our common units. Our phantom units include both service-based and performance-based awards. For our performance-based awards, our fair value estimates are weighted based on probabilities for each performance condition applicable to the award. See Note 15 for more information on these plans. Revenue Recognition Product Sales—Revenues from the sale of crude oil, petroleum products and CO 2 by our supply and logistics segment, and caustic soda and NaHS by our refinery services segment are recognized when title to the inventory is transferred to the customer, pricing is fixed and determinable, collectibility is reasonably assured and there are no further significant obligations for future performance by us. Most frequently, title transfers upon our delivery of the inventory to the customer at a location designated by the customer, although in certain situations, title transfers when the inventory is loaded for transportation to the customer. Our crude oil and petroleum products are typically sold at prices based off daily or monthly published prices. Many of our contracts for sales of NaHS incorporate the price of caustic soda in the pricing formulas. Marine Transportation—Revenues from the inland and offshore marine transportation of heavy refined petroleum products, including asphalt and crude oil, via our barges or vessels are recognized over the transit time of individual shipments as determined on an individual contract basis. Revenue from these contracts is typically based on a set day rate or a set fee per cargo movement. The costs of fuel, substantially all of which is a pass through expense, and other specified operational costs are directly reimbursed by the customer under most of these contracts. Rail Facility Loading and Unloading Revenues—Revenues based on a per barrel fee from the loading and/or unloading of crude oil at our rail facilities is recognized as the crude oil enters or exits the railcars. Pipeline Transportation—Revenues from transportation of crude oil by our pipelines are based on actual volumes at a published tariff. Tariff revenues are recognized either at the point of delivery or at the point of receipt pursuant to the specifications outlined in our regulated tariffs. In order to compensate us for bearing the risk of volumetric losses in volumes that occur to crude oil in our pipelines due to temperature, crude quality and the inherent difficulties of measurement of liquids in a pipeline, our tariffs include the right for us to make volumetric deductions from the shippers for quality and volumetric fluctuations. We refer to these deductions as pipeline loss allowances. We compare these allowances to the actual volumetric gains and losses of the pipeline and the net gain or loss is recorded as revenue or a reduction of revenue, based on prevailing market prices at that time. When net gains occur, we have crude oil inventory. When net losses occur, we reduce any recorded inventory on hand and record a liability for the purchase of crude oil that we must make to replace the lost volumes. We reflect inventories in the Consolidated Financial Statements at the lower of the recorded value or the market value at the balance sheet date. We value liabilities to replace crude oil at current market prices. The crude oil in inventory can then be sold, resulting in additional revenue if the sales price exceeds the inventory value. Income from direct financing leases is being recognized ratably over the term of the leases and is included in pipeline revenues. Cost of Sales and Operating Expenses Supply and logistics costs and expenses include the cost to acquire the product and the associated costs to transport it to our terminal facilities or to a customer for sale. Other than the cost of the products, the most significant costs we incur relate to transportation utilizing our fleet of trucks, railcars and barges, including personnel costs, fuel and maintenance of our equipment. When we enter into buy/sell arrangements concurrently or in contemplation of one another with a single counterparty, we reflect the amounts of revenues and purchases for these transactions on a net basis in our Consolidated Statements of Operations as supply and logistics revenues. Marine operating costs consist primarily of employee and related costs to man the boats, barges, and vessels, maintenance and supply costs related to general upkeep of the boats, barges, and vessels, and fuel costs which are rebillable and passed through to the customer. The most significant operating costs in our refinery services segment consist of the costs to operate NaHS plants located at various refineries, caustic soda used in the process of processing the refiner’s sour gas stream, and costs to transport the NaHS and caustic soda. Pipeline operating costs consist primarily of power costs to operate pumping equipment, personnel costs to operate the pipelines, insurance costs and costs associated with maintaining the integrity of our pipelines. Excise and Sales Taxes We collect and remit excise and sales taxes to state and federal governmental authorities on its sales of fuels. These taxes are presented on a net basis, with any differences due to rebates allowed by those governmental entities reflected as a reduction of product cost in the Consolidated Statements of Operations. Income Taxes We are a limited partnership, organized as a pass-through entity for federal income tax purposes. As such, we do not directly pay federal income tax. Our taxable income or loss, which may vary substantially from the net income or net loss we report in our Consolidated Statements of Operations, is included in the federal income tax returns of each partner. Some of our corporate subsidiaries pay U.S. federal, state, and foreign income taxes. Deferred income tax assets and liabilities for certain operations conducted through corporations are recognized for temporary differences between the assets and liabilities for financial reporting and tax purposes. Changes in tax legislation are included in the relevant computations in the period in which such changes are effective. Deferred tax assets are reduced by a valuation allowance for the amount of any tax benefit not expected to be realized. Penalties and interest related to income taxes will be included in income tax expense in the Consolidated Statements of Operations. Derivative Instruments and Hedging Activities When we hold inventory positions in crude oil and petroleum products, we use derivative instruments to hedge exposure to price risk. Derivative transactions, which can include forward contracts and futures positions on the NYMEX, are recorded in the Consolidated Balance Sheets as assets and liabilities based on the derivative’s fair value. Changes in the fair value of derivative contracts are recognized currently in earnings unless specific hedge accounting criteria are met. We must formally designate the derivative as a hedge and document and assess the effectiveness of derivatives associated with transactions that receive hedge accounting. Accordingly, changes in the fair value of derivatives are included in earnings in the current period for (i) derivatives accounted for as fair value hedges; (ii) derivatives that do not qualify for hedge accounting and (iii) the portion of cash flow hedges that is not highly effective in offsetting changes in cash flows of hedged items. Changes in the fair value of cash flow hedges are deferred in Accumulated Other Comprehensive Income (“AOCI”) and reclassified into earnings when the underlying position affects earnings. See Note 17 . Fair Value of Current Assets and Current Liabilities The carrying amount of other current assets and other current liabilities approximates their fair value due to their short-term nature. Net Income Per Common Unit Basic and diluted net income per common unit is determined by dividing net income attributable to limited partners by the weighted average number of outstanding common units during the period. Prior Period Reclassifications Certain prior period amounts have been reclassified to conform to the current period presentation, including our expanded presentation of "Revenues" and "Costs and Expenses" on our Consolidated Statements of Operations and expanded presentation in Note 1 2 relating to our change in segment reporting as previously discussed in Note 1 . Recent and Proposed Accounting Pronouncements In May 2014, the Financial Accounting Standards Board ("FASB") issued revised guidance on revenue from contracts with customers that will supersede most current revenue recognition guidance, including industry-specific guidance. The core principle of the revenue model is that an entity will recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The new standard provides a five-step analysis for transactions to determine when and how revenue is recognized. The guidance will be effective for us beginning January 1, 2017 and early adoption is not permitted. The guidance permits the use of either a full retrospective or a modified retrospective approach. We are evaluating the transition methods and the impact of the amended guidance on our financial position, results of operations and related disclosures.

Acquisitions and Divestitures A

Acquisitions and Divestitures Acquisitions and Divestitures (Notes)	12 Months Ended
	Dec. 31, 2014
Acquisitions and Divestitures [Abstract]
Acquisitions And Divestitures	3. Acquisitions and Divestitures Acquisitions M/T American Phoenix On November 13, 2014 , we acquired the M/T American Phoenix from Mid Ocean Tanker Company for $157 million . The M/T American Phoenix is a modern double-hulled, Jones Act qualified tanker with 330,000 barrels of cargo capacity that was placed into service during 2012. The purchase price of $157 million was paid to Mid Ocean Tanker Company in cash, as funded with proceeds from available and committed liquidity under our $1 billion revolving credit facility. We have reflected the financial results of the acquired business in our marine transportation segment from the date of acquisition. We have recorded the assets acquired in the Consolidated Financial Statements at their fair values. Those fair values were developed by management. The allocation of the purchase price, as presented on our Consolidated Balance Sheet, is summarized as follows: Property and equipment $ 125,000 Intangible assets 32,000 Total purchase price $ 157,000 Our Consolidated Financial Statements include the results of our acquired offshore marine transportation business since November 13, 2014 , the effective closing date of the acquisition. The following table presents selected financial information included in our Consolidated Financial Statements for the periods presented: Year Ended 2014 Revenues $ 3,038 Net income $ 454 The table below presents selected unaudited pro forma financial information for us incorporating the historical results of the acquired M/T American Phoenix. The pro forma financial information below has been prepared as if the acquisition had been completed on January 1, 2013 and is based upon assumptions deemed appropriate by us and may not be indicative of actual results. Depreciation expense for the fixed assets acquired is calculated on a straight-line basis over an estimated useful life of approximately 30 years. Year Ended 2014 2013 Pro forma earnings data: Revenues from continuing operations $ 3,863,745 $ 4,153,443 Net Income $ 111,132 $ 90,829 Offshore Marine Transportation Business In August 2013 , we acquired substantially all of the assets of the downstream transportation business of Hornbeck Offshore Services, Inc. for $230.9 million , which we refer to as our offshore marine transportation business and assets. The total acquisition cost of $230.9 million was allocated to fixed assets on our Consolidated Balance Sheet. The acquired business was primarily comprised of nine barges and nine tug boats that transport crude oil and refined petroleum products, principally serving refineries and storage terminals along the Gulf Coast, Eastern Seaboard, Great Lakes and Caribbean. That acquisition was funded with proceeds from our $1 billion revolving credit facility. We have reflected the financial results of the acquired business in our marine segment from the date of the acquisition. Our Consolidated Financial Statements include the results of our acquired offshore marine transportation business since August 28, 2013 , the effective closing date of that acquisition. The following table presents selected financial information included in our Consolidated Financial Statements for the periods presented: Year Ended 2013 Revenues $ 30,424 Net income $ 7,348 The table below presents selected unaudited pro forma financial information for us incorporating the historical results of our offshore marine transportation business. The pro forma financial information below has been prepared as if the acquisition had been completed on January 1, 2012 and is based upon assumptions deemed appropriate by us and may not be indicative of actual results. Depreciation expense for the fixed assets acquired is calculated on a straight-line basis over an estimated useful life of approximately 25 years. Year Ended 2013 2012 Pro forma earnings data: Revenues from continuing operations $ 4,177,715 $ 3,416,790 Net Income $ 98,846 $ 98,665 Interests in Gulf of Mexico Crude Oil Pipeline Systems On January 3, 2012 , we acquired from Marathon Oil Company interests in several Gulf of Mexico crude oil pipeline systems. The acquired pipeline interests include a 28% interest in Poseidon Oil Pipeline Company, L.L.C., a 100% interest in Marathon Offshore Pipeline, LLC (subsequently re-named GEL Offshore Pipeline, LLC, or “GOPL”) and a 29% interest in Odyssey Pipeline L.L.C. GOPL owns a 23% interest in the Eugene Island crude oil pipeline system and a 100% interest in two smaller offshore pipelines. The purchase price, net of post-closing adjustments, was $205.6 million . We funded the purchase price with cash available under our credit facility. We account for our interests in Poseidon and Odyssey under the equity method of accounting. We have recorded the assets acquired and liabilities assumed of GOPL in the Consolidated Financial Statements at their estimated fair values. Such fair values were developed by management. Our Consolidated Financial Statements include the results of the acquired pipeline interests since the effective closing date of the acquisition in January 2012 . The following table presents selected financial information included in our Consolidated Financial Statements for the year ended December 31, 2012 : Year Ended 2012 Revenues $ 5,508 Equity in earnings of equity investees $ 13,118 Net income $ 15,112 Divestitures On December 31, 2013 we sold our vehicle fuel procurement and delivery logistics management services business. We sold the business for $ 1 million and recorded a gain on the sale of approximately $ 0.9 million , included in Income (loss) from discontinued operations on the Consolidated Statements of Operations. That business, previously reported in our supply and logistics revenues and costs and expenses, was reclassified as discontinued operations in our Consolidated Statements of Operations for the years ended December 31, 2013 and 2012. The summarized operating results of our discontinued operations are as follows: Year Ended 2013 2012 Revenues $ 593,733 $ 702,695 Cost and expenses 592,505 703,715 Operating income (loss) 1,228 (1,020 ) Interest income 2 2 Income (loss) before income taxes 1,230 (1,018 ) Gain on sale of discontinued operations 875 — Income (loss) from discontinued operations $ 2,105 $ (1,018 )

Receivables

Receivables	12 Months Ended
	Dec. 31, 2014
Accounts Receivable, Net, Current [Abstract]
Receivables	Receivables Accounts receivable – trade, net consisted of the following: December 31, 2014 2013 Accounts receivable - trade $ 274,502 $ 369,559 Allowance for doubtful accounts (2,973 ) (1,526 ) Accounts receivable - trade, net $ 271,529 $ 368,033 The following table presents the activity of our allowance for doubtful accounts for the periods indicated: December 31, 2014 2013 2012 Balance at beginning of period $ 1,526 $ 2,372 $ 1,044 (Credited) charged to costs and expenses 1,447 (86 ) 2,096 Amounts written off — (760 ) (768 ) Balance at end of period $ 2,973 $ 1,526 $ 2,372

Inventories

Inventories	12 Months Ended
	Dec. 31, 2014
Inventory Disclosure [Abstract]
Inventories	5. Inventories The major components of inventories were as follows: December 31, 2014 2013 Petroleum products $ 30,108 $ 71,373 Crude oil 7,266 5,380 Caustic soda 2,850 2,679 NaHS 6,603 5,845 Other 2 53 Total $ 46,829 $ 85,330 Inventories are valued at the lower of cost or market. The market value of inventories was below recorded costs by approximately $6.6 million at December 31, 2014 ; therefore we reduced the value of inventory in our Condensed Consolidated Financial Statements for this difference. At December 31, 2013 , market values of our inventory exceeded recorded costs.

Fixed Assets and Asset Retireme

Fixed Assets and Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2014
Fixed Assets And Asset Retirement Obligations [Abstract]
Fixed Assets and Asset Retirement Obligations	6. Fixed Assets and Asset Retirement Obligations Fixed Assets Fixed assets consisted of the following: December 31, 2014 2013 Pipelines and related assets $ 466,613 $ 338,920 Machinery and equipment 376,672 173,092 Transportation equipment 18,479 19,140 Marine vessels 731,016 554,679 Land, buildings and improvements 38,037 30,170 Office equipment, furniture and fixtures 6,696 5,633 Construction in progress 222,233 183,037 Other 39,312 23,303 Fixed assets, at cost 1,899,058 1,327,974 Less: Accumulated depreciation (268,057 ) (199,230 ) Net fixed assets $ 1,631,001 $ 1,128,744 Depreciation expense was $73.2 million , $46.3 million and $37.4 million for the years ended December 31, 2014 , 2013 , and 2012 , respectively. Asset Retirement Obligations A reconciliation of our liability for asset retirement obligations is as follows: December 31, 2012 $ 12,695 Liabilities incurred 789 Accretion expense 848 December 31, 2013 14,332 Liabilities incurred — Accretion expense 458 December 31, 2014 $ 14,790

Net Investment In Direct Financ

Net Investment In Direct Financing Leases	12 Months Ended
	Dec. 31, 2014
Leases [Abstract]
Net Investment In Direct Financing Leases	7. Net Investment in Direct Financing Leases Our direct financing leases include a lease of the Northeast Jackson Dome (“NEJD”) Pipeline. Under the terms of the agreement, we are paid quarterly payments, which commenced August 2008 . These quarterly payments are fixed at approximately $20.7 million per year during the lease term at an interest rate of 10.25% . At the end of the lease term in 2028 , we will convey all of our interests in the NEJD Pipeline to the lessee for a nominal payment. There are requirements in our leases that would provide credit support should the credit rating of our lessee fall to certain levels. The following table lists the components of the net investment in direct financing leases: December 31, 2014 2013 Total minimum lease payments to be received $ 277,732 $ 298,924 Estimated residual values of leased property (unguaranteed) 292 292 Unamortized initial direct costs 1,444 1,621 Less unearned income (127,531 ) (143,415 ) Net investment in direct financing leases 151,937 157,422 Less current portion (included in other current assets) (5,978 ) (5,519 ) Long-term portion of net investment in direct financing leases $ 145,959 $ 151,903 At December 31, 2014 , minimum lease payments to be received for each of the five succeeding fiscal years are $20.7 million .

Equity Investees

Equity Investees	12 Months Ended
	Dec. 31, 2014
Equity Method Investments and Joint Ventures [Abstract]
Equity Investees	8. Equity Investees We account for our ownership in our joint ventures under the equity method of accounting (see Note 2 for a description of these investments). The price we pay to acquire an ownership interest in a company may exceed the underlying book value of the capital accounts we acquire. Such excess cost amounts are included within the carrying values of our equity investees. At December 31, 2014 and 2013 , the unamortized excess cost amounts totaled $215.4 million and $225.7 million , respectively. We amortize the excess cost as a reduction in equity earnings in a manner similar to depreciation. The following table presents information included in our Consolidated Financial Statements related to our equity investees. Year Ended December 31, 2014 2013 2012 Genesis’ share of operating earnings $ 53,783 $ 33,152 $ 24,532 Amortization of excess purchase price (10,648 ) (10,477 ) (10,187 ) Net equity in earnings $ 43,135 $ 22,675 $ 14,345 Distributions received $ 75,528 $ 46,564 $ 38,809 The following tables present the combined balance sheet information for the last two years and income statement data for the last three years for our equity investees (on a 100% basis): December 31, 2014 2013 BALANCE SHEET DATA: Assets Current assets $ 42,135 $ 70,921 Fixed assets, net 1,015,305 1,028,808 Other assets 4,369 6,823 Total assets $ 1,061,809 $ 1,106,552 Liabilities and equity Current liabilities $ 25,369 $ 55,918 Other liabilities 202,613 190,578 Equity 833,827 860,056 Total liabilities and equity $ 1,061,809 $ 1,106,552 Year Ended December 31, 2014 2013 2012 INCOME STATEMENT DATA: Revenues $ 246,265 $ 183,533 $ 162,267 Operating Income $ 146,760 $ 102,107 $ 80,841 Net Income $ 142,754 $ 99,357 $ 77,975

Intangible Assets, Goodwill And

Intangible Assets, Goodwill And Other Assets	12 Months Ended
	Dec. 31, 2014
Goodwill and Intangible Assets Disclosure [Abstract]
Intangible Assets, Goodwill And Other Assets	9. Intangible Assets, Goodwill and Other Assets Intangible Assets The following table reflects the components of intangible assets being amortized at December 31, 2014 and 2013 : December 31, 2014 December 31, 2013 Weighted Amortization Period in Years Gross Carrying Amount Accumulated Amortization Carrying Value Gross Carrying Amount Accumulated Amortization Carrying Value Refinery Services: Customer relationships 5 $ 94,654 $ 81,880 $ 12,774 $ 94,654 $ 76,283 $ 18,371 Licensing agreements 6 38,678 28,983 9,695 38,678 26,055 12,623 Segment total 133,332 110,863 22,469 133,332 102,338 30,994 Supply & Logistics: Customer relationships 5 35,430 30,228 5,202 35,430 28,568 6,862 Intangibles associated with lease 15 13,260 3,512 9,748 13,260 3,039 10,221 Segment total 48,690 33,740 14,950 48,690 31,607 17,083 Marine contract intangibles 5 32,000 833 31,167 — — — Other 5 22,797 8,452 14,345 21,356 6,505 14,851 Total $ 236,819 $ 153,888 $ 82,931 $ 203,378 $ 140,450 $ 62,928 The licensing agreements referred to in the table above relate to the agreements we have with refiners to provide services. The supply and logistics lease relates to a terminal facility in Shreveport, Louisiana. The marine contract intangibles relate to the contracts we assumed in the purchase of the M/T American Phoenix in November 2014. We are recording amortization of our intangible assets based on the period over which the asset is expected to contribute to our future cash flows. Generally, the contribution to our cash flows of the customer and supplier relationships, licensing agreements and trade name intangible assets is expected to decline over time, such that greater value is attributable to the periods shortly after the acquisition was made. The supply and logistics lease, marine contract, and other intangible assets are being amortized on a straight-line basis. Amortization expense on intangible assets was $13.4 million , $14.6 million and $19.9 million for the years ended December 31, 2014 , 2013 and 2012 , respectively. The following table reflects our estimated amortization expense for each of the five subsequent fiscal years: 2015 2016 2017 2018 2019 Refinery Services: Customer relationships $ 4,405 $ 3,471 $ 2,737 $ 2,161 $ — Licensing agreements 2,711 2,510 2,324 2,150 — Supply and Logistics: Customer relationships 1,275 981 757 586 454 Intangibles associated with lease 474 474 474 474 474 Marine contract intangibles 6,417 5,400 5,400 5,400 5,400 Other 2,057 2,025 2,006 2,006 2,006 Total $ 17,339 $ 14,861 $ 13,698 $ 12,777 $ 8,334 Goodwill The carrying amount of goodwill by business segment at both December 31, 2014 and 2013 was $301.9 million in refinery services and $23.1 million in supply and logistics. We have not recognized any impairment losses related to goodwill for any of the periods presented. Other Assets Other assets consisted of the following: December 31, 2014 2013 CO 2 volumetric production payments, net of amortization $ 9,395 $ 4,421 Deferred marine charges (1) 13,042 2,829 Other deferred costs and deposits 38,854 30,861 Other assets, net of amortization $ 61,291 $ 38,111 (1) See discussion of deferred charges on marine transportation assets in the Summary of Accounting Policies ( Note 2 ) The CO 2 assets are being amortized on a units-of-production method. We recorded amortization of $4.2 million in 2014 , $3.9 million in 2013 and $3.8 million in 2012 .

Debt

Debt	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Debt	10. Debt At December 31, 2014 and 2013 , our obligations under debt arrangements consisted of the following: December 31, 2014 2013 Senior secured credit facility $ 550,400 $ 582,800 7.875% senior unsecured notes (including unamortized premium of $639 and $772 in 2014 and 2013, respectively) 350,639 350,772 5.750% senior unsecured notes $ 350,000 350,000 5.625% senior unsecured notes $ 350,000 — Total long-term debt $ 1,601,039 $ 1,283,572 Senior Secured Credit Facility In June 2014 , we amended and restated our $1 billion senior secured credit facility with a syndicate of banks to, among other things, extend the term of our credit facility to July 25, 2019 . Additionally, the accordion feature was increased from $300 million to $500 million , giving us the ability to expand the size of the facility up to an aggregate $1.5 billion for acquisitions or internal growth projects, subject to lender consent. Our credit facility includes an inventory financing sublimit of $150 million . The key terms for rates under our credit facility, which are dependent on our leverage ratio (as defined in the credit agreement), are as follows: • The interest rate on borrowings may be based on an alternate base rate or a Eurodollar rate, at our option. The alternate base rate is equal to the sum of (a) the greatest of (i) the prime rate as established by the administrative agent for the credit facility, (ii) the federal funds effective rate plus 0.5% of 1% and (iii) the LIBOR rate for a one-month maturity plus 1% and (b) the applicable margin. The Eurodollar rate is equal to the sum of (a) the LIBOR rate for the applicable interest period multiplied by the statutory reserve rate and (b) the applicable margin. The applicable margin varies from 1.50% to 2.50% on Eurodollar borrowings and from 0.50% to 1.50% on alternate base rate borrowings, depending on our leverage ratio. Our leverage ratio is recalculated quarterly and in connection with each material acquisition. At December 31, 2014 , the applicable margins on our borrowings were 1.25% for alternate base rate borrowings and 2.25% for Eurodollar rate borrowings. • Letter of credit fees range from 1.50% to 2.50% based on our leverage ratio as computed under the credit facility. The rate can fluctuate quarterly. At December 31, 2014 , our letter of credit rate was 2.25% . • We pay a commitment fee on the unused portion of the $1 billion maximum facility amount. The commitment fee on the unused committed amount will range from 0.250% to 0.375% per annum depending on our leverage ratio ( 0.375% at December 31, 2014 ). Our credit facility is secured by liens on a substantial portion of our assets, and by guarantees by all of our restricted subsidiaries (as defined in the credit facility). Our credit facility contains customary covenants (affirmative, negative and financial) that could limit the manner in which we may conduct our business. As defined in our credit facility, we are required to meet three primary financial metrics—a maximum leverage ratio, a maximum senior secured leverage ratio and a minimum interest coverage ratio. Our credit agreement provides for the temporary inclusion of certain pro forma adjustments to the calculations of the required ratios following material acquisitions. In general, our leverage ratio calculation compares our consolidated funded debt (including outstanding notes we have issued) to EBITDA (as defined and adjusted in accordance with the credit facility) and cannot exceed 5.00 to 1.00 ( 5.50 to 1.00 in an acquisition period). Our senior secured leverage ratio excludes outstanding debt under senior unsecured notes and cannot exceed 3.75 to 1.00 ( 4.25 to 1.00 in an acquisition period). Our interest coverage ratio calculation compares EBITDA (as defined and adjusted in accordance with the credit facility) to interest expense and must be greater than 3.00 to 1.00 ( 2.75 to 1.00 during an acquisition period). At December 31, 2014 , we had $550.4 million borrowed under our credit facility, with $45.0 million of the borrowed amount designated as a loan under the inventory sublimit. The credit agreement allows up to $100 million of the capacity to be used for letters of credit, of which $10.8 million was outstanding at December 31, 2014 . Due to the revolving nature of loans under our credit facility, additional borrowings and periodic repayments and re-borrowings may be made until the maturity date of July 25, 2019 . The total amount available for borrowings under our credit facility at December 31, 2014 was $438.8 million . Senior Unsecured Notes In November 2010, we issued $250 million in aggregate principal amount of 7.875% senior unsecured notes due December 15, 2018 (the "2018 Notes"). The 2018 Notes were sold at face value. Interest payments are due on June 15 and December 15 of each year. In February 2012 , we issued an additional $100 million of aggregate principal amount of additional 2018 Notes. The additional 2018 Notes were issued at 101% of face value at an effective interest rate of 7.682% . The additional 2018 Notes have the same terms and conditions as the notes previously issued under the indenture. The issuance increased the total aggregate principal amount of the 2018 Notes to $350 million . On February 8, 2013 , we issued $350 million of aggregate principal amount of 5.75% senior unsecured notes (the "2021 Notes"). The 2021 Notes were sold at face value. Interest payments are due on February 15 and August 15 of each year. The 2021 Notes mature on February 15, 2021 . The net proceeds were used to repay borrowings under our credit facility and for general partnership purposes. On May 15, 2014 , we issued $350 million in aggregate principal amount of 5.625% senior unsecured notes (the "2024 Notes"). The 2024 Notes were sold at face value. Interest payments are due on June 15 and December 15 of each year with the initial interest payment due December 15, 2014. The 2024 Notes mature on June 15, 2024 . The 2018, 2021 and 2024 Notes were co-issued by Genesis Energy Finance Corporation (which has no independent assets or operations) and are each fully and unconditionally guaranteed, subject to customary exceptions pursuant to the indentures governing our 2018, 2021 and 2024 Notes, as discussed below, jointly and severally, by certain of our wholly-owned subsidiaries. We have the right to redeem the 2018 Notes at any time after December 15, 2014, at a premium to the face amount of the notes that varies based on the time remaining to maturity of the 2018 Notes. We have the right to redeem the 2021 Notes at any time after February 15, 2017, at a premium to the face amount of the 2021 Notes that varies based on the time remaining to maturity on the 2021 Notes. Prior to February 15, 2016, we may also redeem up to 35% of the principal amount of the 2021 Notes for 105.75% of the face amount with the proceeds from an equity offering of our common units. We have the right to redeem the 2024 Notes at any time after June 15, 2019, at a premium to the face amount of the 2024 Notes that varies based on the time remaining to maturity on the 2024 Notes. Prior to June 15, 2017, we may also redeem up to 35% of the principal amount of the 2024 Notes for 105.625% of the face amount with the proceeds from an equity offering of our common units. Guarantees of the 2018, 2021 and 2024 Notes will be released under certain circumstances, including (i) in connection with any sale or other disposition of (a) all or substantially all of the properties or assets of a guarantor (including by way of merger or consolidation) or (b) all of the capital stock of such guarantor, in each case, to a person that is not a restricted subsidiary of the Partnership (ii) if the Partnership designates any restricted subsidiary that is a guarantor as an unrestricted subsidiary, (iii) upon legal defeasance, covenant defeasance or satisfaction and discharge of the applicable indenture, (iv) upon the liquidation or dissolution of such guarantor, or (v) at such time as such guarantor ceases to guarantee any other indebtedness of either of the issuers and any other guarantor. Covenants and Compliance Our credit agreement and the indenture governing the senior notes contain cross-default provisions. Our credit documents prohibit distributions on, or purchases or redemptions of, units if any default or event of default is continuing. In addition, those agreements contain various covenants limiting our ability to, among other things: • incur indebtedness if certain financial ratios are not maintained; • grant liens; • engage in sale-leaseback transactions; and • sell substantially all of our assets or enter into a merger or consolidation. A default under our credit documents would permit the lenders thereunder to accelerate the maturity of the outstanding debt. As long as we are in compliance with our credit facility, our ability to make distributions of “available cash” is not restricted. As of December 31, 2014 , we were in compliance with the financial covenants contained in our credit facility and indenture.

Partners' Capital and Distribut

Partners' Capital and Distributions	12 Months Ended
	Dec. 31, 2014
Partners' Capital Notes [Abstract]
Partners' Capital And Distributions	11. Partners’ Capital and Distributions At December 31, 2014 , our outstanding equity consisted of 94,989,221 Class A common units and 39,997 Class B common units. The Class A units are traditional common units in us. The Class B units are identical to the Class A units and, accordingly, have voting and distribution rights equivalent to those of the Class A units, and, in addition, the Class B units have the right to elect all of our board of directors and are convertible into Class A units under certain circumstances, subject to certain exceptions. Our outstanding equity also included non-voting securities -- waiver units -- that were entitled to a minimal quarterly distribution until conversion into Class A common units at a 1 to 1 ratio. As of December 31, 2014, all of our waiver units had been converted into common units. Distributions Generally, we will distribute 100% of our available cash (as defined by our partnership agreement) within 45 days after the end of each quarter to unitholders of record. Available cash consists generally of all of our cash receipts less cash disbursements adjusted for net changes to reserves. We paid distributions in 2015 , 2014 and 2013 as follows: Distribution For Date Paid Per Unit Amount Total Amount 2012 4th Quarter February 14, 2013 $ 0.4850 $ 39,390 2013 1st Quarter May 15, 2013 $ 0.4975 $ 40,405 2nd Quarter August 14, 2013 $ 0.5100 $ 42,302 3rd Quarter November 14, 2013 $ 0.5225 $ 46,344 4th Quarter February 14, 2014 $ 0.5350 $ 47,453 2014 1st Quarter May 15, 2014 $ 0.5500 $ 48,783 2nd Quarter August 14, 2014 $ 0.5650 $ 50,114 3rd Quarter November 14, 2014 $ 0.5800 $ 54,112 4th Quarter February 13, 2015 $ 0.5950 $ 56,542 Equity Issuances and Contributions Our partnership agreement authorizes our general partner to cause us to issue additional limited partner interests and other equity securities, the proceeds from which could be used to provide additional funds for acquisitions or other needs. In September 2014 , we issued 4,600,000 Class A common units in a public offering at a price of $50.71 per unit. We received proceeds, net of underwriting discounts and offering costs, of approximately $225.7 million from that offering. We used the net proceeds for general partnership purposes, including the repayment of outstanding borrowings under our revolving credit facility. In September 2013 , we issued 5,750,000 Class A common units in a public offering at a price of $47.51 per unit. We received proceeds, net of underwriting discounts and offering costs, of approximately $263.6 million from that offering. We used the net proceeds for general partnership purposes, including the repayment of outstanding borrowings under our revolving credit facility. In March 2012 , we issued 5,750,000 Class A common units in a public offering at a price of $30.80 per unit. We received proceeds, net of underwriting discounts and offering costs, of $169.4 million from the offering. The net proceeds were used for general corporate purposes, including the repayment of borrowings under our credit facility. The new common units issued in 2014 , 2013 and 2012 to the public for cash were as follows: Period Purchaser of Common Units Units Gross Unit Price Issuance Value Costs Net Proceeds September 2014 Public 4,600 $ 50.71 $ 233,266 $ (7,541 ) $ 225,725 September 2013 Public 5,750 $ 47.51 $ 273,183 $ (9,609 ) $ 263,574 March 2012 Public 5,750 $ 30.80 $ 177,100 $ (7,679 ) $ 169,421

Business Segment Information

Business Segment Information	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Business Segment Information	12. Business Segment Information Our operations consist of five operating segments (see Note 1 for discussion of segment reporting change): • Onshore Pipeline Transportation –transportation of crude oil, and to a lesser extent, CO 2 ; • Offshore Pipeline Transportation – offshore transportation of crude oil in the Gulf of Mexico; • Refinery Services – processing high sulfur (or “sour”) gas streams as part of refining operations to remove the sulfur and selling the related by-product, NaHS; • Marine Transportation – marine transportation to provide waterborne transportation of petroleum products and crude oil throughout North America and; • Supply and Logistics – terminaling, blending, storing, marketing, and transporting crude oil and petroleum products (primarily fuel oil, asphalt, and other heavy refined products) and, on a smaller scale, CO 2 . Substantially all of our revenues are derived from, and substantially all of our assets are located in, the United States. We define Segment Margin as revenues less product costs, operating expenses (excluding non-cash charges, such as depreciation and amortization), and segment general and administrative expenses, plus our equity in distributable cash generated by our equity investees. In addition, our Segment Margin definition excludes the non-cash effects of our legacy stock appreciation rights plan and includes the non-income portion of payments received under direct financing leases. Our chief operating decision maker (our Chief Executive Officer) evaluates segment performance based on a variety of measures including Segment Margin, segment volumes, where relevant, and capital investment. Segment information for each year presented below is as follows: Onshore Pipeline Transportation Offshore Pipeline Transportation Refinery Services Marine Transportation Supply & Logistics (a) Total Year Ended December 31, 2014 Segment Margin (b) $ 61,231 $ 71,598 $ 84,851 $ 86,239 $ 43,345 $ 347,264 Capital expenditures (c) $ 46,611 $ 37,639 $ 2,385 $ 232,783 $ 325,130 $ 644,548 Revenues: External customers $ 66,760 $ 3,296 $ 218,297 $ 214,039 $ 3,343,772 $ 3,846,164 Intersegment (d) 16,397 — (10,896 ) 15,243 (20,744 ) — Total revenues of reportable segments $ 83,157 $ 3,296 $ 207,401 $ 229,282 $ 3,323,028 $ 3,846,164 Year Ended December 31, 2013 Segment Margin (b) $ 64,349 $ 44,530 $ 75,361 $ 47,726 $ 48,394 $ 280,360 Capital expenditures (c) $ 130,787 $ 94,286 $ 3,258 $ 260,736 $ 215,138 $ 704,205 Revenues: External customers $ 65,452 $ 3,923 $ 216,860 $ 131,049 $ 3,717,546 $ 4,134,830 Intersegment (d) 17,133 — (10,875 ) 21,493 (27,751 ) — Total revenues of reportable segments $ 82,585 $ 3,923 $ 205,985 $ 152,542 $ 3,689,795 $ 4,134,830 Year Ended December 31, 2012 Segment Margin (b) $ 58,039 $ 38,500 $ 72,883 $ 37,528 $ 55,383 $ 262,333 Capital expenditures (c) $ 59,345 $ 269,365 $ 2,692 $ 37,188 $ 57,708 $ 426,298 Revenues: External customers $ 56,198 $ 5,508 $ 205,110 $ 99,016 $ 3,001,529 $ 3,367,361 Intersegment (d) 14,584 — (9,093 ) 19,188 (24,679 ) — Total revenues of reportable segments $ 70,782 $ 5,508 $ 196,017 $ 118,204 $ 2,976,850 $ 3,367,361 Total assets by reportable segment were as follows: December 31, 2014 December 31, 2013 December 31, 2012 Onshore pipeline transportation $ 460,012 $ 437,912 $ 325,189 Offshore pipeline transportation 645,668 637,323 565,463 Refinery services 403,703 417,121 414,170 Marine transportation 745,128 529,914 276,736 Supply and logistics 907,189 782,547 473,611 Other assets 68,674 57,385 54,495 Total consolidated assets $ 3,230,374 $ 2,862,202 $ 2,109,664 (a) Discontinued operations are included in Segment Margin but excluded from revenues for all periods presented. (b) A reconciliation of Segment Margin to income from continuing operations before income taxes for each year is presented below. (c) Capital expenditures include maintenance and growth capital expenditures, such as fixed asset additions (including enhancements to existing facilities and construction of internal growth projects) as well as acquisitions of businesses and interests in equity investees. In addition to construction of internal growth projects, capital spending in our Offshore pipeline transportation segment included $36.1 million and $94.3 million during the years ended December 31, 2014 and December 31, 2013 representing capital contributions to our SEKCO equity investee to fund our share of the construction costs for its pipeline. During 2014, capital spending in our marine transportation segment included $157 million for our purchase of the M/T American Phoenix. During 2013, capital spending in our marine segment also included $230.9 million for the acquisition of our offshore marine transportation assets. During 2012, capital spending in our pipeline transportation segment also included $205.6 million for the acquisition of interests in several Gulf of Mexico pipelines. (d) Intersegment sales were conducted under terms that we believe were no more or less favorable than then-existing market conditions. Reconciliation of Segment Margin to income from continuing operations: Year Ended December 31, 2014 2013 2012 Segment Margin $ 347,264 $ 280,360 $ 262,333 Corporate general and administrative expenses (47,065 ) (43,353 ) (38,372 ) Depreciation and amortization (90,908 ) (64,784 ) (61,150 ) Interest expense (66,639 ) (48,583 ) (40,923 ) Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1) (31,093 ) (23,889 ) (24,464 ) Non-cash items not included in Segment Margin 3,017 (7,551 ) (5,280 ) Cash payments from direct financing leases in excess of earnings (5,529 ) (5,110 ) (5,016 ) Income tax expense (2,845 ) (845 ) 9,205 Discontinued operations — (2,241 ) 1,004 Income from continuing operations $ 106,202 $ 84,004 $ 97,337 (1) Includes distributions attributable to the quarter and received during or promptly following such quarter.

Transactions with Related Parti

Transactions with Related Parties	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Transactions with Related Parties	13. Transactions with Related Parties Sales, purchases and other transactions with affiliated companies, in the opinion of management, are conducted under terms no more or less favorable than then-existing market conditions. The transactions with related parties were as follows: Year Ended December 31, 2014 2013 2012 Revenues: Sales of CO 2 to Sandhill Group, LLC (1) $ 3,060 $ 3,076 $ 2,905 Petroleum products sales to Davison family businesses (2) — 1,293 1,344 Petroleum products sales to an affiliate of the Quintana Group (2) (3) — — 21,143 Expenses: Amounts paid to our CEO in connection with the use of his aircraft $ 630 $ 600 $ 600 Marine operating fuel and expenses provided by an affiliate of the Quintana Group (3) — — 6,260 (1) We own a 50% interest in Sandhill Group, LLC (or "Sandhill). (2) Amounts included in discontinued operations for all periods presented. (3) The Quintana Group monetized all of its remaining investment in our common units on October 5, 2012 . Transactions with the Quintana Group are included in the above table as related party transactions through October 5, 2012 . Our CEO, Mr. Sims, owns an aircraft which is used by us for business purposes in the course of operations. We pay Mr. Sims a fixed monthly fee and reimburse the aircraft management company for costs related to our usage of the aircraft, including fuel and the actual out-of-pocket costs. Based on current market rates for chartering of private aircraft under long-term, priority arrangements with industry recognized chartering companies, we believe that the terms of this arrangement are no worse than what we could have expected to obtain in an arms-length transaction. Amounts due from Related Parties At December 31, 2014 , and 2013 , Sandhill owed us $0.3 million and $0.2 million , respectively, for purchases of CO 2 .

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2014
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	14. Supplemental Cash Flow Information The following table provides information regarding the net changes in components of operating assets and liabilities: Year Ended December 31, 2014 2013 2012 (Increase) decrease in: Accounts receivable $ 95,014 $ (96,300 ) $ (34,299 ) Inventories 38,501 1,720 14,074 Deferred Charges (8,935 ) — — Other current assets 62,305 (39,170 ) (9,593 ) Increase (decrease) in: Accounts payable (73,307 ) 41,718 53,146 Accrued liabilities (35,624 ) 45,846 (10,263 ) Net changes in components of operating assets and liabilities $ 77,954 $ (46,186 ) $ 13,065 Payments of interest and commitment fees, net of amounts capitalized, were $74.8 million , $49.7 million and $41.5 million during the years ended December 31, 2014 , 2013 and 2012 , respectively. We capitalized interest of $13.8 million , $13.3 million and $3.9 million during the years ended December 31, 2014 , 2013 and 2012 . During the years ended December 31, 2014 and 2013 , we paid taxes of $0.8 million and $0.6 million . During the year ended December 31, 2012 , we received a tax refund, net of amounts paid, of $0.3 million . At December 31, 2014 , 2013 and 2012 , we had incurred liabilities for fixed and intangible asset additions totaling $61.2 million , $52.5 million and $14.1 million , respectively, which had not been paid at the end of the year. Therefore, these amounts were not included in the caption “Payments to acquire fixed and intangible assets” under Cash Flows from Investing Activities in the Consolidated Statements of Cash Flows. At December 31, 2014 and 2013 , we had incurred liabilities for other asset additions totaling $9.4 million and $0.1 million that had not been paid at the end of the year, and, therefore, were not included in the caption "Other, net" under Cash Flows from Investing Activities in the Consolidated Statements of Cash Flows.

Equity-Based Compensation Plans

Equity-Based Compensation Plans And Employee Benefit Plans	12 Months Ended
	Dec. 31, 2014
Compensation and Retirement Disclosure [Abstract]
Equity-Based Compensation Plans and Employee Benefit Plans	15. Equity-Based Compensation Plans and Employee Benefit Plans 2010 Long Term Incentive Plan In 2010, we adopted the 2010 Long-Term Incentive Plan (the “2010 Plan”). The 2010 Plan provides for the awards of phantom units and distribution equivalent rights to members of our board of directors, and employees who provide services to us. Phantom units are notional units representing unfunded and unsecured promises to pay to the participant a specified amount of cash based on the market value of our common units should specified vesting requirements be met. Distribution equivalent rights (“DERs”) are tandem rights to receive on a quarterly basis a cash amount per phantom unit equal to the amount of cash distributions paid per common unit. The 2010 Plan is administered by the Governance, Compensation and Business Development Committee (the “G&C Committee”) of our board of directors. The G&C Committee (at its discretion) designates participants in the 2010 Plan, determines the types of awards to grant to participants, determines the number of units to be covered by any award, and determines the conditions and terms of any award including vesting, settlement and forfeiture conditions. The compensation cost associated with the phantom units is re-measured each reporting period based on the market value of our common units, and is recognized over the vesting period. The liability recorded for the estimated amount to be paid to the participants under the 2010 LTIP is adjusted to recognize changes in the estimated compensation cost and vesting. Management’s estimates of the fair value of these awards granted in 2014 are adjusted for assumptions about expected forfeitures of units prior to vesting. For our performance-based awards, our fair value estimates are weighted based on probabilities for each performance condition applicable to the award. During 2014 , we granted 125,988 phantom units with tandem DERs at a weighted average grant fair value of $54.14 per unit. During 2013 , we granted 152,964 phantom units with tandem DERs at a weighted average grant date fair value of $46.88 per unit. The phantom units granted during 2014 and 2013 were both service-based and performance-based awards. The service-based awards vest on the third anniversary of the date of grant. Performance-based phantom unit awards granted in 2013 and 2014 will vest on the third anniversary of issuance, in an amount ranging from 50% to 150% of the targeted number of phantom units, if certain quarterly cash distribution per common unit targets are achieved in the fourth quarter of 2015 and 2016 , respectively. If the quarterly cash distribution per common unit is below the threshold target, all of the performance-based phantom units granted will be forfeited. During 2012 , we granted 176,995 phantom units with tandem DERs at a weighted average grant date fair value of $31.14 per unit. These phantom units will vest in April 2015, the third anniversary of the date of grant, at 150% of the targeted number of phantom units due to the distribution per common unit target achieved in the fourth quarter of 2014. A summary of our phantom unit activity for our service-based and performance-based awards is set forth below: Service-Based Awards Performance-Based Awards Number of Phantom Units Average Grant Date Fair Value Total Value (in thousands) Number of Phantom Units Average Grant Date Fair Value Total Value (in thousands) Unvested at December 31, 2013 105,385 $ 35.42 $ 3,733 334,969 $ 35.79 $ 11,989 Granted 43,225 $ 54.05 2,336 82,763 $ 54.18 4,484 Forfeited (4,599 ) $ 43.19 (199 ) (6,899 ) $ 43.20 (298 ) Settled (31,188 ) $ 27.11 (846 ) (96,988 ) $ 28.21 (2,736 ) Unvested at December 31, 2014 112,823 $ 44.53 $ 5,024 313,845 $ 42.82 $ 13,439 At December 31, 2014 , we estimated the unrecognized compensation cost of our phantom awards to be approximately $4.9 million to be recognized over a weighted average period of approximately one year. We recorded $8.8 million and $13.1 million of compensation expense for the years ended December 31, 2014 and 2013 , respectively. Our liability for these awards totaled $15.4 million and $17.1 million at December 31, 2014 and 2013 , respectively. Stock Appreciation Rights Plan Our Stock Appreciation Rights Plan is administered by the G&C Committee, which determines, in its full discretion, who shall receive awards under the Plan, the number of rights to award, the grant date of the units and the formula for allocating rights to the participants and the strike price of the rights awarded. Each right is equivalent to one common unit. The rights have a term of 10 years from the date of grant. If the right has not been exercised at the end of the ten year term and the participant has not terminated employment with us, the right will be deemed exercised as of the date of the right’s expiration and a cash payment will be made as described below. Upon vesting, the participant may exercise rights and receive a cash payment calculated as the difference between the average of the closing market price of our common units for the ten days preceding the date of exercise over the strike price of the right being exercised. If the G&C Committee determines, in its full discretion, that it would cause significant financial harm to the Partnership to make cash payments to participants who have exercised rights under the Stock Appreciation Rights Plan, then the G&C Committee may authorize deferral of the cash payments until a later date. Termination for any reason other than death, disability or normal retirement (as these terms are defined in the Stock Appreciation Rights Plan) will result in the forfeiture of any non-vested rights. Upon death, disability or normal retirement, all rights will become fully vested. If a participant is terminated for any reason within one year after the effective date of a change in control (as defined in the plan) all rights will become fully vested. The compensation cost associated with our Stock Appreciation Rights plan, which upon exercise will result in the payment of cash to the employee, is re-measured each reporting period based on the fair value of the rights calculated using a Black-Scholes option pricing model that takes into consideration the expected future value of the rights at their expected exercise dates and management’s assumptions about expectation of forfeitures prior to vesting. The liability amount accrued on the balance sheet is adjusted to the fair value of the outstanding awards at each balance sheet date with the adjustment reflected in the Consolidated Statement of Operations. The fair value is adjusted for expected forfeitures of rights (due to terminations before vesting, or expirations after vesting). The estimates that we make each period to determine the fair value of these rights include the following assumptions: Assumptions Used for Fair Value of Rights December 31, 2014 December 31, 2013 December 31, 2012 Expected life of rights (in years) Less than 1 Less than 1 Less than 1 Risk-free interest rate —% - 0.07% —% - 0.07% —% - 0.07% Expected unit price volatility 39.3% 39.3% 39.3% Expected future distribution yield 5.00% 5.00% 5.00% The following table reflects rights activity under our Stock Appreciation Rights Plan as of January 1, 2014 , and changes during the year ended December 31, 2014 : Stock Appreciation Rights Weighted Average Strike Price Weighted Average Contractual Remaining Term (Yrs) Aggregate Intrinsic Value Outstanding at December 31, 2013 207,498 $ 17.43 Exercised during 2014 (37,813 ) $ 51.59 Forfeited or expired during 2014 (8,830 ) $ 16.03 Outstanding at December 31, 2014 160,855 $ 18.08 3.47 $ 3,906 Exercisable at December 31, 2014 160,855 $ 18.08 3.47 $ 3,906 The total intrinsic value of rights exercised during 2014 , 2013 and 2012 was $1.4 million , $5.5 million and $3.3 million , respectively, which was paid in cash to the participants. As of December 31, 2014 , all of our SARs were vested and the related total compensation cost had been fully recognized. We recorded a reduction to compensation expense related to our stock appreciation rights from continuing operations of $2.0 million in 2014 . In 2013 and 2012 we recorded compensation expense related to our stock appreciation rights from continuing operations of $5.6 million and $4.3 million , respectively. Equity-Based Compensation Plan Expense Equity-based compensation expense from our continuing operations during the three years ended December 31, 2014 was as follows: Expense Related to Equity-Based Compensation Plans Consolidated Statement of Operations 2014 2013 2012 Supply and logistics operating costs $ 485 $ 4,524 $ 2,707 Marine transportation operating costs 626 586 190 Refinery services operating costs (62 ) 1,978 1,427 Pipeline operating costs (52 ) 510 247 General and administrative expenses 5,824 11,073 6,448 Total $ 6,821 $ 18,671 $ 11,019 Bonus Program Bonuses under our bonus plan are paid at the discretion of the G&C Committee to our employees and executive officers based on quantitative and qualitative measures relating to: our financial and operational performance relative to our peers; industry expectations; progress in attaining strategic goals; and individual performance. In 2014 , the G&C Committee based bonus amounts primarily on the amount of cash we generated for distributions to our unitholders, measured on a calendar-year basis. Two metrics were considered by the G&C Committee in determining the general bonus pool – the level of Available Cash before Reserves (before subtracting bonus expense and related employer tax burdens) that we generated and our company-wide safety record improvement which included a targeted achieved level in our company-wide incident injury rate. The level of Available Cash before Reserves generated for the year as a percentage of a target set by the G&C Committee is weighted 90% and the achieved level of the targeted improvement in our safety record is weighted 10% . The sum of the weighted percentage achievement of these targets is multiplied by the eligible compensation and the target percentages established by the G&C Committee for the various levels of our employees to determine the maximum general bonus pool. In addition, the G&C Committee also considered other subjective factors in determining the general bonus pool and individual award amounts. At December 31, 2014 , we accrued $8.1 million for estimated bonuses to be paid in March 2015 . For 2013 and 2012 , we paid bonuses totaling $5.3 million and $7.9 million , respectively, to our executive officers and employees. Employee Benefit Plans In order to encourage long-term savings and to provide additional funds for retirement to its employees, we sponsor a tax qualified profit-sharing and retirement savings plan. Under this plan, our matching contribution is calculated as an equal match of the first 6% of each employee’s annual pretax contribution. Our profit-sharing plan targets a 3% contribution of each eligible employee’s total compensation (subject to IRS limitations). The expenses included in the Consolidated Statements of Operations for costs relating to this plan were $6.3 million , $4.3 million and $3.4 million for the years ended December 31, 2014 , 2013 and 2012 , respectively. We also provided certain health care and survivor benefits for our active employees. Our health care benefit programs are self-insured, with a catastrophic insurance policy to limit our costs. We plan to continue self-insuring these plans in the future. The expenses included in the Consolidated Statements of Operations for these benefits were $13.5 million , $10.4 million and $8.8 million in 2014 , 2013 and 2012 , respectively.

Major Customers and Credit Risk

Major Customers and Credit Risk	12 Months Ended
	Dec. 31, 2014
Major Customers And Credit Risk [Abstract]
Major Customers and Credit Risk	16. Major Customers and Credit Risk Due to the nature of our supply and logistics operations, a disproportionate percentage of our trade receivables constitute obligations of oil companies. This industry concentration has the potential to impact our overall exposure to credit risk, either positively or negatively, in that our customers could be affected by similar changes in economic, industry or other conditions. However, we believe that the credit risk posed by this industry concentration is offset by the creditworthiness of our customer base. Our portfolio of accounts receivable is comprised in large part of accounts owed by integrated and large independent energy companies with stable payment histories. The credit risk related to contracts which are traded on the NYMEX is limited due to daily margin requirements and other NYMEX requirements. We have established various procedures to manage our credit exposure, including initial credit approvals, credit limits, collateral requirements and rights of offset. Letters of credit, prepayments and guarantees are also utilized to limit credit risk to ensure that our established credit criteria are met. During 2014 , 2013 and 2012 our largest customer was Shell Oil Company, which accounted for 12% , 17% and 14% of total revenues respectively. The revenues from Shell Oil Company in all three years relate primarily to our supply and logistics operations.

Derivatives

Derivatives	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	17. Derivatives Commodity Derivatives We have exposure to commodity price changes related to our inventory and purchase commitments. We utilize derivative instruments (primarily futures and options contracts traded on the NYMEX) to hedge our exposure to commodity prices, primarily of crude oil, fuel oil and petroleum products. Our decision as to whether to designate derivative instruments as fair value hedges for accounting purposes relates to our expectations of the length of time we expect to have the commodity price exposure and our expectations as to whether the derivative contract will qualify as highly effective under accounting guidance in limiting our exposure to commodity price risk. Most of the petroleum products, including fuel oil that we supply cannot be hedged with a high degree of effectiveness with derivative contracts available on the NYMEX; therefore, we do not designate derivative contracts utilized to limit our price risk related to these products as hedges for accounting purposes. Typically we utilize crude oil and other petroleum products futures and option contracts to limit our exposure to the effect of fluctuations in petroleum products prices on the future sale of our inventory or commitments to purchase petroleum products, and we recognize any changes in fair value of the derivative contracts as increases or decreases in our cost of sales. The recognition of changes in fair value of the derivative contracts not designated as hedges for accounting purposes can occur in reporting periods that do not coincide with the recognition of gain or loss on the actual transaction being hedged. Therefore we will, on occasion, report gains or losses in one period that will be partially offset by gains or losses in a future period when the hedged transaction is completed. In accordance with NYMEX requirements, we fund the margin associated with our loss positions on commodity derivative contracts traded on the NYMEX. The amount of the margin is adjusted daily based on the fair value of the commodity contracts. The margin requirements are intended to mitigate a party’s exposure to market volatility and the associated contracting party risk. We offset fair value amounts recorded for our NYMEX derivative contracts against margin funding as required by the NYMEX in Current Assets - Other in our Consolidated Balance Sheets. At December 31, 2014 , we had the following outstanding derivative commodity contracts that were entered into to economically hedge inventory or fixed price purchase commitments. We had no outstanding derivative contracts that were designated as hedges under accounting rules. Sell (Short) Contracts Buy (Long) Contracts Not qualifying or not designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 bbls) 366 168 Weighted average contract price per bbl $ 74.82 $ 65.30 Diesel futures: Contract volumes (1,000 bbls) 56 — Weighted average contract price per gal $ 2.43 $ — #6 Fuel oil futures: Contract volumes (1,000 bbls) 465 95 Weighted average contract price per bbl $ 60.07 $ 44.95 Crude oil options: Contract volumes (1,000 bbls) 125 — Weighted average premium received $ 2.08 $ — Financial Statement Impacts The following table summarizes the accounting treatment and classification of our derivative instruments on our Consolidated Financial Statements. Derivative Instrument Hedged Risk Impact of Unrealized Gains and Losses Consolidated Balance Sheets Consolidated Statements of Operations Not qualifying or not designated as hedges under accounting guidance: Commodity hedges consisting of crude oil, heating oil and natural gas futures and forward contracts and call options Volatility in crude oil and petroleum products prices - effect on market value of inventory or purchase commitments Derivative is recorded in Other current assets (offset against margin deposits) or Accrued liabilities Entire amount of change in fair value of derivative is recorded in Supply and logistics costs - product costs Unrealized gains are subtracted from net income and unrealized losses are added to net income in determining cash flows from operating activities. To the extent that we have fair value hedges outstanding, the offsetting change recorded in the fair value of inventory is also eliminated from net income in determining cash flows from operating activities. Changes in margin deposits necessary to fund unrealized losses also affect cash flows from operating activities. The following tables reflect the estimated fair value gain (loss) position of our derivatives at December 31, 2014 and 2013 : Fair Value of Derivative Assets and Liabilities Fair Value Consolidated Balance Sheets Location December 31, 2014 December 31, 2013 Asset Derivatives: Commodity derivatives—futures and call options (undesignated hedges): Gross amount of recognized assets Current Assets - Other $ 16,383 $ 615 Gross amount offset in the Consolidated Balance Sheets Current Assets - Other (2,310 ) (615 ) Net amount of assets presented in the Consolidated Balance Sheets 14,073 — Liability Derivatives: Commodity derivatives—futures and call options (undesignated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (2,310 ) $ (4,527 ) Gross amount offset in the Consolidated Balance Sheets Current Assets - Other (1) 2,310 4,527 Net amount of liabilities presented in the Consolidated Balance Sheets — — (1) These derivative liabilities have been funded with margin deposits recorded in our Consolidated Balance Sheets under Current Assets - Other in 2013. Our accounting policy is to offset derivative assets and liabilities executed with the same counterparty when a master netting arrangement exists. Accordingly, we also offset derivative assets and liabilities with amounts associated with cash margin. Our exchange-traded derivatives are transacted through brokerage accounts and are subject to margin requirements as established by the respective exchange. On a daily basis, our account equity (consisting of the sum of our cash balance and the fair value of our open derivatives) is compared to our initial margin requirement resulting in the payment or return of variation margin. As of December 31, 2014 , we had a net broker receivable of approximately $2.8 million (consisting of initial margin of $2.4 million increased by $0.3 million of variation margin). As of December 31, 2013 , we had a net broker receivable of approximately $5.3 million (consisting of initial margin of $4.1 million increased by $1.2 million of variation margin that had been returned to us). At December 31, 2014 and December 31, 2013 , none of our outstanding derivatives contained credit-risk related contingent features that would result in a material adverse impact to us upon any change in our credit ratings. Effect on Operating Results Amount of Gain (Loss) Recognized in Income Supply & Logistics Product Costs Year Ended 2014 2013 2012 Commodity derivatives—futures and call options: Contracts designated as hedges under accounting guidance $ — $ — $ — Contracts not considered hedges under accounting guidance 35,468 (3,268 ) (2,936 ) Total derivatives $ 35,468 $ (3,268 ) $ (2,936 ) We have no derivative contracts with credit contingent features.

Fair-Value Measurements

Fair-Value Measurements	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Fair-Value Measurements	18. Fair-Value Measurements We classify financial assets and liabilities into the following three levels based on the inputs used to measure fair value: (1) Level 1 fair values are based on observable inputs such as quoted prices in active markets for identical assets and liabilities; (2) Level 2 fair values are based on pricing inputs other than quoted prices in active markets for identical assets and liabilities and are either directly or indirectly observable as of the measurement date; and (3) Level 3 fair values are based on unobservable inputs in which little or no market data exists. As required by fair value accounting guidance, financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value requires judgment and may affect the placement of assets and liabilities within the fair value hierarchy levels. The following table sets forth by level within the fair value hierarchy our financial assets and liabilities that were accounted for at fair value on a recurring basis as of December 31, 2014 and 2013 . December 31, 2014 December 31, 2013 Recurring Fair Value Measures Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Commodity derivatives: Assets $ 16,383 $ — $ — $ 615 $ — $ — Liabilities $ (2,310 ) $ — $ — $ (4,527 ) $ — $ — Our commodity derivatives include exchange-traded futures and exchange-traded options contracts. The fair value of these exchange-traded derivative contracts is based on unadjusted quoted prices in active markets and is, therefore, included in Level 1 of the fair value hierarchy. See Note 17 for additional information on our derivative instruments. Nonfinancial Assets and Liabilities We utilize fair value on a non-recurring basis to perform impairment tests as required on our property, plant and equipment, goodwill and intangible assets. Assets and liabilities acquired in business combinations are recorded at their fair value as of the date of acquisition. The inputs used to determine such fair value are primarily based upon internally developed cash flow models and would generally be classified in Level 3, in the event that we were required to measure and record such assets within our Consolidated Financial Statements. Additionally, we use fair value to determine the inception value of our asset retirement obligations. The inputs used to determine such fair value are primarily based upon costs incurred historically for similar work, as well as estimates from independent third parties for costs that would be incurred to restore leased property to the contractually stipulated condition, and would generally be classified in Level 3. Other Fair Value Measurements We believe the debt outstanding under our credit facility approximates fair value as the stated rate of interest approximates current market rates of interest for similar instruments with comparable maturities. At December 31, 2014 our senior unsecured notes had a carrying value of $1,050.6 million and a fair value of $1,003.6 million , compared to $700.8 million and $732.4 million , respectively at December 31, 2013 . The fair value of the senior unsecured notes is determined based on trade information in the financial markets of our public debt and is considered a Level 2 fair value measurement.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	19. Commitments and Contingencies Commitments and Guarantees Our office lease for our corporate headquarters extends until October 31, 2022 . To transport products, we lease tractors, trailers and railcars. In addition, we lease tanks and terminals for the storage of crude oil, petroleum products, NaHS and caustic soda. Additionally, we lease a segment of pipeline where under the terms we make payments based on throughput. We have no minimum volumetric or financial requirements remaining on our pipeline lease. The future minimum rental payments under all non-cancelable operating leases as of December 31, 2014 , were as follows (in thousands): Office Space Transportation Equipment Terminals and Tanks Total 2015 $ 2,282 $ 14,796 $ 15,752 $ 32,830 2016 1,846 9,451 7,149 18,446 2017 1,625 7,430 2,687 11,742 2018 1,631 5,967 2,692 10,290 2019 1,580 5,705 2,697 9,982 2020 and thereafter 4,484 6,617 20,866 31,967 Total minimum lease obligations $ 13,448 $ 49,966 $ 51,843 $ 115,257 Total operating lease expense from our continuing operations was as follows (in thousands): Year Ended December 31, 2014 $ 37,941 Year Ended December 31, 2013 $ 27,674 Year Ended December 31, 2012 $ 21,530 We are subject to various environmental laws and regulations. Policies and procedures are in place to monitor compliance and to detect and address any releases of crude oil from our pipelines or other facilities; however no assurance can be made that such environmental releases may not substantially affect our business. Other Matters Our facilities and operations may experience damage as a result of an accident or natural disaster. These hazards can cause personal injury or loss of life, severe damage to and destruction of property and equipment, pollution or environmental damage and suspension of operations. We maintain insurance that we consider adequate to cover our operations and properties, in amounts we consider reasonable. Our insurance does not cover every potential risk associated with operating our facilities, including the potential loss of significant revenues. The occurrence of a significant event that is not fully-insured could materially and adversely affect our results of operations. We believe we are adequately insured for public liability and property damage to others and that our coverage is similar to other companies with operations similar to ours. No assurance can be made that we will be able to maintain adequate insurance in the future at premium rates that we consider reasonable. We are subject to lawsuits in the normal course of business and examination by tax and other regulatory authorities. We do not expect such matters presently pending to have a material effect on our financial position, results of operations or cash flows.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Taxes	20. Income Taxes We are not a taxable entity for federal income tax purposes. As such, we do not directly pay federal income taxes. Other than with respect to our corporate subsidiaries and the Texas Margin Tax, our taxable income or loss is includible in the federal income tax returns of each of our partners. A few of our operations are owned by wholly-owned corporate subsidiaries that are taxable as corporations. We pay federal and state income taxes on these operations. Our income tax (benefit) expense is as follows: Year Ended December 31, 2014 2013 2012 Current: Federal $ — $ 345 $ (8,463 ) State 1,100 650 275 Total current income tax expense (benefit) $ 1,100 $ 995 $ (8,188 ) Deferred: Federal $ 1,508 $ (248 ) $ (1,035 ) State 237 98 18 Total deferred income tax benefit $ 1,745 $ (150 ) $ (1,017 ) Total income tax expense (benefit) from continuing operations (1) $ 2,845 $ 845 $ (9,205 ) (1) Our discontinued operations had no income tax benefit or expense in any period presented. Deferred income taxes relate to temporary differences based on tax laws and statutory rates in effect at the balance sheet date. Deferred tax assets and liabilities consist of the following: December 31, 2014 2013 Deferred tax assets: Current: Other current assets $ 262 $ 297 Other 8 8 Total current deferred tax asset 270 305 Net operating loss carryforwards 9,048 7,784 Total long-term deferred tax asset 9,048 7,784 Valuation allowances (737 ) (660 ) Total deferred tax assets $ 8,581 $ 7,429 Deferred tax liabilities: Current: Other $ (871 ) $ (785 ) Long-term: Fixed assets (4,335 ) (4,441 ) Intangible assets (14,419 ) (11,503 ) Total long-term liability (18,754 ) (15,944 ) Total deferred tax liabilities $ (19,625 ) $ (16,729 ) Total net deferred tax liability $ (11,044 ) $ (9,300 ) We record a valuation allowance when it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of the deferred tax assets depends on the ability to generate sufficient taxable income of the appropriate character in the future and in the appropriate taxing jurisdictions. Our income tax expense (benefit) varies from the amount that would result from applying the federal statutory income tax rate to income from continuing operations before income taxes as follows: Year Ended December 31, 2014 2013 2012 Income from continuing operations before income taxes $ 109,047 $ 84,849 $ 88,132 Partnership income not subject to tax (104,751 ) (85,567 ) (90,815 ) Income (loss) subject to income taxes $ 4,296 $ (718 ) $ (2,683 ) Tax expense (benefit) at federal statutory rate $ 1,504 $ (251 ) $ (939 ) State income taxes, net of federal tax 992 660 460 Effects of unrecognized tax positions, federal and state — — (8,205 ) Return to provision, federal and state (232 ) 88 (166 ) Other 581 348 (355 ) Income tax expense (benefit) $ 2,845 $ 845 $ (9,205 ) Effective tax rate on income from continuing operations before income taxes (1) 3 % 1 % N/A (1) Income tax expense is related to taxable income generated by our corporate subsidiaries and Texas Margin Tax. Due to the income tax benefit in 2012 , the effective tax rate as a percentage of our total income from continuing operations before income taxes is not meaningful for those periods. In 2012, we reversed $8.2 million of uncertain tax positions and recognized an income tax benefit in the Consolidated Statements of Operations as a result of tax audit settlements and the expiration of statutes of limitations. At December 31, 2014 and 2013, we had no uncertain tax positions.

Quarterly Financial Data

Quarterly Financial Data	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Data [Abstract]
Quarterly Financial Information [Text Block]	Quarterly Financial Data (Unaudited) The table below summarizes our unaudited quarterly financial data for 2014 and 2013 . 2014 Quarters Total First Second Third Fourth Year Revenues from continuing operations $ 1,019,719 $ 1,015,049 $ 964,114 $ 847,282 $ 3,846,164 Operating income $ 35,402 $ 31,257 $ 35,268 $ 30,624 $ 132,551 Income from continuing operations $ 29,775 $ 21,148 $ 29,113 $ 26,166 $ 106,202 Net income $ 29,775 $ 21,148 $ 29,113 $ 26,166 $ 106,202 Basic and diluted net income per common unit: Continuing operations $ 0.34 $ 0.24 $ 0.33 $ 0.28 $ 1.18 Net income per common unit $ 0.34 $ 0.24 $ 0.33 $ 0.28 $ 1.18 Cash distributions per common unit (1) $ 0.5350 $ 0.5500 $ 0.5650 $ 0.5800 $ 2.2300 2013 Quarters Total First Second Third Fourth Year Revenues from continuing operations $ 1,014,808 $ 1,068,694 $ 1,090,293 $ 961,035 $ 4,134,830 Operating income $ 30,005 $ 33,360 $ 24,092 $ 23,300 $ 110,757 Income from continuing operations $ 22,704 $ 26,612 $ 17,966 $ 16,722 $ 84,004 Loss from discontinued operations $ 143 $ 290 $ 508 $ 1,164 $ 2,105 Net income $ 22,847 $ 26,902 $ 18,474 $ 17,886 $ 86,109 Basic and diluted net income per common unit: Continuing operations $ 0.28 $ 0.32 $ 0.21 $ 0.19 $ 1.00 Discontinued operations $ — $ 0.01 $ 0.01 $ 0.01 $ 0.03 Net income per common unit $ 0.28 $ 0.33 $ 0.22 $ 0.20 $ 1.03 Cash distributions per common unit (1) $ 0.4850 $ 0.4975 $ 0.5100 $ 0.5225 $ 2.0150 (1) Represents cash distributions declared and paid in the applicable period.

Condensed Consolidating Financi

Condensed Consolidating Financial Information	12 Months Ended
	Dec. 31, 2014
Condensed Consolidating Financial Information [Abstract]
Condensed Consolidating Financial Information	22. Condensed Consolidating Financial Information Our $1,050 million aggregate principal amount of senior unsecured notes co-issued by Genesis Energy, L.P. and Genesis Energy Finance Corporation are fully and unconditionally guaranteed jointly and severally by all of Genesis Energy, L.P.’s current and future 100% owned domestic subsidiaries, except Genesis Free State Pipeline, LLC, Genesis NEJD Pipeline, LLC and certain other minor subsidiaries. Genesis NEJD Pipeline, LLC is 100% owned by Genesis Energy, L.P., the parent company. The remaining non-guarantor subsidiaries are owned by Genesis Crude Oil, L.P., a guarantor subsidiary. Genesis Energy Finance Corporation has no independent assets or operations. See Note 10 for additional information regarding our consolidated debt obligations. During the second quarter of 2015, the Company took actions related to certain non-guarantor subsidiaries that resulted in these subsidiaries previously categorized as non-guarantor becoming wholly owned guarantor subsidiaries. The changes made to guarantor subsidiaries did not impact the Company's previously reported consolidated revenues, operating income or net income. The condensed consolidating balance sheet as of December 31, 2014 and 2013 and the condensed consolidating statements of operations and cash flows for the years ended December 31, 2014, 2013, and 2012 have been retrospectively adjusted to reflect these updates to our guarantor subsidiaries. The following is condensed consolidating financial information for Genesis Energy, L.P. and subsidiary guarantors: Condensed Consolidating Balance Sheet December 31, 2014 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated ASSETS Current assets: Cash and cash equivalents $ 9 $ — $ 8,310 $ 1,143 $ — $ 9,462 Other current assets 1,378,573 — 333,385 46,215 (1,412,269 ) 345,904 Total current assets 1,378,582 — 341,695 47,358 (1,412,269 ) 355,366 Fixed Assets, at cost — — 1,823,556 75,502 — 1,899,058 Less: Accumulated depreciation — — (251,171 ) (16,886 ) — (268,057 ) Net fixed assets — — 1,572,385 58,616 — 1,631,001 Goodwill — — 325,046 — — 325,046 Other assets, net 28,421 — 269,252 146,700 (154,192 ) 290,181 Equity investees and other investments — — 628,780 — — 628,780 Investments in subsidiaries 1,434,255 — 97,195 — (1,531,450 ) — Total assets $ 2,841,258 $ — $ 3,234,353 $ 252,674 $ (3,097,911 ) $ 3,230,374 LIABILITIES AND PARTNERS’ CAPITAL Current liabilities $ 11,016 $ — $ 1,761,856 $ 2,705 $ (1,412,432 ) $ 363,145 Senior secured credit facilities 550,400 — — — — 550,400 Senior unsecured notes 1,050,639 — — — — 1,050,639 Deferred tax liabilities — — 18,754 — — 18,754 Other liabilities — — 18,233 154,021 (154,021 ) 18,233 Total liabilities 1,612,055 — 1,798,843 156,726 (1,566,453 ) 2,001,171 Partners’ capital 1,229,203 — 1,435,510 95,948 (1,531,458 ) 1,229,203 Total liabilities and partners’ capital $ 2,841,258 $ — $ 3,234,353 $ 252,674 $ (3,097,911 ) $ 3,230,374 Condensed Consolidating Balance Sheet December 31, 2013 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated ASSETS Current assets: Cash and cash equivalents $ 20 $ — $ 8,049 $ 797 $ — $ 8,866 Other current assets 1,133,695 — 515,143 37,286 (1,159,767 ) 526,357 Total current assets 1,133,715 — 523,192 38,083 (1,159,767 ) 535,223 Fixed Assets, at cost — — 1,252,445 75,529 — 1,327,974 Less: Accumulated depreciation — — (184,856 ) (14,374 ) — (199,230 ) Net fixed assets — — 1,067,589 61,155 — 1,128,744 Goodwill — — 325,046 — — 325,046 Other assets, net 21,432 — 238,283 152,412 (159,185 ) 252,942 Equity investees and other investments — — 620,247 — — 620,247 Investments in subsidiaries 1,236,164 — 89,600 — (1,325,764 ) — Total assets $ 2,391,311 $ — $ 2,863,957 $ 251,650 $ (2,644,716 ) $ 2,862,202 LIABILITIES AND PARTNERS’ CAPITAL Current liabilities $ 10,002 $ — $ 1,592,376 $ 3,470 $ (1,159,295 ) $ 446,553 Senior secured credit facilities 582,800 — — — — 582,800 Senior unsecured notes 700,772 — — — — 700,772 Deferred tax liabilities — — 15,944 — — 15,944 Other liabilities — — 18,396 159,007 (159,007 ) 18,396 Total liabilities 1,293,574 — 1,626,716 162,477 (1,318,302 ) 1,764,465 Partners' capital 1,097,737 — 1,237,241 89,173 (1,326,414 ) 1,097,737 Total liabilities and partners’ capital $ 2,391,311 $ — $ 2,863,957 $ 251,650 $ (2,644,716 ) $ 2,862,202 Condensed Consolidating Statement of Operations Year Ended December 31, 2014 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated REVENUES: Pipeline transportation services $ — $ — $ 61,686 $ 24,767 $ — $ 86,453 Refinery services — — 202,250 18,289 (13,138 ) 207,401 Marine transportation — — 229,282 — — 229,282 Supply and logistics — — 3,323,028 — — 3,323,028 Total revenues — — 3,816,246 43,056 (13,138 ) 3,846,164 COSTS AND EXPENSES: Supply and logistics costs — — 3,277,052 — — 3,277,052 Marine transportation costs — — 142,793 — — 142,793 Refinery services operating costs — — 117,788 17,393 (13,780 ) 121,401 Pipeline transportation operating costs — — 29,910 857 — 30,767 General and administrative — — 50,692 — — 50,692 Depreciation and amortization — — 88,368 2,540 — 90,908 Total costs and expenses — — 3,706,603 20,790 (13,780 ) 3,713,613 OPERATING INCOME — — 109,643 22,266 642 132,551 Equity in earnings of equity investees — — 43,135 — — 43,135 Equity in earnings of subsidiaries 172,828 — 6,952 — (179,780 ) — Interest (expense) income, net (66,626 ) — 15,662 (15,675 ) — (66,639 ) Income before income taxes 106,202 — 175,392 6,591 (179,138 ) 109,047 Income tax benefit (expense) — — (3,030 ) 185 — (2,845 ) Income from continuing operations 106,202 — 172,362 6,776 (179,138 ) 106,202 NET INCOME $ 106,202 $ — $ 172,362 $ 6,776 $ (179,138 ) $ 106,202 Condensed Consolidating Statement of Operations Year Ended December 31, 2013 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated REVENUES: Pipeline transportation services $ — $ — $ 60,707 $ 25,801 $ — $ 86,508 Refinery services — — 203,021 17,835 (14,871 ) 205,985 Marine transportation — — 152,542 — — 152,542 Supply and logistics — — 3,689,795 — — 3,689,795 Total revenues — — 4,106,065 43,636 (14,871 ) 4,134,830 COSTS AND EXPENSES: Supply and logistics costs — — 3,649,328 — — 3,649,328 Marine transportation costs — — 104,676 — — 104,676 Refinery services operating costs — — 128,814 16,873 (14,398 ) 131,289 Pipeline transportation operating costs — — 26,087 1,119 — 27,206 General and administrative — — 46,790 — — 46,790 Depreciation and amortization — — 62,194 2,590 — 64,784 Total costs and expenses — — 4,017,889 20,582 (14,398 ) 4,024,073 OPERATING INCOME — — 88,176 23,054 (473 ) 110,757 Equity in earnings of equity investees — — 22,675 — — 22,675 Equity in earnings of subsidiaries 134,616 — 6,913 — (141,529 ) — Interest (expense) income, net (48,507 ) — 16,080 (16,156 ) — (48,583 ) Income before income taxes 86,109 — 133,844 6,898 (142,002 ) 84,849 Income tax benefit (expense) — — (676 ) (169 ) — (845 ) Income from continuing operations 86,109 — 133,168 6,729 (142,002 ) 84,004 Income from discontinued operations — — 2,105 — — 2,105 NET INCOME $ 86,109 $ — $ 135,273 $ 6,729 $ (142,002 ) $ 86,109 Condensed Consolidating Statement of Operations Year Ended December 31, 2012 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated REVENUES: Pipeline transportation services $ — $ — $ 50,106 $ 26,184 $ — $ 76,290 Refinery services — — 192,083 19,999 (16,065 ) 196,017 Marine transportation — — 118,204 — — 118,204 Supply and logistics — — 2,976,850 — — 2,976,850 Total revenues — — 3,337,243 46,183 (16,065 ) 3,367,361 COSTS AND EXPENSES: Supply and logistics costs — — 2,923,746 — — 2,923,746 Marine transportation costs — — 80,547 — — 80,547 Refinery services operating costs — — 120,095 19,489 (16,107 ) 123,477 Pipeline transportation operating costs — — 21,081 813 — 21,894 General and administrative — — 41,837 — — 41,837 Depreciation and amortization — — 58,554 2,596 — 61,150 Total costs and expenses — — 3,245,860 22,898 (16,107 ) 3,252,651 OPERATING INCOME — — 91,383 23,285 42 114,710 Equity in earnings of equity investees — — 14,345 — — 14,345 Equity in earnings of subsidiaries 137,151 — 7,184 — (144,335 ) — Interest (expense) income, net (40,832 ) — 16,500 (16,591 ) — (40,923 ) Income before income taxes 96,319 — 129,412 6,694 (144,293 ) 88,132 Income tax benefit — — 8,903 302 — 9,205 Income from continuing operations 96,319 — 138,315 6,996 (144,293 ) 97,337 Loss from discontinued operations — — (1,018 ) — — (1,018 ) NET INCOME 96,319 — 137,297 6,996 (144,293 ) 96,319 Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2014 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated Net cash (used in) provided by operating activities $ (148,008 ) $ — $ 591,431 $ 5,296 $ (157,665 ) $ 291,054 CASH FLOWS FROM INVESTING ACTIVITIES: Payments to acquire fixed and intangible assets — — (443,482 ) — — (443,482 ) Cash distributions received from equity investees - return of investment 42,755 — 18,363 — (42,755 ) 18,363 Investments in equity investees (225,725 ) — (40,926 ) — 225,725 (40,926 ) Acquisitions — — (157,000 ) — — (157,000 ) Repayments on loan to non-guarantor subsidiary — — 4,993 — (4,993 ) — Proceeds from asset sales — — 272 — — 272 Other, net — — (1,214 ) — — (1,214 ) Net cash used in investing activities (182,970 ) — (618,994 ) — 177,977 (623,987 ) CASH FLOWS FROM FINANCING ACTIVITIES: Borrowings on senior secured credit facility 1,839,900 — — — — 1,839,900 Repayments on senior secured credit facility (1,872,300 ) — — — — (1,872,300 ) Proceeds from issuance of senior unsecured notes, including premium 350,000 — — — — 350,000 Debt issuance costs (11,896 ) — — — — (11,896 ) Issuance of common units for cash, net 225,725 — 225,725 — (225,725 ) 225,725 Distributions to partners/owners (200,461 ) — (200,462 ) — 200,462 (200,461 ) Other, net (1 ) — 2,561 (4,950 ) 4,951 2,561 Net cash provided by financing activities 330,967 — 27,824 (4,950 ) (20,312 ) 333,529 Net increase (decrease) in cash and cash equivalents (11 ) — 261 346 — 596 Cash and cash equivalents at beginning of period 20 — 8,049 797 — 8,866 Cash and cash equivalents at end of period $ 9 $ — $ 8,310 $ 1,143 $ — $ 9,462 Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2013 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated Net cash (used in) provided by operating activities $ (280,155 ) $ — $ 557,879 $ 5,101 $ (144,439 ) $ 138,386 CASH FLOWS FROM INVESTING ACTIVITIES: Payments to acquire fixed and intangible assets — — (343,119 ) — — (343,119 ) Cash distributions received from equity investees - return of investment 23,963 — 12,432 — (23,963 ) 12,432 Investments in equity investees (263,574 ) — (94,551 ) — 263,574 (94,551 ) Acquisitions — — (230,880 ) — — (230,880 ) Repayments on loan to non-guarantor subsidiary — — 4,512 — (4,512 ) — Proceeds from assets sales — — 1,910 — — 1,910 Other, net — — (1,622 ) — — (1,622 ) Net cash used in investing activities (239,611 ) — (651,318 ) — 235,099 (655,830 ) CASH FLOWS FROM FINANCING ACTIVITIES: Borrowings on senior secured credit facility 1,593,300 — — — — 1,593,300 Repayments on senior secured credit facility (1,510,500 ) — — — — (1,510,500 ) Proceeds from issuance of senior unsecured notes, including premium 350,000 — — — — 350,000 Debt issuance costs (8,157 ) — — — — (8,157 ) Issuance of ownership interests to partners for cash 263,574 — 263,574 — (263,574 ) 263,574 Distributions to partners/owners (168,441 ) — (168,441 ) — 168,441 (168,441 ) Other, net — — (4,748 ) (4,473 ) 4,473 (4,748 ) Net cash provided by (used in) financing activities 519,776 — 90,385 (4,473 ) (90,660 ) 515,028 Net increase (decrease) in cash and cash equivalents 10 — (3,054 ) 628 — (2,416 ) Cash and cash equivalents at beginning of period 10 — 11,103 169 — 11,282 Cash and cash equivalents at end of period $ 20 $ — $ 8,049 $ 797 $ — $ 8,866 Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2012 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated Net cash (used in) provided by operating activities $ (70,083 ) $ — $ 371,256 $ 2,602 $ (114,471 ) $ 189,304 CASH FLOWS FROM INVESTING ACTIVITIES: Payments to acquire fixed and intangible assets — — (146,296 ) (160 ) — (146,456 ) Cash distributions received from equity investees - return of investment 27,878 — 14,909 — (27,878 ) 14,909 Investments in equity investees (169,421 ) — (63,749 ) — 169,421 (63,749 ) Acquisitions — — (205,576 ) — — (205,576 ) Repayments on loan to non-guarantor subsidiary — — 4,078 — (4,078 ) — Proceeds from asset sales — — 773 — — 773 Other, net — — (1,508 ) — — (1,508 ) Net cash used in investing activities (141,543 ) — (397,369 ) (160 ) 137,465 (401,607 ) CASH FLOWS FROM FINANCING ACTIVITIES: Borrowings on senior secured credit facility 1,674,400 — — — — 1,674,400 Repayments on senior secured credit facility (1,583,700 ) — — — — (1,583,700 ) Proceeds from issuance of senior unsecured notes 101,000 — — — — 101,000 Debt issuance costs (7,105 ) — — — — (7,105 ) Issuance of ownership interests to partners for cash 169,421 — 169,421 — (169,421 ) 169,421 Distributions to partners/owners (142,383 ) — (142,383 ) — 142,383 (142,383 ) Other, net — — 1,135 (4,044 ) 4,044 1,135 Net cash provided by financing activities 211,633 — 28,173 (4,044 ) (22,994 ) 212,768 Net increase in cash and cash equivalents 7 — 2,060 (1,602 ) — 465 Cash and cash equivalents at beginning of period 3 — 9,043 1,771 — 10,817 Cash and cash equivalents at end of period $ 10 $ — $ 11,103 $ 169 $ — $ 11,282

Summary Of Significant Accoun29

Summary Of Significant Accounting Policies (Policy)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Deferred Marine Transportation Charges [Policy Text Block]	Deferred Charges on Marine Transportation Assets Our marine vessels are required by US Coast Guard regulations to be re-certified after a certain period of time, usually every five years. The US Coast Guard states that vessels must meet specified "seaworthiness" standards to maintain required operating certificates. To meet such standards, vessels must undergo regular inspection, monitoring, and maintenance, referred to as "dry-docking." Typical dry-docking costs include costs incurred to comply with regulatory and vessel classification inspection requirements, blasting and steel coating, and steel replacement. We defer and amortize these costs to maintenance and repair expense over the length of time that the certification is supposed to last.
Basis of Consolidation and Presentation	Basis of Consolidation and Presentation The accompanying financial statements and related notes present our consolidated financial position as of December 31, 2014 and 2013 and our results of operations, changes in partners’ capital and cash flows for the years ended December 31, 2014 , 2013 and 2012 . All intercompany balances and transactions have been eliminated. The accompanying Consolidated Financial Statements include Genesis Energy, L.P. and its subsidiaries. Except per unit amounts, or as noted within the context of each footnote disclosure, the dollar amounts presented in the tabular data within these footnote disclosures are stated in thousands of dollars.
Joint Ventures	Joint Ventures We participate in several joint ventures, including a 50% interest in Cameron Highway Oil Pipeline Company (or “CHOPS”), a 50% interest in Southeast Keathley Canyon Pipeline Company, LLC (or “SEKCO”), a 28% interest in Poseidon Oil Pipeline Company, L.L.C. (or "Poseidon") and a 29% interest in Odyssey Pipeline L.L.C. (or "Odyssey"). We account for our investments in these joint ventures by the equity method of accounting. See Notes 3 and 8 .
Use of Estimates	Use of Estimates The preparation of our Consolidated Financial Statements requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities, if any, at the date of the Consolidated Financial Statements and the reported amounts of revenues and expenses during the reporting period. We based these estimates and assumptions on historical experience and other information that we believed to be reasonable under the circumstances. Significant estimates that we make include: (1) liability and contingency accruals, (2) estimated fair value of assets and liabilities acquired and identification of associated goodwill and intangible assets, (3) estimates of future net cash flows from assets for purposes of determining whether impairment of those assets has occurred, and (4) estimates of future asset retirement obligations. Additionally, for purposes of the calculation of the fair value of awards under equity-based compensation plans, we make estimates regarding the expected life of the rights, expected forfeiture rates of the rights, volatility of our unit price and expected future distribution yield on our units. While we believe these estimates are reasonable, actual results could differ from these estimates. Changes in facts and circumstances may result in revised estimates.
Cash and Cash Equivalents	Cash and Cash Equivalents Cash and cash equivalents consist of all demand deposits and funds invested in highly liquid instruments with original maturities of three months or less. We have no requirement for compensating balances or restrictions on cash. We periodically assess the financial condition of the institutions where these funds are held and believe that our credit risk is minimal.
Accounts Receivable	Accounts Receivable We review our outstanding accounts receivable balances on a regular basis and record an allowance for amounts that we expect will not be fully recovered. Actual balances are not applied against the reserve until substantially all collection efforts have been exhausted.
Inventories	Inventories Our inventories are valued at the lower of cost or market. Cost is determined principally under the average cost method within specific inventory pools.
Fixed Assets	Fixed Assets Property and equipment are carried at cost. Depreciation of property and equipment is provided using the straight-line method over the respective estimated useful lives of the assets. Asset lives are 5 to 40 years for pipelines and related assets, 20 to 30 years for marine vessels, 10 to 20 years for machinery and equipment, 3 to 7 years for transportation equipment, and 3 to 10 years for buildings and improvements, office equipment, furniture and fixtures and other equipment. Interest is capitalized in connection with the construction of major facilities. The capitalized interest is recorded as part of the asset to which it relates and is amortized over the asset’s estimated useful life. Maintenance and repair costs are charged to expense as incurred. Costs incurred for major replacements and upgrades are capitalized and depreciated over the remaining useful life of the asset. Certain volumes of crude oil and refined products are classified in fixed assets, as they are necessary to ensure efficient and uninterrupted operations of the gathering businesses. These crude oil and refined products volumes are carried at their weighted average cost. Long-lived assets are reviewed for impairment. An asset is tested for impairment when events or circumstances indicate that its carrying value may not be recoverable. The carrying value of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to be generated from the use and ultimate disposal of the asset. If the carrying value is determined to not be recoverable under this method, an impairment charge equal to the amount the carrying value exceeds the fair value is recognized. Fair value is generally determined from estimated discounted future net cash flows.
Asset Retirement Obligations	Asset Retirement Obligations Some of our assets have contractual or regulatory obligations to perform dismantlement and removal activities, and in some instances remediation, when the assets are abandoned. In general, our future asset retirement obligations relate to future costs associated with the removal of our oil and CO 2 pipelines, barge decommissioning, removal of equipment and facilities from leased acreage and land restoration. The fair value of a liability for an asset retirement obligation is recorded in the period in which it is incurred, discounted to its present value using our credit adjusted risk-free interest rate, and a corresponding amount capitalized by increasing the carrying amount of the related long-lived asset. The capitalized cost is depreciated over the useful life of the related asset. Accretion of the discount increases the liability and is recorded to expense.
Direct Financing Leasing Arrangements	Direct Financing Leasing Arrangements For our direct financing leases, we record the gross finance receivable, unearned income and the estimated residual value of the leased pipelines. Unearned income represents the excess of the gross receivable plus the estimated residual value over the costs of the pipelines. Unearned income is recognized as financing income using the interest method over the term of the transaction and is included in pipeline transportation services revenue in the Consolidated Statements of Operations. The pipeline cost is not included in fixed assets. We review our direct financing lease arrangements for credit risk. Such review includes consideration of the credit rating and financial position of the lessee.
CO2 Assets	CO 2 Assets Our CO 2 assets include three volumetric production payments, which are amortized on a units-of-production method. These assets are included in Other Assets in our Consolidated Balance Sheets.
Intangible and Other Assets	Intangible and Other Assets Intangible assets with finite useful lives are amortized over their respective estimated useful lives. If an intangible asset has a finite useful life, but the precise length of that life is not known, that intangible asset shall be amortized over the best estimate of its useful life. At a minimum, we will assess the useful lives and residual values of all intangible assets on an annual basis to determine if adjustments are required. We are amortizing our customer and supplier relationships, contract agreements, licensing agreements and trade name based on the period over which the asset is expected to contribute to our future cash flows. Generally, the contribution of these assets to our cash flows is expected to decline over time, such that greater value is attributable to the periods shortly after the acquisition was made. Intangible assets associated with lease or other items are being amortized on a straight-line basis. We test intangible assets periodically to determine if impairment has occurred. An impairment loss is recognized for intangibles if the carrying amount of an intangible asset is not recoverable and its carrying amount exceeds its fair value. No impairment has occurred of intangible assets in any of the periods presented. Costs incurred in connection with the issuance of long-term debt and certain amendments to our credit facilities are capitalized and amortized using the straight-line method over the term of the related debt. Use of the straight-line method does not differ materially from the “effective interest” method of amortization.
Goodwill	Goodwill Goodwill represents the excess of purchase price over fair value of net assets acquired. We evaluate, and test if necessary, goodwill for impairment annually at October 1, and more frequently if indicators of impairment are present. During evaluation, we perform a qualitative assessment of relevant events and circumstances to determine the likelihood of goodwill impairment. If it is deemed more likely than not that the fair value of the reporting unit is less than its carrying amount, we calculate the fair value of the reporting unit. Otherwise, further testing is not necessary. If the calculated fair value of the reporting unit exceeds its book value including associated goodwill amounts, the goodwill is considered to be unimpaired and no impairment charge is required. If the fair value of the reporting unit is less than its book value including associated goodwill amounts, a charge to earnings may be necessary to reduce the carrying value of the goodwill to its implied fair value. In the event that we determine that goodwill has become impaired, we will incur a charge for the amount of impairment during the period in which the determination is made. No goodwill impairment has occurred in any of the periods presented.
Environmental Liabilities	Environmental Liabilities We provide for the estimated costs of environmental contingencies when liabilities are probable to occur and a reasonable estimate of the associated costs can be made. Ongoing environmental compliance costs, including maintenance and monitoring costs, are charged to expense as incurred.
Equity-Based Compensation	Equity-Based Compensation Our stock appreciation rights plan and phantom units issued under our 2010 Long-Term Incentive Plan result in the payment of cash to our employees or directors of our general partner upon exercise or vesting of the related award. The fair values of our equity-based awards are re-measured at the end of each reporting period and are recorded as liabilities. The liability and related compensation cost for our stock appreciation rights are calculated using a Black-Scholes option pricing model that takes into consideration the expected future value of the rights at their expected exercise dates and management’s assumptions about expectation of forfeitures prior to vesting. The fair value of our phantom units is equal to the market price of our common units. Our phantom units include both service-based and performance-based awards. For our performance-based awards, our fair value estimates are weighted based on probabilities for each performance condition applicable to the award. See Note 15 for more information on these plans.
Revenue Recognition	Revenue Recognition Product Sales—Revenues from the sale of crude oil, petroleum products and CO 2 by our supply and logistics segment, and caustic soda and NaHS by our refinery services segment are recognized when title to the inventory is transferred to the customer, pricing is fixed and determinable, collectibility is reasonably assured and there are no further significant obligations for future performance by us. Most frequently, title transfers upon our delivery of the inventory to the customer at a location designated by the customer, although in certain situations, title transfers when the inventory is loaded for transportation to the customer. Our crude oil and petroleum products are typically sold at prices based off daily or monthly published prices. Many of our contracts for sales of NaHS incorporate the price of caustic soda in the pricing formulas. Marine Transportation—Revenues from the inland and offshore marine transportation of heavy refined petroleum products, including asphalt and crude oil, via our barges or vessels are recognized over the transit time of individual shipments as determined on an individual contract basis. Revenue from these contracts is typically based on a set day rate or a set fee per cargo movement. The costs of fuel, substantially all of which is a pass through expense, and other specified operational costs are directly reimbursed by the customer under most of these contracts. Rail Facility Loading and Unloading Revenues—Revenues based on a per barrel fee from the loading and/or unloading of crude oil at our rail facilities is recognized as the crude oil enters or exits the railcars. Pipeline Transportation—Revenues from transportation of crude oil by our pipelines are based on actual volumes at a published tariff. Tariff revenues are recognized either at the point of delivery or at the point of receipt pursuant to the specifications outlined in our regulated tariffs. In order to compensate us for bearing the risk of volumetric losses in volumes that occur to crude oil in our pipelines due to temperature, crude quality and the inherent difficulties of measurement of liquids in a pipeline, our tariffs include the right for us to make volumetric deductions from the shippers for quality and volumetric fluctuations. We refer to these deductions as pipeline loss allowances. We compare these allowances to the actual volumetric gains and losses of the pipeline and the net gain or loss is recorded as revenue or a reduction of revenue, based on prevailing market prices at that time. When net gains occur, we have crude oil inventory. When net losses occur, we reduce any recorded inventory on hand and record a liability for the purchase of crude oil that we must make to replace the lost volumes. We reflect inventories in the Consolidated Financial Statements at the lower of the recorded value or the market value at the balance sheet date. We value liabilities to replace crude oil at current market prices. The crude oil in inventory can then be sold, resulting in additional revenue if the sales price exceeds the inventory value. Income from direct financing leases is being recognized ratably over the term of the leases and is included in pipeline revenues.
Cost of Sales and Operating Expenses	Cost of Sales and Operating Expenses Supply and logistics costs and expenses include the cost to acquire the product and the associated costs to transport it to our terminal facilities or to a customer for sale. Other than the cost of the products, the most significant costs we incur relate to transportation utilizing our fleet of trucks, railcars and barges, including personnel costs, fuel and maintenance of our equipment. When we enter into buy/sell arrangements concurrently or in contemplation of one another with a single counterparty, we reflect the amounts of revenues and purchases for these transactions on a net basis in our Consolidated Statements of Operations as supply and logistics revenues. Marine operating costs consist primarily of employee and related costs to man the boats, barges, and vessels, maintenance and supply costs related to general upkeep of the boats, barges, and vessels, and fuel costs which are rebillable and passed through to the customer. The most significant operating costs in our refinery services segment consist of the costs to operate NaHS plants located at various refineries, caustic soda used in the process of processing the refiner’s sour gas stream, and costs to transport the NaHS and caustic soda. Pipeline operating costs consist primarily of power costs to operate pumping equipment, personnel costs to operate the pipelines, insurance costs and costs associated with maintaining the integrity of our pipelines.
Excise and Sales Taxes	Excise and Sales Taxes We collect and remit excise and sales taxes to state and federal governmental authorities on its sales of fuels. These taxes are presented on a net basis, with any differences due to rebates allowed by those governmental entities reflected as a reduction of product cost in the Consolidated Statements of Operations.
Income Taxes	Income Taxes We are a limited partnership, organized as a pass-through entity for federal income tax purposes. As such, we do not directly pay federal income tax. Our taxable income or loss, which may vary substantially from the net income or net loss we report in our Consolidated Statements of Operations, is included in the federal income tax returns of each partner. Some of our corporate subsidiaries pay U.S. federal, state, and foreign income taxes. Deferred income tax assets and liabilities for certain operations conducted through corporations are recognized for temporary differences between the assets and liabilities for financial reporting and tax purposes. Changes in tax legislation are included in the relevant computations in the period in which such changes are effective. Deferred tax assets are reduced by a valuation allowance for the amount of any tax benefit not expected to be realized. Penalties and interest related to income taxes will be included in income tax expense in the Consolidated Statements of Operations.
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities When we hold inventory positions in crude oil and petroleum products, we use derivative instruments to hedge exposure to price risk. Derivative transactions, which can include forward contracts and futures positions on the NYMEX, are recorded in the Consolidated Balance Sheets as assets and liabilities based on the derivative’s fair value. Changes in the fair value of derivative contracts are recognized currently in earnings unless specific hedge accounting criteria are met. We must formally designate the derivative as a hedge and document and assess the effectiveness of derivatives associated with transactions that receive hedge accounting. Accordingly, changes in the fair value of derivatives are included in earnings in the current period for (i) derivatives accounted for as fair value hedges; (ii) derivatives that do not qualify for hedge accounting and (iii) the portion of cash flow hedges that is not highly effective in offsetting changes in cash flows of hedged items. Changes in the fair value of cash flow hedges are deferred in Accumulated Other Comprehensive Income (“AOCI”) and reclassified into earnings when the underlying position affects earnings.
Fair Value of Current Assets and Current Liabilities	Fair Value of Current Assets and Current Liabilities The carrying amount of other current assets and other current liabilities approximates their fair value due to their short-term nature.
Net Income Per Common Unit	Net Income Per Common Unit Basic and diluted net income per common unit is determined by dividing net income attributable to limited partners by the weighted average number of outstanding common units during the period.
Reclassification, Policy [Policy Text Block]	Prior Period Reclassifications Certain prior period amounts have been reclassified to conform to the current period presentation, including our expanded presentation of "Revenues" and "Costs and Expenses" on our Consolidated Statements of Operations and expanded presentation in Note 1 2 relating to our change in segment reporting as previously discussed in Note 1 .
Recent and Proposed Accounting Pronouncements	Recent and Proposed Accounting Pronouncements In May 2014, the Financial Accounting Standards Board ("FASB") issued revised guidance on revenue from contracts with customers that will supersede most current revenue recognition guidance, including industry-specific guidance. The core principle of the revenue model is that an entity will recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The new standard provides a five-step analysis for transactions to determine when and how revenue is recognized. The guidance will be effective for us beginning January 1, 2017 and early adoption is not permitted. The guidance permits the use of either a full retrospective or a modified retrospective approach. We are evaluating the transition methods and the impact of the amended guidance on our financial position, results of operations and related disclosures.

Acquisitions (Tables)

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
American Phoenix Acquisition [Member]
Business Acquisition [Line Items]
Schedule of Purchase Price Allocation	The allocation of the purchase price, as presented on our Consolidated Balance Sheet, is summarized as follows: Property and equipment $ 125,000 Intangible assets 32,000 Total purchase price $ 157,000
Selected Financial Information	The following table presents selected financial information included in our Consolidated Financial Statements for the periods presented: Year Ended 2014 Revenues $ 3,038 Net income $ 454
Schedule of Pro Forma Financial Information	The table below presents selected unaudited pro forma financial information for us incorporating the historical results of the acquired M/T American Phoenix. The pro forma financial information below has been prepared as if the acquisition had been completed on January 1, 2013 and is based upon assumptions deemed appropriate by us and may not be indicative of actual results. Depreciation expense for the fixed assets acquired is calculated on a straight-line basis over an estimated useful life of approximately 30 years. Year Ended 2014 2013 Pro forma earnings data: Revenues from continuing operations $ 3,863,745 $ 4,153,443 Net Income $ 111,132 $ 90,829
Hornbeck Acquisition [Member]
Business Acquisition [Line Items]
Selected Financial Information		The following table presents selected financial information included in our Consolidated Financial Statements for the periods presented: Year Ended 2013 Revenues $ 30,424 Net income $ 7,348
Schedule of Pro Forma Financial Information		The table below presents selected unaudited pro forma financial information for us incorporating the historical results of our offshore marine transportation business. The pro forma financial information below has been prepared as if the acquisition had been completed on January 1, 2012 and is based upon assumptions deemed appropriate by us and may not be indicative of actual results. Depreciation expense for the fixed assets acquired is calculated on a straight-line basis over an estimated useful life of approximately 25 years. Year Ended 2013 2012 Pro forma earnings data: Revenues from continuing operations $ 4,177,715 $ 3,416,790 Net Income $ 98,846 $ 98,665
Gulf Of Mexico Crude Oil Pipeline Systems [Member]
Business Acquisition [Line Items]
Selected Financial Information			The following table presents selected financial information included in our Consolidated Financial Statements for the year ended December 31, 2012 : Year Ended 2012 Revenues $ 5,508 Equity in earnings of equity investees $ 13,118 Net income $ 15,112

Acquisitions and Divestitures D

Acquisitions and Divestitures Divestitures Tables (Tables)	12 Months Ended
	Dec. 31, 2013
Discontinued Operations and Disposal Groups [Abstract]
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	The summarized operating results of our discontinued operations are as follows: Year Ended 2013 2012 Revenues $ 593,733 $ 702,695 Cost and expenses 592,505 703,715 Operating income (loss) 1,228 (1,020 ) Interest income 2 2 Income (loss) before income taxes 1,230 (1,018 ) Gain on sale of discontinued operations 875 — Income (loss) from discontinued operations $ 2,105 $ (1,018 )

Receivables (Tables)

Receivables (Tables)	12 Months Ended
	Dec. 31, 2014
Accounts Receivable, Net, Current [Abstract]
Schedule Of Trade Accounts Receivables Net	December 31, 2014 2013 Accounts receivable - trade $ 274,502 $ 369,559 Allowance for doubtful accounts (2,973 ) (1,526 ) Accounts receivable - trade, net $ 271,529 $ 368,033
Schedule Of Allowance For Doubtful Accounts	The following table presents the activity of our allowance for doubtful accounts for the periods indicated: December 31, 2014 2013 2012 Balance at beginning of period $ 1,526 $ 2,372 $ 1,044 (Credited) charged to costs and expenses 1,447 (86 ) 2,096 Amounts written off — (760 ) (768 ) Balance at end of period $ 2,973 $ 1,526 $ 2,372

Inventories (Tables)

Inventories (Tables)	12 Months Ended
	Dec. 31, 2014
Inventory Disclosure [Abstract]
Schedule Of Major Components Of Inventories	December 31, 2014 2013 Petroleum products $ 30,108 $ 71,373 Crude oil 7,266 5,380 Caustic soda 2,850 2,679 NaHS 6,603 5,845 Other 2 53 Total $ 46,829 $ 85,330

Fixed Assets and Asset Retire34

Fixed Assets and Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2014
Fixed Assets And Asset Retirement Obligations [Abstract]
Schedule Of Fixed Assets	December 31, 2014 2013 Pipelines and related assets $ 466,613 $ 338,920 Machinery and equipment 376,672 173,092 Transportation equipment 18,479 19,140 Marine vessels 731,016 554,679 Land, buildings and improvements 38,037 30,170 Office equipment, furniture and fixtures 6,696 5,633 Construction in progress 222,233 183,037 Other 39,312 23,303 Fixed assets, at cost 1,899,058 1,327,974 Less: Accumulated depreciation (268,057 ) (199,230 ) Net fixed assets $ 1,631,001 $ 1,128,744
Schedule Of Reconciliation Of Liability For Asset Retirement Obligations	A reconciliation of our liability for asset retirement obligations is as follows: December 31, 2012 $ 12,695 Liabilities incurred 789 Accretion expense 848 December 31, 2013 14,332 Liabilities incurred — Accretion expense 458 December 31, 2014 $ 14,790

Net Investment In Direct Fina35

Net Investment In Direct Financing Leases (Tables)	12 Months Ended
	Dec. 31, 2014
Leases [Abstract]
Components Of Net Investment In Direct Financing Leases	December 31, 2014 2013 Total minimum lease payments to be received $ 277,732 $ 298,924 Estimated residual values of leased property (unguaranteed) 292 292 Unamortized initial direct costs 1,444 1,621 Less unearned income (127,531 ) (143,415 ) Net investment in direct financing leases 151,937 157,422 Less current portion (included in other current assets) (5,978 ) (5,519 ) Long-term portion of net investment in direct financing leases $ 145,959 $ 151,903

Equity Investees (Tables)

Equity Investees (Tables)	12 Months Ended
	Dec. 31, 2014
Equity Method Investments and Joint Ventures [Abstract]
Consolidated Financial Statements Related To Equity Investees	Year Ended December 31, 2014 2013 2012 Genesis’ share of operating earnings $ 53,783 $ 33,152 $ 24,532 Amortization of excess purchase price (10,648 ) (10,477 ) (10,187 ) Net equity in earnings $ 43,135 $ 22,675 $ 14,345 Distributions received $ 75,528 $ 46,564 $ 38,809
Schedule Of Balance Sheet Information For Equity Investees	December 31, 2014 2013 BALANCE SHEET DATA: Assets Current assets $ 42,135 $ 70,921 Fixed assets, net 1,015,305 1,028,808 Other assets 4,369 6,823 Total assets $ 1,061,809 $ 1,106,552 Liabilities and equity Current liabilities $ 25,369 $ 55,918 Other liabilities 202,613 190,578 Equity 833,827 860,056 Total liabilities and equity $ 1,061,809 $ 1,106,552
Schedule Of Operations For Equity Investees	Year Ended December 31, 2014 2013 2012 INCOME STATEMENT DATA: Revenues $ 246,265 $ 183,533 $ 162,267 Operating Income $ 146,760 $ 102,107 $ 80,841 Net Income $ 142,754 $ 99,357 $ 77,975

Intangible Assets, Goodwill A37

Intangible Assets, Goodwill And Other Assets (Tables)	12 Months Ended
	Dec. 31, 2014
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule Of Intangible Assets	December 31, 2014 December 31, 2013 Weighted Amortization Period in Years Gross Carrying Amount Accumulated Amortization Carrying Value Gross Carrying Amount Accumulated Amortization Carrying Value Refinery Services: Customer relationships 5 $ 94,654 $ 81,880 $ 12,774 $ 94,654 $ 76,283 $ 18,371 Licensing agreements 6 38,678 28,983 9,695 38,678 26,055 12,623 Segment total 133,332 110,863 22,469 133,332 102,338 30,994 Supply & Logistics: Customer relationships 5 35,430 30,228 5,202 35,430 28,568 6,862 Intangibles associated with lease 15 13,260 3,512 9,748 13,260 3,039 10,221 Segment total 48,690 33,740 14,950 48,690 31,607 17,083 Marine contract intangibles 5 32,000 833 31,167 — — — Other 5 22,797 8,452 14,345 21,356 6,505 14,851 Total $ 236,819 $ 153,888 $ 82,931 $ 203,378 $ 140,450 $ 62,928
Schedule Of Estimated Amortization Expense	2015 2016 2017 2018 2019 Refinery Services: Customer relationships $ 4,405 $ 3,471 $ 2,737 $ 2,161 $ — Licensing agreements 2,711 2,510 2,324 2,150 — Supply and Logistics: Customer relationships 1,275 981 757 586 454 Intangibles associated with lease 474 474 474 474 474 Marine contract intangibles 6,417 5,400 5,400 5,400 5,400 Other 2,057 2,025 2,006 2,006 2,006 Total $ 17,339 $ 14,861 $ 13,698 $ 12,777 $ 8,334
Schedule Of Other Assets	December 31, 2014 2013 CO 2 volumetric production payments, net of amortization $ 9,395 $ 4,421 Deferred marine charges (1) 13,042 2,829 Other deferred costs and deposits 38,854 30,861 Other assets, net of amortization $ 61,291 $ 38,111 (1) See discussion of deferred charges on marine transportation assets in the Summary of Accounting Policies ( Note 2 )

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Schedule Of Obligations Under Debt Arrangements	December 31, 2014 2013 Senior secured credit facility $ 550,400 $ 582,800 7.875% senior unsecured notes (including unamortized premium of $639 and $772 in 2014 and 2013, respectively) 350,639 350,772 5.750% senior unsecured notes $ 350,000 350,000 5.625% senior unsecured notes $ 350,000 — Total long-term debt $ 1,601,039 $ 1,283,572

Partners' Capital and Distrib39

Partners' Capital and Distributions (Tables)	12 Months Ended
	Dec. 31, 2014
Partners' Capital Notes [Abstract]
Distributions	Distribution For Date Paid Per Unit Amount Total Amount 2012 4th Quarter February 14, 2013 $ 0.4850 $ 39,390 2013 1st Quarter May 15, 2013 $ 0.4975 $ 40,405 2nd Quarter August 14, 2013 $ 0.5100 $ 42,302 3rd Quarter November 14, 2013 $ 0.5225 $ 46,344 4th Quarter February 14, 2014 $ 0.5350 $ 47,453 2014 1st Quarter May 15, 2014 $ 0.5500 $ 48,783 2nd Quarter August 14, 2014 $ 0.5650 $ 50,114 3rd Quarter November 14, 2014 $ 0.5800 $ 54,112 4th Quarter February 13, 2015 $ 0.5950 $ 56,542
New Common Units Issued To The Public For Cash	Period Purchaser of Common Units Units Gross Unit Price Issuance Value Costs Net Proceeds September 2014 Public 4,600 $ 50.71 $ 233,266 $ (7,541 ) $ 225,725 September 2013 Public 5,750 $ 47.51 $ 273,183 $ (9,609 ) $ 263,574 March 2012 Public 5,750 $ 30.80 $ 177,100 $ (7,679 ) $ 169,421

Business Segment Information (T

Business Segment Information (Tables)	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Schedule Of Segment Information	Onshore Pipeline Transportation Offshore Pipeline Transportation Refinery Services Marine Transportation Supply & Logistics (a) Total Year Ended December 31, 2014 Segment Margin (b) $ 61,231 $ 71,598 $ 84,851 $ 86,239 $ 43,345 $ 347,264 Capital expenditures (c) $ 46,611 $ 37,639 $ 2,385 $ 232,783 $ 325,130 $ 644,548 Revenues: External customers $ 66,760 $ 3,296 $ 218,297 $ 214,039 $ 3,343,772 $ 3,846,164 Intersegment (d) 16,397 — (10,896 ) 15,243 (20,744 ) — Total revenues of reportable segments $ 83,157 $ 3,296 $ 207,401 $ 229,282 $ 3,323,028 $ 3,846,164 Year Ended December 31, 2013 Segment Margin (b) $ 64,349 $ 44,530 $ 75,361 $ 47,726 $ 48,394 $ 280,360 Capital expenditures (c) $ 130,787 $ 94,286 $ 3,258 $ 260,736 $ 215,138 $ 704,205 Revenues: External customers $ 65,452 $ 3,923 $ 216,860 $ 131,049 $ 3,717,546 $ 4,134,830 Intersegment (d) 17,133 — (10,875 ) 21,493 (27,751 ) — Total revenues of reportable segments $ 82,585 $ 3,923 $ 205,985 $ 152,542 $ 3,689,795 $ 4,134,830 Year Ended December 31, 2012 Segment Margin (b) $ 58,039 $ 38,500 $ 72,883 $ 37,528 $ 55,383 $ 262,333 Capital expenditures (c) $ 59,345 $ 269,365 $ 2,692 $ 37,188 $ 57,708 $ 426,298 Revenues: External customers $ 56,198 $ 5,508 $ 205,110 $ 99,016 $ 3,001,529 $ 3,367,361 Intersegment (d) 14,584 — (9,093 ) 19,188 (24,679 ) — Total revenues of reportable segments $ 70,782 $ 5,508 $ 196,017 $ 118,204 $ 2,976,850 $ 3,367,361 Total assets by reportable segment were as follows: December 31, 2014 December 31, 2013 December 31, 2012 Onshore pipeline transportation $ 460,012 $ 437,912 $ 325,189 Offshore pipeline transportation 645,668 637,323 565,463 Refinery services 403,703 417,121 414,170 Marine transportation 745,128 529,914 276,736 Supply and logistics 907,189 782,547 473,611 Other assets 68,674 57,385 54,495 Total consolidated assets $ 3,230,374 $ 2,862,202 $ 2,109,664 (a) Discontinued operations are included in Segment Margin but excluded from revenues for all periods presented. (b) A reconciliation of Segment Margin to income from continuing operations before income taxes for each year is presented below. (c) Capital expenditures include maintenance and growth capital expenditures, such as fixed asset additions (including enhancements to existing facilities and construction of internal growth projects) as well as acquisitions of businesses and interests in equity investees. In addition to construction of internal growth projects, capital spending in our Offshore pipeline transportation segment included $36.1 million and $94.3 million during the years ended December 31, 2014 and December 31, 2013 representing capital contributions to our SEKCO equity investee to fund our share of the construction costs for its pipeline. During 2014, capital spending in our marine transportation segment included $157 million for our purchase of the M/T American Phoenix. During 2013, capital spending in our marine segment also included $230.9 million for the acquisition of our offshore marine transportation assets. During 2012, capital spending in our pipeline transportation segment also included $205.6 million for the acquisition of interests in several Gulf of Mexico pipelines. (d) Intersegment sales were conducted under terms that we believe were no more or less favorable than then-existing market conditions.
Reconciliation Of Segment Margin To (Loss) Income Before Income Taxes	Reconciliation of Segment Margin to income from continuing operations: Year Ended December 31, 2014 2013 2012 Segment Margin $ 347,264 $ 280,360 $ 262,333 Corporate general and administrative expenses (47,065 ) (43,353 ) (38,372 ) Depreciation and amortization (90,908 ) (64,784 ) (61,150 ) Interest expense (66,639 ) (48,583 ) (40,923 ) Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1) (31,093 ) (23,889 ) (24,464 ) Non-cash items not included in Segment Margin 3,017 (7,551 ) (5,280 ) Cash payments from direct financing leases in excess of earnings (5,529 ) (5,110 ) (5,016 ) Income tax expense (2,845 ) (845 ) 9,205 Discontinued operations — (2,241 ) 1,004 Income from continuing operations $ 106,202 $ 84,004 $ 97,337 (1) Includes distributions attributable to the quarter and received during or promptly following such quarter.

Transactions with Related Par41

Transactions with Related Parties (Tables)	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Schedule Of Transactions With Related Parties	Year Ended December 31, 2014 2013 2012 Revenues: Sales of CO 2 to Sandhill Group, LLC (1) $ 3,060 $ 3,076 $ 2,905 Petroleum products sales to Davison family businesses (2) — 1,293 1,344 Petroleum products sales to an affiliate of the Quintana Group (2) (3) — — 21,143 Expenses: Amounts paid to our CEO in connection with the use of his aircraft $ 630 $ 600 $ 600 Marine operating fuel and expenses provided by an affiliate of the Quintana Group (3) — — 6,260 (1) We own a 50% interest in Sandhill Group, LLC (or "Sandhill). (2) Amounts included in discontinued operations for all periods presented. (3) The Quintana Group monetized all of its remaining investment in our common units on October 5, 2012 . Transactions with the Quintana Group are included in the above table as related party transactions through October 5, 2012 .

Supplemental Cash Flow Inform42

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2014
Supplemental Cash Flow Elements [Abstract]
Net Changes In Components Of Operating Assets And Liabilities	Year Ended December 31, 2014 2013 2012 (Increase) decrease in: Accounts receivable $ 95,014 $ (96,300 ) $ (34,299 ) Inventories 38,501 1,720 14,074 Deferred Charges (8,935 ) — — Other current assets 62,305 (39,170 ) (9,593 ) Increase (decrease) in: Accounts payable (73,307 ) 41,718 53,146 Accrued liabilities (35,624 ) 45,846 (10,263 ) Net changes in components of operating assets and liabilities $ 77,954 $ (46,186 ) $ 13,065

Employee Benefit Plans And Equi

Employee Benefit Plans And Equity-Based Compensation Plans (Tables)	12 Months Ended
	Dec. 31, 2014
Compensation and Retirement Disclosure [Abstract]
Summary Of Service-Based And Performance-Based Awards	Service-Based Awards Performance-Based Awards Number of Phantom Units Average Grant Date Fair Value Total Value (in thousands) Number of Phantom Units Average Grant Date Fair Value Total Value (in thousands) Unvested at December 31, 2013 105,385 $ 35.42 $ 3,733 334,969 $ 35.79 $ 11,989 Granted 43,225 $ 54.05 2,336 82,763 $ 54.18 4,484 Forfeited (4,599 ) $ 43.19 (199 ) (6,899 ) $ 43.20 (298 ) Settled (31,188 ) $ 27.11 (846 ) (96,988 ) $ 28.21 (2,736 ) Unvested at December 31, 2014 112,823 $ 44.53 $ 5,024 313,845 $ 42.82 $ 13,439
Assumptions Used To Determine Fair Value Of Rights	Assumptions Used for Fair Value of Rights December 31, 2014 December 31, 2013 December 31, 2012 Expected life of rights (in years) Less than 1 Less than 1 Less than 1 Risk-free interest rate —% - 0.07% —% - 0.07% —% - 0.07% Expected unit price volatility 39.3% 39.3% 39.3% Expected future distribution yield 5.00% 5.00% 5.00%
Reconciliation Of Rights Activity	Stock Appreciation Rights Weighted Average Strike Price Weighted Average Contractual Remaining Term (Yrs) Aggregate Intrinsic Value Outstanding at December 31, 2013 207,498 $ 17.43 Exercised during 2014 (37,813 ) $ 51.59 Forfeited or expired during 2014 (8,830 ) $ 16.03 Outstanding at December 31, 2014 160,855 $ 18.08 3.47 $ 3,906 Exercisable at December 31, 2014 160,855 $ 18.08 3.47 $ 3,906
Expense Related To Equity-Based Compensation Plans	Expense Related to Equity-Based Compensation Plans Consolidated Statement of Operations 2014 2013 2012 Supply and logistics operating costs $ 485 $ 4,524 $ 2,707 Marine transportation operating costs 626 586 190 Refinery services operating costs (62 ) 1,978 1,427 Pipeline operating costs (52 ) 510 247 General and administrative expenses 5,824 11,073 6,448 Total $ 6,821 $ 18,671 $ 11,019

Derivatives (Tables)

Derivatives (Tables)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule Of Outstanding Derivatives Entered Into Hedge Inventory Or Fixed Price Purchase Commitments	Sell (Short) Contracts Buy (Long) Contracts Not qualifying or not designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 bbls) 366 168 Weighted average contract price per bbl $ 74.82 $ 65.30 Diesel futures: Contract volumes (1,000 bbls) 56 — Weighted average contract price per gal $ 2.43 $ — #6 Fuel oil futures: Contract volumes (1,000 bbls) 465 95 Weighted average contract price per bbl $ 60.07 $ 44.95 Crude oil options: Contract volumes (1,000 bbls) 125 — Weighted average premium received $ 2.08 $ —
Schedule Of Accounting Treatment And Classification Of Derivative Instruments	Derivative Instrument Hedged Risk Impact of Unrealized Gains and Losses Consolidated Balance Sheets Consolidated Statements of Operations Not qualifying or not designated as hedges under accounting guidance: Commodity hedges consisting of crude oil, heating oil and natural gas futures and forward contracts and call options Volatility in crude oil and petroleum products prices - effect on market value of inventory or purchase commitments Derivative is recorded in Other current assets (offset against margin deposits) or Accrued liabilities Entire amount of change in fair value of derivative is recorded in Supply and logistics costs - product costs
Schedule Of Fair Value Of Derivative Assets And Liabilities	Fair Value Consolidated Balance Sheets Location December 31, 2014 December 31, 2013 Asset Derivatives: Commodity derivatives—futures and call options (undesignated hedges): Gross amount of recognized assets Current Assets - Other $ 16,383 $ 615 Gross amount offset in the Consolidated Balance Sheets Current Assets - Other (2,310 ) (615 ) Net amount of assets presented in the Consolidated Balance Sheets 14,073 — Liability Derivatives: Commodity derivatives—futures and call options (undesignated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (2,310 ) $ (4,527 ) Gross amount offset in the Consolidated Balance Sheets Current Assets - Other (1) 2,310 4,527 Net amount of liabilities presented in the Consolidated Balance Sheets — — (1) These derivative liabilities have been funded with margin deposits recorded in our Consolidated Balance Sheets under Current Assets - Other in 2013.
Schedule Of Effect On Consolidated Statements Of Operations And Other Comprehensive Income (Loss)	Amount of Gain (Loss) Recognized in Income Supply & Logistics Product Costs Year Ended 2014 2013 2012 Commodity derivatives—futures and call options: Contracts designated as hedges under accounting guidance $ — $ — $ — Contracts not considered hedges under accounting guidance 35,468 (3,268 ) (2,936 ) Total derivatives $ 35,468 $ (3,268 ) $ (2,936 )

Fair-Value Measurements (Tables

Fair-Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Placement Of Assets And Liabilities Within The Fair Value Hierarchy Levels	December 31, 2014 December 31, 2013 Recurring Fair Value Measures Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Commodity derivatives: Assets $ 16,383 $ — $ — $ 615 $ — $ — Liabilities $ (2,310 ) $ — $ — $ (4,527 ) $ — $ —

Commitments And Contingencies (

Commitments And Contingencies (Tables)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Future Minimum Rental Payments Under All Non-Cancelable Operating Leases	Office Space Transportation Equipment Terminals and Tanks Total 2015 $ 2,282 $ 14,796 $ 15,752 $ 32,830 2016 1,846 9,451 7,149 18,446 2017 1,625 7,430 2,687 11,742 2018 1,631 5,967 2,692 10,290 2019 1,580 5,705 2,697 9,982 2020 and thereafter 4,484 6,617 20,866 31,967 Total minimum lease obligations $ 13,448 $ 49,966 $ 51,843 $ 115,257
Total Operating Lease Expense	Year Ended December 31, 2014 $ 37,941 Year Ended December 31, 2013 $ 27,674 Year Ended December 31, 2012 $ 21,530

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Tax Expense (Benefit)	Year Ended December 31, 2014 2013 2012 Current: Federal $ — $ 345 $ (8,463 ) State 1,100 650 275 Total current income tax expense (benefit) $ 1,100 $ 995 $ (8,188 ) Deferred: Federal $ 1,508 $ (248 ) $ (1,035 ) State 237 98 18 Total deferred income tax benefit $ 1,745 $ (150 ) $ (1,017 ) Total income tax expense (benefit) from continuing operations (1) $ 2,845 $ 845 $ (9,205 ) (1) Our discontinued operations had no income tax benefit or expense in any period presented.
Deferred Tax Assets And Liabilities	December 31, 2014 2013 Deferred tax assets: Current: Other current assets $ 262 $ 297 Other 8 8 Total current deferred tax asset 270 305 Net operating loss carryforwards 9,048 7,784 Total long-term deferred tax asset 9,048 7,784 Valuation allowances (737 ) (660 ) Total deferred tax assets $ 8,581 $ 7,429 Deferred tax liabilities: Current: Other $ (871 ) $ (785 ) Long-term: Fixed assets (4,335 ) (4,441 ) Intangible assets (14,419 ) (11,503 ) Total long-term liability (18,754 ) (15,944 ) Total deferred tax liabilities $ (19,625 ) $ (16,729 ) Total net deferred tax liability $ (11,044 ) $ (9,300 )
Federal Statutory Income Tax Rate To Income Before Income Taxes	Year Ended December 31, 2014 2013 2012 Income from continuing operations before income taxes $ 109,047 $ 84,849 $ 88,132 Partnership income not subject to tax (104,751 ) (85,567 ) (90,815 ) Income (loss) subject to income taxes $ 4,296 $ (718 ) $ (2,683 ) Tax expense (benefit) at federal statutory rate $ 1,504 $ (251 ) $ (939 ) State income taxes, net of federal tax 992 660 460 Effects of unrecognized tax positions, federal and state — — (8,205 ) Return to provision, federal and state (232 ) 88 (166 ) Other 581 348 (355 ) Income tax expense (benefit) $ 2,845 $ 845 $ (9,205 ) Effective tax rate on income from continuing operations before income taxes (1) 3 % 1 % N/A (1) Income tax expense is related to taxable income generated by our corporate subsidiaries and Texas Margin Tax. Due to the income tax benefit in 2012 , the effective tax rate as a percentage of our total income from continuing operations before income taxes is not meaningful for those periods.

Quarterly Financial Data (Table

Quarterly Financial Data (Tables)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Data [Abstract]
Quarterly Financial Information [Text Block]	Quarterly Financial Data (Unaudited) The table below summarizes our unaudited quarterly financial data for 2014 and 2013 . 2014 Quarters Total First Second Third Fourth Year Revenues from continuing operations $ 1,019,719 $ 1,015,049 $ 964,114 $ 847,282 $ 3,846,164 Operating income $ 35,402 $ 31,257 $ 35,268 $ 30,624 $ 132,551 Income from continuing operations $ 29,775 $ 21,148 $ 29,113 $ 26,166 $ 106,202 Net income $ 29,775 $ 21,148 $ 29,113 $ 26,166 $ 106,202 Basic and diluted net income per common unit: Continuing operations $ 0.34 $ 0.24 $ 0.33 $ 0.28 $ 1.18 Net income per common unit $ 0.34 $ 0.24 $ 0.33 $ 0.28 $ 1.18 Cash distributions per common unit (1) $ 0.5350 $ 0.5500 $ 0.5650 $ 0.5800 $ 2.2300 2013 Quarters Total First Second Third Fourth Year Revenues from continuing operations $ 1,014,808 $ 1,068,694 $ 1,090,293 $ 961,035 $ 4,134,830 Operating income $ 30,005 $ 33,360 $ 24,092 $ 23,300 $ 110,757 Income from continuing operations $ 22,704 $ 26,612 $ 17,966 $ 16,722 $ 84,004 Loss from discontinued operations $ 143 $ 290 $ 508 $ 1,164 $ 2,105 Net income $ 22,847 $ 26,902 $ 18,474 $ 17,886 $ 86,109 Basic and diluted net income per common unit: Continuing operations $ 0.28 $ 0.32 $ 0.21 $ 0.19 $ 1.00 Discontinued operations $ — $ 0.01 $ 0.01 $ 0.01 $ 0.03 Net income per common unit $ 0.28 $ 0.33 $ 0.22 $ 0.20 $ 1.03 Cash distributions per common unit (1) $ 0.4850 $ 0.4975 $ 0.5100 $ 0.5225 $ 2.0150 (1) Represents cash distributions declared and paid in the applicable period.
Summary of Quarterly Financial Data	2014 Quarters Total First Second Third Fourth Year Revenues from continuing operations $ 1,019,719 $ 1,015,049 $ 964,114 $ 847,282 $ 3,846,164 Operating income $ 35,402 $ 31,257 $ 35,268 $ 30,624 $ 132,551 Income from continuing operations $ 29,775 $ 21,148 $ 29,113 $ 26,166 $ 106,202 Net income $ 29,775 $ 21,148 $ 29,113 $ 26,166 $ 106,202 Basic and diluted net income per common unit: Continuing operations $ 0.34 $ 0.24 $ 0.33 $ 0.28 $ 1.18 Net income per common unit $ 0.34 $ 0.24 $ 0.33 $ 0.28 $ 1.18 Cash distributions per common unit (1) $ 0.5350 $ 0.5500 $ 0.5650 $ 0.5800 $ 2.2300 2013 Quarters Total First Second Third Fourth Year Revenues from continuing operations $ 1,014,808 $ 1,068,694 $ 1,090,293 $ 961,035 $ 4,134,830 Operating income $ 30,005 $ 33,360 $ 24,092 $ 23,300 $ 110,757 Income from continuing operations $ 22,704 $ 26,612 $ 17,966 $ 16,722 $ 84,004 Loss from discontinued operations $ 143 $ 290 $ 508 $ 1,164 $ 2,105 Net income $ 22,847 $ 26,902 $ 18,474 $ 17,886 $ 86,109 Basic and diluted net income per common unit: Continuing operations $ 0.28 $ 0.32 $ 0.21 $ 0.19 $ 1.00 Discontinued operations $ — $ 0.01 $ 0.01 $ 0.01 $ 0.03 Net income per common unit $ 0.28 $ 0.33 $ 0.22 $ 0.20 $ 1.03 Cash distributions per common unit (1) $ 0.4850 $ 0.4975 $ 0.5100 $ 0.5225 $ 2.0150 (1) Represents cash distributions declared and paid in the applicable period.

Condensed Consolidating Finan49

Condensed Consolidating Financial Information (Tables)	12 Months Ended
	Dec. 31, 2014
Condensed Consolidating Financial Information [Abstract]
Condensed Consolidating Balance Sheet	Condensed Consolidating Balance Sheet December 31, 2014 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated ASSETS Current assets: Cash and cash equivalents $ 9 $ — $ 8,310 $ 1,143 $ — $ 9,462 Other current assets 1,378,573 — 333,385 46,215 (1,412,269 ) 345,904 Total current assets 1,378,582 — 341,695 47,358 (1,412,269 ) 355,366 Fixed Assets, at cost — — 1,823,556 75,502 — 1,899,058 Less: Accumulated depreciation — — (251,171 ) (16,886 ) — (268,057 ) Net fixed assets — — 1,572,385 58,616 — 1,631,001 Goodwill — — 325,046 — — 325,046 Other assets, net 28,421 — 269,252 146,700 (154,192 ) 290,181 Equity investees and other investments — — 628,780 — — 628,780 Investments in subsidiaries 1,434,255 — 97,195 — (1,531,450 ) — Total assets $ 2,841,258 $ — $ 3,234,353 $ 252,674 $ (3,097,911 ) $ 3,230,374 LIABILITIES AND PARTNERS’ CAPITAL Current liabilities $ 11,016 $ — $ 1,761,856 $ 2,705 $ (1,412,432 ) $ 363,145 Senior secured credit facilities 550,400 — — — — 550,400 Senior unsecured notes 1,050,639 — — — — 1,050,639 Deferred tax liabilities — — 18,754 — — 18,754 Other liabilities — — 18,233 154,021 (154,021 ) 18,233 Total liabilities 1,612,055 — 1,798,843 156,726 (1,566,453 ) 2,001,171 Partners’ capital 1,229,203 — 1,435,510 95,948 (1,531,458 ) 1,229,203 Total liabilities and partners’ capital $ 2,841,258 $ — $ 3,234,353 $ 252,674 $ (3,097,911 ) $ 3,230,374 Condensed Consolidating Balance Sheet December 31, 2013 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated ASSETS Current assets: Cash and cash equivalents $ 20 $ — $ 8,049 $ 797 $ — $ 8,866 Other current assets 1,133,695 — 515,143 37,286 (1,159,767 ) 526,357 Total current assets 1,133,715 — 523,192 38,083 (1,159,767 ) 535,223 Fixed Assets, at cost — — 1,252,445 75,529 — 1,327,974 Less: Accumulated depreciation — — (184,856 ) (14,374 ) — (199,230 ) Net fixed assets — — 1,067,589 61,155 — 1,128,744 Goodwill — — 325,046 — — 325,046 Other assets, net 21,432 — 238,283 152,412 (159,185 ) 252,942 Equity investees and other investments — — 620,247 — — 620,247 Investments in subsidiaries 1,236,164 — 89,600 — (1,325,764 ) — Total assets $ 2,391,311 $ — $ 2,863,957 $ 251,650 $ (2,644,716 ) $ 2,862,202 LIABILITIES AND PARTNERS’ CAPITAL Current liabilities $ 10,002 $ — $ 1,592,376 $ 3,470 $ (1,159,295 ) $ 446,553 Senior secured credit facilities 582,800 — — — — 582,800 Senior unsecured notes 700,772 — — — — 700,772 Deferred tax liabilities — — 15,944 — — 15,944 Other liabilities — — 18,396 159,007 (159,007 ) 18,396 Total liabilities 1,293,574 — 1,626,716 162,477 (1,318,302 ) 1,764,465 Partners' capital 1,097,737 — 1,237,241 89,173 (1,326,414 ) 1,097,737 Total liabilities and partners’ capital $ 2,391,311 $ — $ 2,863,957 $ 251,650 $ (2,644,716 ) $ 2,862,202
Condensed Consolidating Statement of Operations	Condensed Consolidating Statement of Operations Year Ended December 31, 2014 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated REVENUES: Pipeline transportation services $ — $ — $ 61,686 $ 24,767 $ — $ 86,453 Refinery services — — 202,250 18,289 (13,138 ) 207,401 Marine transportation — — 229,282 — — 229,282 Supply and logistics — — 3,323,028 — — 3,323,028 Total revenues — — 3,816,246 43,056 (13,138 ) 3,846,164 COSTS AND EXPENSES: Supply and logistics costs — — 3,277,052 — — 3,277,052 Marine transportation costs — — 142,793 — — 142,793 Refinery services operating costs — — 117,788 17,393 (13,780 ) 121,401 Pipeline transportation operating costs — — 29,910 857 — 30,767 General and administrative — — 50,692 — — 50,692 Depreciation and amortization — — 88,368 2,540 — 90,908 Total costs and expenses — — 3,706,603 20,790 (13,780 ) 3,713,613 OPERATING INCOME — — 109,643 22,266 642 132,551 Equity in earnings of equity investees — — 43,135 — — 43,135 Equity in earnings of subsidiaries 172,828 — 6,952 — (179,780 ) — Interest (expense) income, net (66,626 ) — 15,662 (15,675 ) — (66,639 ) Income before income taxes 106,202 — 175,392 6,591 (179,138 ) 109,047 Income tax benefit (expense) — — (3,030 ) 185 — (2,845 ) Income from continuing operations 106,202 — 172,362 6,776 (179,138 ) 106,202 NET INCOME $ 106,202 $ — $ 172,362 $ 6,776 $ (179,138 ) $ 106,202 Condensed Consolidating Statement of Operations Year Ended December 31, 2013 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated REVENUES: Pipeline transportation services $ — $ — $ 60,707 $ 25,801 $ — $ 86,508 Refinery services — — 203,021 17,835 (14,871 ) 205,985 Marine transportation — — 152,542 — — 152,542 Supply and logistics — — 3,689,795 — — 3,689,795 Total revenues — — 4,106,065 43,636 (14,871 ) 4,134,830 COSTS AND EXPENSES: Supply and logistics costs — — 3,649,328 — — 3,649,328 Marine transportation costs — — 104,676 — — 104,676 Refinery services operating costs — — 128,814 16,873 (14,398 ) 131,289 Pipeline transportation operating costs — — 26,087 1,119 — 27,206 General and administrative — — 46,790 — — 46,790 Depreciation and amortization — — 62,194 2,590 — 64,784 Total costs and expenses — — 4,017,889 20,582 (14,398 ) 4,024,073 OPERATING INCOME — — 88,176 23,054 (473 ) 110,757 Equity in earnings of equity investees — — 22,675 — — 22,675 Equity in earnings of subsidiaries 134,616 — 6,913 — (141,529 ) — Interest (expense) income, net (48,507 ) — 16,080 (16,156 ) — (48,583 ) Income before income taxes 86,109 — 133,844 6,898 (142,002 ) 84,849 Income tax benefit (expense) — — (676 ) (169 ) — (845 ) Income from continuing operations 86,109 — 133,168 6,729 (142,002 ) 84,004 Income from discontinued operations — — 2,105 — — 2,105 NET INCOME $ 86,109 $ — $ 135,273 $ 6,729 $ (142,002 ) $ 86,109 Condensed Consolidating Statement of Operations Year Ended December 31, 2012 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated REVENUES: Pipeline transportation services $ — $ — $ 50,106 $ 26,184 $ — $ 76,290 Refinery services — — 192,083 19,999 (16,065 ) 196,017 Marine transportation — — 118,204 — — 118,204 Supply and logistics — — 2,976,850 — — 2,976,850 Total revenues — — 3,337,243 46,183 (16,065 ) 3,367,361 COSTS AND EXPENSES: Supply and logistics costs — — 2,923,746 — — 2,923,746 Marine transportation costs — — 80,547 — — 80,547 Refinery services operating costs — — 120,095 19,489 (16,107 ) 123,477 Pipeline transportation operating costs — — 21,081 813 — 21,894 General and administrative — — 41,837 — — 41,837 Depreciation and amortization — — 58,554 2,596 — 61,150 Total costs and expenses — — 3,245,860 22,898 (16,107 ) 3,252,651 OPERATING INCOME — — 91,383 23,285 42 114,710 Equity in earnings of equity investees — — 14,345 — — 14,345 Equity in earnings of subsidiaries 137,151 — 7,184 — (144,335 ) — Interest (expense) income, net (40,832 ) — 16,500 (16,591 ) — (40,923 ) Income before income taxes 96,319 — 129,412 6,694 (144,293 ) 88,132 Income tax benefit — — 8,903 302 — 9,205 Income from continuing operations 96,319 — 138,315 6,996 (144,293 ) 97,337 Loss from discontinued operations — — (1,018 ) — — (1,018 ) NET INCOME 96,319 — 137,297 6,996 (144,293 ) 96,319
Schedule of Condensed Consolidating Statements of Cash Flow	Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2014 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated Net cash (used in) provided by operating activities $ (148,008 ) $ — $ 591,431 $ 5,296 $ (157,665 ) $ 291,054 CASH FLOWS FROM INVESTING ACTIVITIES: Payments to acquire fixed and intangible assets — — (443,482 ) — — (443,482 ) Cash distributions received from equity investees - return of investment 42,755 — 18,363 — (42,755 ) 18,363 Investments in equity investees (225,725 ) — (40,926 ) — 225,725 (40,926 ) Acquisitions — — (157,000 ) — — (157,000 ) Repayments on loan to non-guarantor subsidiary — — 4,993 — (4,993 ) — Proceeds from asset sales — — 272 — — 272 Other, net — — (1,214 ) — — (1,214 ) Net cash used in investing activities (182,970 ) — (618,994 ) — 177,977 (623,987 ) CASH FLOWS FROM FINANCING ACTIVITIES: Borrowings on senior secured credit facility 1,839,900 — — — — 1,839,900 Repayments on senior secured credit facility (1,872,300 ) — — — — (1,872,300 ) Proceeds from issuance of senior unsecured notes, including premium 350,000 — — — — 350,000 Debt issuance costs (11,896 ) — — — — (11,896 ) Issuance of common units for cash, net 225,725 — 225,725 — (225,725 ) 225,725 Distributions to partners/owners (200,461 ) — (200,462 ) — 200,462 (200,461 ) Other, net (1 ) — 2,561 (4,950 ) 4,951 2,561 Net cash provided by financing activities 330,967 — 27,824 (4,950 ) (20,312 ) 333,529 Net increase (decrease) in cash and cash equivalents (11 ) — 261 346 — 596 Cash and cash equivalents at beginning of period 20 — 8,049 797 — 8,866 Cash and cash equivalents at end of period $ 9 $ — $ 8,310 $ 1,143 $ — $ 9,462 Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2013 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated Net cash (used in) provided by operating activities $ (280,155 ) $ — $ 557,879 $ 5,101 $ (144,439 ) $ 138,386 CASH FLOWS FROM INVESTING ACTIVITIES: Payments to acquire fixed and intangible assets — — (343,119 ) — — (343,119 ) Cash distributions received from equity investees - return of investment 23,963 — 12,432 — (23,963 ) 12,432 Investments in equity investees (263,574 ) — (94,551 ) — 263,574 (94,551 ) Acquisitions — — (230,880 ) — — (230,880 ) Repayments on loan to non-guarantor subsidiary — — 4,512 — (4,512 ) — Proceeds from assets sales — — 1,910 — — 1,910 Other, net — — (1,622 ) — — (1,622 ) Net cash used in investing activities (239,611 ) — (651,318 ) — 235,099 (655,830 ) CASH FLOWS FROM FINANCING ACTIVITIES: Borrowings on senior secured credit facility 1,593,300 — — — — 1,593,300 Repayments on senior secured credit facility (1,510,500 ) — — — — (1,510,500 ) Proceeds from issuance of senior unsecured notes, including premium 350,000 — — — — 350,000 Debt issuance costs (8,157 ) — — — — (8,157 ) Issuance of ownership interests to partners for cash 263,574 — 263,574 — (263,574 ) 263,574 Distributions to partners/owners (168,441 ) — (168,441 ) — 168,441 (168,441 ) Other, net — — (4,748 ) (4,473 ) 4,473 (4,748 ) Net cash provided by (used in) financing activities 519,776 — 90,385 (4,473 ) (90,660 ) 515,028 Net increase (decrease) in cash and cash equivalents 10 — (3,054 ) 628 — (2,416 ) Cash and cash equivalents at beginning of period 10 — 11,103 169 — 11,282 Cash and cash equivalents at end of period $ 20 $ — $ 8,049 $ 797 $ — $ 8,866 Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2012 Genesis Energy, L.P. (Parent and Co-Issuer) Genesis Energy Finance Corporation (Co-Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Genesis Energy, L.P. Consolidated Net cash (used in) provided by operating activities $ (70,083 ) $ — $ 371,256 $ 2,602 $ (114,471 ) $ 189,304 CASH FLOWS FROM INVESTING ACTIVITIES: Payments to acquire fixed and intangible assets — — (146,296 ) (160 ) — (146,456 ) Cash distributions received from equity investees - return of investment 27,878 — 14,909 — (27,878 ) 14,909 Investments in equity investees (169,421 ) — (63,749 ) — 169,421 (63,749 ) Acquisitions — — (205,576 ) — — (205,576 ) Repayments on loan to non-guarantor subsidiary — — 4,078 — (4,078 ) — Proceeds from asset sales — — 773 — — 773 Other, net — — (1,508 ) — — (1,508 ) Net cash used in investing activities (141,543 ) — (397,369 ) (160 ) 137,465 (401,607 ) CASH FLOWS FROM FINANCING ACTIVITIES: Borrowings on senior secured credit facility 1,674,400 — — — — 1,674,400 Repayments on senior secured credit facility (1,583,700 ) — — — — (1,583,700 ) Proceeds from issuance of senior unsecured notes 101,000 — — — — 101,000 Debt issuance costs (7,105 ) — — — — (7,105 ) Issuance of ownership interests to partners for cash 169,421 — 169,421 — (169,421 ) 169,421 Distributions to partners/owners (142,383 ) — (142,383 ) — 142,383 (142,383 ) Other, net — — 1,135 (4,044 ) 4,044 1,135 Net cash provided by financing activities 211,633 — 28,173 (4,044 ) (22,994 ) 212,768 Net increase in cash and cash equivalents 7 — 2,060 (1,602 ) — 465 Cash and cash equivalents at beginning of period 3 — 9,043 1,771 — 10,817 Cash and cash equivalents at end of period $ 10 $ — $ 11,103 $ 169 $ — $ 11,282

Organization (Details)

Organization (Details) - Dec. 31, 2014	Total
Summary Of Significant Accounting Policies [Line Items]
Limited Partners' ownership percentage	100.00%
CHOPS [Member]
Summary Of Significant Accounting Policies [Line Items]
Equity Method Investment, Ownership Percentage	50.00%

Summary Of Significant Accoun51

Summary Of Significant Accounting Policies (Details) - USD ($)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Summary Of Significant Accounting Policies [Line Items]
Impairment of intangible assets	$ 0
Impairment of goodwill	$ 0	$ 0
Poseidon Oil Pipeline Company, L.L.C. [Member]
Summary Of Significant Accounting Policies [Line Items]
Ownership percentage	28.00%
Odyssey Pipeline L.L.C. [Member]
Summary Of Significant Accounting Policies [Line Items]
Ownership percentage	29.00%
CHOPS [Member]
Summary Of Significant Accounting Policies [Line Items]
Ownership percentage	50.00%
SEKCO [Member]
Summary Of Significant Accounting Policies [Line Items]
Ownership percentage	50.00%
Minimum [Member] | Pipelines And Related Assets [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives of assets	5 years
Minimum [Member] | Marine Vessels [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives of assets	20 years
Minimum [Member] | Machinery And Equipment [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives of assets	10 years
Minimum [Member] | Transportation Equipment [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives of assets	3 years
Minimum [Member] | Building And Improvements [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives of assets	3 years
Maximum [Member] | Pipelines And Related Assets [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives of assets	40 years
Maximum [Member] | Marine Vessels [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives of assets	30 years
Maximum [Member] | Machinery And Equipment [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives of assets	20 years
Maximum [Member] | Transportation Equipment [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives of assets	7 years
Maximum [Member] | Building And Improvements [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives of assets	10 years

Acquisitions (Narrative) (Detai

Acquisitions (Narrative) (Details) $ / shares in Units, $ in Thousands	Nov. 13, 2014USD ($)	Sep. 26, 2014USD ($)$ / shares	Sep. 16, 2013USD ($)$ / shares	Mar. 28, 2012USD ($)$ / shares	Jan. 31, 2012	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Dec. 31, 2012USD ($)	Jul. 22, 2013USD ($)Tug_BoatsBarges	Jan. 03, 2012Pipelines
Business Acquisition [Line Items]
Partners' Capital Account, Public Sale of Units Net of Offering Costs		$ 225,725	$ 263,574	$ 169,421
Price per share of common units issued | $ / shares		$ 50.71	$ 47.51	$ 30.80
Proceeds from issuance of senior unsecured notes, including premium						$ 350,000	$ 350,000	$ 101,000
Cash paid for acquisition						$ 157,000	$ 230,880	$ 205,576
Property, Plant and Equipment, Estimated Useful Lives						25
American Phoenix Acquisition [Member]
Business Acquisition [Line Items]
Effective date of acquisition	Nov. 13, 2014
Transaction costs related to business acquisition	$ 157,000
Hornbeck Acquisition [Member]
Business Acquisition [Line Items]
Number of barges acquired | Barges									9
Business Acquisition, Tug Boats Acquired | Tug_Boats									9
Transaction costs related to business acquisition									$ 230,900
Gulf Of Mexico Crude Oil Pipeline Systems [Member]
Business Acquisition [Line Items]
Effective date of acquisition					Jan. 3, 2012
Poseidon Oil Pipeline Company, L.L.C. [Member]
Business Acquisition [Line Items]
Ownership percentage						28.00%
Marathon Offshore Pipeline, LLC [Member]
Business Acquisition [Line Items]
Ownership percentage						100.00%
Odyssey Pipeline L.L.C. [Member]
Business Acquisition [Line Items]
Ownership percentage						29.00%
Eugene Island Pipeline System [Member]
Business Acquisition [Line Items]
Ownership percentage						23.00%
Two Offshore Smaller Pipelines [Member]
Business Acquisition [Line Items]
Ownership percentage						100.00%
Number of piepelines | Pipelines										2
CHOPS [Member]
Business Acquisition [Line Items]
Ownership percentage						50.00%

Acquisitions (Schedule of Purch

Acquisitions (Schedule of Purchase Price Allocation) (Details) - American Phoenix Acquisition [Member] $ in Thousands	Nov. 13, 2014USD ($)
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	$ 125,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Finite-Lived Intangibles	32,000
Total allocation	$ 157,000

Acquisitions (Schedule Of Selec

Acquisitions (Schedule Of Selected Financial Information) (Details) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
American Phoenix Acquisition [Member]
Business Acquisition [Line Items]
Revenues	$ 3,038
Net income	$ 454
Hornbeck Acquisition [Member]
Business Acquisition [Line Items]
Revenues		$ 30,424
Net income		$ 7,348
Gulf Of Mexico Crude Oil Pipeline Systems [Member]
Business Acquisition [Line Items]
Revenues			$ 5,508
Equity in earnings of equity investees			13,118
Net income			$ 15,112

Acquisitions (Schedule Of Pro F

Acquisitions (Schedule Of Pro Forma Financial Information) (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Basic and diluted earnings per unit:
Net income per common unit (in dollars per unit)	$ 1.18	$ 1.03	$ 1.23
As reported units outstanding	90,060	83,957	78,363
American Phoenix Acquisition [Member]
Pro forma earnings data:
Revenues from continuing operations	$ 3,863,745	$ 4,153,443
Net income	$ 111,132	90,829
Hornbeck Acquisition [Member]
Pro forma earnings data:
Revenues from continuing operations		4,177,715	$ 3,416,790
Net income		$ 98,846	$ 98,665

Acquisitions and Divestitures56

Acquisitions and Divestitures Divestitures (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2013USD ($)
Discontinued Operations and Disposal Groups [Abstract]
Proceeds from Divestiture of Businesses	$ 1
Gain (Loss) on Disposition of Business	$ 0.9

Acquisitions and Divestitures57

Acquisitions and Divestitures Divestitures (Schedule of Selected Financial Information) (Details) - USD ($) $ in Thousands	3 Months Ended				12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Discontinued Operations and Disposal Groups [Abstract]
Disposal Group, Including Discontinued Operation, Revenue						$ 593,733	$ 702,695
Disposal Group, Including Discontinued Operation, Operating Expense						592,505	703,715
Disposal Group, Including Discontinued Operation, Operating Income (Loss)						1,228	(1,020)
Disposal Group, Including Discontinued Operation, Interest Income						2	2
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax						1,230	(1,018)
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax						875	0
Income (loss) from discontinued operations	$ 1,164	$ 508	$ 290	$ 143	$ 0	$ 2,105	$ (1,018)

Receivables (Schedule Of Trade

Receivables (Schedule Of Trade Accounts Receivables Net) (Details) - USD ($) $ in Thousands	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Accounts Receivable, Net, Current [Abstract]
Accounts receivable - trade	$ 274,502	$ 369,559
Allowance for doubtful accounts	(2,973)	(1,526)	$ (2,372)	$ (1,044)
Accounts receivable - trade, net	$ 271,529	$ 368,033

Receivables (Schedule Of Allowa

Receivables (Schedule Of Allowance For Doubtful Accounts) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Allowance for Doubtful Accounts Receivable [Roll Forward]
Balance at beginning of period	$ 1,526	$ 2,372	$ 1,044
Charged to costs and expenses	1,447	(86)	2,096
Amounts written off	0	(760)	(768)
Balance at end of period	$ 2,973	$ 1,526	$ 2,372

Inventories (Schedule Of Major

Inventories (Schedule Of Major Components Of Inventories) (Details) - USD ($) $ in Thousands	Dec. 31, 2014	Dec. 31, 2013
Inventory Disclosure [Abstract]
Petroleum products	$ 30,108	$ 71,373
Crude oil	7,266	5,380
Caustic soda	2,850	2,679
NaHS	6,603	5,845
Other	2	53
Total	$ 46,829	$ 85,330

Inventories Inventories (Narrat

Inventories Inventories (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2014USD ($)
Inventory Disclosure [Abstract]
Inventory Write-down	$ 6.6

Fixed Assets and Asset Retire62

Fixed Assets and Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Fixed Assets And Asset Retirement Obligations [Abstract]
Depreciation expense	$ 73.2	$ 46.3	$ 37.4

Fixed Assets And Asset Retire63

Fixed Assets And Asset Retirement Obligations (Schedule Of Fixed Assets) (Details) - USD ($) $ in Thousands	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 1,899,058	$ 1,327,974
Accumulated depreciation	(268,057)	(199,230)
Net fixed assets	1,631,001	1,128,744
Pipelines And Related Assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	466,613	338,920
Machinery And Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	376,672	173,092
Transportation Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	18,479	19,140
Marine Vessels [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	731,016	554,679
Land, Buildings And Improvements [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	38,037	30,170
Office Equipment, Furniture And Fixtures [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	6,696	5,633
Construction In Progress [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	222,233	183,037
Property, Plant And Equipment, Other Types [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 39,312	$ 23,303

Fixed Assets And Asset Retire64

Fixed Assets And Asset Retirement Obligations (Schedule Of Reconciliation Of Liability For Asset Retirement Obligations) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligations, beginning balance	$ 14,332	$ 12,695
Liabilities incurred and assumed in the current period	0	789
Accretion expense	458	848
Asset retirement obligations, ending balance	$ 14,790	$ 14,332

Net Investment In Direct Fina65

Net Investment In Direct Financing Leases (Narrative) (Details) - Dec. 31, 2014 - USD ($) $ in Millions	Total
Leases [Abstract]
Fixed lease payments per year	$ 20.7
Fixed lease interest rate per year	10.25%
Minimum lease payments received, year one	$ 20.7

Net Investment In Direct Fina66

Net Investment In Direct Financing Leases (Components Of Net Investment In Direct Financing Leases) (Details) - USD ($) $ in Thousands	Dec. 31, 2014	Dec. 31, 2013
Leases [Abstract]
Total minimum lease payments to be received	$ 277,732	$ 298,924
Estimated residual values of leased property (unguaranteed)	292	292
Unamortized initial direct costs	1,444	1,621
Less unearned income	(127,531)	(143,415)
Net investment in direct financing leases	151,937	157,422
Less current portion (included in other current assets)	(5,978)	(5,519)
Long-term portion of net investment in direct financing leases	$ 145,959	$ 151,903

Equity Investees (Narrative) (D

Equity Investees (Narrative) (Details) - USD ($) $ in Millions	Dec. 31, 2014	Dec. 31, 2013
Equity Method Investments and Joint Ventures [Abstract]
Unamortized excess cost amount	$ 215.4	$ 225.7

Equity Investees (Consolidated

Equity Investees (Consolidated Financial Statements Related To Equity Investees) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Equity Method Investments and Joint Ventures [Abstract]
Genesis’ share of operating earnings	$ 53,783	$ 33,152	$ 24,532
Amortization of excess purchase price	(10,648)	(10,477)	(10,187)
Net equity in earnings	43,135	22,675	14,345
Distributions received	$ 75,528	$ 46,564	$ 38,809

Equity Investees (Schedule Of B

Equity Investees (Schedule Of Balance Sheet Information For Equity Investees) (Details) - USD ($) $ in Thousands	Dec. 31, 2014	Dec. 31, 2013
Equity Method Investments and Joint Ventures [Abstract]
Current assets	$ 42,135	$ 70,921
Fixed assets, net	1,015,305	1,028,808
Equity Method Investment, Summarized Financial Information, Noncurrent Assets	4,369	6,823
Total assets	1,061,809	1,106,552
Current liabilities	25,369	55,918
Other liabilities	202,613	190,578
Equity	833,827	860,056
Total liabilities and equity	$ 1,061,809	$ 1,106,552

Equity Investees (Schedule Of O

Equity Investees (Schedule Of Operations For Equity Investees) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Equity Method Investments and Joint Ventures [Abstract]
Revenues	$ 246,265	$ 183,533	$ 162,267
Operating Income	146,760	102,107	80,841
Net Income	$ 142,754	$ 99,357	$ 77,975

Intangible Assets, Goodwill A71

Intangible Assets, Goodwill And Other Assets (Narrative) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Intangible Assets, Goodwill And Other Assets [Line Items]
Amortization of Intangible Assets	$ 13,400	$ 14,600	$ 19,900
Amortization of CO2 assets	4,200	3,900	$ 3,800
GOODWILL	325,046	325,046
Goodwill, Impairment Loss	0	0
Supply And Logistics [Member]
Intangible Assets, Goodwill And Other Assets [Line Items]
GOODWILL	23,100	23,100
Refinery Services [Member]
Intangible Assets, Goodwill And Other Assets [Line Items]
GOODWILL	$ 301,900	$ 301,900

Intangible Assets, Goodwill A72

Intangible Assets, Goodwill And Other Assets (Schedule Of Intangible Assets) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross Carrying Amount	$ 236,819	$ 203,378
Intangible assets, Accumulated Amortization	153,888	140,450
Intangible assets, Carrying Value	$ 82,931	62,928
Refinery Services Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Weighted Amortization Period in Years	5 years
Intangible assets, Gross Carrying Amount	$ 94,654	94,654
Intangible assets, Accumulated Amortization	81,880	76,283
Intangible assets, Carrying Value	$ 12,774	18,371
Refinery Services Licensing Agreements [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Weighted Amortization Period in Years	6 years
Intangible assets, Gross Carrying Amount	$ 38,678	38,678
Intangible assets, Accumulated Amortization	28,983	26,055
Intangible assets, Carrying Value	9,695	12,623
Refinery Services [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross Carrying Amount	133,332	133,332
Intangible assets, Accumulated Amortization	110,863	102,338
Intangible assets, Carrying Value	$ 22,469	30,994
Supply And Logistics Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Weighted Amortization Period in Years	5 years
Intangible assets, Gross Carrying Amount	$ 35,430	35,430
Intangible assets, Accumulated Amortization	30,228	28,568
Intangible assets, Carrying Value	$ 5,202	6,862
Supply And Logistics Intangibles associated with lease [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Weighted Amortization Period in Years	15 years
Intangible assets, Gross Carrying Amount	$ 13,260	13,260
Intangible assets, Accumulated Amortization	3,512	3,039
Intangible assets, Carrying Value	9,748	10,221
Supply And Logistics [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross Carrying Amount	48,690	48,690
Intangible assets, Accumulated Amortization	33,740	31,607
Intangible assets, Carrying Value	$ 14,950	17,083
Marine Transportation Contracts [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Weighted Amortization Period in Years	5 years
Intangible assets, Gross Carrying Amount	$ 32,000	0
Intangible assets, Accumulated Amortization	833	0
Intangible assets, Carrying Value	$ 31,167	0
Other [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Weighted Amortization Period in Years	5 years
Intangible assets, Gross Carrying Amount	$ 22,797	21,356
Intangible assets, Accumulated Amortization	8,452	6,505
Intangible assets, Carrying Value	$ 14,345	$ 14,851

Intangible Assets, Goodwill A73

Intangible Assets, Goodwill And Other Assets (Schedule Of Estimated Amortization Expense) (Details) $ in Thousands	Dec. 31, 2014USD ($)
Finite-Lived Intangible Assets [Line Items]
2,015	$ 17,339
2,016	14,861
2,017	13,698
2,018	12,777
2,019	8,334
Refinery Services Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
2,015	4,405
2,016	3,471
2,017	2,737
2,018	2,161
2,019	0
Refinery Services Licensing Agreements [Member]
Finite-Lived Intangible Assets [Line Items]
2,015	2,711
2,016	2,510
2,017	2,324
2,018	2,150
2,019	0
Supply And Logistics Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
2,015	1,275
2,016	981
2,017	757
2,018	586
2,019	454
Supply And Logistics Intangibles associated with lease [Member]
Finite-Lived Intangible Assets [Line Items]
2,015	474
2,016	474
2,017	474
2,018	474
2,019	474
Marine Transportation Contracts [Member]
Finite-Lived Intangible Assets [Line Items]
2,015	6,417
2,016	5,400
2,017	5,400
2,018	5,400
2,019	5,400
Other [Member]
Finite-Lived Intangible Assets [Line Items]
2,015	2,057
2,016	2,025
2,017	2,006
2,018	2,006
2,019	$ 2,006

Intangible Assets, Goodwill A74

Intangible Assets, Goodwill And Other Assets (Schedule Of Other Assets) (Details) - USD ($) $ in Thousands	Dec. 31, 2014	Dec. 31, 2013
Goodwill and Intangible Assets Disclosure [Abstract]
CO2 volumetric production payments, net of amortization	$ 9,395	$ 4,421
Deferred Marine Charges	13,042	2,829	[1]
Other deferred costs and deposits	38,854	30,861
Other assets, net of amortization	$ 61,291	$ 38,111
[1]	(1)See discussion of deferred charges on marine transportation assets in the Summary of Accounting Policies (Note 2)

Debt (Narrative) (Details)

Debt (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2014USD ($)	May. 15, 2014USD ($)	Feb. 08, 2013USD ($)	Feb. 01, 2012USD ($)	Nov. 30, 2010USD ($)
Debt Instrument [Line Items]
Commitment fee percentage	0.375%
Letter Of Credit [Member]
Debt Instrument [Line Items]
Letter of credit, fee percentage	2.25%
Senior Secured Credit Facility [Member]
Debt Instrument [Line Items]
Line of credit facility, aggregate maximum borrowing capacity	$ 1,500
Senior secured credit facility, amount outstanding	550.4
Total amount available for borrowings, remaining borrowing capacity	438.8
Senior Secured Credit Facility [Member] | Letter Of Credit [Member]
Debt Instrument [Line Items]
Letters of credit, outstanding amount	$ 10.8
Maturity date of debt	Jul. 25, 2019
Senior Secured Credit Facility [Member] | Accordion [Member]
Debt Instrument [Line Items]
Senior secured credit facility, maximum borrowing capacity	$ 300
Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Debt instrument, principal amount				$ 350
Debt instrument, percentage of face value				101.00%
Debt instrument, effective interest rate				7.682%
Seven Point Eight Seventy Five Percentage Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Maturity date of debt	Dec. 15, 2018
Debt instrument, principal amount				$ 100	$ 250
Debt instrument, stated rate					7.875%
Federal Funds Effective Rate [Member]
Debt Instrument [Line Items]
Interest rate spreads senior secured credit facility	0.50%
Eurodollar Rate [Member]
Debt Instrument [Line Items]
Interest rate spreads senior secured credit facility	2.25%
Applicable Margin [Member]
Debt Instrument [Line Items]
Interest rate spreads senior secured credit facility	1.25%
Five Point Seventy Five Percentage Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Maturity date of debt	Feb. 15, 2021
Debt instrument, principal amount			$ 350
Debt instrument, stated rate			5.75%
Maximum percentage of principal, early debt redemption	35.00%
Percentage of the redeemable value of debt on Face amount	105.75%
Five Point Six Two Five Percentage Senior Unsecured Notes [Member] [Domain]
Debt Instrument [Line Items]
Maturity date of debt	Jun. 15, 2024
Debt instrument, principal amount		$ 350
Debt instrument, stated rate		5.625%
Maximum percentage of principal, early debt redemption	35.00%
Percentage of the redeemable value of debt on Face amount	105.625%
CHOPS [Member]
Debt Instrument [Line Items]
Ownership percentage	50.00%
Maximum [Member]
Debt Instrument [Line Items]
Commitment fee percentage	0.375%
Maximum [Member] | Senior Secured Credit Facility [Member]
Debt Instrument [Line Items]
Debt instrument covenant, requirement leverage ratio	1
Debt instrument covenant, requirement senior secured leverage ratio	1
Debt instrument covenant, requirement interest coverage ratio	1
Maximum [Member] | Senior Secured Credit Facility [Member] | Letter Of Credit [Member]
Debt Instrument [Line Items]
Letters of credit, outstanding amount	$ 100
Maximum [Member] | Federal Funds Effective Rate [Member]
Debt Instrument [Line Items]
Interest rate spreads senior secured credit facility	1.00%
Maximum [Member] | LIBOR Rate [Member]
Debt Instrument [Line Items]
Interest rate spreads senior secured credit facility	1.00%
Maximum [Member] | Eurodollar Rate [Member]
Debt Instrument [Line Items]
Letter of credit, fee percentage	2.50%
Maximum [Member] | Alternate Base Rate [Member]
Debt Instrument [Line Items]
Letter of credit, fee percentage	1.50%
Minimum [Member]
Debt Instrument [Line Items]
Commitment fee percentage	0.25%
Minimum [Member] | Senior Secured Credit Facility [Member]
Debt Instrument [Line Items]
Debt instrument covenant, requirement leverage ratio	5
Debt instrument covenant, requirement senior secured leverage ratio	3.75
Debt instrument covenant, requirement interest coverage ratio	3
Minimum [Member] | Eurodollar Rate [Member]
Debt Instrument [Line Items]
Letter of credit, fee percentage	1.50%
Minimum [Member] | Alternate Base Rate [Member]
Debt Instrument [Line Items]
Letter of credit, fee percentage	0.50%
Amended Facility [Member]
Debt Instrument [Line Items]
Senior secured credit facility, maximum borrowing capacity	$ 1,000
Amended Facility [Member] | Senior Secured Credit Facility [Member] | Accordion [Member]
Debt Instrument [Line Items]
Senior secured credit facility, maximum borrowing capacity	500
Petroleum Products [Member] | Senior Secured Credit Facility [Member]
Debt Instrument [Line Items]
Senior secured credit facility, amount outstanding	45
Petroleum Products [Member] | Amended Facility [Member] | Senior Secured Credit Facility [Member]
Debt Instrument [Line Items]
Senior secured credit facility, maximum borrowing capacity	$ 150
During Acquisition Period [Member] | Maximum [Member] | Senior Secured Credit Facility [Member]
Debt Instrument [Line Items]
Debt instrument covenant, requirement leverage ratio	1
Debt instrument covenant, requirement senior secured leverage ratio	1
Debt instrument covenant, requirement interest coverage ratio	1
During Acquisition Period [Member] | Minimum [Member] | Senior Secured Credit Facility [Member]
Debt Instrument [Line Items]
Debt instrument covenant, requirement leverage ratio	5.50
Debt instrument covenant, requirement senior secured leverage ratio	4.25
Debt instrument covenant, requirement interest coverage ratio	2.75

Debt (Schedule Of Obligations U

Debt (Schedule Of Obligations Under Debt Arrangements) (Details) - USD ($) $ in Thousands	Dec. 31, 2014	Dec. 31, 2013
Debt Instrument [Line Items]
Senior secured credit facility	$ 550,400	$ 582,800
7.875% senior unsecured notes (including unamortized premium of $639 and $772 in 2014 and 2013, respectively)	1,050,639	700,772
Total long-term debt	1,601,039	1,283,572
Unamortized premium	639	772
Seven Point Eight Seventy Five Percentage Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
7.875% senior unsecured notes (including unamortized premium of $639 and $772 in 2014 and 2013, respectively)	350,639	350,772
Five Point Seventy Five Percentage Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
7.875% senior unsecured notes (including unamortized premium of $639 and $772 in 2014 and 2013, respectively)	350,000	350,000
Five Point Six Two Five Percentage Senior Unsecured Notes [Member] [Domain]
Debt Instrument [Line Items]
7.875% senior unsecured notes (including unamortized premium of $639 and $772 in 2014 and 2013, respectively)	$ 350,000	$ 0

Partners' Capital and Distrib77

Partners' Capital and Distributions (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	Sep. 26, 2014	Sep. 16, 2013	Mar. 28, 2012	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013
Partners Capital And Distributions [Line Items]
Partners' Capital Account, Public Sale of Units Net of Offering Costs	$ 225,725	$ 263,574	$ 169,421
Common units, outstanding				95,029,218				88,690,985
Per Unit Amount				$ 0.5800	$ 0.5650	$ 0.5500	$ 0.5350	$ 0.5225	$ 0.5100	$ 0.4975	$ 0.4850
Number of common units issued	4,600,000	5,750,000		95,029,218				88,690,985
Cash or stock available for distributions, percent usually distributed				100.00%
Days to distribute				45 days
Waiver Units Class 2 [Member]
Partners Capital And Distributions [Line Items]
Waiver units authorized				1,738,000
Cash or stock available for distributions, percent usually distributed				100.00%
Days to distribute				45 days
Waiver Units Class 3 [Member]
Partners Capital And Distributions [Line Items]
Waiver units authorized				1,738,000
Cash or stock available for distributions, percent usually distributed				100.00%
Days to distribute				45 days
Waiver Units Class4 [Member]
Partners Capital And Distributions [Line Items]
Waiver units authorized				1,738,000
Cash or stock available for distributions, percent usually distributed				100.00%
Days to distribute				45 days
Class A [Member]
Partners Capital And Distributions [Line Items]
Partners' Capital Account, Public Sale of Units Net of Offering Costs	$ 225,700	$ 263,600	$ 169,400
Common units, outstanding				94,989,221
Number of common units issued			5,750,000
Class B [Member]
Partners Capital And Distributions [Line Items]
Common units, outstanding				39,997
Class Two [Member]
Partners Capital And Distributions [Line Items]
Conversion feature, minimum distribution coverage ratio				1.1
Class Three [Member]
Partners Capital And Distributions [Line Items]
Conversion feature, minimum distribution coverage ratio				1.1
Class Four [Member]
Partners Capital And Distributions [Line Items]
Conversion feature, minimum distribution coverage ratio				1.1

Partners' Capital and Distrib78

Partners' Capital and Distributions (Distributions) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013
Distribution Made to Limited Partner [Line Items]
Per Unit Amount	$ 0.5800	$ 0.5650	$ 0.5500	$ 0.5350	$ 0.5225	$ 0.5100	$ 0.4975	$ 0.4850
Distribution Made to Limited Partner, Cash Distributions Paid	$ 54,112	$ 50,114	$ 48,783	$ 47,453	$ 46,344	$ 42,302	$ 40,405	$ 39,390
Distribution Made to Limited Partner, Distribution Date	Nov. 14, 2014	Aug. 14, 2014	May 15, 2014	Feb. 14, 2014	Nov. 14, 2013	Aug. 14, 2013	May 15, 2013	Feb. 14, 2013
February 13, 2015 [Member]
Distribution Made to Limited Partner [Line Items]
Per Unit Amount	$ 0.5950
Distribution Made to Limited Partner, Cash Distributions Paid	$ 56,542
Distribution Made to Limited Partner, Distribution Date	Feb. 13, 2015

Partners' Capital and Distrib79

Partners' Capital and Distributions (Computation Of Basic And Diluted Net Income Per Common Unit) (Details) - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Partners' Capital Notes [Abstract]
As reported units outstanding	90,060	83,957	78,363
Basic and diluted net income per common unit	$ 1.18	$ 1.03	$ 1.23

Partners' Capital and Distrib80

Partners' Capital and Distributions (New Common Units Issued To The Public For Cash) (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	Sep. 26, 2014	Sep. 16, 2013	Mar. 28, 2012
Partners' Capital Notes [Abstract]
Units	4,600	5,750	5,750
Gross Unit Price	$ 50.71	$ 47.51	$ 30.80
Issuance Value	$ 233,266	$ 273,183	$ 177,100
Costs	(7,541)	(9,609)	(7,679)
Net Proceeds	$ 225,725	$ 263,574	$ 169,421

Business Segment Information (S

Business Segment Information (Schedule Of Segment Information) (Details) - USD ($) $ in Thousands		3 Months Ended								12 Months Ended
		Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Segment margin	[1]									$ 347,264	$ 280,360	$ 262,333
Revenues		$ 847,282	$ 964,114	$ 1,015,049	$ 1,019,719	$ 961,035	$ 1,090,293	$ 1,068,694	$ 1,014,808	3,846,164	4,134,830	3,367,361
Capital Expenditures	[2]									644,548	704,205	426,298
ExternalCustomerRevenues										3,846,164	4,134,830	3,367,361
IntersegmentRevenues	[3]									0	0	0
Pipeline Transportation [Member]
Segment Reporting Information [Line Items]
Segment margin										61,231	64,349	58,039	[1]
Revenues										83,157	82,585	70,782
Capital Expenditures										46,611	130,787	59,345	[2]
ExternalCustomerRevenues										66,760	65,452	56,198
IntersegmentRevenues										16,397	17,133	14,584
Offshore Pipeline Transportation [Member]
Segment Reporting Information [Line Items]
Segment margin										71,598	44,530	38,500	[1]
Revenues										3,296	3,923	5,508
Capital Expenditures										37,639	94,286	269,365	[2]
ExternalCustomerRevenues										3,296	3,923	5,508
IntersegmentRevenues										0	0	0
Refinery Services [Member]
Segment Reporting Information [Line Items]
Segment margin										84,851	75,361	72,883	[1]
Revenues										207,401	205,985	196,017
Capital Expenditures										2,385	3,258	2,692	[2]
ExternalCustomerRevenues										218,297	216,860	205,110
IntersegmentRevenues										(10,896)	(10,875)	(9,093)
Marine Transportation [Member]
Segment Reporting Information [Line Items]
Segment margin										86,239	47,726	37,528	[1]
Revenues										229,282	152,542	118,204
Capital Expenditures										232,783	260,736	37,188	[2]
ExternalCustomerRevenues										214,039	131,049	99,016
IntersegmentRevenues										15,243	21,493	19,188
Supply And Logistics [Member]
Segment Reporting Information [Line Items]
Segment margin										43,345	48,394	55,383	[1]
Revenues										3,323,028	3,689,795	2,976,850
Capital Expenditures										325,130	215,138	57,708	[2]
ExternalCustomerRevenues										3,343,772	3,717,546	3,001,529
IntersegmentRevenues										(20,744)	(27,751)	(24,679)
SEKCO [Member] | Pipeline Transportation [Member]
Segment Reporting Information [Line Items]
Capital Expenditures										$ 36,100	$ 94,300
Gulf Of Mexico Crude Oil Pipelines [Member] | Pipeline Transportation [Member]
Segment Reporting Information [Line Items]
Capital Expenditures												$ 205,600
[1]	A reconciliation of Segment Margin to income from continuing operations before income taxes for each year is presented below.
[2]	Capital expenditures include maintenance and growth capital expenditures, such as fixed asset additions (including enhancements to existing facilities and construction of internal growth projects) as well as acquisitions of businesses and interests in equity investees. In addition to construction of internal growth projects, capital spending in our Offshore pipeline transportation segment included $36.1 million and $94.3 million during the years ended December 31, 2014 and December 31, 2013 representing capital contributions to our SEKCO equity investee to fund our share of the construction costs for its pipeline. During 2014, capital spending in our marine transportation segment included $157 million for our purchase of the M/T American Phoenix. During 2013, capital spending in our marine segment also included $230.9 million for the acquisition of our offshore marine transportation assets. During 2012, capital spending in our pipeline transportation segment also included $205.6 million for the acquisition of interests in several Gulf of Mexico pipelines
[3]	Intersegment sales were conducted under terms that we believe were no more or less favorable than then-existing market conditions.

Business Segment Information (R

Business Segment Information (Reconciliation Of Segment Margin To (Loss) Income) (Details) - USD ($) $ in Thousands		3 Months Ended								12 Months Ended
		Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Capital Expenditures	[1]									$ 644,548	$ 704,205	$ 426,298
Segment margin	[2]									347,264	280,360	262,333
Corporate general and administrative expenses										(47,065)	(43,353)	(38,372)
Depreciation, amortization and impairment										(90,908)	(64,784)	(61,150)
Interest income (expense), net										(66,639)	(48,583)	(40,923)
Distributable cash from equity investees in excess of equity in earnings										(31,093)	(23,889)	(24,464)	[3]
Non-cash items not included in segment margin										3,017	(7,551)	(5,280)
Cash payments from direct financing leases in excess of earnings										(5,529)	(5,110)	(5,016)
Income tax (expense) benefit										(2,845)	(845)	9,205	[4]
Discontinued Operations for Segment Margin Reconciliation										0	(2,241)	1,004
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest		$ 26,166	$ 29,113	$ 21,148	$ 29,775	$ 16,722	$ 17,966	$ 26,612	$ 22,704	106,202	84,004	97,337
Pipeline Transportation [Member]
Segment Reporting Information [Line Items]
Capital Expenditures										46,611	130,787	59,345	[1]
Segment margin										61,231	64,349	$ 58,039	[2]
SEKCO [Member] | Pipeline Transportation [Member]
Segment Reporting Information [Line Items]
Capital Expenditures										$ 36,100	$ 94,300
[1]	Capital expenditures include maintenance and growth capital expenditures, such as fixed asset additions (including enhancements to existing facilities and construction of internal growth projects) as well as acquisitions of businesses and interests in equity investees. In addition to construction of internal growth projects, capital spending in our Offshore pipeline transportation segment included $36.1 million and $94.3 million during the years ended December 31, 2014 and December 31, 2013 representing capital contributions to our SEKCO equity investee to fund our share of the construction costs for its pipeline. During 2014, capital spending in our marine transportation segment included $157 million for our purchase of the M/T American Phoenix. During 2013, capital spending in our marine segment also included $230.9 million for the acquisition of our offshore marine transportation assets. During 2012, capital spending in our pipeline transportation segment also included $205.6 million for the acquisition of interests in several Gulf of Mexico pipelines
[2]	A reconciliation of Segment Margin to income from continuing operations before income taxes for each year is presented below.
[3]	(1) Includes distributions attributable to the quarter and received during or promptly following such quarter.
[4]	(1)Our discontinued operations had no income tax benefit or expense in any period presented.

Business Segment Information 83

Business Segment Information (Schedule Of Total Assets By Reportable Segment) (Details) - USD ($) $ in Thousands	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Total Conolidated Assets	$ 3,230,374	$ 2,862,202	$ 2,109,664
Pipeline Transportation [Member]
Segment Reporting Information [Line Items]
Total Conolidated Assets	460,012	437,912	325,189
Offshore Pipeline Transportation [Member]
Segment Reporting Information [Line Items]
Total Conolidated Assets	645,668	637,323	565,463
Refinery Services [Member]
Segment Reporting Information [Line Items]
Total Conolidated Assets	403,703	417,121	414,170
Marine Transportation [Member]
Segment Reporting Information [Line Items]
Total Conolidated Assets	745,128	529,914	276,736
Supply And Logistics [Member]
Segment Reporting Information [Line Items]
Total Conolidated Assets	907,189	782,547	473,611
Other Assets [Member]
Segment Reporting Information [Line Items]
Total Conolidated Assets	$ 68,674	$ 57,385	$ 54,495

Transactions with Related Par84

Transactions with Related Parties (Narrative) (Details) - USD ($) $ in Millions	Dec. 31, 2014	Dec. 31, 2013
Related Party Transaction [Line Items]
Guaranty obligation	$ 1,050
Sandhill [Member]
Related Party Transaction [Line Items]
Due from related parties	$ 0.3	$ 0.2
Sandhill Group, LLC [Member]
Related Party Transaction [Line Items]
Ownership percentage	50.00%

Transactions with Related Par85

Transactions with Related Parties (Schedule Of Transactions With Related Parties) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Quintana Group [Member]
Related Party Transaction [Line Items]
Related party transaction, revenues	$ 0	$ 0	$ 21,143	[1],[2]
Related party transaction, expenses	0	0	6,260	[2]
Chief Executive Officer [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses	630	600	600
Sandhill [Member]
Related Party Transaction [Line Items]
Related party transaction, revenues	3,060	3,076	2,905	[3]
Davison [Member]
Related Party Transaction [Line Items]
Related party transaction, revenues	$ 0	$ 1,293	$ 1,344	[1]
Sandhill Group, LLC [Member]
Related Party Transaction [Line Items]
Ownership percentage	50.00%
[1]	Amounts included in discontinued operations for all periods presented.
[2]	The Quintana Group monetized all of its remaining investment in our common units on October 5, 2012. Transactions with the Quintana Group are included in the above table as related party transactions through October 5, 2012.
[3]	We own a 50% interest in Sandhill Group, LLC (or "Sandhill).

Supplemental Cash Flow Inform86

Supplemental Cash Flow Information (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supplemental Cash Flow Elements [Abstract]
Payments of interest and commitment fees	$ 74.8	$ 49.7	$ 41.5
Capitalized interest	13.8	13.3	3.9
Cash paid for income taxes	0.8	(0.6)	(0.3)
Incurred liabilities for fixed and intangible asset additions	61.2	52.5	$ 14.1
Other Asset Additions Incurred but Not yet Paid	$ 9.4	$ 0.1

Supplemental Cash Flow Inform87

Supplemental Cash Flow Information (Net Changes In Components Of Operating Assets And Liabilities) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supplemental Cash Flow Elements [Abstract]
Increase (decrease) in Accounts receivable	$ 95,014	$ (96,300)	$ (34,299)
Increase (decrease) in Inventories	38,501	1,720	14,074
Increase (Decrease) in Deferred Charges	(8,935)	0	0
Increase (decrease) in Other current assets	62,305	(39,170)	(9,593)
Increase (decrease) in Accounts payable	(73,307)	41,718	53,146
Increase (decrease) in Accrued liabilities	(35,624)	45,846	(10,263)
Net changes in components of operating assets and liabilities	$ 77,954	$ (46,186)	$ 13,065

Equity-Based Compensation Pla88

Equity-Based Compensation Plans And Employee Benefit Plans (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Sep. 26, 2014	Sep. 16, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ 6,821	$ 18,671	$ 11,019
Number of common units per right	1
Number of common units issued	95,029,218	88,690,985		4,600,000	5,750,000
Non-cash compensation expense	$ 4,494	$ 12,473	$ 7,197
Employer contribution percentage to retirement plan	6.00%
Employer profit-sharing contribution percentage	3.00%
Service-Based Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Phantom units awarded during the period	43,225
Weighted average grant date fair value of phantom unit	$ 54.05
Forfeited, Number of Phantom Units	4,599
Performance-Based Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Phantom units awarded during the period	82,763
Weighted average grant date fair value of phantom unit	$ 54.18
Forfeited, Number of Phantom Units	6,899
2010 Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Phantom units awarded during the period	125,988	152,964	176,995
Weighted average grant date fair value of phantom unit	$ 54.14	$ 46.88	$ 31.14
Unrecognized compensation cost	$ 4,900
Weighted average period of recognition, years	1 year
Allocated Share-based Compensation Expense	$ 8,800	$ 13,100
Liability for compensation awards	15,400	17,100
2007 Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ (2,000)	5,600	$ 4,300
Stock Appreciation Rights (SARs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average period of recognition, years	1 year
Term of awards, years	10 years
Total intrinsic value of rights exercised	$ 1,400	5,500	3,300
Bonus Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted percentage of target level of available cash before reserves	90.00%
Weighted percentage of achievement level of available cash before reserves	10.00%
Accrued bonus	$ 8,100
Bonus paid		5,300	7,900
Profit-Sharing And Retirement Savings Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Employee retirement plan expenses	6,300	4,300	3,400
Health Care Benefit Programs [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Health care benefits	$ 13,500	$ 10,400	$ 8,800
Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected life of rights (in years), Minimum	1 year	1 year	1 year
Maximum [Member] | 2010 Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance Based Award Percentage	150.00%
Minimum [Member] | 2010 Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance Based Award Percentage	50.00%

Equity-Based Compensation Pla89

Equity-Based Compensation Plans And Employee Benefit Plans (Summary Of Service-Based And Performance-Based Awards) (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2014
Service-Based Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Unvested at December 31, 2013, Number of Phantom Units	105,385
Unvested at December 31, 2013, Average Grant Date Fair Value	$ 35.42
Unvested at December 31, 2013, Total Value	$ 3,733
Granted, Number of Phantom Units	43,225
Granted, Average Grant Date Fair Value	$ 54.05
Granted, Total Value	$ 2,336
Forfeited, Number of Phantom Units	(4,599)
Forfeited, Average Grant Date Fair Value	$ 43.19
Forfeited, Total Value	$ (199)
Settled, Number of Phantom Units	(31,188)
Settled, Average Grant Date Fair Value	$ 27.11
Settled, Total Value	$ (846)
Unvested at December 31, 2014, Number of Phantom Units	112,823
Unvested at December 31, 2014, Average Grant Date Fair Value	$ 44.53
Unvested at December 31, 2014, Total Value	$ 5,024
Performance-Based Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Unvested at December 31, 2013, Number of Phantom Units	334,969
Unvested at December 31, 2013, Average Grant Date Fair Value	$ 35.79
Unvested at December 31, 2013, Total Value	$ 11,989
Granted, Number of Phantom Units	82,763
Granted, Average Grant Date Fair Value	$ 54.18
Granted, Total Value	$ 4,484
Forfeited, Number of Phantom Units	(6,899)
Forfeited, Average Grant Date Fair Value	$ 43.20
Forfeited, Total Value	$ (298)
Settled, Number of Phantom Units	(96,988)
Settled, Average Grant Date Fair Value	$ (28.21)
Settled, Total Value	$ 2,736
Unvested at December 31, 2014, Number of Phantom Units	313,845
Unvested at December 31, 2014, Average Grant Date Fair Value	$ 42.82
Unvested at December 31, 2014, Total Value	$ 13,439

Equity-Based Compensation Pla90

Equity-Based Compensation Plans And Employee Benefit Plans (Assumptions Used To Determine Fair Value Of Rights) (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Risk-free interest rate, Minimum	0.00%	0.00%	0.00%
Risk-free interest rate, Maximum	0.07%	0.07%	0.07%
Expected unit price volatility	39.30%	39.30%	39.30%
Expected future distribution yield	5.00%	5.00%	5.00%
Maximum [Member]
Expected life of rights (in years), Minimum	1 year	1 year	1 year

Equity-Based Compensation Pla91

Equity-Based Compensation Plans And Employee Benefit Plans (Reconciliation Of Rights Activity) (Details) - Dec. 31, 2014 - Stock Appreciation Rights (SARs) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	Total
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Outstanding at December 31, 2013	207,498
Outstanding at December 31, 2013, Weighted Average Strike Price	$ 17.43
Outstanding at December 31, 2013	(37,813)
Exercised during 2014, Weighted Average Strike Price	$ 51.59
Forfeited or expired during 2014	(8,830)
Forfeited or expired during 2014, Weighted Average Strike Price	$ 16.03
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Number	160,855
Outstanding at December 31, 2014, Weighted Average Strike Price	$ 18.08
Outstanding at December 31, 2014	160,855
Outstanding at December 31, 2014, Weighted Average Contractual Remaining Term (Yrs)	3 years 5 months 20 days
Outstanding at December 31, 2014, Average Intrinsic Value	$ 3,906
Exercisable at December 31, 2014, Weighted Average Strike Price	$ 18.08
Exercisable at December 31, 2014, Weighted Average Contractual Remaining Term (Yrs)	3 years 5 months 20 days
Exercisable at December 31, 2014, Average Intrinsic Value	$ 3,906

Equity-Based Compensation Pla92

Equity-Based Compensation Plans And Employee Benefit Plans (Expense Related To Equity-Based Compensation Plans) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Expense related to equity-based compensation plan	$ 6,821	$ 18,671	$ 11,019
Supply and logistics operating costs [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Expense related to equity-based compensation plan	485	4,524	2,707
Marine Transportation Operating Costs [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Expense related to equity-based compensation plan	626	586	190
Refinery servies operating costs [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Expense related to equity-based compensation plan	(62)	1,978	1,427
Pipeline operating costs [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Expense related to equity-based compensation plan	(52)	510	247
General and administrative expenses [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Expense related to equity-based compensation plan	$ 5,824	$ 11,073	$ 6,448

Major Customers and Credit Ri93

Major Customers and Credit Risk (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Shell Oil Company [Member] | Supply And Logistics Revenues [Member]
Concentration Risk [Line Items]
Concentration risk, percentage	12.00%	17.00%	14.00%

Derivatives (Schedule Of Outsta

Derivatives (Schedule Of Outstanding Derivatives Entered Into Hedge Inventory Or Fixed Price Purchase Commitments) (Details) - Dec. 31, 2014 - Not Designated As Hedging Instrument [Member]	USD ($)bbl$ / bbl
Selling Contracts [Member] | Crude Oil Futures [Member]
Derivative [Line Items]
Weighted average contract price per bbl	74.82
Derivative, Nonmonetary Notional Amount | bbl	366
Selling Contracts [Member] | Diesel Futures [Member]
Derivative [Line Items]
Weighted average contract price per bbl	2.43
Derivative, Nonmonetary Notional Amount | bbl	56
Selling Contracts [Member] | Fuel Oil Futures [Member]
Derivative [Line Items]
Weighted average contract price per bbl	60.07
Derivative, Nonmonetary Notional Amount | bbl	465
Selling Contracts [Member] | Crude Oil Options [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl	125
Underlying, Derivative	2.08
Buying Contracts [Member] | Crude Oil Futures [Member]
Derivative [Line Items]
Weighted average contract price per bbl	65.30
Derivative, Nonmonetary Notional Amount | $	168
Buying Contracts [Member] | Diesel Futures [Member]
Derivative [Line Items]
Weighted average contract price per bbl	0
Derivative, Nonmonetary Notional Amount | bbl	0
Buying Contracts [Member] | Fuel Oil Futures [Member]
Derivative [Line Items]
Weighted average contract price per bbl	44.95
Derivative, Nonmonetary Notional Amount | bbl	95
Buying Contracts [Member] | Crude Oil Options [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl	0
Underlying, Derivative	0

Derivatives (Schedule Of Fair V

Derivatives (Schedule Of Fair Value Of Derivative Assets And Liabilities) (Details) - Other Current Assets [Member] - Commodity Derivatives [Member] - Not Designated As Hedging Instrument [Member] - USD ($) $ in Thousands	Dec. 31, 2014	Dec. 31, 2013
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 16,383	$ 615
Derivative Liability, Fair Value, Gross Liability	2,310	4,527	[1]
Derivative Liability, Fair Value, Gross Asset	2,310	4,527	[1]
Derivative Asset, Fair Value, Gross Liability	2,310	615
Derivative Asset	14,073	0
Derivative Liability	$ 0	$ 0
[1]	These derivative liabilities have been funded with margin deposits recorded in our Consolidated Balance Sheets under Current Assets - Other in 2013.

Derivatives (Schedule Of Effect

Derivatives (Schedule Of Effect On Consolidated Statements Of Operations And Other Comprehensive Income (Loss)) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income, Supply & Logistics Product Costs	$ 35,468	$ (3,268)	$ (2,936)
Commodity Derivatives [Member] | Designated As Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income, Supply & Logistics Product Costs		0	0
Commodity Derivatives [Member] | Not Designated As Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income, Supply & Logistics Product Costs	$ 35,468	$ (3,268)	$ (2,936)

Derivatives Derivatives Narrati

Derivatives Derivatives Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Receivables from Brokers-Dealers and Clearing Organizations	$ 2.8	$ 5.3
Margin Deposit Assets	2.4	4.1
Increase (Decrease) in Margin Deposits Outstanding	$ (0.3)	$ (1.2)

Fair-Value Measurements (Narrat

Fair-Value Measurements (Narrative) (Details) - USD ($) $ in Thousands	Dec. 31, 2014	Dec. 31, 2013
7.875% senior unsecured notes (including unamortized premium of $639 and $772 in 2014 and 2013, respectively)	$ 1,050,639	$ 700,772
Fair value of debt	1,003,600	732,400
Seven Point Eight Seventy Five Percentage Senior Unsecured Notes [Member]
7.875% senior unsecured notes (including unamortized premium of $639 and $772 in 2014 and 2013, respectively)	$ 350,639	$ 350,772

Fair-Value Measurements (Placem

Fair-Value Measurements (Placement Of Assets And Liabilities Within The Fair Value Hierarchy Levels) (Details) - Commodity Derivatives [Member] - USD ($) $ in Thousands	Dec. 31, 2014	Dec. 31, 2013
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	$ 16,383	$ 615
Liabilities Fair Value	(2,310)	(4,527)
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	0	0
Liabilities Fair Value	0	0
Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	0	0
Liabilities Fair Value	$ 0	$ 0

Commitments And Contingencie100

Commitments And Contingencies (Future Minimum Rental Payments Under All Non-Cancelable Operating Leases) (Details) $ in Thousands	Dec. 31, 2014USD ($)
Property Subject to or Available for Operating Lease [Line Items]
2,015	$ 32,830
2,016	18,446
2,017	11,742
2,018	10,290
2,019	9,982
2020 and thereafter	31,967
Total minimum lease obligations	115,257
Office Space [Member]
Property Subject to or Available for Operating Lease [Line Items]
2,015	2,282
2,016	1,846
2,017	1,625
2,018	1,631
2,019	1,580
2020 and thereafter	4,484
Total minimum lease obligations	13,448
Transportation Equipment [Member]
Property Subject to or Available for Operating Lease [Line Items]
2,015	14,796
2,016	9,451
2,017	7,430
2,018	5,967
2,019	5,705
2020 and thereafter	6,617
Total minimum lease obligations	49,966
Terminals and Tanks [Member]
Property Subject to or Available for Operating Lease [Line Items]
2,015	15,752
2,016	7,149
2,017	2,687
2,018	2,692
2,019	2,697
2020 and thereafter	20,866
Total minimum lease obligations	$ 51,843

Commitments And Contingencie101

Commitments And Contingencies (Total Operating Lease Expense) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Commitments and Contingencies Disclosure [Abstract]
Operating lease expense	$ 37,941	$ 27,674	$ 21,530

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2012USD ($)
Income Tax Disclosure [Abstract]
Income tax benefit result of tax audit settlements and the expiration of statutes of limitations	$ 8.2

Income Taxes (Income Tax Expens

Income Taxes (Income Tax Expense (Benefit)) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Disclosure [Abstract]
Current, Federal	$ 0	$ 345	$ (8,463)
Current, State	1,100	650	275
Total current income tax expense (benefit)	1,100	995	(8,188)
Deferred, Federal	1,508	(248)	(1,035)
Deferred, State	237	98	18
Total deferred income tax benefit	1,745	(150)	(1,017)
Total income tax expense (benefit) from continuing operations (1)	$ 2,845	$ 845	$ (9,205)	[1]
[1]	(1)Our discontinued operations had no income tax benefit or expense in any period presented.

Income Taxes (Deferred Tax Asse

Income Taxes (Deferred Tax Assets And Liabilities) (Details) - USD ($) $ in Thousands	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Deferred tax assets, Other current assets	$ 262	$ 297
Deferred tax assets, Other	8	8
Total current deferred tax asset	270	305
Net operating loss carryforwards	9,048	7,784
Total long-term deferred tax asset	9,048	7,784
Valuation allowances	(737)	(660)
Total deferred tax assets	8,581	7,429
Deferred tax liabilities, Other	(871)	(785)
Fixed assets	(4,335)	(4,441)
Intangible assets	(14,419)	(11,503)
Total long-term liability	(18,754)	(15,944)
Total deferred tax liabilities	(19,625)	(16,729)
Total net deferred tax liability	$ (11,044)	$ (9,300)

Income Taxes (Federal Statutory

Income Taxes (Federal Statutory Income Tax Rate To Income Before Income Taxes) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Income Tax Disclosure [Abstract]
Income from continuing operations before income taxes	$ 109,047	$ 84,849		$ 88,132
Partnership income not subject to tax	(104,751)	(85,567)		(90,815)
Income (loss) subject to income taxes	4,296	(718)		(2,683)
Tax expense (benefit) at federal statutory rate	1,504	(251)		(939)
State income taxes, net of federal tax	992	660		460
Effects of unrecognized tax positions, federal and state	0	0		(8,205)
Return to provision, federal and state	(232)	88		(166)
Other	581	348		(355)
Total income tax expense (benefit) from continuing operations (1)	$ 2,845	$ 845		$ (9,205)	[1]
Effective Income Tax Rate Reconciliation, Percent	3.00%	1.00%	[2]
[1]	(1)Our discontinued operations had no income tax benefit or expense in any period presented.
[2]	Income tax expense is related to taxable income generated by our corporate subsidiaries and Texas Margin Tax. Due to the income tax benefit in 2012, the effective tax rate as a percentage of our total income from continuing operations before income taxes is not meaningful for those periods.

Quarterly Financial Data (Summa

Quarterly Financial Data (Summary Of Quarterly Financial Data) (Details) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended								12 Months Ended
		Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Quarterly Financial Data [Abstract]
Revenues		$ 847,282	$ 964,114	$ 1,015,049	$ 1,019,719	$ 961,035	$ 1,090,293	$ 1,068,694	$ 1,014,808	$ 3,846,164	$ 4,134,830	$ 3,367,361
Operating income (loss)		30,624	35,268	31,257	35,402	23,300	24,092	33,360	30,005	132,551	110,757	114,710
Income from continuing operations before income taxes										109,047	84,849	88,132
Income from continuing operations		26,166	29,113	21,148	29,775	16,722	17,966	26,612	22,704	106,202	84,004	97,337
Income (loss) from discontinued operations						1,164	508	290	143	0	2,105	(1,018)
Net income (loss)		$ 26,166	$ 29,113	$ 21,148	$ 29,775	$ 17,886	$ 18,474	$ 26,902	$ 22,847	$ 106,202	$ 86,109	$ 96,319
Continuing operations (in dollars per unit)		$ 0.28	$ 0.33	$ 0.24	$ 0.34	$ 0.19	$ 0.21	$ 0.32	$ 0.28	$ 1.18	$ 1	$ 1.24
Discontinued operations (in dollars per unit)						0.01	0.01	0.01	0	0	0.03	$ (0.01)
Net income per common unit-basic and diluted		0.28	0.33	0.24	0.34	0.20	0.22	0.33	0.28	1.18	1.03
Cash distributions per common unit	[1]									2.23000	2.015000
Per Unit Amount		$ 0.5800	$ 0.5650	$ 0.5500	$ 0.5350	$ 0.5225	$ 0.5100	$ 0.4975	$ 0.4850	$ 0.5800	$ 0.5225
[1]	(1)Represents cash distributions declared and paid in the applicable period.

Quarterly Financial Data (Unaud

Quarterly Financial Data (Unaudited) Quarterly Financial Data (Immaterial Restatement) (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supply And Logistics Revenues									$ 3,323,028	$ 3,689,795	$ 2,976,850
Revenues	$ 847,282	$ 964,114	$ 1,015,049	$ 1,019,719	$ 961,035	$ 1,090,293	$ 1,068,694	$ 1,014,808	3,846,164	4,134,830	3,367,361
Supply and logistics costs									3,277,052	3,649,328	2,923,746
Costs and Expenses									3,713,613	4,024,073	3,252,651
Operating income (loss)	$ 30,624	$ 35,268	$ 31,257	$ 35,402	$ 23,300	$ 24,092	$ 33,360	$ 30,005	$ 132,551	$ 110,757	$ 114,710

Condensed Consolidating Fina108

Condensed Consolidating Financial Information (Narrative) (Details) - Dec. 31, 2014 - USD ($) $ in Millions	Total
Condensed Financial Statements, Captions [Line Items]
Guaranty obligation	$ 1,050
Genesis NEJD Pipeline, LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of equity interest	100.00%

Condensed Consolidating Fina109

Condensed Consolidating Financial Information (Condensed Consolidating Balance Sheet) (Details) - USD ($) $ in Thousands	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	$ 9,462	$ 8,866	$ 11,282	$ 10,817
Other current assets	345,904	526,357
Total current assets	355,366	535,223
FIXED ASSETS, at cost	1,899,058	1,327,974
Less: Accumulated depreciation	(268,057)	(199,230)
Net fixed assets	1,631,001	1,128,744
GOODWILL	325,046	325,046
Other assets, net	290,181	252,942
Equity investees and other investments	628,780	620,247
Investments in subsidiaries	0	0
TOTAL ASSETS	3,230,374	2,862,202	2,109,664
Current liabilities	363,145	446,553
Senior secured credit facility	550,400	582,800
SENIOR UNSECURED NOTES	1,050,639	700,772
Deferred tax liabilities	18,754	15,944
Other liabilities	18,233	18,396
Total liabilities	2,001,171	1,764,465
Partners' capital	1,229,203	1,097,737	916,495	792,638
TOTAL LIABILITIES AND PARTNERS’ CAPITAL	3,230,374	2,862,202
Genesis Energy, L.P. (Parent and Co-Issuer)
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	9	20	10	3
Other current assets	1,378,573	1,133,695
Total current assets	1,378,582	1,133,715
FIXED ASSETS, at cost	0	0
Less: Accumulated depreciation	0	0
Net fixed assets	0	0
GOODWILL	0	0
Other assets, net	28,421	21,432
Equity investees and other investments	0	0
Investments in subsidiaries	1,434,255	1,236,164
TOTAL ASSETS	2,841,258	2,391,311
Current liabilities	11,016	10,002
Senior secured credit facility	550,400	582,800
SENIOR UNSECURED NOTES	1,050,639	700,772
Deferred tax liabilities	0	0
Other liabilities	0	0
Total liabilities	1,612,055	1,293,574
Partners' capital	1,229,203	1,097,737
TOTAL LIABILITIES AND PARTNERS’ CAPITAL	2,841,258	2,391,311
Genesis Energy Finance Corporation (Co-Issuer)
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	0	0	0	0
Other current assets	0	0
Total current assets	0	0
FIXED ASSETS, at cost	0	0
Less: Accumulated depreciation	0	0
Net fixed assets	0	0
GOODWILL	0	0
Other assets, net	0	0
Equity investees and other investments	0	0
Investments in subsidiaries	0	0
TOTAL ASSETS	0	0
Current liabilities	0	0
Senior secured credit facility	0	0
SENIOR UNSECURED NOTES	0	0
Deferred tax liabilities	0	0
Other liabilities	0	0
Total liabilities	0	0
Partners' capital	0	0
TOTAL LIABILITIES AND PARTNERS’ CAPITAL	0	0
Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	8,310	8,049	11,103	9,043
Other current assets	333,385	515,143
Total current assets	341,695	523,192
FIXED ASSETS, at cost	1,823,556	1,252,445
Less: Accumulated depreciation	(251,171)	(184,856)
Net fixed assets	1,572,385	1,067,589
GOODWILL	325,046	325,046
Other assets, net	269,252	238,283
Equity investees and other investments	628,780	620,247
Investments in subsidiaries	97,195	89,600
TOTAL ASSETS	3,234,353	2,863,957
Current liabilities	1,761,856	1,592,376
Senior secured credit facility	0	0
SENIOR UNSECURED NOTES	0	0
Deferred tax liabilities	18,754	15,944
Other liabilities	18,233	18,396
Total liabilities	1,798,843	1,626,716
Partners' capital	1,435,510	1,237,241
TOTAL LIABILITIES AND PARTNERS’ CAPITAL	3,234,353	2,863,957
Non-Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	1,143	797	169	1,771
Other current assets	46,215	37,286
Total current assets	47,358	38,083
FIXED ASSETS, at cost	75,502	75,529
Less: Accumulated depreciation	(16,886)	(14,374)
Net fixed assets	58,616	61,155
GOODWILL	0	0
Other assets, net	146,700	152,412
Equity investees and other investments	0	0
Investments in subsidiaries	0	0
TOTAL ASSETS	252,674	251,650
Current liabilities	2,705	3,470
Senior secured credit facility	0	0
SENIOR UNSECURED NOTES	0	0
Deferred tax liabilities	0	0
Other liabilities	154,021	159,007
Total liabilities	156,726	162,477
Partners' capital	95,948	89,173
TOTAL LIABILITIES AND PARTNERS’ CAPITAL	252,674	251,650
Eliminations
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	0	0	$ 0	$ 0
Other current assets	(1,412,269)	(1,159,767)
Total current assets	(1,412,269)	(1,159,767)
FIXED ASSETS, at cost	0	0
Less: Accumulated depreciation	0	0
Net fixed assets	0	0
GOODWILL	0	0
Other assets, net	(154,192)	(159,185)
Equity investees and other investments	0	0
Investments in subsidiaries	(1,531,450)	(1,325,764)
TOTAL ASSETS	(3,097,911)	(2,644,716)
Current liabilities	(1,412,432)	(1,159,295)
Senior secured credit facility	0	0
SENIOR UNSECURED NOTES	0	0
Deferred tax liabilities	0	0
Other liabilities	(154,021)	(159,007)
Total liabilities	(1,566,453)	(1,318,302)
Partners' capital	(1,531,458)	(1,326,414)
TOTAL LIABILITIES AND PARTNERS’ CAPITAL	$ (3,097,911)	$ (2,644,716)

Condensed Consolidating Fina110

Condensed Consolidating Financial Information (Condensed Consolidating Statement Of Operations) (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Condensed Financial Statements, Captions [Line Items]
Supply And Logistics Revenues									$ 3,323,028	$ 3,689,795	$ 2,976,850
Marine Transportation Revenues									229,282	152,542	118,204
Refinery Services Revenues									207,401	205,985	196,017
Pipeline Transportation Services Revenues									86,453	86,508	76,290
Revenues	$ 847,282	$ 964,114	$ 1,015,049	$ 1,019,719	$ 961,035	$ 1,090,293	$ 1,068,694	$ 1,014,808	3,846,164	4,134,830	3,367,361
Supply and logistics costs									3,277,052	3,649,328	2,923,746
Marine transportation operating costs									142,793	104,676	80,547
Refinery services operating costs									121,401	131,289	123,477
Pipeline transportation operating costs									30,767	27,206	21,894
General and administrative									50,692	46,790	41,837
Depreciation and amortization									90,908	64,784	61,150
Total costs and expenses									3,713,613	4,024,073	3,252,651
OPERATING INCOME (LOSS)	30,624	35,268	31,257	35,402	23,300	24,092	33,360	30,005	132,551	110,757	114,710
Equity in earnings of equity investees									43,135	22,675	14,345
Equity in (losses) earnings of subsidiaries									0	0	0
Interest income (expense), net									(66,639)	(48,583)	(40,923)
Income (loss) before income taxes									109,047	84,849	88,132
Income tax benefit (expense)									(2,845)	(845)	9,205	[1]
Income from continuing operations	26,166	29,113	21,148	29,775	16,722	17,966	26,612	22,704	106,202	84,004	97,337
Income (loss) from discontinued operations					1,164	508	290	143	0	2,105	(1,018)
Net income (loss)	$ 26,166	$ 29,113	$ 21,148	$ 29,775	$ 17,886	$ 18,474	$ 26,902	$ 22,847	106,202	86,109	96,319
Genesis Energy, L.P. (Parent and Co-Issuer)
Condensed Financial Statements, Captions [Line Items]
Supply And Logistics Revenues									0	0	0
Marine Transportation Revenues									0	0	0
Refinery Services Revenues									0	0	0
Pipeline Transportation Services Revenues									0	0	0
Revenues									0	0	0
Supply and logistics costs									0	0	0
Marine transportation operating costs									0	0	0
Refinery services operating costs									0	0	0
Pipeline transportation operating costs									0	0	0
General and administrative									0	0	0
Depreciation and amortization									0	0	0
Total costs and expenses									0	0	0
OPERATING INCOME (LOSS)									0	0	0
Equity in earnings of equity investees									0	0	0
Equity in (losses) earnings of subsidiaries									172,828	134,616	137,151
Interest income (expense), net									(66,626)	(48,507)	(40,832)
Income (loss) before income taxes									106,202	86,109	96,319
Income tax benefit (expense)									0	0	0
Income from continuing operations									106,202	86,109	96,319
Income (loss) from discontinued operations										0	0
Net income (loss)									106,202	86,109	96,319
Genesis Energy Finance Corporation (Co-Issuer)
Condensed Financial Statements, Captions [Line Items]
Supply And Logistics Revenues									0	0	0
Marine Transportation Revenues									0	0	0
Refinery Services Revenues									0	0	0
Pipeline Transportation Services Revenues									0	0	0
Revenues									0	0	0
Supply and logistics costs									0	0	0
Marine transportation operating costs									0	0	0
Refinery services operating costs									0	0	0
Pipeline transportation operating costs									0	0	0
General and administrative									0	0	0
Depreciation and amortization									0	0	0
Total costs and expenses									0	0	0
OPERATING INCOME (LOSS)									0	0	0
Equity in earnings of equity investees									0	0	0
Equity in (losses) earnings of subsidiaries									0	0	0
Interest income (expense), net									0	0	0
Income (loss) before income taxes									0	0	0
Income tax benefit (expense)									0	0	0
Income from continuing operations									0	0	0
Income (loss) from discontinued operations										0	0
Net income (loss)									0	0	0
Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Supply And Logistics Revenues									3,323,028	3,689,795	2,976,850
Marine Transportation Revenues									229,282	152,542	118,204
Refinery Services Revenues									202,250	203,021	192,083
Pipeline Transportation Services Revenues									61,686	60,707	50,106
Revenues									3,816,246	4,106,065	3,337,243
Supply and logistics costs									3,277,052	3,649,328	2,923,746
Marine transportation operating costs									142,793	104,676	80,547
Refinery services operating costs									117,788	128,814	120,095
Pipeline transportation operating costs									29,910	26,087	21,081
General and administrative									50,692	46,790	41,837
Depreciation and amortization									88,368	62,194	58,554
Total costs and expenses									3,706,603	4,017,889	3,245,860
OPERATING INCOME (LOSS)									109,643	88,176	91,383
Equity in earnings of equity investees									43,135	22,675	14,345
Equity in (losses) earnings of subsidiaries									6,952	6,913	7,184
Interest income (expense), net									15,662	16,080	16,500
Income (loss) before income taxes									175,392	133,844	129,412
Income tax benefit (expense)									(3,030)	(676)	8,903
Income from continuing operations									172,362	133,168	138,315
Income (loss) from discontinued operations										2,105	(1,018)
Net income (loss)									172,362	135,273	137,297
Non-Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Supply And Logistics Revenues									0	0	0
Marine Transportation Revenues									0	0	0
Refinery Services Revenues									18,289	17,835	19,999
Pipeline Transportation Services Revenues									24,767	25,801	26,184
Revenues									43,056	43,636	46,183
Supply and logistics costs									0	0	0
Marine transportation operating costs									0	0	0
Refinery services operating costs									17,393	16,873	19,489
Pipeline transportation operating costs									857	1,119	813
General and administrative									0	0	0
Depreciation and amortization									2,540	2,590	2,596
Total costs and expenses									20,790	20,582	22,898
OPERATING INCOME (LOSS)									22,266	23,054	23,285
Equity in earnings of equity investees									0	0	0
Equity in (losses) earnings of subsidiaries									0	0	0
Interest income (expense), net									(15,675)	(16,156)	(16,591)
Income (loss) before income taxes									6,591	6,898	6,694
Income tax benefit (expense)									185	(169)	302
Income from continuing operations									6,776	6,729	6,996
Income (loss) from discontinued operations										0	0
Net income (loss)									6,776	6,729	6,996
Eliminations
Condensed Financial Statements, Captions [Line Items]
Supply And Logistics Revenues									0	0	0
Marine Transportation Revenues									0	0	0
Refinery Services Revenues									(13,138)	(14,871)	(16,065)
Pipeline Transportation Services Revenues									0	0	0
Revenues									(13,138)	(14,871)	(16,065)
Supply and logistics costs									0	0	0
Marine transportation operating costs									0	0	0
Refinery services operating costs									(13,780)	(14,398)	(16,107)
Pipeline transportation operating costs									0	0	0
General and administrative									0	0	0
Depreciation and amortization									0	0	0
Total costs and expenses									(13,780)	(14,398)	(16,107)
OPERATING INCOME (LOSS)									642	(473)	42
Equity in earnings of equity investees									0	0	0
Equity in (losses) earnings of subsidiaries									(179,780)	(141,529)	(144,335)
Interest income (expense), net									0	0	0
Income (loss) before income taxes									(179,138)	(142,002)	(144,293)
Income tax benefit (expense)									0	0	0
Income from continuing operations									(179,138)	(142,002)	(144,293)
Income (loss) from discontinued operations										0	0
Net income (loss)									$ (179,138)	$ (142,002)	$ (144,293)
[1]	(1)Our discontinued operations had no income tax benefit or expense in any period presented.

Condensed Consolidating Fina111

Condensed Consolidating Financial Information (Condensed Consolidating Statement of Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	$ 26,166	$ 29,113	$ 21,148	$ 29,775	$ 17,886	$ 18,474	$ 26,902	$ 22,847	$ 106,202	$ 86,109	$ 96,319
Genesis Energy, L.P. (Parent and Co-Issuer)
Condensed Financial Statements, Captions [Line Items]
Net income (loss)									106,202	86,109	96,319
Genesis Energy Finance Corporation (Co-Issuer)
Condensed Financial Statements, Captions [Line Items]
Net income (loss)									0	0	0
Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Net income (loss)									172,362	135,273	137,297
Non-Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Net income (loss)									6,776	6,729	6,996
Eliminations
Condensed Financial Statements, Captions [Line Items]
Net income (loss)									$ (179,138)	$ (142,002)	$ (144,293)

Condensed Consolidating Fina112

Condensed Consolidating Financial Information (Condensed Consolidating Statements Of Cash Flow) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	$ 291,054	$ 138,386	$ 189,304
Payments to acquire fixed and intangible assets	(443,482)	(343,119)	(146,456)
Cash distributions received from equity investees - return of investment	18,363	12,432	14,909
Investments in equity investees	(40,926)	(94,551)	(63,749)
Acquisitions	(157,000)	(230,880)	(205,576)
Repayments on loan to non-guarantor subsidiary	0	0	0
Proceeds from Sales of Assets, Investing Activities	272	1,910	773
Payments for (Proceeds from) Other Investing Activities	1,214	1,622	1,508
Net cash used in investing activities	(623,987)	(655,830)	(401,607)
Borrowings on senior secured credit facility	1,839,900	1,593,300	1,674,400
Repayments on senior secured credit facility	(1,872,300)	(1,510,500)	(1,583,700)
Proceeds from issuance of senior unsecured notes, including premium	350,000	350,000	101,000
Credit facility and senior unsecured notes issuance fees	(11,896)	(8,157)	(7,105)
Payments of Distributions To Common Unitholders	200,461	168,441	142,383
Issuance of common units for cash, net	225,725	263,574	169,421
Other, net	(2,561)	4,748	(1,135)
Net cash provided by financing activities	333,529	515,028	212,768
Net increase in cash and cash equivalents	596	(2,416)	465
Cash and cash equivalents at beginning of period	8,866	11,282	10,817
Cash and cash equivalents at end of period	9,462	8,866	11,282
Genesis Energy, L.P. (Parent and Co-Issuer)
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	(148,008)	(280,155)	(70,083)
Payments to acquire fixed and intangible assets	0	0	0
Cash distributions received from equity investees - return of investment	42,755	23,963	27,878
Investments in equity investees	(225,725)	(263,574)	(169,421)
Acquisitions	0	0	0
Repayments on loan to non-guarantor subsidiary	0	0	0
Proceeds from Sales of Assets, Investing Activities	0	0	0
Payments for (Proceeds from) Other Investing Activities	0	0	0
Net cash used in investing activities	(182,970)	(239,611)	(141,543)
Borrowings on senior secured credit facility	1,839,900	1,593,300	1,674,400
Repayments on senior secured credit facility	(1,872,300)	(1,510,500)	(1,583,700)
Proceeds from issuance of senior unsecured notes, including premium	350,000	350,000	101,000
Credit facility and senior unsecured notes issuance fees	(11,896)	(8,157)	(7,105)
Payments of Distributions To Common Unitholders	200,461	168,441	142,383
Issuance of common units for cash, net	225,725	263,574	169,421
Other, net	1	0	0
Net cash provided by financing activities	330,967	519,776	211,633
Net increase in cash and cash equivalents	(11)	10	7
Cash and cash equivalents at beginning of period	20	10	3
Cash and cash equivalents at end of period	9	20	10
Genesis Energy Finance Corporation (Co-Issuer)
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	0	0	0
Payments to acquire fixed and intangible assets	0	0	0
Cash distributions received from equity investees - return of investment	0	0	0
Investments in equity investees	0	0	0
Acquisitions	0	0	0
Repayments on loan to non-guarantor subsidiary	0	0	0
Proceeds from Sales of Assets, Investing Activities	0	0	0
Payments for (Proceeds from) Other Investing Activities	0	0	0
Net cash used in investing activities	0	0	0
Borrowings on senior secured credit facility	0	0	0
Repayments on senior secured credit facility	0	0	0
Proceeds from issuance of senior unsecured notes, including premium	0	0	0
Credit facility and senior unsecured notes issuance fees	0	0	0
Payments of Distributions To Common Unitholders	0	0	0
Issuance of common units for cash, net	0	0	0
Other, net	0	0	0
Net cash provided by financing activities	0	0	0
Net increase in cash and cash equivalents	0	0	0
Cash and cash equivalents at beginning of period	0	0	0
Cash and cash equivalents at end of period	0	0	0
Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	591,431	557,879	371,256
Payments to acquire fixed and intangible assets	(443,482)	(343,119)	(146,296)
Cash distributions received from equity investees - return of investment	18,363	12,432	14,909
Investments in equity investees	(40,926)	(94,551)	(63,749)
Acquisitions	(157,000)	(230,880)	(205,576)
Repayments on loan to non-guarantor subsidiary	4,993	4,512	4,078
Proceeds from Sales of Assets, Investing Activities	272	1,910	773
Payments for (Proceeds from) Other Investing Activities	1,214	1,622	1,508
Net cash used in investing activities	(618,994)	(651,318)	(397,369)
Borrowings on senior secured credit facility	0	0	0
Repayments on senior secured credit facility	0	0	0
Proceeds from issuance of senior unsecured notes, including premium	0	0	0
Credit facility and senior unsecured notes issuance fees	0	0	0
Payments of Distributions To Common Unitholders	200,462	168,441	142,383
Issuance of common units for cash, net	225,725	263,574	169,421
Other, net	(2,561)	4,748	(1,135)
Net cash provided by financing activities	27,824	90,385	28,173
Net increase in cash and cash equivalents	261	(3,054)	2,060
Cash and cash equivalents at beginning of period	8,049	11,103	9,043
Cash and cash equivalents at end of period	8,310	8,049	11,103
Non-Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	5,296	5,101	2,602
Payments to acquire fixed and intangible assets	0	0	(160)
Cash distributions received from equity investees - return of investment	0	0	0
Investments in equity investees	0	0	0
Acquisitions	0	0	0
Repayments on loan to non-guarantor subsidiary	0	0	0
Proceeds from Sales of Assets, Investing Activities	0	0	0
Payments for (Proceeds from) Other Investing Activities	0	0	0
Net cash used in investing activities	0	0	(160)
Borrowings on senior secured credit facility	0	0	0
Repayments on senior secured credit facility	0	0	0
Proceeds from issuance of senior unsecured notes, including premium	0	0	0
Credit facility and senior unsecured notes issuance fees	0	0	0
Payments of Distributions To Common Unitholders	0	0	0
Issuance of common units for cash, net	0	0	0
Other, net	4,950	4,473	4,044
Net cash provided by financing activities	(4,950)	(4,473)	(4,044)
Net increase in cash and cash equivalents	346	628	(1,602)
Cash and cash equivalents at beginning of period	797	169	1,771
Cash and cash equivalents at end of period	1,143	797	169
Eliminations
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	(157,665)	(144,439)	(114,471)
Payments to acquire fixed and intangible assets	0	0	0
Cash distributions received from equity investees - return of investment	(42,755)	(23,963)	(27,878)
Investments in equity investees	225,725	263,574	169,421
Acquisitions	0	0	0
Repayments on loan to non-guarantor subsidiary	(4,993)	(4,512)	(4,078)
Proceeds from Sales of Assets, Investing Activities	0	0	0
Payments for (Proceeds from) Other Investing Activities	0	0	0
Net cash used in investing activities	177,977	235,099	137,465
Borrowings on senior secured credit facility	0	0	0
Repayments on senior secured credit facility	0	0	0
Proceeds from issuance of senior unsecured notes, including premium	0	0	0
Credit facility and senior unsecured notes issuance fees	0	0	0
Payments of Distributions To Common Unitholders	(200,462)	(168,441)	(142,383)
Issuance of common units for cash, net	(225,725)	(263,574)	(169,421)
Other, net	(4,951)	(4,473)	(4,044)
Net cash provided by financing activities	(20,312)	(90,660)	(22,994)
Net increase in cash and cash equivalents	0	0	0
Cash and cash equivalents at beginning of period	0	0	0
Cash and cash equivalents at end of period	$ 0	$ 0	$ 0