Genesis Energy (GEL) 10-Q 4 May 18 2018 Q1 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	3 Months Ended
	Mar. 31, 2018	May 04, 2018
Entity Information [Line Items]
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
Document Type	10-Q
Document Period End Date	Mar. 31, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q1
Amendment Flag	false
Common Class A
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding		122,539,221
Common Class B
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding		39,997

Unaudited Condensed Consolidate

Unaudited Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
CURRENT ASSETS:
Cash and cash equivalents	$ 16,092	$ 9,041
Accounts receivable - trade, net	419,903	495,449
Inventories	95,667	88,653
Other	48,432	42,890
Total current assets	580,094	636,033
FIXED ASSETS, at cost	5,652,880	5,601,015
Less: Accumulated depreciation	(802,261)	(734,986)
Net fixed assets	4,850,619	4,866,029
MINERAL LEASEHOLDS, net of accumulated depletion	563,369	564,506
NET INVESTMENT IN DIRECT FINANCING LEASES, net of unearned income	123,270	125,283
EQUITY INVESTEES	372,493	381,550
INTANGIBLE ASSETS, net of amortization	178,755	182,406
GOODWILL	325,046	325,046
OTHER ASSETS, net of amortization	116,190	56,628
TOTAL ASSETS	7,109,836	7,137,481
CURRENT LIABILITIES:
Accounts payable - trade	263,527	270,855
Accrued liabilities	152,163	185,409
Total current liabilities	415,690	456,264
SENIOR SECURED CREDIT FACILITY	1,279,000	1,099,200
SENIOR UNSECURED NOTES, net of debt issuance costs	2,456,749	2,598,918
DEFERRED TAX LIABILITIES	12,138	11,913
OTHER LONG-TERM LIABILITIES	290,401	256,571
Total liabilities	4,453,978	4,422,866
MEZZANINE CAPITAL:
Class A Convertible Preferred Units, 22,901,980 and 22,411,728 issued and outstanding at March 31, 2018 and December 31, 2017, respectively	712,687	697,151
PARTNERS’ CAPITAL:
Common unitholders, 122,579,218 and 122,579,218 units issued and outstanding at March 31, 2018 and December 31, 2017, respectively	1,951,590	2,026,147
Accumulated other comprehensive loss	(604)	(604)
Noncontrolling interests	(7,815)	(8,079)
Total partners' capital	1,943,171	2,017,464
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	$ 7,109,836	$ 7,137,481

Unaudited Condensed Consolidat3

Unaudited Condensed Consolidated Balance Sheets (Parenthetical) - shares	Mar. 31, 2018	Dec. 31, 2017
Statement of Financial Position [Abstract]
Common units, issued	122,579,218	122,579,218
Common units, outstanding	122,579,218	122,579,218
Preferred units, issued	22,901,980	22,411,728
Preferred units, outstanding	22,901,980	22,411,728

Unaudited Condensed Consolidat4

Unaudited Condensed Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
REVENUES:
Offshore pipeline transportation services	$ 73,260	$ 85,128
Sodium minerals and sulfur services	285,910	45,046
Marine transportation	48,929	50,302
Onshore facilities and transportation	317,709	235,015
Total revenues	725,808	415,491
COSTS AND EXPENSES:
Onshore facilities and transportation product costs	277,818	192,093
Onshore facilities and transportation operating costs	22,295	22,239
Marine transportation costs	37,847	37,242
Sodium minerals and sulfur services operating costs	223,498	27,364
Offshore pipeline transportation operating costs	18,340	17,868
General and administrative	11,674	9,976
Depreciation, depletion and amortization	75,255	56,112
Total costs and expenses	666,727	362,894
OPERATING INCOME	59,081	52,597
Equity in earnings of equity investees	10,572	11,335
Interest expense	(56,136)	(36,739)
Other expense	(5,244)	0
Income before income taxes	8,273	27,193
Income tax expense	(375)	(255)
NET INCOME	7,898	26,938
Net loss attributable to noncontrolling interests	136	152
NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P.	8,034	27,090
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(16,888)	0
Net Income (loss) Available to Common Unitholders	$ (8,854)	$ 27,090
NET INCOME PER COMMON UNIT:
Basic and Diluted (in dollars shares)	$ (0.07)	$ 0.23
WEIGHTED AVERAGE OUTSTANDING COMMON UNITS:
Basic and Diluted (in shares)	122,579	118,388

Unaudited Condensed Consolidat5

Unaudited Condensed Consolidated Statement of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Statement of Comprehensive Income [Abstract]
Net income	$ 7,898	$ 26,938
Change in benefit plan liability	0	0
Total Comprehensive income	7,898	26,938
Comprehensive loss attributable to non-controlling interests	(136)	(152)
Comprehensive income attributable to Genesis Energy, L.P.	$ 8,034	$ 27,090

Unaudited Condensed Consolidat6

Unaudited Condensed Consolidated Statements of Partners' Capital - USD ($) $ in Thousands	Total	Partners’ Capital	Noncontrolling Interest	Accumulated Other Comprehensive Loss	Common UnitsPartners’ Capital
Partners' capital, beginning balance (units) at Dec. 31, 2016					117,979,000
Partners' capital, beginning balance at Dec. 31, 2016	$ 2,120,050	$ 2,130,331	$ (10,281)	$ 0
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	26,938	27,090	(152)	0	$ 0
Cash distributions to partners	(83,765)	(83,765)	0	0	$ 0
Issuance of common units for cash, net (units)					4,600,000
Issuance of common units for cash, net	140,537	140,537	0	0
Partners' capital, ending balance (units) at Mar. 31, 2017					122,579,000
Partners' capital, ending balance at Mar. 31, 2017	2,203,760	2,214,193	(10,433)	0
Increase (Decrease) in Partners' Capital [Roll Forward]
Impact of adoption of ASC 606 | Scenario, Adjustment | ASC 606	(3,550)	(3,550)	0	0	$ 0
Partners' capital, adjusted beginning balance	$ 2,013,914	2,022,597	(8,079)	(604)
Partners' capital, beginning balance (units) (Scenario, Previously Reported) at Dec. 31, 2017					122,579,000
Partners' capital, beginning balance (units) at Dec. 31, 2017	122,579,218				122,579,000
Partners' capital, beginning balance (Scenario, Previously Reported) at Dec. 31, 2017	$ 2,017,464	2,026,147	(8,079)	(604)
Partners' capital, beginning balance at Dec. 31, 2017	2,017,464
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	7,898	8,034	(136)	0	$ 0
Cash distributions to partners	(62,515)	(62,515)	0	0	0
Cash contributions from noncontrolling interests	400	0	400	0	0
Distributions to Class A Convertible Preferred unitholders	$ (16,526)	(16,526)	0	0	$ 0
Partners' capital, ending balance (units) at Mar. 31, 2018	122,579,218				122,579,000
Partners' capital, ending balance at Mar. 31, 2018	$ 1,943,171	$ 1,951,590	$ (7,815)	$ (604)

Unaudited Condensed Consolidat7

Unaudited Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$ 7,898	$ 26,938
Adjustments to reconcile net income to net cash provided by operating activities -
Depreciation, depletion and amortization	75,255	56,112
Amortization and writeoff of debt issuance costs and discount	4,161	2,582
Amortization Of Unearned Income And Initial Direct Costs On Direct Financing Leases	(3,330)	(3,500)
Payments received under direct financing leases	5,167	5,167
Equity in earnings of investments in equity investees	(10,572)	(11,335)
Cash distributions of earnings of equity investees	10,352	11,542
Non-cash effect of equity-based compensation plans	(136)	864
Deferred and other tax liabilities	225	205
Unrealized loss on derivative transactions	2,642	142
Other, net	(1,552)	1,391
Net changes in components of operating assets and liabilities (Note 14)	(3,782)	(29,068)
Net cash provided by operating activities	86,328	61,040
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	(66,051)	(61,292)
Cash distributions received from equity investees - return of investment	9,277	9,083
Contributions in aid of construction costs	0	124
Proceeds from asset sales	6	1,234
Net cash used in investing activities	(56,768)	(50,851)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	333,800	216,700
Repayments on senior secured credit facility	(154,000)	(284,900)
Repayment of senior unsecured notes	(145,170)	0
Debt issuance costs	(159)	0
Issuance of common units for cash, net	0	140,968
Contributions from noncontrolling interest	400	0
Distributions to common unitholders	(62,515)	(83,765)
Other, net	5,135	4,552
Net cash used in financing activities	(22,509)	(6,445)
Net increase in cash and cash equivalents	7,051	3,744
Cash and cash equivalents at beginning of period	9,041	7,029
Cash and cash equivalents at end of period	$ 16,092	$ 10,773

Organization and Basis of Prese

Organization and Basis of Presentation and Consolidation	3 Months Ended
	Mar. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Basis of Presentation and Consolidation	Organization and Basis of Presentation and Consolidation Organization We are a growth-oriented master limited partnership formed in Delaware in 1996 and focused on the midstream segment of the crude oil and natural gas industry in the Gulf Coast region of the United States, Wyoming and the Gulf of Mexico. We have a diverse portfolio of assets, including pipelines, offshore hub and junction platforms, soda ash businesses, refinery-related plants, storage tanks and terminals, railcars, rail loading and unloading facilities, barges and other vessels, and trucks. We 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. On September 1, 2017, we acquired our trona and trona-based exploring, mining, processing, producing, marketing and selling business (our"Alkali Business") for approximately $1.325 billion in cash. We funded that acquisition and the related transaction costs with proceeds from a $750 million private placement of Class A Convertible Preferred units (our "preferred units"), a $550 million public offering of notes, our revolving credit facility, and cash on hand. At the closing, we entered into transition service agreements to facilitate the transition of operations and uninterrupted services for both employees and customers. We report the results of our Alkali Business in our renamed sodium minerals and sulfur services segment, which includes our Alkali Business as well as our legacy refinery services operations. We currently manage our businesses through four divisions that constitute our reportable segments - offshore pipeline transportation, sodium minerals and sulfur services, onshore facilities and transportation and marine transportation. These four divisions that constitute our reportable segments consist of the following: • Offshore pipeline transportation and processing of crude oil and natural gas in the Gulf of Mexico; • Sodium minerals and sulfur services involving trona and trona-based exploring, mining, processing, producing, marketing and selling activities, as well as 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"); • Onshore facilities and transportation, which include terminalling, blending, storing, marketing, and transporting crude oil, petroleum products, and CO 2 ; and • Marine transportation to provide waterborne transportation of petroleum products and crude oil throughout North America. Basis of Presentation and Consolidation The accompanying Unaudited Condensed Consolidated Financial Statements include Genesis Energy, L.P. and its subsidiaries, including our general partner, Genesis Energy, LLC. Our results of operations for the interim periods shown in this report are not necessarily indicative of results to be expected for the fiscal year. The Condensed Consolidated Financial Statements included herein have been prepared by us without audit pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”). Accordingly, they reflect all adjustments (which consist solely of normal recurring adjustments) that are, in the opinion of management, necessary for a fair presentation of the financial results for interim periods. Certain information and notes normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to such rules and regulations. However, we believe that the disclosures are adequate to make the information presented not misleading when read in conjunction with the information contained in the periodic reports we file with the SEC pursuant to the Securities Exchange Act of 1934, including the Consolidated Financial Statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2017 . 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.

Recent Accounting Developments

Recent Accounting Developments	3 Months Ended
	Mar. 31, 2018
Accounting Policies [Abstract]
Recent Accounting Developments	Recent Accounting Developments Recently Issued We have adopted guidance under ASC Topic 606, Revenue from Contracts with Customers, and all related ASUs (collectively "ASC 606") as of January 1, 2018 utilizing the modified retrospective method of adoption. The adoption date for our material equity method investment in the Poseidon Oil Pipeline Company, LLC will follow the non-public business entity adoption date of January 1, 2019 for its stand-alone financial statements. Refer to Note 3 for further details. In February 2016, the FASB issued guidance to improve the transparency and comparability among companies by requiring lessees to recognize a lease liability and a corresponding lease asset for virtually all lease contracts. The guidance also requires additional disclosure about leasing arrangements. The guidance is effective for interim and annual periods beginning after December 15, 2018 and requires a modified retrospective approach to adoption. Early adoption is permitted. We are currently evaluating this guidance. In August 2016, the FASB issued ASU 2016-15, Classification of Certain Cash Receipts and Cash Payments. ASU 2016-15 addresses how certain cash receipts and cash payments are presented and classified in the statement of cash flows under Topic 230, Statement of Cash flow, and other Topics. ASU 2016-15 is effective for annual reporting periods, and interim periods therein, beginning after December 15, 2017. We have adopted this guidance as of January 1, 2018 using the retrospective transition method to each period presented on the Consolidated Statements of Cash Flows. We reclassified $3.6 million from operating cash flows to investing cash flows for the three months ended March 31, 2017. In January 2017, the FASB issued guidance to simplify the goodwill impairment testing at annual or interim periods. The guidance eliminates Step 2 from the goodwill impairment testing process, and any identified impairment charge would be simplified to be the difference between the carrying value and fair value of a reporting unit, but would not exceed the total amount of goodwill allocated to the reporting unit in question. The guidance is effective for annual reporting periods, and interim periods therein, beginning after December 15, 2019, with early adoption permitted. We early adopted this guidance and it did not have an impact on our consolidated financial statements. In March 2017, the FASB issued ASU 2017-07, Compensation-Retirement Benefits (Topic 715). ASU 2017-07 requires employers to separate the service cost component from the other components of net benefit cost in the period. The new standard requires the other components of net benefit costs (excluding service costs), be reclassified to "Other expense" from "General and administrative." We adopted this standard as of January 1, 2018. This standard is applied retrospectively. The effect was not material to our financial statements.

Revenue Recognition

Revenue Recognition	3 Months Ended
	Mar. 31, 2017
Revenue Recognition [Abstract]
Revenue Recognition	Revenue Recognition Adoption of ASC 606 and its related Transition effects The modified retrospective method of adoption required us to apply the new revenue standard to all new revenue contracts entered into after January 1, 2018 and revenue contracts that were not completed as of January 1, 2018. Our consolidated revenues for periods prior to January 1, 2018 were not revised and the cumulative effect of our adoption of ASC 606 was recorded as an adjustment to partners' capital at January 1, 2018. Based on this application, the following adjustments were made to our consolidated balance sheet as of January 1, 2018: December 31, 2017 Adjustments January 1, 2018 ASSETS Accounts receivable- trade, net $ 495,449 $ (48,028 ) $ 447,421 Inventories 88,653 5,138 93,791 Other assets, net of amortization 56,628 59,204 115,832 LIABILITIES AND CAPITAL Other long-term liabilities 256,571 19,864 276,435 Partners' capital 2,026,147 (3,550 ) 2,022,597 Current Impact of New Revenue Recognition Guidance The tables below summarize the impact of adoption on our unaudited condensed consolidated balance sheet and statement of operations as of and for the three months ended March 31, 2018: As of March 31, 2018 Unaudited Condensed Consolidated Balance Sheet As Reported Without adoption of ASC 606 Effect of Change Increase/(Decrease) ASSETS Accounts receivable-trade, net 419,903 472,116 (52,213 ) Inventories 95,667 92,628 3,039 Other Assets, net of amortization 116,190 51,948 64,242 LIABILITIES AND CAPITAL Other Long-Term Liabilities 290,401 268,832 21,569 Partners' Capital 1,951,590 1,958,091 (6,501 ) Three months ended March 31, 2018 Unaudited Condensed Consolidated Statement of Operations As Reported Without adoption of ASC 606 Effect of Change Increase/(Decrease) Offshore pipeline transportation services 73,260 74,111 (851 ) Sodium minerals and sulfur services 285,910 263,965 21,945 Marine transportation 48,929 48,929 — Onshore facilities and transportation 317,709 317,709 — Total revenues 725,808 704,714 21,094 Onshore facilities and transportation product costs 277,818 277,818 — Onshore facilities and transportation operating costs 22,295 22,295 — Marine transportation operating costs 37,847 37,847 — Sodium minerals and sulfur services operating costs 223,498 199,454 24,044 Offshore pipeline transportation operating costs 18,340 18,340 — OPERATING INCOME 59,081 62,032 (2,951 ) The effects of changes pursuant to ASC 606 in the tables above are attributable to our offshore pipeline transportation services operating segment and our sodium minerals and sulfur services operating segment. In our offshore pipeline transportation services segment, we have certain contracts with customers that contain tiered pricing structures that are dependent upon reaching certain cumulative milestones of throughput volumes on our pipelines. In addition, we have a contract that contains fixed and variable consideration for us to stand ready and provide reservation capacity for a fixed minimum quantity on our pipeline. Pursuant to the new guidance, we have allocated our estimated total transaction price over the life of the contract to the related performance obligation and recognized the effects in our Consolidated Financial Statements. In our sodium minerals and sulfur services operating segment, specifically our legacy refinery services business, we have two distinct performance obligations, including the completion of our refinery sulfur removal process, for which we receive in-kind consideration, and our sale of NaHS to our customers. Due to this, we have recorded revenue and the related cost of sales in the Consolidated Financial Statements for the three months ended March 31, 2018 (the "2018 Quarter") for services performed for the in-kind consideration for our services. Further discussion of our performance obligations by type and segment are below. Revenue from Contracts with Customers The following table reflects the disaggregation of our revenues by major category for the three months ended March 31, 2018: Period ended March 31, 2018 Onshore Facilities & Transportation Sodium Minerals & Sulfur Services Offshore Pipeline Transportation Marine Transportation Consolidated Fee-based revenues 30,338 — 73,260 48,929 152,527 Product Sales 287,371 263,965 — — 551,336 Refinery Services — 21,945 — — 21,945 $ 317,709 $ 285,910 $ 73,260 $ 48,929 $ 725,808 The Company recognizes revenue upon the satisfaction of its performance obligations under its contracts. The timing of revenue recognition varies for the revenue streams described in more detail below. In general, the timing includes recognition of revenue over time as services are being performed as well as recognition of revenue at a point in time, for delivery of products. Fee-based Revenues We provide a variety of fee-based transportation and logistics services to our customers across several of our reportable segments as outlined below. Offshore Pipeline Transportation Revenue from our offshore pipelines is generally based upon a fixed fee per unit of volume (typically per Mcf of natural gas or per barrel of crude oil) gathered, transported, or processed multiplied by the volume delivered. Fees are based either on contractual arrangements or tariffs regulated by the FERC. Revenue associated with these fee-based services is recognized as volumes are delivered over the performance obligation period. In addition to the offshore pipeline transportation revenue discussed above, we also have certain contracts with customers in which we earn either demand-type fees or firm capacity reservation fees. These fees are charged to a customer regardless of the volume the customer actually delivers to the platform or through the pipeline. These contracts include a single performance obligation to stand ready, on a monthly basis, to provide capacity on our assets. In addition to these offshore pipeline transportation services revenue streams, we also have certain customer contracts in which the transportation fee has a tiered pricing structure based on cumulative milestones of throughput on the related pipeline asset and contract, or on a specified date. The performance obligation for these contracts is to transport, gather or process commodity volumes for the customer based on firm (stand ready) service or from monthly nominations made by our customers, which can also be on an interruptible basis. While our transportation rate changes when milestones are achieved for certain cumulative throughput, the performance obligation satisfied by us does not change throughout the life of the contract. Therefore revenue is recognized on an average rate basis throughout the life of the contract. We have estimated the total consideration to be received under the contract beginning at the contract inception date based on the estimated volumes (including certain minimum volumes we are required to stand ready for), price indexing, estimated production or contracted volumes, and the contract period. We have constrained the estimates of variable consideration such that it is probable that a significant reversal of previously recognized revenue will not occur throughout the life of the contract. These estimates will be reassessed at each reporting period as required. Billings to our customers are reflected at the contract rate. This variability between the consideration received from our customers from invoicing compared to the revenue recognized creates a contract asset or liability. In circumstances where the estimated average contract rate is less than the billed current price tier in the contract, we will recognize a contract liability. In circumstances where the estimated average contract rate is higher than the billed current price tier in the contract, we will recognize a contract asset. Onshore Facilities and Transportation Within our onshore facilities and transportation segment, we provide our customers with pipeline transportation, terminalling services, and rail loading/unloading services, among others, primarily on a per barrel fee basis. Revenues from contracts for the transportation of crude oil by our pipelines are based on actual volumes at a published tariff and some contain minimum throughput provisions which reset within one year. We recognize revenues for transportation and other services over the performance obligation period, which is the contract term. Revenues for both firm and interruptible transportation and other services are recognized when product is delivered to the agreed upon delivery point or at the point of receipt because they specifically relate to our efforts to transfer the distinct services. Service contracts contain a series of distinct services that are substantially the same and have the same pattern of transfer to the customer over the contract period, and therefore qualify as a single performance obligation that is satisfied over time. The customer receives and consumes the benefit of our services simultaneous with the provision of those services. Pricing for our services is determined through a variety of mechanisms, including specified contract pricing or regulated tariff pricing. Consideration to be received by us under these contracts is variable, as the volume of the commodity to be transported is unknown at contract inception. At the end of a day or month (as specified in the contract), both the price and volume are known (or “fixed”) in order to allow us to accurately calculate the amount of consideration we are entitled to invoice. The measurement of these services and invoicing occurs on a monthly basis. Pipeline Loss Allowances In order to compensate us for bearing the risk of volumetric losses of crude oil in transit in our pipelines (for our onshore and offshore pipelines) due to temperature, crude quality, and the inherent difficulties of measurement of liquids in a pipeline, our tariffs and agreements include the right for us to make volumetric deductions from the customer for quality and volumetric fluctuations. We refer to these deductions as pipeline loss allowances ("PLA"). 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. As the allowance is related to our pipeline transportation services, the performance obligation is the obligation to transport and deliver the barrels and is considered a single obligation. 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 required to replace the lost volumes. Under ASC 606, we record excess oil as non-cash consideration at the lower of the recorded value or the market value and include this amount in the transaction price. The crude oil in inventory can then be sold at current prevailing market prices, resulting in additional revenue if the sales price exceeds the inventory value when control transfers to the customer. Marine Transportation Our marine transportation business consists of revenues from the inland and offshore marine transportation of heavy refined petroleum products, asphalt and crude oil, using our barges or vessels. This revenue is recognized over the passage of time of individual trips 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 and certain other operational costs may be directly reimbursed by the customer, if stipulated in the contract. A performance obligation is driven by providing transportation services using our vessels for a single day either under a term or spot based contract. The transaction price is usually fixed per the contract either as a day rate or as a lump sum to be allocated over days required to complete the service. Revenue is recognizable as the transportation service utilizing our vessels occurs, as the customer simultaneously receives and consumes these services as they are provided. If provided in the contract, certain items such as fuel or operational costs can be rebilled to the customer in the same period in which the costs are incurred. In the event timing of a trip to provide our services crosses a reporting period under a lump sum fee contract, the revenue earned is accrued based on the progress completed in the current period on the related performance obligation as we are entitled to payment for each day. Customer invoicing occurs at the completion of a trip, or earlier at the customer’s request. Product Sales Sodium Minerals and Sulfur Services Product sales in our sodium minerals and sulfur services segment primarily involve the sales of caustic soda, NaHS, soda ash and other alkali products. As it relates to revenue recognition, these sales transactions contain a single performance obligation, which is the delivery of the product to the customer at the agreed upon point of sale. For some transactions, control of product transfers to the customer at the shipping point, but we are obligated to arrange for shipment of the product as directed by the customer. Rather than treat these shipping activities as separate performance obligations, our policy is to account for them as fulfillment costs in accordance with ASC 606. The transaction price for these product sales are determined by specific contracts, typically at a fixed rate or based on a market or indexed rate. This pricing is known, or is “fixed,” at the time of revenue recognition. Invoicing and related payment terms are in accordance with industry standard or contract specification based on final pricing. The entirety of the transaction price is allocated to the performance obligation which is delivery of the product at the agreed upon point of sale. As this type of revenue is earned at a point in time, there is no allocation of transaction price to future performance obligations. Onshore Facilities and Transportation Product sales in our onshore facilities and transportation segment primarily involve the sales of crude oil and petroleum products. These contracts contain a single performance obligation, which is the delivery of the product to the customer at a specified location. These contracts are settled on a monthly basis for term contracts, or on a spot basis. Invoicing and related payment terms are in accordance with industry standard or contract specification based on final pricing. Pricing is designated within the contracts and is either fixed, index-based or formulaic, utilizing an average price for the month or for a specified range of days, regardless of when delivery occurs. In either case, pricing is known at the time of invoicing. The entirety of the consideration is allocated to a single performance obligation which is delivery of the product to a specified location. As this type of revenue is earned at a point in time, there is no allocation of transaction price to future performance obligations. Refinery Services Our refinery services business primarily provides sulfur extraction services to refiners’ high sulfur (or “sour”) gas streams that the refineries have generated from crude oil processing operations. Our process applies our proprietary technology, which uses caustic soda to act as a scrubbing agent under prescribed temperature and pressure to remove sulfur. The technology returns a clean (sulfur-free) hydrocarbon stream to the refinery for further processing into refined products, and simultaneously produces NaHS. Units of NaHS are produced ratably as a gas stream is processed. We obtain control and ownership of the NaHS immediately upon production which constitutes the sole consideration received for our sulfur removal services. We later market this product to third parties as part of our product sales, as described above. As part of some of our arrangements, we pay a refinery access fee (“RSA fee”) for any benefits received by virtue of our plant’s proximity to the customer’s refinery. Our RSA fee is recorded as a reduction of revenue. Providing sulfur removal services is the singular performance obligation in our refinery service agreements. As our customers simultaneously receive and consume the refinery service benefits, control is transferred and revenue is recognized over time based on the extent of progress towards completion of the performance obligations. We use units of NaHS produced during a period to measure progress as the amount we receive corresponds directly with the efforts to provide our services completed to date. The transaction price for each performance obligation is determined using the fair value of a unit of NaHS on the contract inception date for each refinery services agreement. Accordingly, we record the value of NaHS received as non cash consideration in inventory until it is subsequently sold to our customers (see Product Sales, above). Contract Assets and Liabilities The table below depicts our contract asset and liability balances and related activity from January 1, 2018 to March 31, 2018: Contract Assets Contract Liabilities Non-Current Non-Current Balance at January 1, 2018 59,204 19,864 Balance at March 31, 2018 64,240 21,570 During the three months ended March 31, 2018 there were no balances that were previously classified as contract liabilities at the beginning of the period that were recognized as revenues. Accounts receivable-trade, net does not include consideration received in kind from our refinery services process. We did not have any contract modifications during the period that would affect our contract asset and liability balances. Transaction Price Allocations to Future Performance Obligations We are required to disclose the amount of our transaction prices that are allocated to future unrecognized performance obligations as of March 31, 2018. However, ASC 606 does provide the following practical expedients and exemptions that we utilized: 1) Performance obligations are part of a contract with an expected duration of one year or less; 2) Revenue recognized from the satisfaction of performance obligations where we have a right to consideration in an amount that corresponds directly with the value provided to customers; and 3) Contracts that contain variable consideration, such as index-based pricing or variable volumes, that is allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied promise to transfer a distinct good or service that is part of a series. We apply these practical expedients and exceptions to our revenue streams recognized over time. The majority of our contracts qualify for one of these expedients or exceptions. After considering these practical expedients and identifying the remaining contract types that involve revenue recognition over a long-term period and include long-term fixed consideration (adjusted for indexing as required), we determined our allocations of transaction price that relate to unsatisfied performance obligations. As it relates to our tiered pricing offshore transportation contracts, we provide firm capacity for both fixed and variable consideration over a long term period. Therefore, we have allocated our remaining contract value (as estimated and discussed above) to future periods. As of March 31, 2018 have an estimated aggregate transaction price allocated to unsatisfied performance obligations of $379.9 million for our offshore transportation segment. Similarly, in our marine transportation segment, our contract related to our M/T American Phoenix contains minimum fixed consideration over the life of the contract, which ends in September 2020. The estimated aggregate transaction price allocated to unsatisfied performance obligations is $67.5 million as of March 31, 2018. In our onshore facilities and transportation segment, we have certain contractual arrangements in which we receive fixed minimum payments for our obligation to provide minimum capacity on our pipelines and related assets. These fixed minimum billings totaling $202.7 million will be recognized over their remaining contract period as shown below. The following chart depicts how we expect to recognize revenues for future periods related to these contracts: Offshore Pipeline Transportation Marine Transportation Onshore Facilities and Transportation Remainder of 2018 $ 63,672 $ 20,350 $ 49,773 2019 73,918 27,010 66,267 2020 50,883 20,128 60,689 2021 34,261 — 21,714 2022 22,558 — 4,283 Thereafter 134,623 — — Total $ 379,915 $ 67,488 $ 202,726

Acquisition

Acquisition	3 Months Ended
	Mar. 31, 2018
Business Combinations [Abstract]
Acquisition	Acquisition Acquisition Alkali Business On September 1, 2017 , we acquired our Alkali Business for approximately $1.325 billion (inclusive of approximately $105 million in working capital). Our Alkali Business produces natural soda ash, also known as sodium carbonate (Na2CO3), a basic building block for a number of ubiquitous products, including flat glass, container glass, dry detergent and a variety of chemicals and other industrial products. To finance that transaction and the related costs, we used proceeds from (i) a $550.0 million public offering of 6.50% senior unsecured notes due 2025 in August 2017, generating net proceeds of $540.1 million after issuance discount and underwriting fees, (ii) a $750 million private placement of our preferred units in September 2017, generating net proceeds of $726.2 million , (iii) borrowings under our revolving credit facility and (iv) cash on hand. We have reflected the financial results of our Alkali Business in our sodium minerals and sulfur services segment from the date of acquisition. The purchase price has been allocated to the assets acquired and liabilities assumed based on estimated preliminary fair values. Those preliminary fair values were developed by management with the assistance of a third-party valuation firm and we do not expect any material adjustments to these preliminary purchase allocations. We expect to finalize the purchase price allocation for this transaction during the first half of 2018. Our preliminary purchase price allocation remains unchanged from what was disclosed in our Annual Report on Form 10-K for the year ended December 31, 2017. Our Consolidated Financial Statements include the results of our Alkali Business since September 1, 2017 , the closing date of the acquisition. The following table presents selected financial information included in our Consolidated Financial Statements for the periods presented: Three Months Ended March 31, 2018 Revenues 208,549 Net income 31,740 The table below presents selected unaudited pro forma financial information incorporating the historical results of our Alkali Business. The pro forma financial information below has been prepared as if the acquisition had been completed on January 1, 2017 and is based upon assumptions deemed appropriate by us and may not be indicative of actual results. This pro forma information was prepared using historical financial data of the Tronox trona and trona-based exploring, mining, processing, producing, marketing and selling business and reflects certain estimates and assumptions made by our management. Our unaudited pro forma financial information is not necessarily indicative of what our consolidated financial results would have been had our Alkali Business acquisition been completed on January 1, 2017 . Pro forma net income includes the effects of distributions on our preferred units and interest expense on incremental borrowings. The dilutive effect of our preferred units is calculated using the if-converted method. Three Months Ended 2017 Pro forma consolidated financial operating results: Revenues $ 606,100 Net Income Attributable to Genesis Energy, L.P. 36,490 Net Income Available to Common Unitholders 20,083 Basic and diluted earnings per common unit: As reported net income per common unit $ 0.23 Pro forma net income per common unit $ 0.17

Inventories

Inventories	3 Months Ended
	Mar. 31, 2018
Inventory Disclosure [Abstract]
Inventories	Inventories The major components of inventories were as follows: March 31, December 31, Petroleum products $ 20,048 $ 8,731 Crude oil 25,133 29,873 Caustic soda 5,016 5,755 NaHS 9,655 8,277 Raw materials - Alkali operations 4,648 4,550 Work-in-process - Alkali operations 9,747 7,355 Finished goods, net - Alkali operations 10,914 14,075 Materials and supplies, net - Alkali operations 10,498 10,030 Other 8 7 Total $ 95,667 $ 88,653 Inventories are valued at the lower of cost or net realizable value. The net realizable value of inventories were not below cost as of March 31, 2018 and December 31, 2017 .

Fixed Assets and Mineral Leaseh

Fixed Assets and Mineral Leaseholds	3 Months Ended
	Mar. 31, 2018
Fixed Assets And Asset Retirement Obligations [Abstract]
Fixed Assets and Mineral Leaseholds	Fixed Assets and Mineral Leaseholds Fixed Assets Fixed assets consisted of the following: March 31, December 31, Crude oil pipelines and natural gas pipelines and related assets $ 3,081,841 $ 3,028,657 Alkali facilities, machinery, and equipment 499,539 497,601 Onshore facilities, machinery, and equipment 725,217 692,364 Transportation equipment 21,468 21,483 Marine vessels 934,315 918,953 Land, buildings and improvements 224,055 223,186 Office equipment, furniture and fixtures 18,162 18,112 Construction in progress 96,800 151,768 Other 51,483 48,891 Fixed assets, at cost 5,652,880 5,601,015 Less: Accumulated depreciation (802,261 ) (734,986 ) Net fixed assets $ 4,850,619 $ 4,866,029 Mineral Leaseholds Our Mineral Leaseholds, as relating to our recently acquired Alkali Business, consist of the following: March 31, December 31, Mineral leaseholds 566,019 566,019 Less: Accumulated depletion (2,650 ) (1,513 ) Mineral leaseholds, net $ 563,369 $ 564,506 Our depreciation and depletion expense for the periods presented was as follows: Three Months Ended 2018 2017 Depreciation expense $ 68,428 $ 49,924 Depletion expense 1,137 — Asset Retirement Obligations We record AROs in connection with legal requirements to perform specified retirement activities under contractual arrangements and/or governmental regulations. The following table presents information regarding our AROs since December 31, 2017 : ARO liability balance, December 31, 2017 $ 198,187 Accretion expense 2,718 Change in estimate 1,163 Settlements (2,836 ) ARO liability balance, March 31, 2018 $ 199,232 Of the ARO balances disclosed above, $11.8 million and $20.9 million is included as current in "Accrued liabilities" on our Unaudited Condensed Consolidated Balance Sheet as of March 31, 2018 and December 31, 2017 , respectively. The remainder of the ARO liability as of March 31, 2018 and December 31, 2017 is included in "Other long-term liabilities" on our Unaudited Condensed Consolidated Balance Sheet. With respect to our AROs, the following table presents our forecast of accretion expense for the periods indicated: Remainder of 2018 $ 8,264 2019 $ 9,908 2020 $ 8,743 2021 $ 9,337 2022 $ 9,972 Certain of our unconsolidated affiliates have AROs recorded at March 31, 2018 relating to contractual agreements and regulatory requirements. These amounts are immaterial to our Consolidated Financial Statements.

Equity Investees

Equity Investees	3 Months Ended
	Mar. 31, 2018
Equity Method Investments and Joint Ventures [Abstract]
Equity Investees	Equity Investees We account for our ownership in our joint ventures under the equity method of accounting. The price we pay to acquire an ownership interest in a company may exceed or be less than 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 March 31, 2018 and December 31, 2017 , the unamortized excess cost amounts totaled $378.4 million and $382.4 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 Unaudited Condensed Consolidated Financial Statements related to our equity investees. Three Months Ended 2018 2017 Genesis’ share of operating earnings $ 14,514 $ 15,277 Amortization of excess purchase price (3,942 ) (3,942 ) Net equity in earnings $ 10,572 $ 11,335 Distributions received $ 19,629 $ 20,625 The following tables present the unaudited balance sheet and income statement information (on a 100% basis) for Poseidon Oil Pipeline Company (which is our most significant equity investment): March 31, December 31, BALANCE SHEET DATA: Assets Current assets $ 13,626 $ 18,711 Fixed assets, net 213,472 217,343 Other assets 1,123 1,203 Total assets $ 228,221 $ 237,257 Liabilities and equity Current liabilities $ 17,846 $ 17,560 Other liabilities 235,834 237,434 Equity (25,459 ) (17,737 ) Total liabilities and equity $ 228,221 $ 237,257 Three Months Ended 2018 2017 INCOME STATEMENT DATA: Revenues $ 28,944 $ 28,905 Operating income $ 20,347 $ 20,787 Net income $ 18,578 $ 19,435 Poseidon's revolving credit facility Borrowings under Poseidon’s revolving credit facility, which was amended and restated in February 2015, are primarily used to fund spending on capital projects. The February 2015 credit facility is non-recourse to Poseidon’s owners and secured by substantially all of Poseidon's assets. The February 2015 credit facility contains customary covenants such as restrictions on debt levels, liens, guarantees, mergers, sale of assets and distributions to owners. A breach of any of these covenants could result in acceleration of the maturity date of Poseidon’s debt. Poseidon was in compliance with the terms of its credit agreement for all periods presented in these Unaudited Condensed Consolidated Financial Statements.

Intangible Assets

Intangible Assets	3 Months Ended
	Mar. 31, 2018
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Intangible Assets	Intangible Assets The following table summarizes the components of our intangible assets at the dates indicated: March 31, 2018 December 31, 2017 Gross Carrying Amount Accumulated Amortization Carrying Value Gross Carrying Amount Accumulated Amortization Carrying Value Sodium minerals and sulfur services: Customer relationships $ 94,654 $ 93,033 $ 1,621 $ 94,654 $ 92,493 $ 2,161 Licensing agreements 38,678 37,066 1,612 38,678 36,528 2,150 Non-compete agreement 800 156 644 800 89 711 Segment total 134,132 130,255 3,877 134,132 129,110 5,022 Onshore Facilities & Transportation: Customer relationships 35,430 35,093 337 35,430 35,082 348 Intangibles associated with lease 13,260 5,051 8,209 13,260 4,933 8,327 Segment total 48,690 40,144 8,546 48,690 40,015 8,675 Marine contract intangibles 27,000 13,050 13,950 27,000 11,700 15,300 Offshore pipeline contract intangibles 158,101 22,190 135,911 158,101 20,109 137,992 Other 30,684 14,213 16,471 28,900 13,483 15,417 Total $ 398,607 $ 219,852 $ 178,755 $ 396,823 $ 214,417 $ 182,406 Our amortization of intangible assets for the periods presented was as follows: Three Months Ended 2018 2017 Amortization of intangible assets $ 5,433 $ 5,872 We estimate that our amortization expense for the next five years will be as follows: Remainder of 2018 $ 16,475 2019 $ 16,914 2020 $ 16,661 2021 $ 11,080 2022 $ 10,695

Debt

Debt	3 Months Ended
	Mar. 31, 2018
Debt Disclosure [Abstract]
Debt	Debt Our obligations under debt arrangements consisted of the following: March 31, 2018 December 31, 2017 Principal Unamortized Discount and Debt Issuance Costs (1) Net Value Principal Unamortized Discount and Debt Issuance Costs (1) Net Value Senior secured credit facility $ 1,279,000 $ — $ 1,279,000 $ 1,099,200 $ — $ 1,099,200 5.750% senior unsecured notes due February 2021 — — — 145,170 1,303 143,867 6.750% senior unsecured notes due August 2022 750,000 15,257 734,743 750,000 16,077 733,923 6.000% senior unsecured notes due May 2023 400,000 5,424 394,576 400,000 5,691 394,309 5.625% senior unsecured notes due June 2024 350,000 5,493 344,507 350,000 5,717 344,283 6.500% senior unsecured notes due October 2025 550,000 9,157 540,843 550,000 9,462 540,538 6.250% senior unsecured notes due May 2026 450,000 7,920 442,080 450,000 8,002 441,998 Total long-term debt $ 3,779,000 $ 43,251 $ 3,735,749 $ 3,744,370 $ 46,252 $ 3,698,118 (1) Unamortized debt issuance costs associated with our senior secured credit facility (included in Other Long Term Assets on the Unaudited Condensed Consolidated Balance Sheet) were $13.1 million and $14.1 million as of March 31, 2018 and December 31, 2017, respectively. As of March 31, 2018 , we were in compliance with the financial covenants contained in our credit agreement and senior unsecured notes indentures. Senior Secured Credit Facility The key terms for rates under our $1.7 billion senior secured credit facility, which are dependent on our leverage ratio (as defined in the credit agreement), are as follows: • The applicable margin varies from 1.50% to 3.00% on Eurodollar borrowings and from 0.50% to 2.00% on alternate base rate borrowings. • Letter of credit fees range from 1.50% to 3.00% • The commitment fee on the unused committed amount will range from 0.25% to 0.50% . • The accordion feature is $300.0 million , giving us the ability to expand the size of the facility to up to $2.0 billion for acquisitions or growth projects, subject to lender consent. At March 31, 2018 , we had $1.3 billion borrowed under our $1.7 billion credit facility, with $40.5 million of the borrowed amount designated as a loan under the inventory sublimit. Our credit agreement allows up to $100.0 million of the capacity to be used for letters of credit, of which $1.2 million was outstanding at March 31, 2018 . 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. The total amount available for borrowings under our credit facility at March 31, 2018 was $419.8 million . Senior Unsecured Note Issuances, Redemption, and Extinguishment On December 11, 2017, we issued $450 million in aggregate principal amount of 6.25% senior unsecured notes due May 15, 2026 (the "2026 Notes"). Interest payments are due May 15 and November 15 of each year with the initial interest payment due May 15, 2018. Our 2026 Notes mature on May 15, 2026. That issuance generated proceeds of $441.8 million , net of issuance costs incurred. We used $204.8 million of the net proceeds to redeem the portion of the 5.75% senior unsecured notes due February 15, 2021 (the "2021 Notes") that were validly tendered and the remaining net proceeds to repay a portion of the borrowings outstanding under our revolving credit facility. On February 15, 2018, we redeemed our remaining 2021 Notes in full at a redemption price of 101.438% of the principal amount, plus accrued and unpaid interest up to, but not including, the redemption date. We incurred a total loss of approximately $3.3 million relating to the extinguishment of those notes (including the writeoff of the related unamortized debt issuance costs), which loss is recorded as "Other income/(expense), net" in our Consolidated Statements of Operations.

Partners' Capital, Mezzanine Eq

Partners' Capital, Mezzanine Equity and Distributions	3 Months Ended
	Mar. 31, 2018
Partners' Capital and Distributions [Abstract]
Partners' Capital, Mezzanine Equity and Distributions	Partners’ Capital, Mezzanine Capital and Distributions At March 31, 2018 , our outstanding common units consisted of 122,539,221 Class A units and 39,997 Class B units. Distributions We paid or will pay the following distributions to our common unitholders in 2017 and 2018 : Distribution For Date Paid Per Unit Amount Total Amount 2017 1 st Quarter May 15, 2017 $ 0.7200 $ 88,257 2 nd Quarter August 14, 2017 $ 0.7225 $ 88,563 3 rd Quarter November 14, 2017 $ 0.5000 $ 61,290 4 th Quarter February 14, 2018 $ 0.5100 $ 62,515 2018 1 st Quarter May 15, 2018 (1) $ 0.5200 $ 63,741 (1) This distribution will be paid to unitholders of record as of May 1, 2018 . Class A Convertible Preferred Units On September 1, 2017, we sold $750 million of our preferred units in a private placement, comprised of 22,249,494 units for a cash purchase price per unit of $33.71 (subject to certain adjustments, the “Issue Price”) to two initial purchasers. Our general partner executed an amendment to our partnership agreement in connection therewith, which, among other things, authorized and established the rights and preferences of our preferred units. Our preferred units are a new class of security that ranks senior to all of our currently outstanding classes or series of limited partner interests with respect to distribution and/or liquidation rights. Holders of our preferred units vote on an as-converted basis with holders of our common units and have certain class voting rights, including with respect to any amendment to the partnership agreement that would adversely affect the rights, preferences or privileges, or otherwise modify the terms, of those preferred units. Accounting for the Class A Convertible Preferred Units Our preferred units are considered redeemable securities under GAAP due to the existence of redemption provisions upon a deemed liquidation event that is outside our control. Therefore, we present them as temporary equity in the mezzanine section of the Consolidated Balance Sheet. We recorded our preferred units at their issuance date fair value, net of issuance costs. Because our preferred units are not currently redeemable and we do not have plans or expect any events that constitute a change of control in our partnership agreement, we present our preferred units at their initial carrying amount. However, we would be required to adjust that carrying amount if it becomes probable that we would be required to redeem our preferred units . Initial and Subsequent Measurement We initially recognized our preferred units at their issuance date fair value, net of issuance costs. We will not be required to adjust the carrying amount of our preferred units until it becomes probable that they would become redeemable. Once redemption becomes probable, we would adjust the carrying amount of our preferred units to the redemption value over a period of time comprising the date the feature first becomes probable and the date the units can first be redeemed. Preferred unit distributions are recognized on the date in which they are declared. In January 2018, we declared a $16.5 million distribution on our preferred units owned as of January 31, 2018. This distribution was paid in kind ("PIK") through the issuance of 490,252 additional preferred units. The following table shows the change in our preferred units from December 31, 2017 to March 31, 2018: As of March 31, Mezzanine Capital Balance 2018 Balance as of December 31, 2017 697,151 Distribution paid-in-kind 16,527 Allocation of Distribution paid in-kind to Preferred Distribution Rate Reset Election ( Note 16 ) (991 ) Balance as of March 31, 2018 712,687 Three months ended March 31, Number of Class A Convertible Preferred Units 2018 Balance as of December 31, 2017 22,411,728 Distribution paid-in-kind 490,252 Balance as of March 31, 2018 22,901,980 Net income attributable to common unitholders is reduced by preferred unit distributions that accumulated during the period. During 2018, net income attributable to common unitholders was reduced by $16.9 million as a result of distributions that accumulated during the period. With respect to our preferred units to be issued relating to the first quarter of 2018, we elected to make a PIK payment for the quarterly distribution, which will result in the issuance of an additional 500,976 preferred units. This PIK amount equates to a distribution of $0.7374 per preferred unit for the first quarter of 2018, or $2.9496 annualized. These distributions will be paid on May 15, 2018 to unitholders holders of record at the close of business May 1, 2018.

Net Income Per Common Unit

Net Income Per Common Unit	3 Months Ended
	Mar. 31, 2018
Net Income per Common Unit [Abstract]
Net income Per Common Unit	Net Income Per Common Unit Basic net income per common unit is computed by dividing net income, after considering income attributable to our preferred unitholders, by the weighted average number of common units outstanding. The dilutive effect of our preferred units is calculated using the if-converted method. Under the if-converted method, our preferred units are assumed to be converted at the beginning of the period (beginning with their respective issuance date), and the resulting common units are included in the denominator of the diluted net income per common unit calculation for the period being presented. Distributions declared in the period and undeclared distributions that accumulated during the period are added back to the numerator for purposes of the if-converted calculation. For the three months ended March 31, 2018 , the effect of the assumed conversion of the 22,901,980 preferred units was anti-dilutive and was not included in the computation of diluted earnings per unit. The following table reconciles net income and weighted average units used in computing basic and diluted net income per common unit (in thousands, except per unit amounts): Three Months Ended 2018 2017 Net Income Attributable to Genesis Energy L.P. $ 8,034 $ 27,090 Less: Accumulated distributions attributable to Class A Convertible Preferred Units (16,888 ) — Net Income (loss) Available to Common Unitholders $ (8,854 ) $ 27,090 Weighted Average Outstanding Units 122,579 118,388 Basic and Diluted Net Income (loss) per Common Unit $ (0.07 ) $ 0.23

Business Segment Information

Business Segment Information	3 Months Ended
	Mar. 31, 2018
Segment Reporting [Abstract]
Business Segment Information	Business Segment Information We currently manage our businesses through four divisions that constitute our reportable segments: • Offshore pipeline transportation – offshore transportation of crude oil and natural gas in the Gulf of Mexico; • Sodium minerals and sulfur services – trona and trona-based exploring, mining, processing, producing, marketing and selling activities, as well as processing high sulfur (or “sour”) gas streams for refineries to remove the sulfur, and selling the related by-product, NaHS; • Onshore facilities and transportation – terminalling, blending, storing, marketing and transporting crude oil, petroleum products (primarily fuel oil, asphalt, and other heavy refined products) and CO 2 ;and • Marine transportation – marine transportation to provide waterborne transportation of petroleum products and crude oil throughout North America. 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 gains and charges, such as depreciation, depletion 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 the periods presented below was as follows: Offshore Pipeline Transportation Sodium Minerals & Sulfur Services Onshore Facilities & Transportation Marine Transportation Total Three Months Ended March 31, 2018 Segment Margin (a) $ 73,173 $ 64,391 $ 21,689 $ 10,987 $ 170,240 Capital expenditures (b) $ 654 $ 9,699 $ 23,289 $ 10,865 44,507 Revenues: External customers $ 73,260 $ 287,403 $ 320,215 $ 44,930 725,808 Intersegment (c) — (1,493 ) (2,506 ) 3,999 — Total revenues of reportable segments $ 73,260 $ 285,910 $ 317,709 $ 48,929 $ 725,808 Three Months Ended March 31, 2017 Segment Margin (a) $ 87,089 $ 17,496 $ 21,097 $ 12,963 $ 138,645 Capital expenditures (b) $ 2,239 $ 513 $ 46,702 $ 9,533 58,987 Revenues: External customers $ 85,405 $ 47,271 $ 234,611 $ 48,204 415,491 Intersegment (c) (277 ) (2,225 ) 404 2,098 — Total revenues of reportable segments $ 85,128 $ 45,046 $ 235,015 $ 50,302 $ 415,491 Total assets by reportable segment were as follows: March 31, December 31, Offshore pipeline transportation $ 2,472,742 $ 2,486,803 Sodium minerals and sulfur services 1,842,607 1,848,188 Onshore facilities and transportation 1,916,102 1,927,976 Marine transportation 819,057 824,777 Other assets 59,328 49,737 Total consolidated assets 7,109,836 7,137,481 (a) A reconciliation of total Segment Margin to net income attributable to Genesis Energy, L.P. for the periods is presented below. (b) Capital expenditures include maintenance and growth capital expenditures, such as fixed asset additions (including enhancements to existing facilities and construction of growth projects) as well as acquisitions of businesses and contributions to equity investees related to same. (c) Intersegment sales were conducted under terms that we believe were no more or less favorable than then-existing market conditions. Reconciliation of total Segment Margin to net income: Three Months Ended 2018 2017 Total Segment Margin $ 170,240 $ 138,645 Corporate general and administrative expenses (10,460 ) (8,327 ) Depreciation, depletion, amortization and accretion (78,008 ) (58,395 ) Interest expense (56,136 ) (36,739 ) Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1) (9,057 ) (9,290 ) Non-cash items not included in Segment Margin (6,137 ) 437 Cash payments from direct financing leases in excess of earnings (1,839 ) (1,667 ) Loss on extinguishment of debt (3,339 ) — Differences in timing of cash receipts for certain contractual arrangements (2) 3,331 2,681 Non-cash provision for leased items no longer in use (186 ) — Income tax expense (375 ) (255 ) Net income attributable to Genesis Energy, L.P. $ 8,034 $ 27,090 (1) Includes distributions attributable to the quarter and received during or promptly following such quarter. (2) Includes the difference in timing of cash receipts from customers during the period and the revenue we recognize in accordance with GAAP on our related contracts.

Transactions with Related Parti

Transactions with Related Parties	3 Months Ended
	Mar. 31, 2018
Related Party Transactions [Abstract]
Transactions with Related Parties	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: Three Months Ended 2018 2017 Revenues: Sales of CO 2 to Sandhill Group, LLC (1) $ 543 $ 677 Revenues from services and fees to Poseidon Oil Pipeline Company, LLC (2) 3,200 3,022 Revenues from product sales to ANSAC 90,796 — Costs and expenses: Amounts paid to our CEO in connection with the use of his aircraft $ 165 $ 165 Charges for services from Poseidon Oil Pipeline Company, LLC (2) 249 241 Charges for services from ANSAC 1,778 — (1) We own a 50% interest in Sandhill Group, LLC. (2) We own 64% interest in Poseidon Oil Pipeline Company, LLC. 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. Poseidon At March 31, 2018 and December 31, 2017 Poseidon Oil Pipeline Company, LLC owed us $1.8 million and $2.2 million , respectively, for services rendered. We are the operator of Poseidon and provide management, administrative and pipeline operator services to Poseidon under an Operation and Management Agreement . Currently, that agreement renews automatically annually unless terminated by either party (as defined in the agreement). Our revenues for the three months ended March 31, 2018 reflect $2.2 million of fees we earned through the provision of services under that agreement. ANSAC We (through a subsidiary of our Alkali Business) are a member of the American Natural Soda Ash Corp. (ANSAC), an organization whose purpose is promoting and increasing the use and sale of natural soda ash and other refined or processed sodium products produced in the U.S. and consumed in specified countries outside of the U.S. Members sell products to ANSAC to satisfy ANSAC’s sales commitments to its customers. ANSAC passes its costs through to its members using a pro rata calculation based on sales. Those costs include sales and marketing, employees, office supplies, professional fees, travel, rent, and certain other costs. Those transactions do not necessarily represent arm's length transactions and may not represent all costs we would otherwise incur if we operated our Alkali Business on a stand-alone basis. We also benefit from favorable shipping rates for our direct exports when using ANSAC to arrange for ocean transport. Net sales to ANSAC were $90.8 million during the period ended March 31, 2018 . The costs charged to us by ANSAC, included in operating costs, were $1.8 million during the peri od ended March 31, 2018 . Receivables from ANSAC as of March 31, 2018 and December 31, 2017 are as follows: March 31, December 31, 2018 2017 Receivables: ANSAC $ 71,276 $ 74,490 Payables: ANSAC $ 1,970 $ 1,223 ANSAC is considered a variable interest entity (VIE) because we experience certain risks and rewards from our relationship with it. Because we do not exercise control over ANSAC and are not considered its primary beneficiary, we do not consolidate ANSAC.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	3 Months Ended
	Mar. 31, 2018
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information The following table provides information regarding the net changes in components of operating assets and liabilities. Three Months Ended 2018 2017 (Increase) decrease in: Accounts receivable $ 27,368 $ 9,169 Inventories (4,469 ) 6,009 Deferred charges (4,161 ) (348 ) Other current assets (7,694 ) (4,605 ) Increase (decrease) in: Accounts payable 94 (17,305 ) Accrued liabilities (14,920 ) (21,988 ) Net changes in components of operating assets and liabilities (3,782 ) (29,068 ) Payments of interest and commitment fees were $43.0 million and $46.7 million for the three months ended March 31, 2018 and March 31, 2017 , respectively. We capitalized interest of $1.4 million and $6.0 million during the three months ended March 31, 2018 and March 31, 2017 . At March 31, 2018 and March 31, 2017 , we had incurred liabilities for fixed and intangible asset additions totaling $20.6 million and $31.6 million , respectively, that had not been paid at the end of the quarter, and, therefore, were not included in the caption “Payments to acquire fixed and intangible assets” under Cash Flows from Investing Activities in the Unaudited Condensed Consolidated Statements of Cash Flows.

Derivatives

Derivatives	3 Months Ended
	Mar. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	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. We have designated certain crude oil futures contracts as hedges of crude oil inventory due to our expectation that these contracts will be highly effective in hedging our exposure to fluctuations in crude oil prices during the period that we expect to hold that inventory. We account for these derivative instruments as fair value hedges under the accounting guidance. Changes in the fair value of these derivative instruments designated as fair value hedges are used to offset related changes in the fair value of the hedged crude oil inventory. Any hedge ineffectiveness in these fair value hedges and any amounts excluded from effectiveness testing are recorded as a gain or loss in the Unaudited Consolidated Statements of Operations. 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 Unaudited Consolidated Balance Sheets. Additionally, in 2018 we have entered into swap arrangements. Our Alkali Business relies on natural gas to generate heat and electricity for operations. We use a combination of commodity price swap contracts and future purchase contracts to manage our exposure to fluctuations in natural gas prices. The swap contracts fix the basis differential between NYMEX Henry Hub and NW Rocky Mountain posted prices. We do not designate these contracts as hedges for accounting purposes. We recognize any changes in fair value of the derivative contracts as increases or decreases in our cost of sales. At March 31, 2018 , we had the following outstanding derivative commodity contracts that were entered into to economically hedge inventory or fixed price purchase commitments. Sell (Short) Contracts Buy (Long) Contracts Designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 bbls) 243 — Weighted average contract price per bbl $ 62.41 $ — Not qualifying or not designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 bbls) 283 145 Weighted average contract price per bbl $ 63.92 $ 64.68 Natural gas swaps: Contract volumes (10,000 MMBTU) 275 — Weighted average price differential per MMBTU $ 0.61 $ — Natural gas futures: Contract volumes (10,000 MMBTU) 35 275 Weighted average contract price per MMBTU $ 2.74 $ 2.83 Diesel futures: Contract volumes (1,000 bbls) 6 — Weighted average contract price per bbl $ 1.94 $ — NYM RBOB Gas futures: Contract volumes (42,000 gallons) 24 16 Weighted average contract price per gallon $ 1.97 $ 1.94 Fuel oil futures: Contract volumes (1,000 bbls) 397 40 Weighted average contract price per bbl $ 54.55 $ 54.03 Crude oil options: Contract volumes (1,000 bbls) 70 20 Weighted average premium received $ 1.16 $ 0.29 Financial Statement Impacts 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 March 31, 2018 and December 31, 2017 : Fair Value of Derivative Assets and Liabilities Unaudited Condensed Consolidated Balance Sheets Location Fair Value March 31, December 31, Asset Derivatives: Commodity derivatives - futures and call options (undesignated hedges): Gross amount of recognized assets Current Assets - Other $ 394 $ 505 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (394 ) (505 ) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ — Commodity derivatives - futures and call options (designated hedges): Gross amount of recognized assets Current Assets - Other $ 34 $ 54 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (34 ) (54 ) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ — Liability Derivatives: Preferred Distribution Rate Reset Election (2) Other long-term liabilities (48,106 ) (45,209 ) Natural Gas Swap (undesignated hedge) Current Liabilities - Accrued Liabilities (358 ) — Commodity derivatives - futures and call options (undesignated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (1,001 ) $ (1,203 ) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 1,001 1,203 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ — Commodity derivatives - futures and call options (designated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (646 ) $ (863 ) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 646 338 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ (525 ) (1) These derivative liabilities have been funded with margin deposits recorded in our Unaudited Condensed Consolidated Balance Sheets under Current Assets - Other. (2) Refer to Note 10 and Note 16 for additional discussion surrounding the Preferred Distribution Rate Reset Election derivative. 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 March 31, 2018 , we had a net broker receivable of approximately $1.9 million consisting of our initial margin balance of $1.9 million . As of December 31, 2017 , we had a net broker receivable of approximately $1.0 million (consisting of initial margin of $1.3 million decreased by $0.3 million of variation margin). At March 31, 2018 and December 31, 2017 , 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. Preferred Distribution Rate Reset Election A derivative feature embedded in a contract that does not meet the definition of a derivative in its entirety must be bifurcated and accounted for separately if the economic characteristics and risks of the embedded derivative are not clearly and closely related to those of the host contract. For a period of 30 days following (i) September 1, 2022 and (ii) each subsequent anniversary thereof, the holders of our preferred units may make a one-time election to reset the quarterly distribution amount (a "Rate Reset Election") to a cash amount per preferred unit equal to the amount that would be payable per quarter if a preferred unit accrued interest on the Issue Price at an annualized rate equal to three-month LIBOR plus 750 basis points ; provided, however, that such reset rate shall be equal to 10.75% if (i) such alternative rate is higher than the LIBOR-based rate and (ii) the then market price for our common units is then less than 110% of the Issue Price. The Rate Reset Election of our preferred units represents an embedded derivative that must be bifurcated from the related host contract and recorded at fair value on our Unaudited Condensed Consolidated Balance Sheet. Corresponding changes in fair value are recognized in Other Expense in our Unaudited Condensed Consolidated Statement of Operations. At March 31, 2018 , the fair value of this embedded derivative was a liability of $48.1 million . See Note 10 for additional information regarding our preferred units and the Rate Reset Election. Effect on Operating Results Amount of Gain (Loss) Recognized in Income Unaudited Condensed Consolidated Statements of Operations Location Three Months Ended 2018 2017 Commodity derivatives - futures and call options: Contracts designated as hedges under accounting guidance Onshore facilities and transportation product costs $ (1,366 ) $ 6,286 Contracts not considered hedges under accounting guidance Onshore facilities and transportation product costs, sodium minerals and sulfur services operating costs (332 ) 1,093 Total commodity derivatives $ (1,698 ) $ 7,379 Natural Gas Swap Liability Sodium minerals and sulfur services operating costs $ (275 ) $ — Preferred Distribution Rate Reset Election Other expense $ (1,906 ) $ —

Fair-Value Measurements

Fair-Value Measurements	3 Months Ended
	Mar. 31, 2018
Fair Value Disclosures [Abstract]
Fair-Value Measurements	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 March 31, 2018 and December 31, 2017 . Fair Value at Fair Value at March 31, 2018 December 31, 2017 Recurring Fair Value Measures Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Commodity derivatives: Assets $ 428 $ — $ — $ 559 $ — $ — Liabilities $ (1,647 ) $ (358 ) $ — $ (2,066 ) $ — $ — Preferred Distribution Rate Reset Election $ — $ — $ (48,106 ) $ — $ — $ (45,209 ) Rollforward of Level 3 Fair Value Measurements The following table provides a reconciliation of changes in fair value at the beginning and ending balances for our derivatives classified as level 3: Three months ended March 31, 2018 Balance as of December 31, 2017 (45,209) Net Loss for the period included in earnings (1,906) Allocation of Distribution Paid-in-kind (991) Balance as of March 31, 2018 (48,106) 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. The fair value of the swaps contracts was determined using market price quotations and a pricing model. The swap contracts were considered a level 2 input in the fair value hierarchy at March 31, 2018 . The fair value of the embedded derivative feature is based on a valuation model that estimates the fair value of our preferred units with and without a Rate Reset Election. This model contains inputs, including our common unit price, a ten year history of the dividend yield, default probabilities and timing estimates which involve management judgment. A significant increase or decrease in the value of these inputs could result in a material change in fair value to this embedded derivative feature. We report unrealized gains and losses associated with this embedded derivative in our Unaudited Condensed Consolidated Statements of Operations as Other income (expense), net. See Note 15 for additional information on our derivative instruments. 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 March 31, 2018 our senior unsecured notes had a carrying value and fair value of $2.5 billion compared to $2.6 billion and $2.7 billion , respectively, at December 31, 2017 . 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	3 Months Ended
	Mar. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies We are subject to various environmental laws and regulations. Policies and procedures are in place to aid in monitoring compliance and detecting and addressing releases of crude oil from our pipelines or other facilities and from our mining operations relating to our Alkali Business; however, no assurance can be made that such environmental releases may not substantially affect our business. 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. In the second quarter of 2017, we recorded a non-cash provision of $12.6 million (included within Onshore facilities and transportation operating costs in our Unaudited Condensed Consolidated Statements of Operations during that period) relating to certain leased railcars no longer in use. As of March 31, 2018, our remaining provision is $9.3 million , of which $3.9 million is recorded as current and included in accrued liabilities in our Unaudited Condensed Consolidated Balance Sheet, with the remainder included in other long-term liabilities.

Condensed Consolidating Financi

Condensed Consolidating Financial Information	3 Months Ended
	Mar. 31, 2018
Condensed Consolidating Financial Information [Abstract]
Condensed Consolidating Financial Information	Condensed Consolidating Financial Information Our $2.5 billion 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 9 for additional information regarding our consolidated debt obligations. The following is condensed consolidating financial information for Genesis Energy, L.P., the guarantor subsidiaries and the non-guarantor subsidiaries. Unaudited Condensed Consolidating Balance Sheet March 31, 2018 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 $ 6 $ — $ 14,677 $ 1,409 $ — $ 16,092 Other current assets 25 — 551,885 12,137 (45 ) 564,002 Total current assets 31 — 566,562 13,546 (45 ) 580,094 Fixed assets, at cost — — 5,575,295 77,585 — 5,652,880 Less: Accumulated depreciation — — (774,919 ) (27,342 ) — (802,261 ) Net fixed assets — — 4,800,376 50,243 — 4,850,619 Mineral Leaseholds — — 563,369 — — 563,369 Goodwill — — 325,046 — — 325,046 Other assets, net 13,083 — 438,693 124,242 (157,803 ) 418,215 Advances to affiliates 3,799,305 — — 89,334 (3,888,639 ) — Equity investees — — 372,493 — — 372,493 Investments in subsidiaries 2,693,391 — 83,624 — (2,777,015 ) — Total assets $ 6,505,810 $ — $ 7,150,163 $ 277,365 $ (6,823,502 ) $ 7,109,836 LIABILITIES AND CAPITAL Current liabilities $ 57,677 $ — $ 348,421 $ 10,137 $ (545 ) $ 415,690 Senior secured credit facility 1,279,000 — — — — 1,279,000 Senior unsecured notes 2,456,749 — — — — 2,456,749 Deferred tax liabilities — — 12,138 — — 12,138 Advances from affiliates — — 3,888,239 — (3,888,239 ) — Other liabilities 48,107 — 214,494 185,456 (157,656 ) 290,401 Total liabilities 3,841,533 — 4,463,292 195,593 (4,046,440 ) 4,453,978 Mezzanine Capital: Class A Convertible Preferred Units 712,687 — — — — 712,687 Partners’ capital, common units 1,951,590 — 2,687,475 89,587 (2,777,062 ) 1,951,590 Accumulated other comprehensive loss (1) — — (604 ) — — (604 ) Noncontrolling interests — — — (7,815 ) — (7,815 ) Total liabilities, mezzanine capital and partners’ capital $ 6,505,810 $ — $ 7,150,163 $ 277,365 $ (6,823,502 ) $ 7,109,836 (1) The entire balance and activity within Accumulated Other Comprehensive Income is related to our pension held within our Guarantor Subsidiaries. Unaudited Condensed Consolidating Balance Sheet December 31, 2017 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 $ 6 $ — $ 8,340 $ 695 $ — $ 9,041 Other current assets 50 — 614,682 12,316 (56 ) 626,992 Total current assets 56 — 623,022 13,011 (56 ) 636,033 Fixed assets, at cost — — 5,523,431 77,584 — 5,601,015 Less: Accumulated depreciation — — (708,269 ) (26,717 ) — (734,986 ) Net fixed assets — — 4,815,162 50,867 — 4,866,029 Mineral Leaseholds — — 564,506 — — 564,506 Goodwill — — 325,046 — — 325,046 Other assets, net 14,083 — 378,371 126,300 (154,437 ) 364,317 Advances to affiliates 3,808,712 — — 85,423 (3,894,135 ) — Equity investees and other investments — — 381,550 — — 381,550 Investments in subsidiaries 2,689,861 — 82,616 — (2,772,477 ) — Total assets $ 6,512,712 $ — $ 7,170,273 $ 275,601 $ (6,821,105 ) $ 7,137,481 LIABILITIES AND CAPITAL Current liabilities $ 46,086 $ — $ 399,017 $ 11,417 $ (256 ) $ 456,264 Senior secured credit facilities 1,099,200 — — — — 1,099,200 Senior unsecured notes 2,598,918 — — — — 2,598,918 Deferred tax liabilities — — 11,913 — — 11,913 Advances from affiliates — — 3,894,027 — (3,894,027 ) — Other liabilities 45,210 — 182,414 183,237 (154,290 ) 256,571 Total liabilities 3,789,414 — 4,487,371 194,654 (4,048,573 ) 4,422,866 Mezzanine Capital: Class A Convertible Preferred Units 697,151 — — — — 697,151 Partners’ capital, common units 2,026,147 — 2,683,506 89,026 (2,772,532 ) 2,026,147 Accumulated other comprehensive loss (1) — — (604 ) — — (604 ) Noncontrolling interests — — — (8,079 ) — (8,079 ) Total liabilities, mezzanine capital and partners’ capital $ 6,512,712 $ — $ 7,170,273 $ 275,601 $ (6,821,105 ) $ 7,137,481 (1) The entire balance and activity within Accumulated Other Comprehensive Income is related to our pension held within our Guarantor Subsidiaries. Unaudited Condensed Consolidating Statement of Operations Three Months Ended March 31, 2018 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: Offshore pipeline transportation services $ — $ — $ 73,260 $ — $ — $ 73,260 Sodium minerals and sulfur services — — 285,097 3,066 (2,253 ) 285,910 Marine transportation — — 48,929 — — 48,929 Onshore facilities and transportation — — 312,874 4,835 — 317,709 Total revenues — — 720,160 7,901 (2,253 ) 725,808 COSTS AND EXPENSES: Onshore facilities and transportation costs — — 299,841 272 — 300,113 Marine transportation costs — — 37,847 — — 37,847 Sodium minerals and sulfur services operating costs — — 223,247 2,504 (2,253 ) 223,498 Offshore pipeline transportation operating costs — — 17,662 678 — 18,340 General and administrative — — 11,674 — — 11,674 Depreciation, depletion and amortization — — 74,630 625 — 75,255 Total costs and expenses — — 664,901 4,079 (2,253 ) 666,727 OPERATING INCOME — — 55,259 3,822 — 59,081 Equity in earnings of subsidiaries 69,592 — 632 — (70,224 ) — Equity in earnings of equity investees — — 10,572 — — 10,572 Interest (expense) income, net (56,314 ) — 3,544 (3,366 ) — (56,136 ) Other expense (5,244 ) — — — — (5,244 ) Income before income taxes 8,034 — 70,007 456 (70,224 ) 8,273 Income tax expense — — (377 ) 2 — (375 ) NET INCOME 8,034 — 69,630 458 (70,224 ) 7,898 Net loss attributable to noncontrolling interest — — — 136 — 136 NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P. $ 8,034 $ — $ 69,630 $ 594 $ (70,224 ) $ 8,034 Less: Accumulated distributions attributable to Class A Convertible Preferred Units (16,888 ) — — — — $ (16,888 ) NET INCOME(LOSS) AVAILABLE TO COMMON UNIT HOLDERS $ (8,854 ) $ — $ 69,630 $ 594 $ (70,224 ) $ (8,854 ) Unaudited Condensed Consolidating Statement of Operations Three Months Ended March 31, 2017 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: Offshore pipeline transportation services $ — $ — $ 85,128 $ — $ 85,128 Sodium minerals and sulfur services — — 45,034 1,810 (1,798 ) 45,046 Marine transportation — — 50,302 — — 50,302 Onshore facilities and transportation — — 230,070 4,945 — 235,015 Total revenues — — 410,534 6,755 (1,798 ) 415,491 COSTS AND EXPENSES: Onshore facilities and transportation costs — — 214,071 261 — 214,332 Marine transportation costs — — 37,242 — — 37,242 Sodium minerals and sulfur services operating costs — — 27,153 2,009 (1,798 ) 27,364 Offshore pipeline transportation operating costs — — 17,106 762 — 17,868 General and administrative — — 9,976 — — 9,976 Depreciation, depletion and amortization — — 55,487 625 — 56,112 Total costs and expenses — — 361,035 3,657 (1,798 ) 362,894 OPERATING INCOME — — 49,499 3,098 — 52,597 Equity in earnings of subsidiaries 63,809 — (250 ) — (63,559 ) — Equity in earnings of equity investees — — 11,335 — — 11,335 Interest (expense) income, net (36,719 ) — 3,520 (3,540 ) — (36,739 ) Income before income taxes 27,090 — 64,104 (442 ) (63,559 ) 27,193 Income tax (expense) benefit — — (255 ) — — (255 ) NET INCOME 27,090 — 63,849 (442 ) (63,559 ) 26,938 Net loss attributable to noncontrolling interest — — — 152 — 152 NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P. $ 27,090 $ — $ 63,849 $ (290 ) $ (63,559 ) $ 27,090 Less: Accumulated distributions attributable to Class A Convertible Preferred Units — — — — — — NET INCOME AVAILABLE TO COMMON UNIT HOLDERS $ 27,090 $ — $ 63,849 $ (290 ) $ (63,559 ) $ 27,090 Unaudited Condensed Consolidating Statement of Cash Flows Three Months Ended March 31, 2018 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 provided by operating activities $ 18,637 $ — $ 124,180 $ 874 $ (57,363 ) $ 86,328 CASH FLOWS FROM INVESTING ACTIVITIES: Payments to acquire fixed and intangible assets — — (66,051 ) — — (66,051 ) Cash distributions received from equity investees - return of investment — — 9,277 — — 9,277 Acquisitions — — — — — — Intercompany transfers 9,407 — — — (9,407 ) — Repayments on loan to non-guarantor subsidiary — — 1,801 — (1,801 ) — Contributions in aid of construction costs — — — — — — Proceeds from asset sales — — 6 — — 6 Other, net — — — — — — Net cash used in investing activities 9,407 — (54,967 ) — (11,208 ) (56,768 ) CASH FLOWS FROM FINANCING ACTIVITIES: Borrowings on senior secured credit facility 333,800 — — — — 333,800 Repayments on senior secured credit facility (154,000 ) — — — — (154,000 ) Proceeds from issuance of senior unsecured notes — — — — — — Repayment of senior unsecured notes (145,170 ) — — — — (145,170 ) Proceeds from issuance of Class A convertible preferred units, net — — — — — — Debt issuance costs (159 ) — — — — (159 ) Intercompany transfers — — (5,496 ) (3,911 ) 9,407 — Issuance of common units for cash, net — — — — — — Distributions to common unitholders (62,515 ) — (62,515 ) — 62,515 (62,515 ) Contributions from noncontrolling interest — — — 400 — 400 Other, net — — 5,135 3,351 (3,351 ) 5,135 Net cash used in financing activities (28,044 ) — (62,876 ) (160 ) 68,571 (22,509 ) Net increase in cash and cash equivalents — — 6,337 714 — 7,051 Cash and cash equivalents at beginning of period 6 — 8,340 695 — 9,041 Cash and cash equivalents at end of period $ 6 $ — $ 14,677 $ 1,409 $ — $ 16,092 Unaudited Condensed Consolidating Statement of Cash Flows Three Months Ended March 31, 2017 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 provided by operating activities $ 42,623 $ — $ 95,023 $ 2,007 $ (78,613 ) $ 61,040 CASH FLOWS FROM INVESTING ACTIVITIES: Payments to acquire fixed and intangible assets — — (61,292 ) — — (61,292 ) Cash distributions received from equity investees - return of investment — — 9,083 — — 9,083 Investments in equity investees (140,968 ) — — — 140,968 — Acquisitions — — — — — — Intercompany transfers 109,342 — — — (109,342 ) — Repayments on loan to non-guarantor subsidiary — — 1,627 — (1,627 ) — Contributions in aid of construction costs — — 124 — — 124 Proceeds from asset sales — — 1,234 — — 1,234 Other, net — — — — — — Net cash used in investing activities (31,626 ) — (49,224 ) — 29,999 (50,851 ) CASH FLOWS FROM FINANCING ACTIVITIES: Borrowings on senior secured credit facility 216,700 — — — — 216,700 Repayments on senior secured credit facility (284,900 ) — — — — (284,900 ) Debt issuance costs — — — — — — Intercompany transfers — — (104,276 ) (5,066 ) 109,342 — Issuance of common units for cash, net 140,968 — 140,968 — (140,968 ) 140,968 Distributions to common unitholders (83,765 ) — (83,765 ) — 83,765 (83,765 ) Distributions to noncontrolling interest — — — — — — Other, net — — 4,552 3,525 (3,525 ) 4,552 Net cash provided by financing activities (10,997 ) — (42,521 ) (1,541 ) 48,614 (6,445 ) Net decrease in cash and cash equivalents — — 3,278 466 — 3,744 Cash and cash equivalents at beginning of period 6 — 6,360 663 — 7,029 Cash and cash equivalents at end of period $ 6 $ — $ 9,638 $ 1,129 $ — $ 10,773

Recent Accounting Developments

Recent Accounting Developments (Policies)	3 Months Ended
	Mar. 31, 2018
Accounting Policies [Abstract]
Recent Accounting Developments	Recent Accounting Developments Recently Issued We have adopted guidance under ASC Topic 606, Revenue from Contracts with Customers, and all related ASUs (collectively "ASC 606") as of January 1, 2018 utilizing the modified retrospective method of adoption. The adoption date for our material equity method investment in the Poseidon Oil Pipeline Company, LLC will follow the non-public business entity adoption date of January 1, 2019 for its stand-alone financial statements. Refer to Note 3 for further details. In February 2016, the FASB issued guidance to improve the transparency and comparability among companies by requiring lessees to recognize a lease liability and a corresponding lease asset for virtually all lease contracts. The guidance also requires additional disclosure about leasing arrangements. The guidance is effective for interim and annual periods beginning after December 15, 2018 and requires a modified retrospective approach to adoption. Early adoption is permitted. We are currently evaluating this guidance. In August 2016, the FASB issued ASU 2016-15, Classification of Certain Cash Receipts and Cash Payments. ASU 2016-15 addresses how certain cash receipts and cash payments are presented and classified in the statement of cash flows under Topic 230, Statement of Cash flow, and other Topics. ASU 2016-15 is effective for annual reporting periods, and interim periods therein, beginning after December 15, 2017. We have adopted this guidance as of January 1, 2018 using the retrospective transition method to each period presented on the Consolidated Statements of Cash Flows. We reclassified $3.6 million from operating cash flows to investing cash flows for the three months ended March 31, 2017. In January 2017, the FASB issued guidance to simplify the goodwill impairment testing at annual or interim periods. The guidance eliminates Step 2 from the goodwill impairment testing process, and any identified impairment charge would be simplified to be the difference between the carrying value and fair value of a reporting unit, but would not exceed the total amount of goodwill allocated to the reporting unit in question. The guidance is effective for annual reporting periods, and interim periods therein, beginning after December 15, 2019, with early adoption permitted. We early adopted this guidance and it did not have an impact on our consolidated financial statements. In March 2017, the FASB issued ASU 2017-07, Compensation-Retirement Benefits (Topic 715). ASU 2017-07 requires employers to separate the service cost component from the other components of net benefit cost in the period. The new standard requires the other components of net benefit costs (excluding service costs), be reclassified to "Other expense" from "General and administrative." We adopted this standard as of January 1, 2018. This standard is applied retrospectively. The effect was not material to our financial statements.
Revenue Recognition	The effects of changes pursuant to ASC 606 in the tables above are attributable to our offshore pipeline transportation services operating segment and our sodium minerals and sulfur services operating segment. In our offshore pipeline transportation services segment, we have certain contracts with customers that contain tiered pricing structures that are dependent upon reaching certain cumulative milestones of throughput volumes on our pipelines. In addition, we have a contract that contains fixed and variable consideration for us to stand ready and provide reservation capacity for a fixed minimum quantity on our pipeline. Pursuant to the new guidance, we have allocated our estimated total transaction price over the life of the contract to the related performance obligation and recognized the effects in our Consolidated Financial Statements. In our sodium minerals and sulfur services operating segment, specifically our legacy refinery services business, we have two distinct performance obligations, including the completion of our refinery sulfur removal process, for which we receive in-kind consideration, and our sale of NaHS to our customers. Due to this, we have recorded revenue and the related cost of sales in the Consolidated Financial Statements for the three months ended March 31, 2018 (the "2018 Quarter") for services performed for the in-kind consideration for our services. Revenue Recognition Adoption of ASC 606 and its related Transition effects The modified retrospective method of adoption required us to apply the new revenue standard to all new revenue contracts entered into after January 1, 2018 and revenue contracts that were not completed as of January 1, 2018. Our consolidated revenues for periods prior to January 1, 2018 were not revised and the cumulative effect of our adoption of ASC 606 was recorded as an adjustment to partners' capital at January 1, 2018. Transaction Price Allocations to Future Performance Obligations We are required to disclose the amount of our transaction prices that are allocated to future unrecognized performance obligations as of March 31, 2018. However, ASC 606 does provide the following practical expedients and exemptions that we utilized: 1) Performance obligations are part of a contract with an expected duration of one year or less; 2) Revenue recognized from the satisfaction of performance obligations where we have a right to consideration in an amount that corresponds directly with the value provided to customers; and 3) Contracts that contain variable consideration, such as index-based pricing or variable volumes, that is allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied promise to transfer a distinct good or service that is part of a series. We apply these practical expedients and exceptions to our revenue streams recognized over time. The majority of our contracts qualify for one of these expedients or exceptions. After considering these practical expedients and identifying the remaining contract types that involve revenue recognition over a long-term period and include long-term fixed consideration (adjusted for indexing as required), we determined our allocations of transaction price that relate to unsatisfied performance obligations. As it relates to our tiered pricing offshore transportation contracts, we provide firm capacity for both fixed and variable consideration over a long term period. Therefore, we have allocated our remaining contract value (as estimated and discussed above) to future periods. As of March 31, 2018 have an estimated aggregate transaction price allocated to unsatisfied performance obligations of $379.9 million for our offshore transportation segment. Similarly, in our marine transportation segment, our contract related to our M/T American Phoenix contains minimum fixed consideration over the life of the contract, which ends in September 2020. The estimated aggregate transaction price allocated to unsatisfied performance obligations is $67.5 million as of March 31, 2018. In our onshore facilities and transportation segment, we have certain contractual arrangements in which we receive fixed minimum payments for our obligation to provide minimum capacity on our pipelines and related assets. These fixed minimum billings totaling $202.7 million will be recognized over their remaining contract period as shown below. The Company recognizes revenue upon the satisfaction of its performance obligations under its contracts. The timing of revenue recognition varies for the revenue streams described in more detail below. In general, the timing includes recognition of revenue over time as services are being performed as well as recognition of revenue at a point in time, for delivery of products. Fee-based Revenues We provide a variety of fee-based transportation and logistics services to our customers across several of our reportable segments as outlined below. Offshore Pipeline Transportation Revenue from our offshore pipelines is generally based upon a fixed fee per unit of volume (typically per Mcf of natural gas or per barrel of crude oil) gathered, transported, or processed multiplied by the volume delivered. Fees are based either on contractual arrangements or tariffs regulated by the FERC. Revenue associated with these fee-based services is recognized as volumes are delivered over the performance obligation period. In addition to the offshore pipeline transportation revenue discussed above, we also have certain contracts with customers in which we earn either demand-type fees or firm capacity reservation fees. These fees are charged to a customer regardless of the volume the customer actually delivers to the platform or through the pipeline. These contracts include a single performance obligation to stand ready, on a monthly basis, to provide capacity on our assets. In addition to these offshore pipeline transportation services revenue streams, we also have certain customer contracts in which the transportation fee has a tiered pricing structure based on cumulative milestones of throughput on the related pipeline asset and contract, or on a specified date. The performance obligation for these contracts is to transport, gather or process commodity volumes for the customer based on firm (stand ready) service or from monthly nominations made by our customers, which can also be on an interruptible basis. While our transportation rate changes when milestones are achieved for certain cumulative throughput, the performance obligation satisfied by us does not change throughout the life of the contract. Therefore revenue is recognized on an average rate basis throughout the life of the contract. We have estimated the total consideration to be received under the contract beginning at the contract inception date based on the estimated volumes (including certain minimum volumes we are required to stand ready for), price indexing, estimated production or contracted volumes, and the contract period. We have constrained the estimates of variable consideration such that it is probable that a significant reversal of previously recognized revenue will not occur throughout the life of the contract. These estimates will be reassessed at each reporting period as required. Billings to our customers are reflected at the contract rate. This variability between the consideration received from our customers from invoicing compared to the revenue recognized creates a contract asset or liability. In circumstances where the estimated average contract rate is less than the billed current price tier in the contract, we will recognize a contract liability. In circumstances where the estimated average contract rate is higher than the billed current price tier in the contract, we will recognize a contract asset. Onshore Facilities and Transportation Within our onshore facilities and transportation segment, we provide our customers with pipeline transportation, terminalling services, and rail loading/unloading services, among others, primarily on a per barrel fee basis. Revenues from contracts for the transportation of crude oil by our pipelines are based on actual volumes at a published tariff and some contain minimum throughput provisions which reset within one year. We recognize revenues for transportation and other services over the performance obligation period, which is the contract term. Revenues for both firm and interruptible transportation and other services are recognized when product is delivered to the agreed upon delivery point or at the point of receipt because they specifically relate to our efforts to transfer the distinct services. Service contracts contain a series of distinct services that are substantially the same and have the same pattern of transfer to the customer over the contract period, and therefore qualify as a single performance obligation that is satisfied over time. The customer receives and consumes the benefit of our services simultaneous with the provision of those services. Pricing for our services is determined through a variety of mechanisms, including specified contract pricing or regulated tariff pricing. Consideration to be received by us under these contracts is variable, as the volume of the commodity to be transported is unknown at contract inception. At the end of a day or month (as specified in the contract), both the price and volume are known (or “fixed”) in order to allow us to accurately calculate the amount of consideration we are entitled to invoice. The measurement of these services and invoicing occurs on a monthly basis. Pipeline Loss Allowances In order to compensate us for bearing the risk of volumetric losses of crude oil in transit in our pipelines (for our onshore and offshore pipelines) due to temperature, crude quality, and the inherent difficulties of measurement of liquids in a pipeline, our tariffs and agreements include the right for us to make volumetric deductions from the customer for quality and volumetric fluctuations. We refer to these deductions as pipeline loss allowances ("PLA"). 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. As the allowance is related to our pipeline transportation services, the performance obligation is the obligation to transport and deliver the barrels and is considered a single obligation. 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 required to replace the lost volumes. Under ASC 606, we record excess oil as non-cash consideration at the lower of the recorded value or the market value and include this amount in the transaction price. The crude oil in inventory can then be sold at current prevailing market prices, resulting in additional revenue if the sales price exceeds the inventory value when control transfers to the customer. Marine Transportation Our marine transportation business consists of revenues from the inland and offshore marine transportation of heavy refined petroleum products, asphalt and crude oil, using our barges or vessels. This revenue is recognized over the passage of time of individual trips 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 and certain other operational costs may be directly reimbursed by the customer, if stipulated in the contract. A performance obligation is driven by providing transportation services using our vessels for a single day either under a term or spot based contract. The transaction price is usually fixed per the contract either as a day rate or as a lump sum to be allocated over days required to complete the service. Revenue is recognizable as the transportation service utilizing our vessels occurs, as the customer simultaneously receives and consumes these services as they are provided. If provided in the contract, certain items such as fuel or operational costs can be rebilled to the customer in the same period in which the costs are incurred. In the event timing of a trip to provide our services crosses a reporting period under a lump sum fee contract, the revenue earned is accrued based on the progress completed in the current period on the related performance obligation as we are entitled to payment for each day. Customer invoicing occurs at the completion of a trip, or earlier at the customer’s request. Product Sales Sodium Minerals and Sulfur Services Product sales in our sodium minerals and sulfur services segment primarily involve the sales of caustic soda, NaHS, soda ash and other alkali products. As it relates to revenue recognition, these sales transactions contain a single performance obligation, which is the delivery of the product to the customer at the agreed upon point of sale. For some transactions, control of product transfers to the customer at the shipping point, but we are obligated to arrange for shipment of the product as directed by the customer. Rather than treat these shipping activities as separate performance obligations, our policy is to account for them as fulfillment costs in accordance with ASC 606. The transaction price for these product sales are determined by specific contracts, typically at a fixed rate or based on a market or indexed rate. This pricing is known, or is “fixed,” at the time of revenue recognition. Invoicing and related payment terms are in accordance with industry standard or contract specification based on final pricing. The entirety of the transaction price is allocated to the performance obligation which is delivery of the product at the agreed upon point of sale. As this type of revenue is earned at a point in time, there is no allocation of transaction price to future performance obligations. Onshore Facilities and Transportation Product sales in our onshore facilities and transportation segment primarily involve the sales of crude oil and petroleum products. These contracts contain a single performance obligation, which is the delivery of the product to the customer at a specified location. These contracts are settled on a monthly basis for term contracts, or on a spot basis. Invoicing and related payment terms are in accordance with industry standard or contract specification based on final pricing. Pricing is designated within the contracts and is either fixed, index-based or formulaic, utilizing an average price for the month or for a specified range of days, regardless of when delivery occurs. In either case, pricing is known at the time of invoicing. The entirety of the consideration is allocated to a single performance obligation which is delivery of the product to a specified location. As this type of revenue is earned at a point in time, there is no allocation of transaction price to future performance obligations. Refinery Services Our refinery services business primarily provides sulfur extraction services to refiners’ high sulfur (or “sour”) gas streams that the refineries have generated from crude oil processing operations. Our process applies our proprietary technology, which uses caustic soda to act as a scrubbing agent under prescribed temperature and pressure to remove sulfur. The technology returns a clean (sulfur-free) hydrocarbon stream to the refinery for further processing into refined products, and simultaneously produces NaHS. Units of NaHS are produced ratably as a gas stream is processed. We obtain control and ownership of the NaHS immediately upon production which constitutes the sole consideration received for our sulfur removal services. We later market this product to third parties as part of our product sales, as described above. As part of some of our arrangements, we pay a refinery access fee (“RSA fee”) for any benefits received by virtue of our plant’s proximity to the customer’s refinery. Our RSA fee is recorded as a reduction of revenue. Providing sulfur removal services is the singular performance obligation in our refinery service agreements. As our customers simultaneously receive and consume the refinery service benefits, control is transferred and revenue is recognized over time based on the extent of progress towards completion of the performance obligations. We use units of NaHS produced during a period to measure progress as the amount we receive corresponds directly with the efforts to provide our services completed to date. The transaction price for each performance obligation is determined using the fair value of a unit of NaHS on the contract inception date for each refinery services agreement. Accordingly, we record the value of NaHS received as non cash consideration in inventory until it is subsequently sold to our customers (see Product Sales, above).

Revenue Recognition (Tables)

Revenue Recognition (Tables)	3 Months Ended
	Mar. 31, 2018
Revenue Recognition [Abstract]
Schedule of Impact on Balance Sheet and Operating Income	Adoption of ASC 606 and its related Transition effects The modified retrospective method of adoption required us to apply the new revenue standard to all new revenue contracts entered into after January 1, 2018 and revenue contracts that were not completed as of January 1, 2018. Our consolidated revenues for periods prior to January 1, 2018 were not revised and the cumulative effect of our adoption of ASC 606 was recorded as an adjustment to partners' capital at January 1, 2018. Based on this application, the following adjustments were made to our consolidated balance sheet as of January 1, 2018: December 31, 2017 Adjustments January 1, 2018 ASSETS Accounts receivable- trade, net $ 495,449 $ (48,028 ) $ 447,421 Inventories 88,653 5,138 93,791 Other assets, net of amortization 56,628 59,204 115,832 LIABILITIES AND CAPITAL Other long-term liabilities 256,571 19,864 276,435 Partners' capital 2,026,147 (3,550 ) 2,022,597 The tables below summarize the impact of adoption on our unaudited condensed consolidated balance sheet and statement of operations as of and for the three months ended March 31, 2018: As of March 31, 2018 Unaudited Condensed Consolidated Balance Sheet As Reported Without adoption of ASC 606 Effect of Change Increase/(Decrease) ASSETS Accounts receivable-trade, net 419,903 472,116 (52,213 ) Inventories 95,667 92,628 3,039 Other Assets, net of amortization 116,190 51,948 64,242 LIABILITIES AND CAPITAL Other Long-Term Liabilities 290,401 268,832 21,569 Partners' Capital 1,951,590 1,958,091 (6,501 ) Three months ended March 31, 2018 Unaudited Condensed Consolidated Statement of Operations As Reported Without adoption of ASC 606 Effect of Change Increase/(Decrease) Offshore pipeline transportation services 73,260 74,111 (851 ) Sodium minerals and sulfur services 285,910 263,965 21,945 Marine transportation 48,929 48,929 — Onshore facilities and transportation 317,709 317,709 — Total revenues 725,808 704,714 21,094 Onshore facilities and transportation product costs 277,818 277,818 — Onshore facilities and transportation operating costs 22,295 22,295 — Marine transportation operating costs 37,847 37,847 — Sodium minerals and sulfur services operating costs 223,498 199,454 24,044 Offshore pipeline transportation operating costs 18,340 18,340 — OPERATING INCOME 59,081 62,032 (2,951 )
Schedule of Disaggregation of Revenue	The following table reflects the disaggregation of our revenues by major category for the three months ended March 31, 2018: Period ended March 31, 2018 Onshore Facilities & Transportation Sodium Minerals & Sulfur Services Offshore Pipeline Transportation Marine Transportation Consolidated Fee-based revenues 30,338 — 73,260 48,929 152,527 Product Sales 287,371 263,965 — — 551,336 Refinery Services — 21,945 — — 21,945 $ 317,709 $ 285,910 $ 73,260 $ 48,929 $ 725,808
Schedule of Contract Asset and Liabilities Balances Activity	The table below depicts our contract asset and liability balances and related activity from January 1, 2018 to March 31, 2018: Contract Assets Contract Liabilities Non-Current Non-Current Balance at January 1, 2018 59,204 19,864 Balance at March 31, 2018 64,240 21,570
Schedule of Revenue Expected to be Recognized in Future Periods	The following chart depicts how we expect to recognize revenues for future periods related to these contracts: Offshore Pipeline Transportation Marine Transportation Onshore Facilities and Transportation Remainder of 2018 $ 63,672 $ 20,350 $ 49,773 2019 73,918 27,010 66,267 2020 50,883 20,128 60,689 2021 34,261 — 21,714 2022 22,558 — 4,283 Thereafter 134,623 — — Total $ 379,915 $ 67,488 $ 202,726

Acquisition (Tables)

Acquisition (Tables)	3 Months Ended
	Mar. 31, 2018
Business Combinations [Abstract]
Schedule of Selected Financial Information	The following table presents selected financial information included in our Consolidated Financial Statements for the periods presented: Three Months Ended March 31, 2018 Revenues 208,549 Net income 31,740
Schedule of Pro Forma Financial Information	Our unaudited pro forma financial information is not necessarily indicative of what our consolidated financial results would have been had our Alkali Business acquisition been completed on January 1, 2017 . Pro forma net income includes the effects of distributions on our preferred units and interest expense on incremental borrowings. The dilutive effect of our preferred units is calculated using the if-converted method. Three Months Ended 2017 Pro forma consolidated financial operating results: Revenues $ 606,100 Net Income Attributable to Genesis Energy, L.P. 36,490 Net Income Available to Common Unitholders 20,083 Basic and diluted earnings per common unit: As reported net income per common unit $ 0.23 Pro forma net income per common unit $ 0.17

Inventories (Tables)

Inventories (Tables)	3 Months Ended
	Mar. 31, 2018
Inventory Disclosure [Abstract]
Schedule of Major Components of Inventories	The major components of inventories were as follows: March 31, December 31, Petroleum products $ 20,048 $ 8,731 Crude oil 25,133 29,873 Caustic soda 5,016 5,755 NaHS 9,655 8,277 Raw materials - Alkali operations 4,648 4,550 Work-in-process - Alkali operations 9,747 7,355 Finished goods, net - Alkali operations 10,914 14,075 Materials and supplies, net - Alkali operations 10,498 10,030 Other 8 7 Total $ 95,667 $ 88,653

Fixed Assets and Mineral Leas30

Fixed Assets and Mineral Leaseholds (Tables)	3 Months Ended
	Mar. 31, 2018
Fixed Assets And Asset Retirement Obligations [Abstract]
Schedule of Fixed Assets	Fixed assets consisted of the following: March 31, December 31, Crude oil pipelines and natural gas pipelines and related assets $ 3,081,841 $ 3,028,657 Alkali facilities, machinery, and equipment 499,539 497,601 Onshore facilities, machinery, and equipment 725,217 692,364 Transportation equipment 21,468 21,483 Marine vessels 934,315 918,953 Land, buildings and improvements 224,055 223,186 Office equipment, furniture and fixtures 18,162 18,112 Construction in progress 96,800 151,768 Other 51,483 48,891 Fixed assets, at cost 5,652,880 5,601,015 Less: Accumulated depreciation (802,261 ) (734,986 ) Net fixed assets $ 4,850,619 $ 4,866,029
Schedule of Mineral Leaseholds	Our Mineral Leaseholds, as relating to our recently acquired Alkali Business, consist of the following: March 31, December 31, Mineral leaseholds 566,019 566,019 Less: Accumulated depletion (2,650 ) (1,513 ) Mineral leaseholds, net $ 563,369 $ 564,506
Schedule of Depreciation and Depletion Expense	Our depreciation and depletion expense for the periods presented was as follows: Three Months Ended 2018 2017 Depreciation expense $ 68,428 $ 49,924 Depletion expense 1,137 —
Schedule of Change in Asset Retirement Obligation	The following table presents information regarding our AROs since December 31, 2017 : ARO liability balance, December 31, 2017 $ 198,187 Accretion expense 2,718 Change in estimate 1,163 Settlements (2,836 ) ARO liability balance, March 31, 2018 $ 199,232
Schedule of Forecast of Accretion Expense of Asset Retirement Obligations	With respect to our AROs, the following table presents our forecast of accretion expense for the periods indicated: Remainder of 2018 $ 8,264 2019 $ 9,908 2020 $ 8,743 2021 $ 9,337 2022 $ 9,972

Equity Investees (Tables)

Equity Investees (Tables)	3 Months Ended
	Mar. 31, 2018
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Consolidated Financial Statements Related to Equity Investees	The following table presents information included in our Unaudited Condensed Consolidated Financial Statements related to our equity investees. Three Months Ended 2018 2017 Genesis’ share of operating earnings $ 14,514 $ 15,277 Amortization of excess purchase price (3,942 ) (3,942 ) Net equity in earnings $ 10,572 $ 11,335 Distributions received $ 19,629 $ 20,625
Schedule of Balance Sheet Information for Equity Investees	The following tables present the unaudited balance sheet and income statement information (on a 100% basis) for Poseidon Oil Pipeline Company (which is our most significant equity investment): March 31, December 31, BALANCE SHEET DATA: Assets Current assets $ 13,626 $ 18,711 Fixed assets, net 213,472 217,343 Other assets 1,123 1,203 Total assets $ 228,221 $ 237,257 Liabilities and equity Current liabilities $ 17,846 $ 17,560 Other liabilities 235,834 237,434 Equity (25,459 ) (17,737 ) Total liabilities and equity $ 228,221 $ 237,257
Schedule of Operations for Equity Investees	Three Months Ended 2018 2017 INCOME STATEMENT DATA: Revenues $ 28,944 $ 28,905 Operating income $ 20,347 $ 20,787 Net income $ 18,578 $ 19,435

Intangible Assets (Tables)

Intangible Assets (Tables)	3 Months Ended
	Mar. 31, 2018
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Schedule of Components of Intangible Assets	The following table summarizes the components of our intangible assets at the dates indicated: March 31, 2018 December 31, 2017 Gross Carrying Amount Accumulated Amortization Carrying Value Gross Carrying Amount Accumulated Amortization Carrying Value Sodium minerals and sulfur services: Customer relationships $ 94,654 $ 93,033 $ 1,621 $ 94,654 $ 92,493 $ 2,161 Licensing agreements 38,678 37,066 1,612 38,678 36,528 2,150 Non-compete agreement 800 156 644 800 89 711 Segment total 134,132 130,255 3,877 134,132 129,110 5,022 Onshore Facilities & Transportation: Customer relationships 35,430 35,093 337 35,430 35,082 348 Intangibles associated with lease 13,260 5,051 8,209 13,260 4,933 8,327 Segment total 48,690 40,144 8,546 48,690 40,015 8,675 Marine contract intangibles 27,000 13,050 13,950 27,000 11,700 15,300 Offshore pipeline contract intangibles 158,101 22,190 135,911 158,101 20,109 137,992 Other 30,684 14,213 16,471 28,900 13,483 15,417 Total $ 398,607 $ 219,852 $ 178,755 $ 396,823 $ 214,417 $ 182,406
Schedule of Amortization Expense	Our amortization of intangible assets for the periods presented was as follows: Three Months Ended 2018 2017 Amortization of intangible assets $ 5,433 $ 5,872
Schedule of Expected Amortization Expense	We estimate that our amortization expense for the next five years will be as follows: Remainder of 2018 $ 16,475 2019 $ 16,914 2020 $ 16,661 2021 $ 11,080 2022 $ 10,695

Debt (Tables)

Debt (Tables)	3 Months Ended
	Mar. 31, 2018
Debt Disclosure [Abstract]
Schedule of Obligations Under Debt Arrangements	Our obligations under debt arrangements consisted of the following: March 31, 2018 December 31, 2017 Principal Unamortized Discount and Debt Issuance Costs (1) Net Value Principal Unamortized Discount and Debt Issuance Costs (1) Net Value Senior secured credit facility $ 1,279,000 $ — $ 1,279,000 $ 1,099,200 $ — $ 1,099,200 5.750% senior unsecured notes due February 2021 — — — 145,170 1,303 143,867 6.750% senior unsecured notes due August 2022 750,000 15,257 734,743 750,000 16,077 733,923 6.000% senior unsecured notes due May 2023 400,000 5,424 394,576 400,000 5,691 394,309 5.625% senior unsecured notes due June 2024 350,000 5,493 344,507 350,000 5,717 344,283 6.500% senior unsecured notes due October 2025 550,000 9,157 540,843 550,000 9,462 540,538 6.250% senior unsecured notes due May 2026 450,000 7,920 442,080 450,000 8,002 441,998 Total long-term debt $ 3,779,000 $ 43,251 $ 3,735,749 $ 3,744,370 $ 46,252 $ 3,698,118 (1) Unamortized debt issuance costs associated with our senior secured credit facility (included in Other Long Term Assets on the Unaudited Condensed Consolidated Balance Sheet) were $13.1 million and $14.1 million as of March 31, 2018 and December 31, 2017, respectively.

Partners' Capital, Mezzanine 34

Partners' Capital, Mezzanine Equity and Distributions (Tables)	3 Months Ended
	Mar. 31, 2018
Partners' Capital and Distributions [Abstract]
Schedule of Paid Distributions	We paid or will pay the following distributions to our common unitholders in 2017 and 2018 : Distribution For Date Paid Per Unit Amount Total Amount 2017 1 st Quarter May 15, 2017 $ 0.7200 $ 88,257 2 nd Quarter August 14, 2017 $ 0.7225 $ 88,563 3 rd Quarter November 14, 2017 $ 0.5000 $ 61,290 4 th Quarter February 14, 2018 $ 0.5100 $ 62,515 2018 1 st Quarter May 15, 2018 (1) $ 0.5200 $ 63,741 (1) This distribution will be paid to unitholders of record as of May 1, 2018 .
Schedule of Changes in Preferred Stock Units	The following table shows the change in our preferred units from December 31, 2017 to March 31, 2018: As of March 31, Mezzanine Capital Balance 2018 Balance as of December 31, 2017 697,151 Distribution paid-in-kind 16,527 Allocation of Distribution paid in-kind to Preferred Distribution Rate Reset Election ( Note 16 ) (991 ) Balance as of March 31, 2018 712,687 Three months ended March 31, Number of Class A Convertible Preferred Units 2018 Balance as of December 31, 2017 22,411,728 Distribution paid-in-kind 490,252 Balance as of March 31, 2018 22,901,980

Net Income Per Common Unit (Tab

Net Income Per Common Unit (Tables)	3 Months Ended
	Mar. 31, 2018
Net Income per Common Unit [Abstract]
Schedule of Earnings Per Share, Basic and Diluted	The following table reconciles net income and weighted average units used in computing basic and diluted net income per common unit (in thousands, except per unit amounts): Three Months Ended 2018 2017 Net Income Attributable to Genesis Energy L.P. $ 8,034 $ 27,090 Less: Accumulated distributions attributable to Class A Convertible Preferred Units (16,888 ) — Net Income (loss) Available to Common Unitholders $ (8,854 ) $ 27,090 Weighted Average Outstanding Units 122,579 118,388 Basic and Diluted Net Income (loss) per Common Unit $ (0.07 ) $ 0.23

Business Segment Information (T

Business Segment Information (Tables)	3 Months Ended
	Mar. 31, 2018
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	Segment information for the periods presented below was as follows: Offshore Pipeline Transportation Sodium Minerals & Sulfur Services Onshore Facilities & Transportation Marine Transportation Total Three Months Ended March 31, 2018 Segment Margin (a) $ 73,173 $ 64,391 $ 21,689 $ 10,987 $ 170,240 Capital expenditures (b) $ 654 $ 9,699 $ 23,289 $ 10,865 44,507 Revenues: External customers $ 73,260 $ 287,403 $ 320,215 $ 44,930 725,808 Intersegment (c) — (1,493 ) (2,506 ) 3,999 — Total revenues of reportable segments $ 73,260 $ 285,910 $ 317,709 $ 48,929 $ 725,808 Three Months Ended March 31, 2017 Segment Margin (a) $ 87,089 $ 17,496 $ 21,097 $ 12,963 $ 138,645 Capital expenditures (b) $ 2,239 $ 513 $ 46,702 $ 9,533 58,987 Revenues: External customers $ 85,405 $ 47,271 $ 234,611 $ 48,204 415,491 Intersegment (c) (277 ) (2,225 ) 404 2,098 — Total revenues of reportable segments $ 85,128 $ 45,046 $ 235,015 $ 50,302 $ 415,491 Total assets by reportable segment were as follows: March 31, December 31, Offshore pipeline transportation $ 2,472,742 $ 2,486,803 Sodium minerals and sulfur services 1,842,607 1,848,188 Onshore facilities and transportation 1,916,102 1,927,976 Marine transportation 819,057 824,777 Other assets 59,328 49,737 Total consolidated assets 7,109,836 7,137,481 (a) A reconciliation of total Segment Margin to net income attributable to Genesis Energy, L.P. for the periods is presented below. (b) Capital expenditures include maintenance and growth capital expenditures, such as fixed asset additions (including enhancements to existing facilities and construction of growth projects) as well as acquisitions of businesses and contributions to equity investees related to same. (c) Intersegment sales were conducted under terms that we believe were no more or less favorable than then-existing market conditions.
Reconciliation of Operating Profit (Loss) from Segments to Consolidated	Reconciliation of total Segment Margin to net income: Three Months Ended 2018 2017 Total Segment Margin $ 170,240 $ 138,645 Corporate general and administrative expenses (10,460 ) (8,327 ) Depreciation, depletion, amortization and accretion (78,008 ) (58,395 ) Interest expense (56,136 ) (36,739 ) Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1) (9,057 ) (9,290 ) Non-cash items not included in Segment Margin (6,137 ) 437 Cash payments from direct financing leases in excess of earnings (1,839 ) (1,667 ) Loss on extinguishment of debt (3,339 ) — Differences in timing of cash receipts for certain contractual arrangements (2) 3,331 2,681 Non-cash provision for leased items no longer in use (186 ) — Income tax expense (375 ) (255 ) Net income attributable to Genesis Energy, L.P. $ 8,034 $ 27,090 (1) Includes distributions attributable to the quarter and received during or promptly following such quarter. (2)

Transactions with Related Par37

Transactions with Related Parties (Tables)	3 Months Ended
	Mar. 31, 2018
Related Party Transactions [Abstract]
Schedule Of Transactions with Related Parties	Receivables from ANSAC as of March 31, 2018 and December 31, 2017 are as follows: March 31, December 31, 2018 2017 Receivables: ANSAC $ 71,276 $ 74,490 Payables: ANSAC $ 1,970 $ 1,223 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: Three Months Ended 2018 2017 Revenues: Sales of CO 2 to Sandhill Group, LLC (1) $ 543 $ 677 Revenues from services and fees to Poseidon Oil Pipeline Company, LLC (2) 3,200 3,022 Revenues from product sales to ANSAC 90,796 — Costs and expenses: Amounts paid to our CEO in connection with the use of his aircraft $ 165 $ 165 Charges for services from Poseidon Oil Pipeline Company, LLC (2) 249 241 Charges for services from ANSAC 1,778 — (1) We own a 50% interest in Sandhill Group, LLC. (2) We own 64% interest in Poseidon Oil Pipeline Company, LLC.

Supplemental Cash Flow Inform38

Supplemental Cash Flow Information (Tables)	3 Months Ended
	Mar. 31, 2018
Supplemental Cash Flow Elements [Abstract]
Net Changes In Components of Operating Assets and Liabilities	The following table provides information regarding the net changes in components of operating assets and liabilities. Three Months Ended 2018 2017 (Increase) decrease in: Accounts receivable $ 27,368 $ 9,169 Inventories (4,469 ) 6,009 Deferred charges (4,161 ) (348 ) Other current assets (7,694 ) (4,605 ) Increase (decrease) in: Accounts payable 94 (17,305 ) Accrued liabilities (14,920 ) (21,988 ) Net changes in components of operating assets and liabilities (3,782 ) (29,068 )

Derivatives (Tables)

Derivatives (Tables)	3 Months Ended
	Mar. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Outstanding Derivatives Entered Into to Hedge Inventory or Fixed Price Purchase Commitments	At March 31, 2018 , we had the following outstanding derivative commodity contracts that were entered into to economically hedge inventory or fixed price purchase commitments. Sell (Short) Contracts Buy (Long) Contracts Designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 bbls) 243 — Weighted average contract price per bbl $ 62.41 $ — Not qualifying or not designated as hedges under accounting rules: Crude oil futures: Contract volumes (1,000 bbls) 283 145 Weighted average contract price per bbl $ 63.92 $ 64.68 Natural gas swaps: Contract volumes (10,000 MMBTU) 275 — Weighted average price differential per MMBTU $ 0.61 $ — Natural gas futures: Contract volumes (10,000 MMBTU) 35 275 Weighted average contract price per MMBTU $ 2.74 $ 2.83 Diesel futures: Contract volumes (1,000 bbls) 6 — Weighted average contract price per bbl $ 1.94 $ — NYM RBOB Gas futures: Contract volumes (42,000 gallons) 24 16 Weighted average contract price per gallon $ 1.97 $ 1.94 Fuel oil futures: Contract volumes (1,000 bbls) 397 40 Weighted average contract price per bbl $ 54.55 $ 54.03 Crude oil options: Contract volumes (1,000 bbls) 70 20 Weighted average premium received $ 1.16 $ 0.29
Schedule of Fair Value of Derivative Assets and Liabilities	The following tables reflect the estimated fair value gain (loss) position of our derivatives at March 31, 2018 and December 31, 2017 : Fair Value of Derivative Assets and Liabilities Unaudited Condensed Consolidated Balance Sheets Location Fair Value March 31, December 31, Asset Derivatives: Commodity derivatives - futures and call options (undesignated hedges): Gross amount of recognized assets Current Assets - Other $ 394 $ 505 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (394 ) (505 ) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ — Commodity derivatives - futures and call options (designated hedges): Gross amount of recognized assets Current Assets - Other $ 34 $ 54 Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (34 ) (54 ) Net amount of assets presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ — Liability Derivatives: Preferred Distribution Rate Reset Election (2) Other long-term liabilities (48,106 ) (45,209 ) Natural Gas Swap (undesignated hedge) Current Liabilities - Accrued Liabilities (358 ) — Commodity derivatives - futures and call options (undesignated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (1,001 ) $ (1,203 ) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 1,001 1,203 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ — Commodity derivatives - futures and call options (designated hedges): Gross amount of recognized liabilities Current Assets - Other (1) $ (646 ) $ (863 ) Gross amount offset in the Unaudited Condensed Consolidated Balance Sheets Current Assets - Other (1) 646 338 Net amount of liabilities presented in the Unaudited Condensed Consolidated Balance Sheets related to commodity derivatives $ — $ (525 ) (1) These derivative liabilities have been funded with margin deposits recorded in our Unaudited Condensed Consolidated Balance Sheets under Current Assets - Other. (2) Refer to Note 10 and Note 16 for additional discussion surrounding the Preferred Distribution Rate Reset Election derivative.
Schedule of Effect on Operating Results	Effect on Operating Results Amount of Gain (Loss) Recognized in Income Unaudited Condensed Consolidated Statements of Operations Location Three Months Ended 2018 2017 Commodity derivatives - futures and call options: Contracts designated as hedges under accounting guidance Onshore facilities and transportation product costs $ (1,366 ) $ 6,286 Contracts not considered hedges under accounting guidance Onshore facilities and transportation product costs, sodium minerals and sulfur services operating costs (332 ) 1,093 Total commodity derivatives $ (1,698 ) $ 7,379 Natural Gas Swap Liability Sodium minerals and sulfur services operating costs $ (275 ) $ — Preferred Distribution Rate Reset Election Other expense $ (1,906 ) $ —

Fair-Value Measurements (Tables

Fair-Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2018
Fair Value Disclosures [Abstract]
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 March 31, 2018 and December 31, 2017 . Fair Value at Fair Value at March 31, 2018 December 31, 2017 Recurring Fair Value Measures Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Commodity derivatives: Assets $ 428 $ — $ — $ 559 $ — $ — Liabilities $ (1,647 ) $ (358 ) $ — $ (2,066 ) $ — $ — Preferred Distribution Rate Reset Election $ — $ — $ (48,106 ) $ — $ — $ (45,209 )
Reconciliation of Changes in Fair Value of Derivatives Classified as Level 3	The following table provides a reconciliation of changes in fair value at the beginning and ending balances for our derivatives classified as level 3: Three months ended March 31, 2018 Balance as of December 31, 2017 (45,209) Net Loss for the period included in earnings (1,906) Allocation of Distribution Paid-in-kind (991) Balance as of March 31, 2018 (48,106)

Condensed Consolidating Finan41

Condensed Consolidating Financial Information (Tables)	3 Months Ended
	Mar. 31, 2018
Condensed Consolidating Financial Information [Abstract]
Condensed Consolidating Financial Statements	The following is condensed consolidating financial information for Genesis Energy, L.P., the guarantor subsidiaries and the non-guarantor subsidiaries. Unaudited Condensed Consolidating Balance Sheet March 31, 2018 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 $ 6 $ — $ 14,677 $ 1,409 $ — $ 16,092 Other current assets 25 — 551,885 12,137 (45 ) 564,002 Total current assets 31 — 566,562 13,546 (45 ) 580,094 Fixed assets, at cost — — 5,575,295 77,585 — 5,652,880 Less: Accumulated depreciation — — (774,919 ) (27,342 ) — (802,261 ) Net fixed assets — — 4,800,376 50,243 — 4,850,619 Mineral Leaseholds — — 563,369 — — 563,369 Goodwill — — 325,046 — — 325,046 Other assets, net 13,083 — 438,693 124,242 (157,803 ) 418,215 Advances to affiliates 3,799,305 — — 89,334 (3,888,639 ) — Equity investees — — 372,493 — — 372,493 Investments in subsidiaries 2,693,391 — 83,624 — (2,777,015 ) — Total assets $ 6,505,810 $ — $ 7,150,163 $ 277,365 $ (6,823,502 ) $ 7,109,836 LIABILITIES AND CAPITAL Current liabilities $ 57,677 $ — $ 348,421 $ 10,137 $ (545 ) $ 415,690 Senior secured credit facility 1,279,000 — — — — 1,279,000 Senior unsecured notes 2,456,749 — — — — 2,456,749 Deferred tax liabilities — — 12,138 — — 12,138 Advances from affiliates — — 3,888,239 — (3,888,239 ) — Other liabilities 48,107 — 214,494 185,456 (157,656 ) 290,401 Total liabilities 3,841,533 — 4,463,292 195,593 (4,046,440 ) 4,453,978 Mezzanine Capital: Class A Convertible Preferred Units 712,687 — — — — 712,687 Partners’ capital, common units 1,951,590 — 2,687,475 89,587 (2,777,062 ) 1,951,590 Accumulated other comprehensive loss (1) — — (604 ) — — (604 ) Noncontrolling interests — — — (7,815 ) — (7,815 ) Total liabilities, mezzanine capital and partners’ capital $ 6,505,810 $ — $ 7,150,163 $ 277,365 $ (6,823,502 ) $ 7,109,836 (1) The entire balance and activity within Accumulated Other Comprehensive Income is related to our pension held within our Guarantor Subsidiaries. Unaudited Condensed Consolidating Balance Sheet December 31, 2017 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 $ 6 $ — $ 8,340 $ 695 $ — $ 9,041 Other current assets 50 — 614,682 12,316 (56 ) 626,992 Total current assets 56 — 623,022 13,011 (56 ) 636,033 Fixed assets, at cost — — 5,523,431 77,584 — 5,601,015 Less: Accumulated depreciation — — (708,269 ) (26,717 ) — (734,986 ) Net fixed assets — — 4,815,162 50,867 — 4,866,029 Mineral Leaseholds — — 564,506 — — 564,506 Goodwill — — 325,046 — — 325,046 Other assets, net 14,083 — 378,371 126,300 (154,437 ) 364,317 Advances to affiliates 3,808,712 — — 85,423 (3,894,135 ) — Equity investees and other investments — — 381,550 — — 381,550 Investments in subsidiaries 2,689,861 — 82,616 — (2,772,477 ) — Total assets $ 6,512,712 $ — $ 7,170,273 $ 275,601 $ (6,821,105 ) $ 7,137,481 LIABILITIES AND CAPITAL Current liabilities $ 46,086 $ — $ 399,017 $ 11,417 $ (256 ) $ 456,264 Senior secured credit facilities 1,099,200 — — — — 1,099,200 Senior unsecured notes 2,598,918 — — — — 2,598,918 Deferred tax liabilities — — 11,913 — — 11,913 Advances from affiliates — — 3,894,027 — (3,894,027 ) — Other liabilities 45,210 — 182,414 183,237 (154,290 ) 256,571 Total liabilities 3,789,414 — 4,487,371 194,654 (4,048,573 ) 4,422,866 Mezzanine Capital: Class A Convertible Preferred Units 697,151 — — — — 697,151 Partners’ capital, common units 2,026,147 — 2,683,506 89,026 (2,772,532 ) 2,026,147 Accumulated other comprehensive loss (1) — — (604 ) — — (604 ) Noncontrolling interests — — — (8,079 ) — (8,079 ) Total liabilities, mezzanine capital and partners’ capital $ 6,512,712 $ — $ 7,170,273 $ 275,601 $ (6,821,105 ) $ 7,137,481 (1) The entire balance and activity within Accumulated Other Comprehensive Income is related to our pension held within our Guarantor Subsidiaries. Unaudited Condensed Consolidating Statement of Operations Three Months Ended March 31, 2018 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: Offshore pipeline transportation services $ — $ — $ 73,260 $ — $ — $ 73,260 Sodium minerals and sulfur services — — 285,097 3,066 (2,253 ) 285,910 Marine transportation — — 48,929 — — 48,929 Onshore facilities and transportation — — 312,874 4,835 — 317,709 Total revenues — — 720,160 7,901 (2,253 ) 725,808 COSTS AND EXPENSES: Onshore facilities and transportation costs — — 299,841 272 — 300,113 Marine transportation costs — — 37,847 — — 37,847 Sodium minerals and sulfur services operating costs — — 223,247 2,504 (2,253 ) 223,498 Offshore pipeline transportation operating costs — — 17,662 678 — 18,340 General and administrative — — 11,674 — — 11,674 Depreciation, depletion and amortization — — 74,630 625 — 75,255 Total costs and expenses — — 664,901 4,079 (2,253 ) 666,727 OPERATING INCOME — — 55,259 3,822 — 59,081 Equity in earnings of subsidiaries 69,592 — 632 — (70,224 ) — Equity in earnings of equity investees — — 10,572 — — 10,572 Interest (expense) income, net (56,314 ) — 3,544 (3,366 ) — (56,136 ) Other expense (5,244 ) — — — — (5,244 ) Income before income taxes 8,034 — 70,007 456 (70,224 ) 8,273 Income tax expense — — (377 ) 2 — (375 ) NET INCOME 8,034 — 69,630 458 (70,224 ) 7,898 Net loss attributable to noncontrolling interest — — — 136 — 136 NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P. $ 8,034 $ — $ 69,630 $ 594 $ (70,224 ) $ 8,034 Less: Accumulated distributions attributable to Class A Convertible Preferred Units (16,888 ) — — — — $ (16,888 ) NET INCOME(LOSS) AVAILABLE TO COMMON UNIT HOLDERS $ (8,854 ) $ — $ 69,630 $ 594 $ (70,224 ) $ (8,854 ) Unaudited Condensed Consolidating Statement of Operations Three Months Ended March 31, 2017 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: Offshore pipeline transportation services $ — $ — $ 85,128 $ — $ 85,128 Sodium minerals and sulfur services — — 45,034 1,810 (1,798 ) 45,046 Marine transportation — — 50,302 — — 50,302 Onshore facilities and transportation — — 230,070 4,945 — 235,015 Total revenues — — 410,534 6,755 (1,798 ) 415,491 COSTS AND EXPENSES: Onshore facilities and transportation costs — — 214,071 261 — 214,332 Marine transportation costs — — 37,242 — — 37,242 Sodium minerals and sulfur services operating costs — — 27,153 2,009 (1,798 ) 27,364 Offshore pipeline transportation operating costs — — 17,106 762 — 17,868 General and administrative — — 9,976 — — 9,976 Depreciation, depletion and amortization — — 55,487 625 — 56,112 Total costs and expenses — — 361,035 3,657 (1,798 ) 362,894 OPERATING INCOME — — 49,499 3,098 — 52,597 Equity in earnings of subsidiaries 63,809 — (250 ) — (63,559 ) — Equity in earnings of equity investees — — 11,335 — — 11,335 Interest (expense) income, net (36,719 ) — 3,520 (3,540 ) — (36,739 ) Income before income taxes 27,090 — 64,104 (442 ) (63,559 ) 27,193 Income tax (expense) benefit — — (255 ) — — (255 ) NET INCOME 27,090 — 63,849 (442 ) (63,559 ) 26,938 Net loss attributable to noncontrolling interest — — — 152 — 152 NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P. $ 27,090 $ — $ 63,849 $ (290 ) $ (63,559 ) $ 27,090 Less: Accumulated distributions attributable to Class A Convertible Preferred Units — — — — — — NET INCOME AVAILABLE TO COMMON UNIT HOLDERS $ 27,090 $ — $ 63,849 $ (290 ) $ (63,559 ) $ 27,090 Unaudited Condensed Consolidating Statement of Cash Flows Three Months Ended March 31, 2018 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 provided by operating activities $ 18,637 $ — $ 124,180 $ 874 $ (57,363 ) $ 86,328 CASH FLOWS FROM INVESTING ACTIVITIES: Payments to acquire fixed and intangible assets — — (66,051 ) — — (66,051 ) Cash distributions received from equity investees - return of investment — — 9,277 — — 9,277 Acquisitions — — — — — — Intercompany transfers 9,407 — — — (9,407 ) — Repayments on loan to non-guarantor subsidiary — — 1,801 — (1,801 ) — Contributions in aid of construction costs — — — — — — Proceeds from asset sales — — 6 — — 6 Other, net — — — — — — Net cash used in investing activities 9,407 — (54,967 ) — (11,208 ) (56,768 ) CASH FLOWS FROM FINANCING ACTIVITIES: Borrowings on senior secured credit facility 333,800 — — — — 333,800 Repayments on senior secured credit facility (154,000 ) — — — — (154,000 ) Proceeds from issuance of senior unsecured notes — — — — — — Repayment of senior unsecured notes (145,170 ) — — — — (145,170 ) Proceeds from issuance of Class A convertible preferred units, net — — — — — — Debt issuance costs (159 ) — — — — (159 ) Intercompany transfers — — (5,496 ) (3,911 ) 9,407 — Issuance of common units for cash, net — — — — — — Distributions to common unitholders (62,515 ) — (62,515 ) — 62,515 (62,515 ) Contributions from noncontrolling interest — — — 400 — 400 Other, net — — 5,135 3,351 (3,351 ) 5,135 Net cash used in financing activities (28,044 ) — (62,876 ) (160 ) 68,571 (22,509 ) Net increase in cash and cash equivalents — — 6,337 714 — 7,051 Cash and cash equivalents at beginning of period 6 — 8,340 695 — 9,041 Cash and cash equivalents at end of period $ 6 $ — $ 14,677 $ 1,409 $ — $ 16,092 Unaudited Condensed Consolidating Statement of Cash Flows Three Months Ended March 31, 2017 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 provided by operating activities $ 42,623 $ — $ 95,023 $ 2,007 $ (78,613 ) $ 61,040 CASH FLOWS FROM INVESTING ACTIVITIES: Payments to acquire fixed and intangible assets — — (61,292 ) — — (61,292 ) Cash distributions received from equity investees - return of investment — — 9,083 — — 9,083 Investments in equity investees (140,968 ) — — — 140,968 — Acquisitions — — — — — — Intercompany transfers 109,342 — — — (109,342 ) — Repayments on loan to non-guarantor subsidiary — — 1,627 — (1,627 ) — Contributions in aid of construction costs — — 124 — — 124 Proceeds from asset sales — — 1,234 — — 1,234 Other, net — — — — — — Net cash used in investing activities (31,626 ) — (49,224 ) — 29,999 (50,851 ) CASH FLOWS FROM FINANCING ACTIVITIES: Borrowings on senior secured credit facility 216,700 — — — — 216,700 Repayments on senior secured credit facility (284,900 ) — — — — (284,900 ) Debt issuance costs — — — — — — Intercompany transfers — — (104,276 ) (5,066 ) 109,342 — Issuance of common units for cash, net 140,968 — 140,968 — (140,968 ) 140,968 Distributions to common unitholders (83,765 ) — (83,765 ) — 83,765 (83,765 ) Distributions to noncontrolling interest — — — — — — Other, net — — 4,552 3,525 (3,525 ) 4,552 Net cash provided by financing activities (10,997 ) — (42,521 ) (1,541 ) 48,614 (6,445 ) Net decrease in cash and cash equivalents — — 3,278 466 — 3,744 Cash and cash equivalents at beginning of period 6 — 6,360 663 — 7,029 Cash and cash equivalents at end of period $ 6 $ — $ 9,638 $ 1,129 $ — $ 10,773

Organization and Basis of Pre42

Organization and Basis of Presentation and Consolidation (Details) $ in Thousands	Sep. 01, 2017USD ($)	Mar. 31, 2018USD ($)segment	Mar. 31, 2017USD ($)	Dec. 31, 2017USD ($)
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Limited Partners' ownership percentage		100.00%
Number of reportable segments | segment		4
Business Acquisition [Line Items]
Cash payment to acquire business		$ 0	$ 0
6.500% Senior Unsecured Notes Due October 2025
Business Acquisition [Line Items]
Debt issued		$ 550,000		$ 550,000
Private Placement | Class A Convertible Preferred Stock Units
Business Acquisition [Line Items]
Temporary Equity, Stock Issued During Period, Value, New Issues	$ 750,000
Alkali Business
Business Acquisition [Line Items]
Cash payment to acquire business	1,325,000
Alkali Business | 6.500% Senior Unsecured Notes Due October 2025
Business Acquisition [Line Items]
Debt issued	550,000
Alkali Business | Private Placement | Class A Convertible Preferred Stock Units
Business Acquisition [Line Items]
Temporary Equity, Stock Issued During Period, Value, New Issues	$ 750,000

Recent Accounting Development43

Recent Accounting Developments Recent Accounting Developments (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Decrease in cash flows from operating activities reclassified to investing activities	$ 86,328	$ 61,040
Increase in cash flows from investing activities reclassified from operating activities	$ (56,768)	(50,851)
Accounting Standards Update 2016-15 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Decrease in cash flows from operating activities reclassified to investing activities		(3,600)
Increase in cash flows from investing activities reclassified from operating activities		$ 3,600

Revenue Recognition (Impact on

Revenue Recognition (Impact on Balance Sheet and Operating Income) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Jan. 01, 2018	Dec. 31, 2017
ASSETS
Accounts receivable - trade, net	$ 419,903		$ 447,421	$ 495,449
Inventories	95,667		93,791	88,653
Other assets, net of amortization	116,190		115,832	56,628
LIABILITIES AND CAPITAL
Other long-term liabilities	290,401		276,435	256,571
Partner's capital	1,951,590		2,022,597	$ 2,026,147
OPERATING INCOME
Total revenues	725,808
Operating Income	59,081	$ 52,597
Offshore Pipeline Transportation
OPERATING INCOME
Total revenues	73,260
Cost of revenues	18,340
Sodium Minerals & Sulfur Services
OPERATING INCOME
Total revenues	285,910
Cost of revenues	223,498
Marine Transportation
OPERATING INCOME
Total revenues	48,929
Cost of revenues	37,847
Onshore Facilities & Transportation
OPERATING INCOME
Total revenues	317,709
Onshore Facilities & Transportation | Onshore facilities and transportation product costs
OPERATING INCOME
Cost of revenues	277,818
Onshore Facilities & Transportation | Onshore facilities and transportation operating costs
OPERATING INCOME
Cost of revenues	22,295
Adjustment/Without adoption of ASC 606 | Accounting Standards Update 2014-09
ASSETS
Accounts receivable - trade, net	472,116
Inventories	92,628
Other assets, net of amortization	51,948
LIABILITIES AND CAPITAL
Other long-term liabilities	268,832
Partner's capital	1,958,091
OPERATING INCOME
Total revenues	704,714
Operating Income	62,032
Adjustment/Without adoption of ASC 606 | Accounting Standards Update 2014-09 | Offshore Pipeline Transportation
OPERATING INCOME
Total revenues	74,111
Cost of revenues	18,340
Adjustment/Without adoption of ASC 606 | Accounting Standards Update 2014-09 | Sodium Minerals & Sulfur Services
OPERATING INCOME
Total revenues	263,965
Cost of revenues	199,454
Adjustment/Without adoption of ASC 606 | Accounting Standards Update 2014-09 | Marine Transportation
OPERATING INCOME
Total revenues	48,929
Cost of revenues	37,847
Adjustment/Without adoption of ASC 606 | Accounting Standards Update 2014-09 | Onshore Facilities & Transportation
OPERATING INCOME
Total revenues	317,709
Adjustment/Without adoption of ASC 606 | Accounting Standards Update 2014-09 | Onshore Facilities & Transportation | Onshore facilities and transportation product costs
OPERATING INCOME
Cost of revenues	277,818
Adjustment/Without adoption of ASC 606 | Accounting Standards Update 2014-09 | Onshore Facilities & Transportation | Onshore facilities and transportation operating costs
OPERATING INCOME
Cost of revenues	22,295
Effect of Change Increase/(Decrease)
OPERATING INCOME
Total revenues	21,094
Operating Income	(2,951)
Effect of Change Increase/(Decrease) | Offshore Pipeline Transportation
OPERATING INCOME
Total revenues	(851)
Cost of revenues	0
Effect of Change Increase/(Decrease) | Sodium Minerals & Sulfur Services
OPERATING INCOME
Total revenues	21,945
Cost of revenues	24,044
Effect of Change Increase/(Decrease) | Marine Transportation
OPERATING INCOME
Total revenues	0
Cost of revenues	0
Effect of Change Increase/(Decrease) | Onshore Facilities & Transportation
OPERATING INCOME
Total revenues	0
Effect of Change Increase/(Decrease) | Onshore Facilities & Transportation | Onshore facilities and transportation product costs
OPERATING INCOME
Cost of revenues	0
Effect of Change Increase/(Decrease) | Onshore Facilities & Transportation | Onshore facilities and transportation operating costs
OPERATING INCOME
Cost of revenues	0
Effect of Change Increase/(Decrease) | Accounting Standards Update 2014-09
ASSETS
Accounts receivable - trade, net	(52,213)		(48,028)
Inventories	3,039		5,138
Other assets, net of amortization	64,242		59,204
LIABILITIES AND CAPITAL
Other long-term liabilities	21,569		19,864
Partner's capital	$ (6,501)		$ (3,550)

Revenue Recognition (Disaggrega

Revenue Recognition (Disaggregated Revenue) (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2018USD ($)
Disaggregation of Revenue [Line Items]
Total revenues	$ 725,808
Transferred over time | Fee-based revenues
Disaggregation of Revenue [Line Items]
Total revenues	152,527
Transferred over time | Refinery Services
Disaggregation of Revenue [Line Items]
Total revenues	21,945
Transferred at point in time | Product Sales
Disaggregation of Revenue [Line Items]
Total revenues	551,336
Onshore Facilities & Transportation
Disaggregation of Revenue [Line Items]
Total revenues	317,709
Onshore Facilities & Transportation | Transferred over time | Fee-based revenues
Disaggregation of Revenue [Line Items]
Total revenues	30,338
Onshore Facilities & Transportation | Transferred over time | Refinery Services
Disaggregation of Revenue [Line Items]
Total revenues	0
Onshore Facilities & Transportation | Transferred at point in time | Product Sales
Disaggregation of Revenue [Line Items]
Total revenues	287,371
Sodium Minerals & Sulfur Services
Disaggregation of Revenue [Line Items]
Total revenues	285,910
Sodium Minerals & Sulfur Services | Transferred over time | Fee-based revenues
Disaggregation of Revenue [Line Items]
Total revenues	0
Sodium Minerals & Sulfur Services | Transferred over time | Refinery Services
Disaggregation of Revenue [Line Items]
Total revenues	21,945
Sodium Minerals & Sulfur Services | Transferred at point in time | Product Sales
Disaggregation of Revenue [Line Items]
Total revenues	263,965
Offshore Pipeline Transportation
Disaggregation of Revenue [Line Items]
Total revenues	73,260
Offshore Pipeline Transportation | Transferred over time | Fee-based revenues
Disaggregation of Revenue [Line Items]
Total revenues	73,260
Offshore Pipeline Transportation | Transferred over time | Refinery Services
Disaggregation of Revenue [Line Items]
Total revenues	0
Offshore Pipeline Transportation | Transferred at point in time | Product Sales
Disaggregation of Revenue [Line Items]
Total revenues	0
Marine Transportation
Disaggregation of Revenue [Line Items]
Total revenues	48,929
Marine Transportation | Transferred over time | Fee-based revenues
Disaggregation of Revenue [Line Items]
Total revenues	48,929
Marine Transportation | Transferred over time | Refinery Services
Disaggregation of Revenue [Line Items]
Total revenues	0
Marine Transportation | Transferred at point in time | Product Sales
Disaggregation of Revenue [Line Items]
Total revenues	$ 0

Revenue Recognition (Contract A

Revenue Recognition (Contract Assets and Liabilities) (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Jan. 01, 2018
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Contract Assets, Non-Current		$ 59,204
Contract Liabilities, Non-Current		$ 19,864
Calculated under Revenue Guidance in Effect before Topic 606
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Contract Assets, Non-Current	$ 64,240
Contract Liabilities, Non-Current	$ 21,570

Revenue Recognition (Narrative)

Revenue Recognition (Narrative) (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2018USD ($)
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Reset tariff period for transportation contracts	1 year
Expected duration of performance obligations	1 year
Offshore Pipeline Transportation | Fixed-price Contract
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Estimated aggregate transaction price of unsatisfied performance obligations	$ 379,915
Marine Transportation | M/T American Phoenix | Fixed-price Contract
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Estimated aggregate transaction price of unsatisfied performance obligations	67,488
Onshore Facilities & Transportation | Fixed-price Contract
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Estimated aggregate transaction price of unsatisfied performance obligations	$ 202,726

Revenue Recognition (Revenue Ex

Revenue Recognition (Revenue Expected to be Recognized in Future Periods) (Details) $ in Thousands	Mar. 31, 2018USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-04-01 | Offshore Pipeline Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	$ 63,672
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-04-01 | Marine Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	20,350
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-04-01 | Onshore Facilities & Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	49,773
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | Offshore Pipeline Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	73,918
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | Marine Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	27,010
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | Onshore Facilities & Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	66,267
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Offshore Pipeline Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	50,883
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Marine Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	20,128
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Onshore Facilities & Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	60,689
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Offshore Pipeline Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	34,261
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Marine Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	0
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Onshore Facilities & Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	21,714
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Offshore Pipeline Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	22,558
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Marine Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	0
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Onshore Facilities & Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	4,283
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Offshore Pipeline Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	134,623
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Marine Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	0
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Onshore Facilities & Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	0
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | Offshore Pipeline Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	379,915
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | Marine Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	67,488
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | Onshore Facilities & Transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation	$ 202,726

Acquisition (Narrative) (Detail

Acquisition (Narrative) (Details) - USD ($) $ in Thousands	Sep. 01, 2017	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Business Acquisition [Line Items]
Cash payment to acquire business		$ 0	$ 0
Proceeds from issuance of Class A convertible preferred units, net		0
6.500% Senior Unsecured Notes Due October 2025
Business Acquisition [Line Items]
Debt issued		$ 550,000		$ 550,000
Senior unsecured notes, stated rate		6.50%		6.50%
Class A Convertible Preferred Stock Units | Private Placement
Business Acquisition [Line Items]
Temporary Equity, Stock Issued During Period, Value, New Issues	$ 750,000
Alkali Business
Business Acquisition [Line Items]
Cash payment to acquire business	1,325,000
Working capital included in cash payment to acquire business	105,000
Alkali Business | 6.500% Senior Unsecured Notes Due October 2025
Business Acquisition [Line Items]
Debt issued	$ 550,000
Senior unsecured notes, stated rate	6.50%
Proceeds from issuance of unsecured debt	$ 540,100
Alkali Business | Class A Convertible Preferred Stock Units | Private Placement
Business Acquisition [Line Items]
Temporary Equity, Stock Issued During Period, Value, New Issues	750,000
Proceeds from issuance of Class A convertible preferred units, net	$ 726,200

Acquisition (Selected Financial

Acquisition (Selected Financial Information) (Details) - Alkali Business $ in Thousands	3 Months Ended
	Mar. 31, 2018USD ($)
SelectedFinancialInformation [Line Items]
Revenues	$ 208,549
Net income	$ 31,740

Acquisition (Schedule of Pro Fo

Acquisition (Schedule of Pro Forma Information) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
As reported net income per unit (in dollars per share)	$ (0.07)	$ 0.23
Alkali Business
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
Revenues		$ 606,100
Net Income Attributable to Genesis Energy, L.P.		36,490
Net Income Available to Common Unitholders		$ 20,083
As reported net income per unit (in dollars per share)		$ 0.23
Pro forma net income per unit (in dollars per share)		$ 0.17

Inventories (Major Components o

Inventories (Major Components of Inventories) (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Jan. 01, 2018	Dec. 31, 2017
Inventory Disclosure [Abstract]
Petroleum products	$ 20,048		$ 8,731
Crude oil	25,133		29,873
Caustic soda	5,016		5,755
NaHS	9,655		8,277
Raw materials - Alkali operations	4,648		4,550
Work-in-process - Alkali operations	9,747		7,355
Finished goods, net - Alkali operations	10,914		14,075
Materials and supplies, net - Alkali operations	10,498		10,030
Other	8		7
Total	$ 95,667	$ 93,791	$ 88,653

Inventories (Narrative) (Detail

Inventories (Narrative) (Details) - USD ($)	3 Months Ended	12 Months Ended
	Mar. 31, 2018	Dec. 31, 2017
Inventory Disclosure [Abstract]
Inventory write-down	$ 0	$ 0

Fixed Assets and Mineral Leas54

Fixed Assets and Mineral Leaseholds (Schedule of Fixed Assets) (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Fixed assets, at cost	$ 5,652,880	$ 5,601,015
Less: Accumulated depreciation	(802,261)	(734,986)
Net fixed assets	4,850,619	4,866,029
Crude oil pipelines and natural gas pipelines and related assets
Fixed assets, at cost	3,081,841	3,028,657
Onshore facilities, machinery, and equipment
Fixed assets, at cost	725,217	692,364
Onshore facilities, machinery, and equipment | Alkali Business
Fixed assets, at cost	499,539	497,601
Transportation equipment
Fixed assets, at cost	21,468	21,483
Marine vessels
Fixed assets, at cost	934,315	918,953
Land, buildings and improvements
Fixed assets, at cost	224,055	223,186
Office equipment, furniture and fixtures
Fixed assets, at cost	18,162	18,112
Construction in progress
Fixed assets, at cost	96,800	151,768
Other
Fixed assets, at cost	$ 51,483	$ 48,891

Fixed Assets and Mineral Leas55

Fixed Assets and Mineral Leaseholds (Mineral Leaseholds) (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Mineral leaseholds	$ 566,019	$ 566,019
Less: Accumulated depletion	(2,650)	(1,513)
Mineral leaseholds, net	$ 563,369	$ 564,506

Fixed Assets and Mineral Leas56

Fixed Assets and Mineral Leaseholds (Depreciation and Depletion Expense) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Fixed Assets And Asset Retirement Obligations [Abstract]
Depreciation expense	$ 68,428	$ 49,924
Depletion expense	$ 1,137	$ 0

Fixed Assets and Mineral Leas57

Fixed Assets and Mineral Leaseholds (Asset Retirement Obiligation Rollforward) (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2018USD ($)
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
ARO liability balance, December 31, 2017	$ 198,187
Accretion expense	2,718
Change in estimate	1,163
Settlements	(2,836)
ARO liability balance, March 31, 2018	$ 199,232

Fixed Assets and Mineral Leas58

Fixed Assets and Mineral Leaseholds (Narrative) (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Asset Retirement Obligations Details [Line Items]
Asset retirement obligation balance	$ 199,232	$ 198,187
Accrued Liabilities
Asset Retirement Obligations Details [Line Items]
Asset retirement obligation balance	$ 11,800	$ 20,900

Fixed Assets and Mineral Leas59

Fixed Assets and Mineral Leaseholds (Forecast of Accretion Expense) (Details) $ in Thousands	Mar. 31, 2018USD ($)
Fixed Assets And Asset Retirement Obligations [Abstract]
Remainder of 2018	$ 8,264
2,019	9,908
2,020	8,743
2,021	9,337
2,022	$ 9,972

Equity Investees (Narrative) (D

Equity Investees (Narrative) (Details) - USD ($) $ in Millions	Mar. 31, 2018	Dec. 31, 2017
Equity Method Investments and Joint Ventures [Abstract]
Unamortized excess cost amount	$ 378.4	$ 382.4

Equity Investees (Consolidated

Equity Investees (Consolidated Financial Statements Related to Equity Investees) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Equity Method Investments and Joint Ventures [Abstract]
Genesis’ share of operating earnings	$ 14,514	$ 15,277
Amortization of excess purchase price	(3,942)	(3,942)
Net equity in earnings	10,572	11,335
Distributions received	$ 19,629	$ 20,625

Equity Investees (Schedule of B

Equity Investees (Schedule of Balance Sheet Information for Equity Investees) (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Assets
Current assets	$ 13,626	$ 18,711
Fixed assets, net	213,472	217,343
Other assets	1,123	1,203
Total assets	228,221	237,257
Liabilities and equity
Current liabilities	17,846	17,560
Other liabilities	235,834	237,434
Equity	(25,459)	(17,737)
Total liabilities and equity	$ 228,221	$ 237,257

Equity Investees (Schedule of O

Equity Investees (Schedule of Operations for Equity Investees) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
INCOME STATEMENT DATA:
Revenues	$ 28,944	$ 28,905
Operating income	20,347	20,787
Net income	$ 18,578	$ 19,435

Intangible Assets (Schedule of

Intangible Assets (Schedule of Components of Intangible Assets) (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 398,607	$ 396,823
Accumulated Amortization	219,852	214,417
Carrying Value	178,755	182,406
Other
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	30,684	28,900
Accumulated Amortization	14,213	13,483
Carrying Value	16,471	15,417
Sodium Minerals & Sulfur Services
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	134,132	134,132
Accumulated Amortization	130,255	129,110
Carrying Value	3,877	5,022
Sodium Minerals & Sulfur Services | Customer relationships
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	94,654	94,654
Accumulated Amortization	93,033	92,493
Carrying Value	1,621	2,161
Sodium Minerals & Sulfur Services | Licensing agreements
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	38,678	38,678
Accumulated Amortization	37,066	36,528
Carrying Value	1,612	2,150
Sodium Minerals & Sulfur Services | Non-compete agreement
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	800	800
Accumulated Amortization	156	89
Carrying Value	644	711
Onshore Facilities & Transportation
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	48,690	48,690
Accumulated Amortization	40,144	40,015
Carrying Value	8,546	8,675
Onshore Facilities & Transportation | Customer relationships
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	35,430	35,430
Accumulated Amortization	35,093	35,082
Carrying Value	337	348
Onshore Facilities & Transportation | Intangibles associated with lease
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	13,260	13,260
Accumulated Amortization	5,051	4,933
Carrying Value	8,209	8,327
Marine Transportation
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	27,000	27,000
Accumulated Amortization	13,050	11,700
Carrying Value	13,950	15,300
Offshore pipeline transportation
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	158,101	158,101
Accumulated Amortization	22,190	20,109
Carrying Value	$ 135,911	$ 137,992

Intangible Assets (Schedule o65

Intangible Assets (Schedule of Current and Future Amortization Expense) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Amortization expense on intangible assets	$ 5,433	$ 5,872
Remainder of 2018	16,475
2,019	16,914
2,020	16,661
2,021	11,080
2,022	$ 10,695

Debt (Schedule of Obligations U

Debt (Schedule of Obligations Under Debt Arrangements) (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017	Dec. 11, 2017	Feb. 08, 2013
Debt Instrument [Line Items]
Senior secured credit facility, principal	$ 1,279,000	$ 1,099,200
Unamortized Debt Issuance Expense and Discounts (Premiums)	43,251	46,252
Senior unsecured notes	2,456,749	2,598,918
Total long-term debt, principal	3,779,000	3,744,370
Total long-term debt	3,735,749	3,698,118
Senior Secured Credit Facility
Debt Instrument [Line Items]
Unamortized Debt Issuance Expense and Discounts (Premiums)	$ 13,100	$ 14,100
5.750% senior unsecured notes due February 2021
Debt Instrument [Line Items]
Senior unsecured notes, stated rate	5.75%	5.75%		5.75%
Principal	$ 0	$ 145,170
Unamortized Debt Issuance Expense and Discounts (Premiums)	0	1,303
Senior unsecured notes	$ 0	$ 143,867
6.750% senior unsecured notes due August 2022
Debt Instrument [Line Items]
Senior unsecured notes, stated rate	6.75%	6.75%
Principal	$ 750,000	$ 750,000
Unamortized Debt Issuance Expense and Discounts (Premiums)	15,257	16,077
Senior unsecured notes	$ 734,743	$ 733,923
6.000% senior unsecured notes due May 2023
Debt Instrument [Line Items]
Senior unsecured notes, stated rate	6.00%	6.00%
Principal	$ 400,000	$ 400,000
Unamortized Debt Issuance Expense and Discounts (Premiums)	5,424	5,691
Senior unsecured notes	$ 394,576	$ 394,309
5.625% senior unsecured notes due June 2024
Debt Instrument [Line Items]
Senior unsecured notes, stated rate	5.625%	5.625%
Principal	$ 350,000	$ 350,000
Unamortized Debt Issuance Expense and Discounts (Premiums)	5,493	5,717
Senior unsecured notes	$ 344,507	$ 344,283
6.500% senior unsecured notes due October 2025
Debt Instrument [Line Items]
Senior unsecured notes, stated rate	6.50%	6.50%
Principal	$ 550,000	$ 550,000
Unamortized Debt Issuance Expense and Discounts (Premiums)	9,157	9,462
Senior unsecured notes	$ 540,843	$ 540,538
6.250% senior unsecured notes due May 2026
Debt Instrument [Line Items]
Senior unsecured notes, stated rate	6.25%	6.25%	6.25%
Principal	$ 450,000	$ 450,000	$ 450,000
Unamortized Debt Issuance Expense and Discounts (Premiums)	7,920	8,002
Senior unsecured notes	442,080	441,998
Line of Credit
Debt Instrument [Line Items]
Unamortized Debt Issuance Expense and Discounts (Premiums)	$ 0	$ 0

Debt (Narrative) (Details)

Debt (Narrative) (Details) - USD ($)	Feb. 15, 2018	Dec. 11, 2017	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017	Feb. 08, 2013
Debt Instrument [Line Items]
Debt instrument, redemption price percentage	101.438%
Loss on extinguishment of debt	$ 3,300,000		$ 3,339,000	$ 0
Amended Facility | Accordion Feature
Debt Instrument [Line Items]
Line of credit facility aggregate maximum borrowing capacity			$ 2,000,000,000
Eurodollar Rate | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			3.00%
Letter of credit, fee percentage			1.50%
Eurodollar Rate | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			1.50%
Letter of credit, fee percentage			3.00%
Alternate Base Rate | Minimum
Debt Instrument [Line Items]
Letter of credit, fee percentage			0.50%
Alternate Base Rate | Maximum
Debt Instrument [Line Items]
Letter of credit, fee percentage			2.00%
Senior Secured Credit Facility
Debt Instrument [Line Items]
Credit facility, amount outstanding			$ 1,279,000,000
Total amount available for borrowings under credit facility			419,800,000
Senior Secured Credit Facility | Letters Of Credit
Debt Instrument [Line Items]
Letters of credit, outstanding amount			1,200,000
Senior Secured Credit Facility | Amended Facility
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity			1,700,000,000
Senior Secured Credit Facility | Amended Facility | Accordion Feature
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity			$ 300,000,000
Senior Secured Credit Facility | Minimum
Debt Instrument [Line Items]
Line of credit, unused capacity commitment fee percentage			0.25%
Senior Secured Credit Facility | Maximum
Debt Instrument [Line Items]
Line of credit, unused capacity commitment fee percentage			0.50%
Senior Secured Credit Facility | Maximum | Letters Of Credit
Debt Instrument [Line Items]
Letters of credit, outstanding amount			$ 100,000,000
Senior Secured Credit Facility | Petroleum Products
Debt Instrument [Line Items]
Credit facility, amount outstanding			$ 40,500,000
5.750% senior unsecured notes due February 2021
Debt Instrument [Line Items]
Senior unsecured notes, stated rate			5.75%		5.75%	5.75%
Debt issued			$ 0		$ 145,170,000
Proceeds used to repay unsecured debt principal		$ 204,800,000
6.500% Senior Unsecured Notes Due October 2025
Debt Instrument [Line Items]
Senior unsecured notes, stated rate			6.50%		6.50%
Debt issued			$ 550,000,000		$ 550,000,000
6.250% senior unsecured notes due May 2026
Debt Instrument [Line Items]
Senior unsecured notes, stated rate		6.25%	6.25%		6.25%
Debt issued		$ 450,000,000	$ 450,000,000		$ 450,000,000
Proceeds from issuance of unsecured debt		$ 441,800,000

Partners' Capital, Mezzanine 68

Partners' Capital, Mezzanine Equity and Distributions (Distributions) (Details) - USD ($) $ / shares in Units, $ in Thousands	May 15, 2018	Feb. 14, 2018	Nov. 14, 2017	Aug. 14, 2017	May 15, 2017
Partners Capital And Distributions [Line Items]
Date Paid		Feb. 14, 2018	Nov. 14, 2017	Aug. 14, 2017	May 15, 2017
Per Unit Amount (in dollars per unit)		$ 0.5100	$ 0.5000	$ 0.7225	$ 0.7200
Total Amount		$ 62,515	$ 61,290	$ 88,563	$ 88,257
Subsequent Event | Scenario, Forecast
Partners Capital And Distributions [Line Items]
Date Paid	May 15, 2018
Per Unit Amount (in dollars per unit)	$ 0.5200
Total Amount	$ 63,741

Partners' Capital, Mezzanine 69

Partners' Capital, Mezzanine Equity and Distributions (Narrative) (Details) $ / shares in Units, $ in Thousands	May 15, 2018$ / sharesshares	Sep. 01, 2017USD ($)$ / sharesshares	Jan. 31, 2018USD ($)shares	Mar. 31, 2018USD ($)shares	Dec. 31, 2017shares
Temporary Equity [Line Items]
Partners' capital, units outstanding (in shares)				122,579,218	122,579,218
Number of convertible preferred units issued (in shares)				22,901,980	22,411,728
Class A Convertible Preferred Stock Units
Temporary Equity [Line Items]
Distribution paid-in-kind | $			$ 16,500	$ 16,527
Distributions paid-in-kind, shares (in shares)			490,252	490,252
Preferred units, cumulative cash distributions | $				$ 16,900
Private Placement | Class A Convertible Preferred Stock Units
Temporary Equity [Line Items]
Temporary Equity, Stock Issued During Period, Value, New Issues | $		$ 750,000
Number of convertible preferred units issued (in shares)		22,249,494
Cash purchase price per unit (in dollars per share) | $ / shares		$ 33.71
Number of initial purchasers		2
Partners’ Capital | Common Class A
Temporary Equity [Line Items]
Partners' capital, units outstanding (in shares)				122,539,221
Partners’ Capital | Common Class B
Temporary Equity [Line Items]
Partners' capital, units outstanding (in shares)				39,997
Subsequent Event | Class A Convertible Preferred Stock Units
Temporary Equity [Line Items]
Distributions paid-in-kind, shares (in shares)	500,976
Subsequent Event | Class A Convertible Preferred Stock Units | Quarterly Rate
Temporary Equity [Line Items]
Stock dividend rate per unit (in dollars per share) | $ / shares	$ 0.7374
Subsequent Event | Class A Convertible Preferred Stock Units | In Arrears At Annual Rate
Temporary Equity [Line Items]
Stock dividend rate per unit (in dollars per share) | $ / shares	$ 2.9496

Partners' Capital, Mezzanine 70

Partners' Capital, Mezzanine Equity and Distributions (Change in Class A Convertible Preferred Units) (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended
	Jan. 31, 2018	Mar. 31, 2018
Mezzanine Capital Balance
Balance as of December 31, 2017	$ 697,151	$ 697,151
Balance as of March 31, 2018		$ 712,687
Number of Class A Convertible Preferred Units
Balance as of December 31, 2017	22,411,728	22,411,728
Balance as of March 31, 2018		22,901,980
Class A Convertible Preferred Stock Units
Mezzanine Capital Balance
Balance as of December 31, 2017	$ 697,151	$ 697,151
Distribution paid-in-kind	$ 16,500	16,527
Allocation of Distribution paid in-kind to Preferred Distribution Rate Reset Election (Note 16)		(991)
Balance as of March 31, 2018		$ 712,687
Number of Class A Convertible Preferred Units
Balance as of December 31, 2017	22,411,728	22,411,728
Distribution paid-in-kind	490,252	490,252
Balance as of March 31, 2018		22,901,980

Net Income Per Common Unit (Det

Net Income Per Common Unit (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Earnings Per Share Reconciliation [Abstract]
Net Income Attributable to Genesis Energy L.P.	$ 8,034	$ 27,090
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(16,888)	0
Net Income (loss) Available to Common Unitholders	$ (8,854)	$ 27,090
Weighted Average Outstanding Shares (in shares)	122,579,000	118,388,000
Basic and Diluted Net Income per Common Unit (in dollars per unit)	$ (0.07)	$ 0.23
Alkali Business
Earnings Per Share Reconciliation [Abstract]
Basic and Diluted Net Income per Common Unit (in dollars per unit)		$ 0.23
Class A Convertible Preferred Stock Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities not included in computation of dilutive earnings (in shares)	22,901,980

Business Segment Information (N

Business Segment Information (Narrative) (Details)	3 Months Ended
	Mar. 31, 2018segment
Segment Reporting [Abstract]
Number of reportable segments	4

Business Segment Information (S

Business Segment Information (Schedule of Segment Information) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Segment Reporting Information [Line Items]
Segment margin	$ 170,240	$ 138,645
Total revenues	725,808	415,491
Offshore pipeline transportation
Segment Reporting Information [Line Items]
Total revenues	73,260	85,128
Sodium minerals and sulfur services
Segment Reporting Information [Line Items]
Total revenues	285,910	45,046
Onshore Facilities & Transportation
Segment Reporting Information [Line Items]
Total revenues	317,709	235,015
Marine transportation
Segment Reporting Information [Line Items]
Total revenues	48,929	50,302
Operating Segments
Segment Reporting Information [Line Items]
Segment margin	170,240	138,645
Capital Expenditures	44,507	58,987
External customers	725,808	415,491
Operating Segments | Offshore pipeline transportation
Segment Reporting Information [Line Items]
Segment margin	73,173	87,089
Capital Expenditures	654	2,239
External customers	73,260	85,405
Operating Segments | Sodium minerals and sulfur services
Segment Reporting Information [Line Items]
Segment margin	64,391	17,496
Capital Expenditures	9,699	513
External customers	287,403	47,271
Operating Segments | Onshore Facilities & Transportation
Segment Reporting Information [Line Items]
Segment margin	21,689	21,097
Capital Expenditures	23,289	46,702
External customers	320,215	234,611
Operating Segments | Marine transportation
Segment Reporting Information [Line Items]
Segment margin	10,987	12,963
Capital Expenditures	10,865	9,533
External customers	44,930	48,204
Intersegment
Segment Reporting Information [Line Items]
Intersegment	0	0
Intersegment | Offshore pipeline transportation
Segment Reporting Information [Line Items]
Intersegment	0	(277)
Intersegment | Sodium minerals and sulfur services
Segment Reporting Information [Line Items]
Intersegment	(1,493)	(2,225)
Intersegment | Onshore Facilities & Transportation
Segment Reporting Information [Line Items]
Intersegment	(2,506)	404
Intersegment | Marine transportation
Segment Reporting Information [Line Items]
Intersegment	$ 3,999	$ 2,098

Business Segment Information 74

Business Segment Information (Schedule of Total Assets by Reportable Segment) (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Total consolidated assets	$ 7,109,836	$ 7,137,481
Other assets
Segment Reporting Information [Line Items]
Total consolidated assets	59,328	49,737
Offshore pipeline transportation
Segment Reporting Information [Line Items]
Total consolidated assets	2,472,742	2,486,803
Sodium Minerals & Sulfur Services
Segment Reporting Information [Line Items]
Total consolidated assets	1,842,607	1,848,188
Marine transportation
Segment Reporting Information [Line Items]
Total consolidated assets	819,057	824,777
Onshore Facilities & Transportation
Segment Reporting Information [Line Items]
Total consolidated assets	$ 1,916,102	$ 1,927,976

Business Segment Information (R

Business Segment Information (Reconciliation of Segment Margin to (Loss) Income from Continuing Operations) (Details) - USD ($) $ in Thousands	Feb. 15, 2018	Mar. 31, 2018	Mar. 31, 2017
Segment Reporting [Abstract]
Total Segment Margin		$ 170,240	$ 138,645
Corporate general and administrative expenses		(10,460)	(8,327)
Depreciation, depletion, amortization and accretion		(78,008)	(58,395)
Interest expense		(56,136)	(36,739)
Adjustment to exclude distributable cash generated by equity investees not included in income and include equity in investees net income (1)		(9,057)	(9,290)
Non-cash items not included in Segment Margin		(6,137)	437
Cash payments from direct financing leases in excess of earnings		(1,839)	(1,667)
Loss on extinguishment of debt	$ (3,300)	(3,339)	0
Differences in timing of cash receipts for certain contractual arrangements		3,331	2,681
Non-cash provision for leased items no longer in use		(186)	0
Income tax expense		(375)	(255)
NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P.		$ 8,034	$ 27,090

Transactions with Related Par76

Transactions with Related Parties (Schedule of Transactions with Related Parties) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Sandhill Group LLC
Related Party Transaction [Line Items]
Related party transaction, revenues	$ 543	$ 677
ANSAC
Related Party Transaction [Line Items]
Related party transaction, revenues	90,796	0
Related party transaction, costs and expenses	1,778	0
Poseidon Oil Pipeline Company
Related Party Transaction [Line Items]
Related party transaction, revenues	3,200	3,022
Related party transaction, costs and expenses	249	241
Chief Executive Officer
Related Party Transaction [Line Items]
Related party transaction, costs and expenses	$ 165	$ 165
Sandhill Group LLC
Related Party Transaction [Line Items]
Equity method investment, ownership percentage	50.00%
Poseidon Oil Pipeline Company
Related Party Transaction [Line Items]
Equity method investment, ownership percentage	64.00%

Transactions with Related Par77

Transactions with Related Parties (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Poseidon Oil Pipeline Company
Related Party Transaction [Line Items]
Due from related parties	$ 1,800		$ 2,200
Management Fees Revenue	2,200
Revenue from Related Parties	3,200	$ 3,022
Related Party Transaction, Expenses from Transactions with Related Party	249	241
ANSAC
Related Party Transaction [Line Items]
Due from related parties	71,276		$ 74,490
Revenue from Related Parties	90,796	0
Related Party Transaction, Expenses from Transactions with Related Party	$ 1,778	$ 0

Transactions with Related Par78

Transactions with Related Parties (ANSAC) (Details) - ANSAC - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Related Party Transaction [Line Items]
Receivables	$ 71,276	$ 74,490
Payables	$ 1,970	$ 1,223

Supplemental Cash Flow Inform79

Supplemental Cash Flow Information (Net Changes in Components of Operating Assets and Liabilities) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
(Increase) decrease in:
Accounts receivable	$ 27,368	$ 9,169
Inventories	(4,469)	6,009
Deferred charges	(4,161)	(348)
Other current assets	(7,694)	(4,605)
Increase (decrease) in:
Accounts payable	94	(17,305)
Accrued liabilities	(14,920)	(21,988)
Net changes in components of operating assets and liabilities	$ (3,782)	$ (29,068)

Supplemental Cash Flow Inform80

Supplemental Cash Flow Information (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Supplemental Cash Flow Elements [Abstract]
Payments of interest and commitment fees	$ 43	$ 46.7
Interest paid, capitalized	1.4	6
Incurred liabilities for fixed and intangible asset additions	$ 20.6	$ 31.6

Derivatives (Schedule of Outsta

Derivatives (Schedule of Outstanding Derivatives Entered Into to Hedge Inventory or Fixed Price Purchase Commitments) (Details) bbl in Thousands	3 Months Ended
	Mar. 31, 2018bbl$ / bbl$ / units
Designated as Hedging Instrument | Sell (Short) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (1,000 bbls)	243
Weighted average contract price per bbl | $ / bbl	62.41
Designated as Hedging Instrument | Buy (Long) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (1,000 bbls)	0
Weighted average contract price per bbl | $ / bbl	0
Not Designated As Hedging Instrument | Sell (Short) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (1,000 bbls)	283
Weighted average contract price per bbl | $ / bbl	63.92
Not Designated As Hedging Instrument | Sell (Short) Contracts | Future | Natural Gas
Derivative [Line Items]
Contract volumes (1,000 bbls)	35
Weighted average contract price per bbl | $ / bbl	2.74
Not Designated As Hedging Instrument | Sell (Short) Contracts | Future | Diesel Futures
Derivative [Line Items]
Contract volumes (1,000 bbls)	6
Weighted average contract price per bbl | $ / bbl	1.94
Not Designated As Hedging Instrument | Sell (Short) Contracts | Future | NYM RBOB Gas Futures
Derivative [Line Items]
Contract volumes (1,000 bbls)	24
Weighted average contract price per bbl | $ / bbl	1.97
Not Designated As Hedging Instrument | Sell (Short) Contracts | Future | Fuel Oil Futures
Derivative [Line Items]
Contract volumes (1,000 bbls)	397
Weighted average contract price per bbl | $ / bbl	54.55
Not Designated As Hedging Instrument | Sell (Short) Contracts | Swap | Natural Gas
Derivative [Line Items]
Contract volumes (1,000 bbls)	275
Weighted average contract price per bbl | $ / bbl	0.61
Not Designated As Hedging Instrument | Sell (Short) Contracts | Options | Crude Oil
Derivative [Line Items]
Contract volumes (1,000 bbls)	70
Weighted average premium received | $ / bbl	1.16
Not Designated As Hedging Instrument | Buy (Long) Contracts | Future | Crude Oil
Derivative [Line Items]
Contract volumes (1,000 bbls)	145
Weighted average contract price per bbl | $ / bbl	64.68
Not Designated As Hedging Instrument | Buy (Long) Contracts | Future | Natural Gas
Derivative [Line Items]
Contract volumes (1,000 bbls)	275
Weighted average contract price per bbl | $ / bbl	2.83
Not Designated As Hedging Instrument | Buy (Long) Contracts | Future | Diesel Futures
Derivative [Line Items]
Contract volumes (1,000 bbls)	0
Weighted average contract price per bbl | $ / bbl	0
Not Designated As Hedging Instrument | Buy (Long) Contracts | Future | NYM RBOB Gas Futures
Derivative [Line Items]
Contract volumes (1,000 bbls)	16
Weighted average contract price per bbl | $ / bbl	1.94
Not Designated As Hedging Instrument | Buy (Long) Contracts | Future | Fuel Oil Futures
Derivative [Line Items]
Contract volumes (1,000 bbls)	40
Weighted average contract price per bbl | $ / bbl	54.03
Not Designated As Hedging Instrument | Buy (Long) Contracts | Swap | Natural Gas
Derivative [Line Items]
Contract volumes (1,000 bbls)	0
Weighted average contract price per bbl | $ / units	0
Not Designated As Hedging Instrument | Buy (Long) Contracts | Options | Crude Oil
Derivative [Line Items]
Contract volumes (1,000 bbls)	20
Weighted average premium received | $ / bbl	0.29

Derivatives (Schedule of Fair V

Derivatives (Schedule of Fair Value of Derivative Assets and Liabilities) (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Derivatives, Fair Value [Line Items]
Embedded Derivative, Fair Value, Liability	$ (48,100)
Preferred Distribution Rate Reset Election | Other long-term liabilities
Derivatives, Fair Value [Line Items]
Embedded Derivative, Fair Value, Liability	(48,106)	$ (45,209)
Not Designated As Hedging Instrument | Commodity Derivatives | Current Assets - Other
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	394	505
Derivative Asset, Fair Value, Gross Liability	(394)	(505)
Derivative Asset	0	0
Derivative Liability, Fair Value, Gross Liability	(1,001)	(1,203)
Derivative Liability, Fair Value, Gross Asset	1,001	1,203
Derivative Liability	0	0
Not Designated As Hedging Instrument | Swap | Accrued Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	(358)	0
Designated as Hedging Instrument | Commodity Derivatives | Current Assets - Other
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	34	54
Derivative Asset, Fair Value, Gross Liability	(34)	(54)
Derivative Asset	0	0
Derivative Liability, Fair Value, Gross Liability	(646)	(863)
Derivative Liability, Fair Value, Gross Asset	646	338
Derivative Liability	$ 0	$ (525)

Derivatives (Narrative) (Detail

Derivatives (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2017USD ($)	Sep. 01, 2022	Mar. 31, 2018USD ($)
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Net broker receivable	$ 1		$ 1.9
Initial margin	1.3		1.9
(Decrease) increase in margin deposits outstanding	$ (0.3)
Derivatives, Fair Value [Line Items]
Embedded derivative liability			$ 48.1
Scenario, Forecast | Class A Convertible Preferred Stock Units
Derivatives, Fair Value [Line Items]
Stock reset rate percentage		10.75%
Percentage below issue price per share		110.00%
LIBOR | Scenario, Forecast | Class A Convertible Preferred Stock Units
Derivatives, Fair Value [Line Items]
Basis spread on variable rate over stock price		7.50

Derivatives (Schedule of Effect

Derivatives (Schedule of Effect on Operating Results) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Commodity Derivatives | Onshore Facilities and Transportation Product Costs & Sodium Minerals and Sulfur Services Operating costs [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	$ (1,698)	$ 7,379
Commodity Derivatives | Designated as Hedging Instrument | Onshore facilities and transportation product costs
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	(1,366)	6,286
Commodity Derivatives | Not Designated As Hedging Instrument | Onshore Facilities and Transportation Product Costs & Sodium Minerals and Sulfur Services Operating costs [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	(332)	1,093
Swap | Not Designated As Hedging Instrument | Sodium minerals and sulfur services operating costs
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	(275)	0
Preferred Distribution Rate Reset Election | Other expense
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income	$ (1,906)	$ 0

Fair-Value Measurements (Placem

Fair-Value Measurements (Placement of Assets and Liabilities Within the Fair Value Hierarchy Levels) (Details) - Recurring Fair Value Measures - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Level 1 | Commodity Derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	$ 428	$ 559
Level 1 | Swap
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value	(1,647)	(2,066)
Level 1 | Preferred Distribution Rate Reset Election
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value	0	0
Level 2 | Commodity Derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	0	0
Level 2 | Swap
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value	(358)	0
Level 2 | Preferred Distribution Rate Reset Election
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value	0	0
Level 3 | Commodity Derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	0	0
Level 3 | Swap
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value	0	0
Level 3 | Preferred Distribution Rate Reset Election
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liabilities Fair Value	$ (48,106)	$ (45,209)

Fair-Value Measurements (Reconc

Fair-Value Measurements (Reconciliation of Changes in Derivatives Classified as Level 3) (Details) - Level 3 $ in Thousands	3 Months Ended
	Mar. 31, 2018USD ($)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance as of December 31, 2017	$ (45,209)
Net Loss for the period included in earnings	(1,906)
Allocation of Distribution Paid-in-kind	(991)
Balance as of March 31, 2018	$ (48,106)

Fair-Value Measurements (Narrat

Fair-Value Measurements (Narrative) (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Senior unsecured notes	$ 2,456,749	$ 2,598,918
Fair value of senior unsecured notes	$ 2,500,000	$ 2,700,000

Commitments and Contingencies (

Commitments and Contingencies (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Jun. 30, 2017	Mar. 31, 2017
Write off of Amortization of Leased Assets [Line Items]
Non-cash provision for leased items no longer in use	$ 186		$ 0
Loss Contingency Accrual	9,300
Accrued Liabilities
Write off of Amortization of Leased Assets [Line Items]
Loss contingency, accrual, current	$ 3,900
Onshore Facilities & Transportation
Write off of Amortization of Leased Assets [Line Items]
Non-cash provision for leased items no longer in use		$ 12,600

Condensed Consolidating Finan89

Condensed Consolidating Financial Information (Narrative) (Details) $ in Billions	3 Months Ended
	Mar. 31, 2018USD ($)
Condensed Financial Statements, Captions [Line Items]
Guarantor Obligations, Current Carrying Value	$ 2.5
Genesis NEJD Pipeline, LLC
Condensed Financial Statements, Captions [Line Items]
Percentage of equity interest	100.00%

Condensed Consolidating Finan90

Condensed Consolidating Financial Information (Condensed Consolidating Balance Sheet) (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Jan. 01, 2018	Dec. 31, 2017	Mar. 31, 2017	Dec. 31, 2016
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	$ 16,092		$ 9,041	$ 10,773	$ 7,029
Other current assets	564,002		626,992
Total current assets	580,094		636,033
Fixed assets, at cost	5,652,880		5,601,015
Less: Accumulated depreciation	(802,261)		(734,986)
Net fixed assets	4,850,619		4,866,029
Mineral Properties, Net	563,369		564,506
Goodwill	325,046		325,046
Other assets, net	418,215		364,317
Advances to affiliates	0		0
Equity investees	372,493		381,550
Investments in subsidiaries	0		0
TOTAL ASSETS	7,109,836		7,137,481
Current liabilities	415,690		456,264
Senior secured credit facility, principal	1,279,000		1,099,200
Senior unsecured notes	2,456,749		2,598,918
Deferred tax liabilities	12,138		11,913
Advances from affiliates	0		0
Other long-term liabilities	290,401	$ 276,435	256,571
Total liabilities	4,453,978		4,422,866
Class A Convertible Preferred Units	712,687		697,151
Partner's capital	1,951,590	$ 2,022,597	2,026,147
Accumulated Other Comprehensive Income (Loss), Net of Tax	(604)		(604)
Noncontrolling interests	(7,815)		(8,079)
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	7,109,836		7,137,481
Reportable Legal Entities | 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
Mineral Properties, Net	0		0
Goodwill	0		0
Other assets, net	0		0
Advances to affiliates	0		0
Equity investees	0		0
Investments in subsidiaries	0		0
TOTAL ASSETS	0		0
Current liabilities	0		0
Senior secured credit facility, principal	0		0
Senior unsecured notes	0		0
Deferred tax liabilities	0		0
Advances from affiliates	0		0
Other long-term liabilities	0		0
Total liabilities	0		0
Class A Convertible Preferred Units	0		0
Partner's capital	0		0
Accumulated Other Comprehensive Income (Loss), Net of Tax	0		0
Noncontrolling interests	0		0
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	0		0
Reportable Legal Entities | Genesis Energy, L.P. (Parent and Co-Issuer)
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	6		6	6	6
Other current assets	25		50
Total current assets	31		56
Fixed assets, at cost	0		0
Less: Accumulated depreciation	0		0
Net fixed assets	0		0
Mineral Properties, Net	0		0
Goodwill	0		0
Other assets, net	13,083		14,083
Advances to affiliates	3,799,305		3,808,712
Equity investees	0		0
Investments in subsidiaries	2,693,391		2,689,861
TOTAL ASSETS	6,505,810		6,512,712
Current liabilities	57,677		46,086
Senior secured credit facility, principal	1,279,000		1,099,200
Senior unsecured notes	2,456,749		2,598,918
Deferred tax liabilities	0		0
Advances from affiliates	0		0
Other long-term liabilities	48,107		45,210
Total liabilities	3,841,533		3,789,414
Class A Convertible Preferred Units	712,687		697,151
Partner's capital	1,951,590		2,026,147
Accumulated Other Comprehensive Income (Loss), Net of Tax	0		0
Noncontrolling interests	0		0
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	6,505,810		6,512,712
Reportable Legal Entities | Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	14,677		8,340	9,638	6,360
Other current assets	551,885		614,682
Total current assets	566,562		623,022
Fixed assets, at cost	5,575,295		5,523,431
Less: Accumulated depreciation	(774,919)		(708,269)
Net fixed assets	4,800,376		4,815,162
Mineral Properties, Net	563,369		564,506
Goodwill	325,046		325,046
Other assets, net	438,693		378,371
Advances to affiliates	0		0
Equity investees	372,493		381,550
Investments in subsidiaries	83,624		82,616
TOTAL ASSETS	7,150,163		7,170,273
Current liabilities	348,421		399,017
Senior secured credit facility, principal	0		0
Senior unsecured notes	0		0
Deferred tax liabilities	12,138		11,913
Advances from affiliates	3,888,239		3,894,027
Other long-term liabilities	214,494		182,414
Total liabilities	4,463,292		4,487,371
Class A Convertible Preferred Units	0		0
Partner's capital	2,687,475		2,683,506
Accumulated Other Comprehensive Income (Loss), Net of Tax	(604)		(604)
Noncontrolling interests	0		0
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	7,150,163		7,170,273
Reportable Legal Entities | Non-Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	1,409		695	1,129	663
Other current assets	12,137		12,316
Total current assets	13,546		13,011
Fixed assets, at cost	77,585		77,584
Less: Accumulated depreciation	(27,342)		(26,717)
Net fixed assets	50,243		50,867
Mineral Properties, Net	0		0
Goodwill	0		0
Other assets, net	124,242		126,300
Advances to affiliates	89,334		85,423
Equity investees	0		0
Investments in subsidiaries	0		0
TOTAL ASSETS	277,365		275,601
Current liabilities	10,137		11,417
Senior secured credit facility, principal	0		0
Senior unsecured notes	0		0
Deferred tax liabilities	0		0
Advances from affiliates	0		0
Other long-term liabilities	185,456		183,237
Total liabilities	195,593		194,654
Class A Convertible Preferred Units	0		0
Partner's capital	89,587		89,026
Accumulated Other Comprehensive Income (Loss), Net of Tax	0		0
Noncontrolling interests	(7,815)		(8,079)
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	277,365		275,601
Eliminations
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	0		0	$ 0	$ 0
Other current assets	(45)		(56)
Total current assets	(45)		(56)
Fixed assets, at cost	0		0
Less: Accumulated depreciation	0		0
Net fixed assets	0		0
Mineral Properties, Net	0		0
Goodwill	0		0
Other assets, net	(157,803)		(154,437)
Advances to affiliates	(3,888,639)		(3,894,135)
Equity investees	0		0
Investments in subsidiaries	(2,777,015)		(2,772,477)
TOTAL ASSETS	(6,823,502)		(6,821,105)
Current liabilities	(545)		(256)
Senior secured credit facility, principal	0		0
Senior unsecured notes	0		0
Deferred tax liabilities	0		0
Advances from affiliates	(3,888,239)		(3,894,027)
Other long-term liabilities	(157,656)		(154,290)
Total liabilities	(4,046,440)		(4,048,573)
Class A Convertible Preferred Units	0		0
Partner's capital	(2,777,062)		(2,772,532)
Accumulated Other Comprehensive Income (Loss), Net of Tax	0		0
Noncontrolling interests	0		0
TOTAL LIABILITIES, MEZZANINE CAPITAL AND PARTNERS’ CAPITAL	$ (6,823,502)		$ (6,821,105)

Condensed Consolidating Finan91

Condensed Consolidating Financial Information (Condensed Consolidating Statement of Operations) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Condensed Financial Statements, Captions [Line Items]
Offshore pipeline transportation services	$ 73,260	$ 85,128
Sodium minerals and sulfur services	285,910	45,046
Marine transportation	48,929	50,302
Onshore facilities and transportation	317,709	235,015
Total revenues	725,808	415,491
Onshore Facilities and Transportation Products and Operating Costs	300,113	214,332
Marine transportation costs	37,847	37,242
Sodium minerals and sulfur services operating costs	223,498	27,364
Offshore pipeline transportation operating costs	18,340	17,868
General and administrative	11,674	9,976
Depreciation, depletion and amortization	75,255	56,112
Total costs and expenses	666,727	362,894
OPERATING INCOME	59,081	52,597
Equity in earnings of subsidiaries	0	0
Equity in earnings of equity investees	10,572	11,335
Interest (expense) income, net	(56,136)	(36,739)
Other expense	(5,244)	0
Income before income taxes	8,273	27,193
Income tax (expense) benefit	(375)	(255)
NET INCOME	7,898	26,938
Net loss attributable to noncontrolling interest	136	152
NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P.	8,034	27,090
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(16,888)	0
Net Income (loss) Available to Common Unitholders	(8,854)	27,090
Reportable Legal Entities | Genesis Energy Finance Corporation (Co-Issuer)
Condensed Financial Statements, Captions [Line Items]
Offshore pipeline transportation services	0	0
Sodium minerals and sulfur services	0	0
Marine transportation	0	0
Onshore facilities and transportation	0	0
Total revenues	0	0
Onshore Facilities and Transportation Products and Operating Costs	0	0
Marine transportation costs	0	0
Sodium minerals and sulfur services operating costs	0	0
Offshore pipeline transportation operating costs	0	0
General and administrative	0	0
Depreciation, depletion and amortization	0	0
Total costs and expenses	0	0
OPERATING INCOME	0	0
Equity in earnings of subsidiaries	0	0
Equity in earnings of equity investees	0	0
Interest (expense) income, net	0	0
Other expense	0
Income before income taxes	0	0
Income tax (expense) benefit	0	0
NET INCOME	0	0
Net loss attributable to noncontrolling interest	0	0
NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P.	0	0
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	0	0
Net Income (loss) Available to Common Unitholders	0	0
Reportable Legal Entities | Genesis Energy, L.P. (Parent and Co-Issuer)
Condensed Financial Statements, Captions [Line Items]
Offshore pipeline transportation services	0	0
Sodium minerals and sulfur services	0	0
Marine transportation	0	0
Onshore facilities and transportation	0	0
Total revenues	0	0
Onshore Facilities and Transportation Products and Operating Costs	0	0
Marine transportation costs	0	0
Sodium minerals and sulfur services operating costs	0	0
Offshore pipeline transportation operating costs	0	0
General and administrative	0	0
Depreciation, depletion and amortization	0	0
Total costs and expenses	0	0
OPERATING INCOME	0	0
Equity in earnings of subsidiaries	69,592	63,809
Equity in earnings of equity investees	0	0
Interest (expense) income, net	(56,314)	(36,719)
Other expense	(5,244)
Income before income taxes	8,034	27,090
Income tax (expense) benefit	0	0
NET INCOME	8,034	27,090
Net loss attributable to noncontrolling interest	0	0
NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P.	8,034	27,090
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	(16,888)	0
Net Income (loss) Available to Common Unitholders	(8,854)	27,090
Reportable Legal Entities | Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Offshore pipeline transportation services	73,260	85,128
Sodium minerals and sulfur services	285,097	45,034
Marine transportation	48,929	50,302
Onshore facilities and transportation	312,874	230,070
Total revenues	720,160	410,534
Onshore Facilities and Transportation Products and Operating Costs	299,841	214,071
Marine transportation costs	37,847	37,242
Sodium minerals and sulfur services operating costs	223,247	27,153
Offshore pipeline transportation operating costs	17,662	17,106
General and administrative	11,674	9,976
Depreciation, depletion and amortization	74,630	55,487
Total costs and expenses	664,901	361,035
OPERATING INCOME	55,259	49,499
Equity in earnings of subsidiaries	632	(250)
Equity in earnings of equity investees	10,572	11,335
Interest (expense) income, net	3,544	3,520
Other expense	0
Income before income taxes	70,007	64,104
Income tax (expense) benefit	(377)	(255)
NET INCOME	69,630	63,849
Net loss attributable to noncontrolling interest	0	0
NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P.	69,630	63,849
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	0	0
Net Income (loss) Available to Common Unitholders	69,630	63,849
Reportable Legal Entities | Non-Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Offshore pipeline transportation services	0
Sodium minerals and sulfur services	3,066	1,810
Marine transportation	0	0
Onshore facilities and transportation	4,835	4,945
Total revenues	7,901	6,755
Onshore Facilities and Transportation Products and Operating Costs	272	261
Marine transportation costs	0	0
Sodium minerals and sulfur services operating costs	2,504	2,009
Offshore pipeline transportation operating costs	678	762
General and administrative	0	0
Depreciation, depletion and amortization	625	625
Total costs and expenses	4,079	3,657
OPERATING INCOME	3,822	3,098
Equity in earnings of subsidiaries	0	0
Equity in earnings of equity investees	0	0
Interest (expense) income, net	(3,366)	(3,540)
Other expense	0
Income before income taxes	456	(442)
Income tax (expense) benefit	2	0
NET INCOME	458	(442)
Net loss attributable to noncontrolling interest	136	152
NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P.	594	(290)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	0	0
Net Income (loss) Available to Common Unitholders	594	(290)
Eliminations
Condensed Financial Statements, Captions [Line Items]
Offshore pipeline transportation services	0	0
Sodium minerals and sulfur services	(2,253)	(1,798)
Marine transportation	0	0
Onshore facilities and transportation	0	0
Total revenues	(2,253)	(1,798)
Onshore Facilities and Transportation Products and Operating Costs	0	0
Marine transportation costs	0	0
Sodium minerals and sulfur services operating costs	(2,253)	(1,798)
Offshore pipeline transportation operating costs	0	0
General and administrative	0	0
Depreciation, depletion and amortization	0	0
Total costs and expenses	(2,253)	(1,798)
OPERATING INCOME	0	0
Equity in earnings of subsidiaries	(70,224)	(63,559)
Equity in earnings of equity investees	0	0
Interest (expense) income, net	0	0
Other expense	0
Income before income taxes	(70,224)	(63,559)
Income tax (expense) benefit	0	0
NET INCOME	(70,224)	(63,559)
Net loss attributable to noncontrolling interest	0	0
NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P.	(70,224)	(63,559)
Less: Accumulated distributions attributable to Class A Convertible Preferred Units	0	0
Net Income (loss) Available to Common Unitholders	$ (70,224)	$ (63,559)

Condensed Consolidating Finan92

Condensed Consolidating Financial Information (Condensed Consolidating Statement of Cash Flows) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	$ 86,328	$ 61,040
Payments to acquire fixed and intangible assets	(66,051)	(61,292)
Cash distributions received from equity investees - return of investment	9,277	9,083
Investments in equity investees		0
Acquisitions	0	0
Intercompany transfers	0	0
Repayments on loan to non-guarantor subsidiary	0	0
Contributions in aid of construction costs	0	124
Proceeds from asset sales	6	1,234
Other, net	0	0
Net cash used in investing activities	(56,768)	(50,851)
Borrowings on senior secured credit facility	333,800	216,700
Repayments on senior secured credit facility	(154,000)	(284,900)
Proceeds from issuance of senior unsecured notes	0
Repayments of Unsecured Debt	145,170	0
Proceeds from issuance of Class A convertible preferred units, net	0
Debt issuance costs	(159)	0
Intercompany transfers	0	0
Issuance of common units for cash, net	0	140,968
Distributions to partners/owners	(62,515)	(83,765)
Contributions from noncontrolling interest	400	0
Other, net	5,135	4,552
Net cash used in financing activities	(22,509)	(6,445)
Net increase in cash and cash equivalents	7,051	3,744
Cash and cash equivalents at beginning of period	9,041	7,029
Cash and cash equivalents at end of period	16,092	10,773
Reportable Legal Entities | Genesis Energy Finance Corporation (Co-Issuer)
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	0	0
Payments to acquire fixed and intangible assets	0	0
Cash distributions received from equity investees - return of investment	0	0
Investments in equity investees		0
Acquisitions	0	0
Intercompany transfers	0	0
Repayments on loan to non-guarantor subsidiary	0	0
Contributions in aid of construction costs	0	0
Proceeds from asset sales	0	0
Other, net	0	0
Net cash used in investing activities	0	0
Borrowings on senior secured credit facility	0	0
Repayments on senior secured credit facility	0	0
Proceeds from issuance of senior unsecured notes	0
Repayments of Unsecured Debt	0
Proceeds from issuance of Class A convertible preferred units, net	0
Debt issuance costs	0	0
Intercompany transfers	0	0
Issuance of common units for cash, net	0	0
Distributions to partners/owners	0	0
Contributions from noncontrolling interest	0	0
Other, net	0	0
Net cash used in financing activities	0	0
Net increase in cash and cash equivalents	0	0
Cash and cash equivalents at beginning of period	0	0
Cash and cash equivalents at end of period	0	0
Reportable Legal Entities | Genesis Energy, L.P. (Parent and Co-Issuer)
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	18,637	42,623
Payments to acquire fixed and intangible assets	0	0
Cash distributions received from equity investees - return of investment	0	0
Investments in equity investees		(140,968)
Acquisitions	0	0
Intercompany transfers	9,407	109,342
Repayments on loan to non-guarantor subsidiary	0	0
Contributions in aid of construction costs	0	0
Proceeds from asset sales	0	0
Other, net	0	0
Net cash used in investing activities	9,407	(31,626)
Borrowings on senior secured credit facility	333,800	216,700
Repayments on senior secured credit facility	(154,000)	(284,900)
Proceeds from issuance of senior unsecured notes	0
Repayments of Unsecured Debt	145,170
Proceeds from issuance of Class A convertible preferred units, net	0
Debt issuance costs	(159)	0
Intercompany transfers	0	0
Issuance of common units for cash, net	0	140,968
Distributions to partners/owners	(62,515)	(83,765)
Contributions from noncontrolling interest	0	0
Other, net	0	0
Net cash used in financing activities	(28,044)	(10,997)
Net increase in cash and cash equivalents	0	0
Cash and cash equivalents at beginning of period	6	6
Cash and cash equivalents at end of period	6	6
Reportable Legal Entities | Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	124,180	95,023
Payments to acquire fixed and intangible assets	(66,051)	(61,292)
Cash distributions received from equity investees - return of investment	9,277	9,083
Investments in equity investees		0
Acquisitions	0	0
Intercompany transfers	0	0
Repayments on loan to non-guarantor subsidiary	1,801	1,627
Contributions in aid of construction costs	0	124
Proceeds from asset sales	6	1,234
Other, net	0	0
Net cash used in investing activities	(54,967)	(49,224)
Borrowings on senior secured credit facility	0	0
Repayments on senior secured credit facility	0	0
Proceeds from issuance of senior unsecured notes	0
Repayments of Unsecured Debt	0
Proceeds from issuance of Class A convertible preferred units, net	0
Debt issuance costs	0	0
Intercompany transfers	(5,496)	(104,276)
Issuance of common units for cash, net	0	140,968
Distributions to partners/owners	(62,515)	(83,765)
Contributions from noncontrolling interest	0	0
Other, net	5,135	4,552
Net cash used in financing activities	(62,876)	(42,521)
Net increase in cash and cash equivalents	6,337	3,278
Cash and cash equivalents at beginning of period	8,340	6,360
Cash and cash equivalents at end of period	14,677	9,638
Reportable Legal Entities | Non-Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	874	2,007
Payments to acquire fixed and intangible assets	0	0
Cash distributions received from equity investees - return of investment	0	0
Investments in equity investees		0
Acquisitions	0	0
Intercompany transfers	0	0
Repayments on loan to non-guarantor subsidiary	0	0
Contributions in aid of construction costs	0	0
Proceeds from asset sales	0	0
Other, net	0	0
Net cash used in investing activities	0	0
Borrowings on senior secured credit facility	0	0
Repayments on senior secured credit facility	0	0
Proceeds from issuance of senior unsecured notes	0
Repayments of Unsecured Debt	0
Proceeds from issuance of Class A convertible preferred units, net	0
Debt issuance costs	0	0
Intercompany transfers	(3,911)	(5,066)
Issuance of common units for cash, net	0	0
Distributions to partners/owners	0	0
Contributions from noncontrolling interest	400	0
Other, net	3,351	3,525
Net cash used in financing activities	(160)	(1,541)
Net increase in cash and cash equivalents	714	466
Cash and cash equivalents at beginning of period	695	663
Cash and cash equivalents at end of period	1,409	1,129
Eliminations
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	(57,363)	(78,613)
Payments to acquire fixed and intangible assets	0	0
Cash distributions received from equity investees - return of investment	0	0
Investments in equity investees		140,968
Acquisitions	0	0
Intercompany transfers	(9,407)	(109,342)
Repayments on loan to non-guarantor subsidiary	(1,801)	(1,627)
Contributions in aid of construction costs	0	0
Proceeds from asset sales	0	0
Other, net	0	0
Net cash used in investing activities	(11,208)	29,999
Borrowings on senior secured credit facility	0	0
Repayments on senior secured credit facility	0	0
Proceeds from issuance of senior unsecured notes	0
Repayments of Unsecured Debt	0
Proceeds from issuance of Class A convertible preferred units, net	0
Debt issuance costs	0	0
Intercompany transfers	9,407	109,342
Issuance of common units for cash, net	0	(140,968)
Distributions to partners/owners	62,515	83,765
Contributions from noncontrolling interest	0	0
Other, net	(3,351)	(3,525)
Net cash used in financing activities	68,571	48,614
Net increase in cash and cash equivalents	0	0
Cash and cash equivalents at beginning of period	0	0
Cash and cash equivalents at end of period	$ 0	$ 0