10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

ý QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2012

OR

¨TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission file number 1-12295

GENESIS ENERGY, L.P.

(Exact name of registrant as specified in its charter)

Delaware	76-0513049
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
919 Milam, Suite 2100, Houston, TX	77002
(Address of principal executive offices)	(Zip code)
Registrant’s telephone number, including area code: (713) 860-2500

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  ý    No  ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or such shorter period that the registrant was required to submit and post such files).    Yes  ý    No  ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer  x Accelerated filer  ¨ Non-accelerated filer  ¨ Smaller reporting company  ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2) of the Exchange Act).    Yes  ¨    No  ý

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date. Class A Common Units outstanding as of November 1, 2012 was 81,162,755.

GENESIS ENERGY, L.P.

TABLE OF CONTENTS

		Page
	PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements	3
	Unaudited Condensed Consolidated Balance Sheets	3
	Unaudited Condensed Consolidated Statements of Operations	4
	Unaudited Condensed Consolidated Statements of Partners’ Capital	5
	Unaudited Condensed Consolidated Statements of Cash Flows	6
	Notes to Unaudited Condensed Consolidated Financial Statements	7
	1. Organization and Basis of Presentation and Consolidation	7
	2. Acquisitions	7
	3. Inventories	9
	4. Fixed Assets and Asset Retirement Obligations	9
	5. Equity Investees	10
	6. Intangible Assets	10
	7. Debt	11
	8. Partner's Capital and Distributions	12
	9. Business Segment Information	13
	10. Transactions with Related Parties	15
	11. Supplemental Cash Flow Information	16
	12. Derivatives	16
	13. Fair-Value Measurements	18
	14. Contingencies	19
	15. Income Taxes	19
	16. Condensed Consolidating Financial Information	19
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	28
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	40
Item 4.	Controls and Procedures	41
	PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	41
Item 1A.	Risk Factors	41
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	42
Item 3.	Defaults upon Senior Securities	42
Item 4.	Mine Safety Disclosures	42
Item 5.	Other Information	42
Item 6.	Exhibits	42
SIGNATURES		44

2

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except units)

	September 30, 2012			December 31, 2011
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	15,461		$	10,817
Accounts receivable - trade, net	318,892			237,989
Inventories	67,298			101,124
Other	25,616			26,174
Total current assets	427,267			376,104
FIXED ASSETS, at cost	684,663			541,138
Less: Accumulated depreciation	(148,712		)	(124,213		)
Net fixed assets	535,951			416,925
NET INVESTMENT IN DIRECT FINANCING LEASES, net of unearned income	158,698			162,460
EQUITY INVESTEES	547,925			326,947
INTANGIBLE ASSETS, net of amortization	79,140			93,356
GOODWILL	325,046			325,046
OTHER ASSETS, net of amortization	33,128			30,006
TOTAL ASSETS	$	2,107,155		$	1,730,844
LIABILITIES AND PARTNERS’ CAPITAL
CURRENT LIABILITIES:
Accounts payable - trade	$	254,688		$	199,357
Accrued liabilities	63,691			50,071
Total current liabilities	318,379			249,428
SENIOR SECURED CREDIT FACILITY	483,000			409,300
SENIOR UNSECURED NOTES	350,924			250,000
DEFERRED TAX LIABILITIES	11,598			12,549
OTHER LONG-TERM LIABILITIES	15,321			16,929
COMMITMENTS AND CONTINGENCIES (Note 14)
PARTNERS’ CAPITAL:
Common unitholders, 81,202,752 and 71,965,062 units issued and outstanding at September 30, 2012 and December 31, 2011, respectively	927,933			792,638
TOTAL LIABILITIES AND PARTNERS’ CAPITAL	$	2,107,155		$	1,730,844

The accompanying notes are an integral part of these Unaudited Condensed Consolidated Financial Statements.

3

GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except per unit amounts)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
REVENUES:
Supply and logistics	$	875,193		$	765,714		$	2,597,809		$	2,091,854
Refinery services	47,977			48,392			144,342			145,301
Pipeline transportation services	19,164			16,094			55,794			45,633
Total revenues	942,334			830,200			2,797,945			2,282,788
COSTS AND EXPENSES:
Supply and logistics product costs	811,896			710,355			2,412,404			1,961,038
Supply and logistics operating costs	40,953			33,478			119,576			83,516
Refinery services operating costs	29,243			30,136			91,072			89,986
Pipeline transportation operating costs	5,911			3,988			15,995			12,414
General and administrative	10,375			8,905			29,934			25,339
Depreciation and amortization	14,838			14,706			45,447			43,100
Total costs and expenses	913,216			801,568			2,714,428			2,215,393
OPERATING INCOME	29,118			28,632			83,517			67,395
Equity in earnings (losses) of equity investees	3,432			(412		)	7,971			3,377
Interest expense	(9,873		)	(8,960		)	(30,697		)	(26,670		)
Income before income taxes	22,677			19,260			60,791			44,102
Income tax benefit (expense)	8,517			(172		)	8,591			(626		)
NET INCOME	$	31,194		$	19,088		$	69,382		$	43,476
NET INCOME PER COMMON UNIT:
Basic and Diluted	$	0.39		$	0.27		$	0.90		$	0.65
WEIGHTED AVERAGE OUTSTANDING COMMON UNITS:
Basic and Diluted	79,901			70,447			77,410			66,580

The accompanying notes are an integral part of these Unaudited Condensed Consolidated Financial Statements.

4

GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL

(In thousands)

	Number of Common Units		Partners’ Capital
	2012	2011	2012			2011
Partners’ capital, January 1	71,965	64,615	$	792,638		$	669,264
Net income	—	—	69,382			43,476
Cash distributions	—	—	(104,008		)	(82,067		)
Issuance of common units for cash, net	5,750	7,350	169,421			184,969
Conversion of waiver units	3,476	—	—			—
Other	12	—	500			—
Partners' capital, September 30	81,203	71,965	$	927,933		$	815,642

The accompanying notes are an integral part of these Unaudited Condensed Consolidated Financial Statements.

5

GENESIS ENERGY, L.P.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

	Nine Months Ended September 30,
	2012			2011
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	69,382		$	43,476
Adjustments to reconcile net income to net cash provided by operating activities -
Depreciation and amortization	45,447			43,100
Amortization of debt issuance costs and premium	2,655			2,102
Amortization of unearned income and initial direct costs on direct financing leases	(12,641		)	(12,968		)
Payments received under direct financing leases	16,389			16,389
Equity in earnings of investments in equity investees	(7,971		)	(3,377		)
Cash distributions of earnings of equity investees	16,151			6,725
Non-cash effect of equity-based compensation plans	4,617			(1,505		)
Deferred and other tax liabilities	(9,156		)	(27		)
Unrealized gains on derivative transactions	(1,251		)	(4,370		)
Other, net	438			339
Net changes in components of operating assets and liabilities (Note 11)	18,878			(50,738		)
Net cash provided by operating activities	142,938			39,146
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	(116,702		)	(15,157		)
Cash distributions received from equity investees - return of investment	10,918			8,577
Investments in equity investees	(57,072		)	(194		)
Acquisitions	(205,576		)	(143,489		)
Proceeds from asset sales	667			4,444
Other, net	(1,012		)	129
Net cash used in investing activities	(368,777		)	(145,690		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	1,407,000			571,700
Repayments on senior secured credit facility	(1,333,300		)	(563,800		)
Proceeds from issuance of senior unsecured notes, including premium	101,000			—
Debt issuance costs	(7,109		)	(3,018		)
Issuance of common units for cash, net	169,421			184,969
Distributions to common unitholders	(104,008		)	(82,067		)
Other, net	(2,521		)	(2,626		)
Net cash provided by financing activities	230,483			105,158
Net increase (decrease) in cash and cash equivalents	4,644			(1,386		)
Cash and cash equivalents at beginning of period	10,817			5,762
Cash and cash equivalents at end of period	$	15,461		$	4,376

The accompanying notes are an integral part of these Unaudited Condensed Consolidated Financial Statements.

6

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

1. Organization and Basis of Presentation and Consolidation

Organization

We are a limited partnership focused on the midstream segment of the oil and gas industry in the Gulf Coast region of the United States, primarily Texas, Louisiana, Arkansas, Mississippi, Alabama, Florida and in the Gulf of Mexico. We have a diverse portfolio of assets, including pipelines, refinery-related plants, storage tanks and terminals, barges and trucks. We were formed in 1996 and are owned 100% by our limited partners. Genesis Energy, LLC, our general partner, is a wholly-owned subsidiary. Our general partner has sole responsibility for conducting our business and managing our operations. We conduct our operations and own our operating assets through our subsidiaries and joint ventures. We manage our businesses through the following three divisions that constitute our reportable segments:

• Pipeline transportation of interstate, intrastate and offshore crude oil, and, to a lesser extent, carbon dioxide (or "CO₂");

• Refinery services involving processing of high sulfur (or “sour”) gas streams for refineries to remove the sulfur and selling the related by-product, sodium hydrosulfide (or “NaHS”, commonly pronounced "nash"); and

• Supply and logistics services, which include terminaling, blending, storing, marketing, and transporting crude oil and petroleum products and, on a smaller scale, CO₂.

Basis of Presentation and Consolidation

The accompanying Unaudited Condensed Consolidated Financial Statements include Genesis Energy, L.P. and its subsidiaries, including Genesis Energy, LLC, our general partner.

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, 2011.

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.

2. Acquisitions

Interests in Gulf of Mexico Crude Oil Pipeline Systems

On January 3, 2012, we acquired from Marathon Oil Company interests in several Gulf of Mexico crude oil pipeline systems. The acquired pipeline interests include a 28% interest in Poseidon Oil Pipeline Company, L.L.C. (or “Poseidon”), a 100% interest in Marathon Offshore Pipeline, LLC (subsequently re-named GEL Offshore Pipeline, LLC, or “GOPL”) and a 29% interest in Odyssey Pipeline L.L.C. (or “Odyssey”). GOPL owns a 23% interest in the Eugene Island crude oil pipeline system and a 100% interest in two smaller offshore pipelines. The purchase price, net of post-closing adjustments, was $205.6 million. We funded the purchase price with cash available under our credit facility. We account for our interests in Poseidon and Odyssey under the equity method of accounting. We have recorded the assets acquired and liabilities assumed of GOPL in the Unaudited Condensed Consolidated Financial Statements at their estimated fair values on a preliminary basis. Management developed these preliminary fair values and we do not expect any material adjustments to these preliminary purchase price allocations as a result of the final valuation.

7

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The preliminary allocation of the purchase price is summarized as follows:

Property and equipment	$	28,456
Equity investees	182,993
Asset retirement obligation assumed	(5,873		)
Total allocation	$	205,576

The Poseidon pipeline system is comprised of a 367-mile network of crude oil pipelines, varying in diameter from 16 to 24 inches, with capacity to deliver approximately 400,000 barrels per day of crude oil from developments in the central and western offshore Gulf of Mexico to other pipelines and terminals onshore and offshore Louisiana. The Eugene Island pipeline system is primarily comprised of a 183-mile network of crude oil pipelines, the main pipeline of which is 20 inches in diameter, with capacity to deliver approximately 200,000 barrels per day of crude oil from developments in the central Gulf of Mexico to other pipelines and terminals onshore Louisiana. The Odyssey pipeline system is comprised of a 120-mile network of crude oil pipelines, varying in diameter from 12 to 20 inches, with capacity to deliver up to 300,000 barrels per day of crude oil from developments in the eastern Gulf of Mexico to other pipelines and terminals onshore Louisiana.

Our Unaudited Condensed Consolidated Financial Statements include the results of the acquired pipeline interests since the effective closing date of the acquisition in January 2012. The following table presents selected financial information included in our Unaudited Condensed Consolidated Financial Statements for the three and nine months ended September 30, 2012:

	Three Months Ended September 30,		Nine Months Ended September 30,
	2012
Revenues	$	1,180	$	4,334
Equity in earnings of equity investees	$	3,497	$	9,194
Net income	$	3,950	$	11,128

The table below presents selected unaudited pro forma financial information for the three and nine months ended September 30, 2011 incorporating the historical results of the acquired pipeline interests. The pro forma financial information below has been prepared as if the acquisition had been completed at the beginning of the prior year and is based upon assumptions deemed appropriate by us and may not be indicative of actual results.

	Three Months Ended September 30,		Nine Months Ended September 30,
	2011
Pro forma earnings data:
Revenues	$	831,956	$	2,288,056
Equity in earnings of equity investees	$	2,605	$	11,963
Net income	$	20,903	$	48,941
Basic and diluted earnings per unit:
As reported net income per unit	$	0.27	$	0.65
Pro forma net income per unit	$	0.30	$	0.74
As reported units outstanding	70,447		66,580
Pro forma units outstanding	70,447		66,580

FMT Black Oil Barge Transportation Business

In August 2011, we completed the acquisition of the black oil barge transportation business of Florida Marine Transporters, Inc. and its affiliates (“FMT”). The purchase price was $143.5 million (including $2.5 million for fuel inventory and other costs). The acquired business was comprised of 30 barges (seven of which were initially sub-leased under terms similar to those of an existing FMT lease, which we subsequently purchased in February 2012 for $30.6 million) and 14 push/tow boats which transport heavy refined products, primarily serving refineries and storage terminals along the Gulf Coast,

8

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Intracoastal Canal and western river systems of the United States, including the Red, Ouachita and Mississippi Rivers. The August 2011 acquisition and related transaction costs were funded with a portion of the net proceeds from the July 2011 public offering of our common units, whereby we raised approximately $185 million in net proceeds of equity capital. The February 2012 vessels purchase was funded with cash available under our credit facility.

The financial results of the acquired business are included in our supply and logistics segment from the date of the acquisition.

3. Inventories

The major components of inventories were as follows:

	September 30, 2012		December 31, 2011
Petroleum products	$	41,076	$	70,769
Crude oil	12,014		11,701
Caustic soda	6,829		11,312
NaHS	7,376		7,337
Other	3		5
Total	$	67,298	$	101,124

Inventories are valued at the lower of cost or market. At September 30, 2012 and December 31, 2011, market values of our inventories exceeded recorded costs.

4. Fixed Assets and Asset Retirement Obligations

Fixed Assets

Fixed assets consisted of the following:

	September 30, 2012			December 31, 2011
Pipelines and related assets	$	218,155		$	167,865
Machinery and equipment	63,091			46,233
Transportation equipment	20,280			21,732
Marine vessels	297,416			262,216
Land, buildings and improvements	14,037			13,140
Office equipment, furniture and fixtures	4,487			3,778
Construction in progress	53,135			14,236
Other	14,062			11,938
Fixed assets, at cost	684,663			541,138
Less: Accumulated depreciation	(148,712		)	(124,213		)
Net fixed assets	$	535,951		$	416,925

Our depreciation expense for the periods presented was as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
Depreciation expense	$	9,202	$	5,960	$	27,246	$	17,838

9

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Asset Retirement Obligations

A reconciliation of our liability for asset retirement obligations is as follows:

December 31, 2011	$	5,900
Liabilities incurred and assumed in the current period	5,995
Accretion expense	600
September 30, 2012	$	12,495

We assumed asset retirement obligations of $5.9 million related to pipelines in connection with our acquisition of GOPL. See Note 2 for information related to our acquisitions.

5. 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 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 September 30, 2012 and December 31, 2011, the unamortized excess cost amounts totaled $236.6 million and $97.8 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 September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
Genesis’ share of operating earnings	$	5,978		$	729		$	15,611		$	6,800
Amortization of excess purchase price	(2,546		)	(1,141		)	(7,640		)	(3,423		)
Net equity in earnings (losses)	$	3,432		$	(412	)	$	7,971		$	3,377
Distributions received	$	9,045		$	3,289		$	27,069		$	15,302

The following tables present the combined unaudited balance sheet and income statement information (on a 100% basis) of our equity investees:

	September 30, 2012		December 31, 2011
Balance Sheet Information:
Assets
Current assets	$	65,250	$	12,732
Fixed assets, net	760,788		441,894
Other assets	10,964		18,000
Total assets	$	837,002	$	472,626
Liabilities and equity
Current liabilities	$	53,667	$	5,891
Other liabilities	118,226		8,536
Equity	665,109		458,199
Total liabilities and equity	$	837,002	$	472,626

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
Income Statement Information:
Revenues	$	39,799	$	7,975	$	113,769	$	32,819
Operating income	$	19,810	$	576	$	53,597	$	11,768
Net income	$	19,196	$	576	$	51,553	$	11,778

10

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

6. Intangible Assets

The following table summarizes the components of our intangible assets at the dates indicated:

	September 30, 2012						December 31, 2011
	Gross Carrying Amount		Accumulated Amortization		Carrying Value		Gross Carrying Amount		Accumulated Amortization		Carrying Value
Refinery Services:
Customer relationships	$	94,654	$	67,403	$	27,251	$	94,654	$	62,111	$	32,543
Licensing agreements	38,678		22,038		16,640		38,678		19,476		19,202
Supplier relationships	36,469		35,878		591		36,469		34,105		2,364
Segment total	169,801		125,319		44,482		169,801		115,692		54,109
Supply & Logistics:
Customer relationships	35,430		25,698		9,732		35,430		23,584		11,846
Intangibles associated with lease	13,260		2,447		10,813		13,260		2,092		11,168
Trade names	18,888		18,888		—		18,888		17,048		1,840
Segment total	67,578		47,033		20,545		67,578		42,724		24,854
Other	18,467		4,354		14,113		17,292		2,899		14,393
Total	$	255,846	$	176,706	$	79,140	$	254,671	$	161,315	$	93,356

Our amortization expense for the periods presented was as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
Amortization expense	$	4,520	$	7,721	$	15,390	$	22,367

We estimate that our amortization expense for the next five years will be as follows:

Remainder of	2012	$	4,520
	2013	$	14,597
	2014	$	12,297
	2015	$	10,489
	2016	$	9,028

7. Debt

Our obligations under debt arrangements consisted of the following:

	September 30, 2012		December 31, 2011
Senior secured credit facility	$	483,000	$	409,300
7.875% senior unsecured notes (including unamortized premium of $924 and $0 in 2012 and 2011, respectively)	350,924		250,000
Total long-term debt	$	833,924	$	659,300

As of September 30, 2012, we were in compliance with the financial covenants contained in our credit agreement and senior unsecured notes indenture.

11

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Senior Secured Credit Facility

In July 2012, we amended and restated our senior secured credit facility with a syndicate of banks to, among other things, increase the committed amount from $775 million to $1 billion and the accordion feature from $225 million to $300 million, giving us the ability to expand the size of the facility up to an aggregate $1.3 billion for acquisitions or internal growth projects, subject to lender consent. The inventory financing sublimit tranche was increased from $125 million to $150 million, and the term of our credit facility was extended to July 25, 2017.

The key terms for rates under our credit facility, which are dependent on our leverage ratio (as defined in the credit agreement), are as follows:

• The applicable margin varies from 1.75% to 2.75% on eurodollar borrowings and from 0.75% to 1.75% on alternate base rate borrowings.

•Letter of credit fees range from 1.75% to 2.75%.

• The commitment fee on the unused committed amount will range from 0.375% to 0.50%.

At September 30, 2012, we had $483 million borrowed under our credit facility, with $48.6 million of the borrowed amount designated as a loan under the inventory sublimit. The credit agreement allows up to $100 million of the capacity to be used for letters of credit, of which $12.6 million was outstanding at September 30, 2012. 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 September 30, 2012 was $504.4 million.

Senior Unsecured Notes Issuance

On February 1, 2012, we issued an additional $100 million of aggregate principal amount of senior unsecured notes under our existing 7.875% senior unsecured notes due 2018 indenture. The notes were issued at 101% of face value at an effective interest rate of 7.682%. The notes have the same terms and conditions as the notes previously issued under the indenture. The issuance increased the total aggregate principal amount under the indenture to $350 million. The net proceeds were used to repay borrowings under our credit facility.

8. Partners’ Capital and Distributions

On March 28, 2012, we issued 5,750,000 Class A common units in a public offering at a price of $30.80 per unit. We received proceeds, net of underwriting discounts and offering costs, of $169.4 million from the offering. The net proceeds were used for general corporate purposes, including the repayment of borrowings under our credit facility. At September 30, 2012, our outstanding common units consisted of 81,162,755 Class A units and 39,997 Class B units.

Waiver Units

Our waiver units are non-voting securities entitled to a minimal preferential quarterly distribution. At issuance our waiver units were comprised of four classes (designated Class 1, Class 2, Class 3 and Class 4) of 1,738,000 units. The waiver units in each class are convertible into Class A common units in the calendar quarter at a 1:1 conversion rate during which each of our common units receives a specified minimum quarterly distribution and our distribution coverage ratio (after giving effect to the then convertible waiver units) would be at least 1.1 times. The minimum distribution per common unit required for conversion is $0.43 (Class 1), $0.46 (Class 2), $0.49 (Class 3) and $0.52 (Class 4).

On February 14, 2012, our Class 1 waiver units became convertible as we paid a distribution of $0.44 per common unit and satisfied the conversion coverage ratio requirement. All Class 1 waiver units were converted into common units by March 31, 2012.

On August 14, 2012, our Class 2 waiver units became convertible as we paid a distribution of $0.46 per common unit and satisfied the conversion coverage ratio requirement. All Class 2 waiver units were converted into common units by September 30, 2012.

At September 30, 2012, we had 3,476,466 waiver units outstanding comprised of the last two classes.

12

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Distributions

We paid or will pay the following distributions in 2011 and 2012:

Distribution For	Date Paid		Per Unit Amount		Total Amount
2011
1st Quarter	May 13, 2011		$	0.4075	$	26,343
2nd Quarter	August 12, 2011		$	0.4150	$	29,878
3rd Quarter	November 14, 2011		$	0.4275	$	30,777
4th Quarter	February 14, 2012		$	0.4400	$	31,677
2012
1st Quarter	May 15, 2012		$	0.4500	$	35,759
2nd Quarter	August 14, 2012		$	0.4600	$	36,554
3rd Quarter	November 14, 2012	(1)	$	0.4725	$	38,368

(1) This distribution will be paid to unitholders of record as of November 1, 2012.

9. Business Segment Information

Our operations consist of three operating segments:

(1) Pipeline Transportation – interstate, intrastate and offshore crude oil, and to a lesser extent, CO₂;

(2) Refinery Services – processing high sulfur (or “sour”) gas streams as part of refining operations to remove the sulfur and selling the related by-product, NaHS and;

(3) Supply and Logistics – terminaling, blending, storing, marketing, and transporting crude oil and petroleum products (primarily fuel oil, asphalt, and other heavy refined products) and, on a smaller scale, CO₂.

Substantially all of our revenues are derived from, and substantially all of our assets are located in, the United States.

We define Segment Margin as revenues less product costs, operating expenses (excluding non-cash charges, such as depreciation and amortization), and segment general and administrative expenses, plus our equity in distributable cash generated by our equity investees. In addition, our Segment Margin definition excludes the non-cash effects of our 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.

13

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Segment information for the periods presented below was as follows:

	Pipeline Transportation		Refinery Services			Supply & Logistics			Total
Three Months Ended September 30, 2012
Segment margin (a)	$	23,295	$	18,983		$	23,651		$	65,929
Capital expenditures (b)	$	21,764	$	1,025		$	14,410		$	37,199
Revenues:
External customers	$	16,190	$	50,378		$	875,766		$	942,334
Intersegment (c)	2,974		(2,401		)	(573		)	—
Total revenues of reportable segments	$	19,164	$	47,977		$	875,193		$	942,334
Three Months Ended September 30, 2011
Segment margin (a)	$	16,030	$	17,992		$	18,909		$	52,931
Capital expenditures (b)	$	1,582	$	852		$	146,999		$	149,433
Revenues:
External customers	$	12,658	$	50,982		$	766,560		$	830,200
Intersegment (c)	3,436		(2,590		)	(846		)	—
Total revenues of reportable segments	$	16,094	$	48,392		$	765,714		$	830,200
Nine Months Ended September 30, 2012
Segment margin (a)	$	69,427	$	53,510		$	66,075		$	189,012
Capital expenditures (b)	$	300,093	$	2,295		$	77,414		$	379,802
Revenues:
External customers	$	44,564	$	151,326		$	2,602,055		$	2,797,945
Intersegment (c)	11,230		(6,984		)	(4,246		)	—
Total revenues of reportable segments	$	55,794	$	144,342		$	2,597,809		$	2,797,945
Nine Months Ended September 30, 2011
Segment margin (a)	$	50,639	$	54,887		$	44,233		$	149,759
Capital expenditures (b)	$	3,264	$	1,321		$	149,126		$	153,711
Revenues:
External customers	$	37,302	$	151,899		$	2,093,587		$	2,282,788
Intersegment (c)	8,331		(6,598		)	(1,733		)	—
Total revenues of reportable segments	$	45,633	$	145,301		$	2,091,854		$	2,282,788

Total assets by reportable segment were as follows:

	September 30, 2012		December 31, 2011
Pipeline transportation	$	870,966	$	594,728
Refinery services	413,888		426,993
Supply and logistics	774,002		659,576
Other assets	48,299		49,547
Total consolidated assets	$	2,107,155	$	1,730,844

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(a) A reconciliation of Segment Margin to income before income taxes for the periods presented is as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
Segment Margin	$	65,929		$	52,931		$	189,012		$	149,759
Corporate general and administrative expenses	(9,428		)	(8,194		)	(26,756		)	(23,267		)
Depreciation and amortization	(14,838		)	(14,706		)	(45,447		)	(43,100		)
Interest expense	(9,873		)	(8,960		)	(30,697		)	(26,670		)
Distributable cash from equity investees in excess of equity in earnings	(5,613		)	(3,701		)	(19,098		)	(11,925		)
Non-cash items not included in segment margin	(2,222		)	3,061			(2,475		)	2,729
Cash payments from direct financing leases in excess of earnings	(1,278		)	(1,171		)	(3,748		)	(3,424		)
Income before income taxes	$	22,677		$	19,260		$	60,791		$	44,102

(b) Capital expenditures include maintenance and growth capital expenditures, such as fixed asset additions (including enhancements to existing facilities and construction of internal growth projects) as well as acquisitions of businesses and interests in equity investees. Capital spending in our pipeline transportation segment included $5.7 million and $57.1 million during the three and nine months ended September 30, 2012, respectively, representing capital contributions to our SEKCO equity investee to fund our share of the construction costs for its pipeline. For the nine months ended September 30, 2012, capital spending in our pipeline transportation segment also included $205.6 million for the acquisition of interests in several Gulf of Mexico pipelines. For the nine months ended September 30, 2012, capital spending in our supply and logistics segment also included $30.6 million for the purchase of barge assets.

(c) Intersegment sales were conducted under terms that we believe were no more or less favorable than then-existing market conditions.

10. 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 September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
Revenues:
Petroleum products sales to an affiliate of the Quintana Group (1)	$	6,376	$	5,948	$	21,142	$	27,202
Sales of CO2 to Sandhill Group, LLC (2)	838		946		2,111		1,921
Petroleum products sales to Davison family businesses (1)	326		737		1,012		1,224
Costs and expenses:
Marine operating fuel and expenses provided by an affiliate of the Quintana Group (1)	1,980		902		6,181		2,722
Amounts paid to our CEO in connection with the use of his aircraft	150		166		450		166

(1) The Quintana Group, a private equity fund based in Houston, Texas, owned 10% of our Class A common units and 74% of our Class B common units at September 30, 2012. The Davison family owned 15% of our Class A common units at September 30, 2012. The Quintana Group monetized all of its remaining investment in us on October 5, 2012. Substantially in connection with that transaction, certain members of the Davison family, collectively, increased their investment in us to 17.2% of our Class A common units and 76.9% of our Class B units. Soley for financial statement disclosure purposes, we will continue to treat the Davison family and their affiliates as related parties.

(2) We own a 50% interest in Sandhill Group, LLC.

Amounts due to and from Related Parties

At September 30, 2012 and December 31, 2011, an affiliate of the Quintana Group owed us $1.2 million and $1.9 million, respectively, for petroleum product sales. We owed such affiliate $0.1 million at September 30, 2012 and December 31, 2011, respectively, for marine related costs. Sandhill Group, LLC owed us $0.3 million and $0.2 million at September 30, 2012 and December 31, 2011, respectively, for purchases of CO₂.

15

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

11. Supplemental Cash Flow Information

The following table provides information regarding the net changes in components of operating assets and liabilities.

	Nine Months Ended September 30,
	2012			2011
(Increase) decrease in:
Accounts receivable	$	(80,789	)	$	(52,355	)
Inventories	33,826			(34,757		)
Other current assets	1,846			1,515
Increase (decrease) in:
Accounts payable	57,851			16,953
Accrued liabilities	6,144			17,906
Net changes in components of operating assets and liabilities	$	18,878		$	(50,738	)

Payments of interest and commitment fees were $24.4 million and $20.3 million for the nine months ended September 30, 2012 and 2011, respectively.

At September 30, 2012 and 2011, we had incurred liabilities for fixed and intangible asset additions totaling $4.8 million and $1.3 million, respectively, that had not been paid at the end of the third 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.

At September 30, 2012, we had incurred liabilities for other asset additions totaling $0.6 million that had not been paid at the end of the third quarter, and, therefore, were not included in the caption "Other, net" under Cash Flows from Investing Activities in the Unaudited Condensed Consolidated Statements of Cash Flows.

12. Derivatives

Commodity Derivatives

We have exposure to commodity price changes related to our inventory and purchase commitments. We utilize derivative instruments (primarily futures and options contracts traded on the NYMEX) to hedge our exposure to commodity prices, primarily of crude oil, fuel oil and petroleum products. Our decision as to whether to designate derivative instruments as fair value hedges for accounting purposes relates to our expectations of the length of time we expect to have the commodity price exposure and our expectations as to whether the derivative contract will qualify as highly effective under accounting guidance in limiting our exposure to commodity price risk. Most of the petroleum products, including fuel oil that we supply, cannot be hedged with a high degree of effectiveness with derivative contracts available on the NYMEX; therefore, we do not designate derivative contracts utilized to limit our price risk related to these products as hedges for accounting purposes. Typically we utilize crude oil and other petroleum products futures and option contracts to limit our exposure to the effect of fluctuations in petroleum products prices on the future sale of our inventory or commitments to purchase petroleum products, and we recognize any changes in fair value of the derivative contracts as increases or decreases in our cost of sales. The recognition of changes in fair value of the derivative contracts not designated as hedges for accounting purposes can occur in reporting periods that do not coincide with the recognition of gain or loss on the actual transaction being hedged. Therefore we will, on occasion, report gains or losses in one period that will be partially offset by gains or losses in a future period when the hedged transaction is completed.

In accordance with NYMEX requirements, we fund the margin associated with our loss positions on commodity derivative contracts traded on the NYMEX. The amount of the margin is adjusted daily based on the fair value of the commodity contracts. The margin requirements are intended to mitigate a party’s exposure to market volatility and the associated contracting party risk. We offset fair value amounts recorded for our NYMEX derivative contracts against margin funding as required by the NYMEX in Current Assets - Other in our Unaudited Condensed Consolidated Balance Sheets.

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GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

At September 30, 2012, we had the following outstanding derivative commodity futures and options contracts that were entered into to economically hedge inventory or fixed price purchase commitments. We had no outstanding derivative contracts that were designated as hedges under accounting rules.

	Sell (Short) Contracts		Buy (Long) Contracts
Not qualifying or not designated as hedges under accounting rules:
Crude oil futures:
Contract volumes (1,000 bbls)	59		25
Weighted average contract price per bbl	$	92.69	$	92.19
Crude oil LLS/WTI swap:
Contract volumes (1,000 bbls)	100		—
Weighted average contract price per bbl	$	18.63	$	—
Heating oil futures:
Contract volumes (1,000 bbls)	94		66
Weighted average contract price per gal	$	3.12	$	3.16
#6 Fuel oil futures:
Contract volumes (1,000 bbls)	640		200
Weighted average contract price per bbl	$	97.59	$	98.05
Crude oil options:
Contract volumes (1,000 bbls)	360		105
Weighted average premium received	$	1.69	$	0.54
Heating oil options:
Contract volumes (1,000 bbls)	10		—
Weighted average premium received	$	0.08	$	—

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 September 30, 2012 and December 31, 2011:

Fair Value of Derivative Assets and Liabilities

	Unaudited Condensed Consolidated Balance Sheets Location	Fair Value
		September 30, 2012				December 31, 2011
Asset Derivatives:
Commodity derivatives - futures and call options:
Undesignated hedges	Current Assets - Other	$	178			$	306
Total asset derivatives		$	178			$	306
Liability Derivatives:
Commodity derivatives - futures and call options:
Undesignated hedges	Current Assets - Other	$	(1,440	)	(1)	$	(2,820	)	(1)
Total liability derivatives		$	(1,440	)		$	(2,820	)

(1) These derivative liabilities have been funded with margin deposits recorded in our Unaudited Condensed Consolidated Balance Sheets under Current Assets - Other.

17

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Effect on Operating Results

		Amount of Gain (Loss) Recognized in Income
	Unaudited Condensed Consolidated Statements of Operations Location	Three Months Ended September 30,					Nine Months Ended September 30,
		2012			2011		2012			2011
Commodity derivatives - futures and call options:
Contracts designated as hedges under accounting guidance	Supply and logistics product costs	$	—		$	—	$	—		$	(173	)
Contracts not considered hedges under accounting guidance	Supply and logistics product costs	(5,817		)	2,587		(2,959		)	(11,050		)
Total commodity derivatives		$	(5,817	)	$	2,587	$	(2,959	)	$	(11,223	)

13. 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;

(2) Level 2 fair values are based on pricing inputs other than quoted prices in active markets 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 at the dates indicated.

	Fair Value at							Fair Value at
	September 30, 2012							December 31, 2011
Recurring Fair Value Measures	Level 1			Level 2		Level 3		Level 1			Level 2		Level 3
Commodity derivatives:
Assets	$	178		$	—	$	—	$	306		$	—	$	—
Liabilities	$	(1,440	)	$	—	$	—	$	(2,820	)	$	—	$	—

Our commodity derivatives include exchange-traded futures and exchange-traded options contracts. The fair value of these exchange-traded derivative contracts is based on unadjusted quoted prices in active markets and is, therefore, included in Level 1 of the fair value hierarchy.

See Note 12 for additional information on our derivative instruments.

Nonfinancial Assets and Liabilities

We utilize fair value on a non-recurring basis to perform impairment tests as required on our property, plant and equipment, goodwill and intangible assets. Assets and liabilities acquired in business combinations are recorded at their fair value as of the date of acquisition. The inputs used to determine such fair value are primarily based upon internally developed cash flow models and would generally be classified in Level 3, in the event that we were required to measure and record such assets within our Unaudited Condensed Consolidated Financial Statements. Additionally, we use fair value to determine the inception value of our asset retirement obligations. The inputs used to determine such fair value are primarily based upon costs incurred historically for similar work, as well as estimates from independent third parties for costs that would be incurred to restore leased property to the contractually stipulated condition, and would generally be classified in Level 3.

18

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 for similar instruments with comparable maturities. At September 30, 2012, our senior unsecured notes had a carrying value of $351 million and a fair value of $371.4 million, compared to $250 million and $253.1 million, respectively, at December 31, 2011. 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.

14. Contingencies

We are subject to various environmental laws and regulations. Policies and procedures are in place to monitor compliance and to detect and address any material releases of crude oil from our pipelines or other facilities; however, no assurance can be made that such environmental releases may not substantially affect our business.

We are subject to lawsuits in the normal course of business, as well as examinations 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.

15. Income Taxes

In the third quarter of 2012, we reversed $8.2 million of uncertain tax positions and recognized an income tax benefit in the Unaudited Condensed Consolidated Statements of Operations as a result of tax audit settlements and the expiration of statutes of limitations. These uncertain tax positions were included in Other Long-Term Liabilities in our Unaudited Condensed Consolidated Balance Sheets.

16. Condensed Consolidating Financial Information

Our $350 million aggregate principal amount of senior unsecured notes co-issued by Genesis Energy, L.P. and Genesis Energy Finance Corporation are fully and unconditionally guaranteed jointly and severally by all of Genesis Energy, L.P.’s 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. Each subsidiary guarantor and the subsidiary co-issuer are 100% owned, directly or indirectly, by Genesis Energy, L.P. See Note 7 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.

19

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Unaudited Condensed Consolidating Balance Sheet

September 30, 2012

	Genesis Energy, L.P. (Parent and Co-Issuer)		Genesis Energy Finance Corporation (Co-Issuer)		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Genesis Energy, L.P. Consolidated
ASSETS
Current assets:
Cash and cash equivalents	$	11	$	—	$	14,753		$	697		$	—		$	15,461
Other current assets	744,217		—		387,772			38,521			(758,704		)	411,806
Total current assets	744,228		—		402,525			39,218			(758,704		)	427,267
Fixed assets, at cost	—		—		583,751			100,912			—			684,663
Less: Accumulated depreciation	—		—		(136,459		)	(12,253		)	—			(148,712		)
Net fixed assets	—		—		447,292			88,659			—			535,951
Goodwill	—		—		325,046			—			—			325,046
Other assets, net	19,152		—		257,694			158,875			(164,755		)	270,966
Equity investees	—		—		547,925			—			—			547,925
Investments in subsidiaries	1,007,650		—		100,005			—			(1,107,655		)	—
Total assets	$	1,771,030	$	—	$	2,080,487		$	286,752		$	(2,031,114	)	$	2,107,155
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities	$	9,173	$	—	$	1,047,542		$	19,987		$	(758,323	)	$	318,379
Senior secured credit facility	483,000		—		—			—			—			483,000
Senior unsecured notes	350,924		—		—			—			—			350,924
Deferred tax liabilities	—		—		11,598			—			—			11,598
Other liabilities	—		—		12,850			167,041			(164,570		)	15,321
Total liabilities	843,097		—		1,071,990			187,028			(922,893		)	1,179,222
Partners’ capital	927,933		—		1,008,497			99,724			(1,108,221		)	927,933
Total liabilities and partners’ capital	$	1,771,030	$	—	$	2,080,487		$	286,752		$	(2,031,114	)	$	2,107,155

20

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Unaudited Condensed Consolidating Balance Sheet

December 31, 2011

	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	$	3	$	—	$	9,182		$	1,632		$	—		$	10,817
Other current assets	597,966		—		341,131			31,897			(605,707		)	365,287
Total current assets	597,969		—		350,313			33,529			(605,707		)	376,104
Fixed assets, at cost	—		—		444,262			96,876			—			541,138
Less: Accumulated depreciation	—		—		(114,655		)	(9,558		)	—			(124,213		)
Net fixed assets	—		—		329,607			87,318			—			416,925
Goodwill	—		—		325,046			—			—			325,046
Other assets, net	14,773		—		276,450			162,373			(167,774		)	285,822
Equity investees	—		—		326,947			—			—			326,947
Investments in subsidiaries	841,725		—		96,303			—			(938,028		)	—
Total assets	$	1,454,467	$	—	$	1,704,666		$	283,220		$	(1,711,509	)	$	1,730,844
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities	$	2,529	$	—	$	835,013		$	17,562		$	(605,676	)	$	249,428
Senior secured credit facility	409,300		—		—			—			—			409,300
Senior unsecured notes	250,000		—		—			—			—			250,000
Deferred tax liabilities	—		—		12,549			—			—			12,549
Other liabilities	—		—		14,673			169,842			(167,586		)	16,929
Total liabilities	661,829		—		862,235			187,404			(773,262		)	938,206
Partners’ capital	792,638		—		842,431			95,816			(938,247		)	792,638
Total liabilities and partners’ capital	$	1,454,467	$	—	$	1,704,666		$	283,220		$	(1,711,509	)	$	1,730,844

21

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Unaudited Condensed Consolidating Statement of Operations

Three Months Ended September 30, 2012

	Genesis Energy, L.P. (Parent and Co-Issuer)			Genesis Energy Finance Corporation (Co-Issuer)		Guarantor Subsidiaries		Non-Guarantor Subsidiaries			Eliminations			Genesis Energy, L.P. Consolidated
REVENUES:
Supply and logistics	$	—		$	—	$	869,726	$	31,113		$	(25,646	)	$	875,193
Refinery services	—			—		48,809		4,367			(5,199		)	47,977
Pipeline transportation services	—			—		12,596		6,568			—			19,164
Total revenues	—			—		931,131		42,048			(30,845		)	942,334
COSTS AND EXPENSES:
Supply and logistics costs	—			—		852,009		26,488			(25,648		)	852,849
Refinery services operating costs	—			—		29,339		4,565			(4,661		)	29,243
Pipeline transportation operating costs	—			—		5,661		250			—			5,911
General and administrative	—			—		10,343		32			—			10,375
Depreciation and amortization	—			—		13,940		898			—			14,838
Total costs and expenses	—			—		911,292		32,233			(30,309		)	913,216
OPERATING INCOME	—			—		19,839		9,815			(536		)	29,118
Equity in earnings of subsidiaries	41,052			—		5,738		—			(46,790		)	—
Equity in earnings of equity investees	—			—		3,432		—			—			3,432
Interest (expense) income, net	(9,858		)	—		4,119		(4,134		)	—			(9,873		)
Income before income taxes	31,194			—		33,128		5,681			(47,326		)	22,677
Income tax benefit	—			—		8,509		8			—			8,517
NET INCOME	$	31,194		$	—	$	41,637	$	5,689		$	(47,326	)	$	31,194

22

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Unaudited Condensed Consolidating Statement of Operations

Three Months Ended September 30, 2011

	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:
Supply and logistics	$	—		$	—	$	765,714		$	—		$	—		$	765,714
Refinery services	—			—		48,700			3,805			(4,113		)	48,392
Pipeline transportation services	—			—		9,388			6,706			—			16,094
Total revenues	—			—		823,802			10,511			(4,113		)	830,200
COSTS AND EXPENSES:
Supply and logistics costs	—			—		743,833			—			—			743,833
Refinery services operating costs	—			—		30,448			3,612			(3,924		)	30,136
Pipeline transportation operating costs	—			—		3,818			170			—			3,988
General and administrative	—			—		8,905			—			—			8,905
Depreciation and amortization	—			—		14,057			649			—			14,706
Total costs and expenses	—			—		801,061			4,431			(3,924		)	801,568
OPERATING INCOME	—			—		22,741			6,080			(189		)	28,632
Equity in losses of subsidiaries	28,032			—		1,945			—			(29,977		)	—
Equity in earnings of equity investees	—			—		(412		)	—			—			(412		)
Interest (expense) income, net	(8,944		)	—		4,226			(4,242		)	—			(8,960		)
Income before income taxes	19,088			—		28,500			1,838			(30,166		)	19,260
Income tax (expense) benefit	—			—		(233		)	61			—			(172		)
NET INCOME	$	19,088		$	—	$	28,267		$	1,899		$	(30,166	)	$	19,088

23

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Unaudited Condensed Consolidating Statement of Operations

Nine Months Ended September 30, 2012

	Genesis Energy, L.P. (Parent and Co-Issuer)			Genesis Energy Finance Corporation (Co-Issuer)		Guarantor Subsidiaries		Non-Guarantor Subsidiaries			Eliminations			Genesis Energy, L.P. Consolidated
REVENUES:
Supply and logistics	$	—		$	—	$	2,579,102	$	95,451		$	(76,744	)	$	2,597,809
Refinery services	—			—		142,716		13,756			(12,130		)	144,342
Pipeline transportation services	—			—		36,381		19,413			—			55,794
Total revenues	—			—		2,758,199		128,620			(88,874		)	2,797,945
COSTS AND EXPENSES:
Supply and logistics costs	—			—		2,525,474		83,250			(76,744		)	2,531,980
Refinery services operating costs	—			—		89,155		13,701			(11,784		)	91,072
Pipeline transportation operating costs	—			—		15,351		644			—			15,995
General and administrative	—			—		29,842		92			—			29,934
Depreciation and amortization	—			—		42,759		2,688			—			45,447
Total costs and expenses	—			—		2,702,581		100,375			(88,528		)	2,714,428
OPERATING INCOME	—			—		55,618		28,245			(346		)	83,517
Equity in earnings of subsidiaries	100,011			—		15,869		—			(115,880		)	—
Equity in earnings of equity investees	—			—		7,971		—			—			7,971
Interest (expense) income, net	(30,629		)	—		12,414		(12,482		)	—			(30,697		)
Income before income taxes	69,382			—		91,872		15,763			(116,226		)	60,791
Income tax benefit (expense)	—			—		8,630		(39		)	—			8,591
NET INCOME	$	69,382		$	—	$	100,502	$	15,724		$	(116,226	)	$	69,382

24

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Unaudited Condensed Consolidating Statement of Operations

Nine Months Ended September 30, 2011

	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:
Supply and logistics	$	—		$	—	$	2,091,854		$	—		$	—		$	2,091,854
Refinery services	—			—		142,992			12,953			(10,644		)	145,301
Pipeline transportation services	—			—		26,292			19,341			—			45,633
Total revenues	—			—		2,261,138			32,294			(10,644		)	2,282,788
COSTS AND EXPENSES:
Supply and logistics costs	—			—		2,044,554			—			—			2,044,554
Refinery services operating costs	—			—		88,641			11,836			(10,491		)	89,986
Pipeline transportation operating costs	—			—		11,937			477			—			12,414
General and administrative	—			—		25,339			—			—			25,339
Depreciation and amortization	—			—		41,153			1,947			—			43,100
Total costs and expenses	—			—		2,211,624			14,260			(10,491		)	2,215,393
OPERATING INCOME	—			—		49,514			18,034			(153		)	67,395
Equity in earnings of subsidiaries	70,092			—		5,238			—			(75,330		)	—
Equity in earnings of equity investees	—			—		3,377			—			—			3,377
Interest (expense) income, net	(26,616		)	—		12,726			(12,780		)	—			(26,670		)
Income before income taxes	43,476			—		70,855			5,254			(75,483		)	44,102
Income tax expense	—			—		(467		)	(159		)	—			(626		)
NET INCOME	$	43,476		$	—	$	70,388		$	5,095		$	(75,483	)	$	43,476

25

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Unaudited Condensed Consolidating Statement of Cash Flows

Nine Months Ended September 30, 2012

	Genesis Energy, L.P. (Parent and Co-Issuer)			Genesis Energy Finance Corporation (Co-Issuer)		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Genesis Energy, L.P. Consolidated
Net cash (used in) provided by operating activities	$	(91,453	)	$	—	$	304,617		$	17,700		$	(87,926	)	$	142,938
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	—			—		(112,665		)	(4,037		)	—			(116,702		)
Cash distributions received from equity investees - return of investment	27,878			—		10,918			—			(27,878		)	10,918
Investments in equity investees	(169,421		)	—		(57,072		)	—			169,421			(57,072		)
Acquisitions	—			—		(205,576		)	—			—			(205,576		)
Repayments on loan to non-guarantor subsidiary	—			—		3,019			—			(3,019		)	—
Proceeds from asset sales	—			—		667			—			—			667
Other, net	—			—		(1,012		)	—			—			(1,012		)
Net cash used in investing activities	(141,543		)	—		(361,721		)	(4,037		)	138,524			(368,777		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	1,407,000			—		—			—			—			1,407,000
Repayments on senior secured credit facility	(1,333,300		)	—		—			—			—			(1,333,300		)
Proceeds from issuance of senior unsecured notes, including premium	101,000			—		—			—			—			101,000
Debt issuance costs	(7,109		)	—		—			—			—			(7,109		)
Issuance of common units for cash, net	169,421			—		169,421			—			(169,421		)	169,421
Distributions to partners/owners	(104,008		)	—		(104,008		)	(11,819		)	115,827			(104,008		)
Other, net	—			—		(2,738		)	(2,779		)	2,996			(2,521		)
Net cash provided by (used in) financing activities	233,004			—		62,675			(14,598		)	(50,598		)	230,483
Net increase (decrease) in cash and cash equivalents	8			—		5,571			(935		)	—			4,644
Cash and cash equivalents at beginning of period	3			—		9,182			1,632			—			10,817
Cash and cash equivalents at end of period	$	11		$	—	$	14,753		$	697		$	—		$	15,461

26

GENESIS ENERGY, L.P.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Unaudited Condensed Consolidating Statement of Cash Flows

Nine Months Ended September 30, 2011

	Genesis Energy, L.P. (Parent and Co-Issuer)			Genesis Energy Finance Corporation (Co-Issuer)		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Genesis Energy, L.P. Consolidated
Net cash (used in) provided by operating activities	$	(4,881	)	$	—	$	41,160		$	2,844		$	23		$	39,146
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	—			—		(15,060		)	(97		)	—			(15,157		)
Cash distributions received from equity investees - return of investment	82,067			—		8,577			—			(82,067		)	8,577
Investments in equity investees	(184,969		)	—		(194		)	—			184,969			(194		)
Acquisitions	—			—		(143,489		)	—			—			(143,489		)
Repayments on loan to non-guarantor subsidiary	—			—		2,729			—			(2,729		)	—
Proceeds from asset sales	—			—		4,444			—			—			4,444
Other, net	—			—		129			—			—			129
Net cash used in investing activities	(102,902		)	—		(142,864		)	(97		)	100,173			(145,690		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	571,700			—		—			—			—			571,700
Repayments on senior secured credit facility	(563,800		)	—		—			—			—			(563,800		)
Debt issuance costs	(3,018		)	—		—			—			—			(3,018		)
Distributions to partners/owners	(82,067		)	—		(82,067		)	—			82,067			(82,067		)
Issuance of common units for cash, net	184,969			—		184,969			—			(184,969		)	184,969
Other, net	—			—		(2,626		)	(2,706		)	2,706			(2,626		)
Net cash provided by (used in) financing activities	107,784			—		100,276			(2,706		)	(100,196		)	105,158
Net increase (decrease) in cash and cash equivalents	1			—		(1,428		)	41			—			(1,386		)
Cash and cash equivalents at beginning of period	1			—		5,082			679			—			5,762
Cash and cash equivalents at end of period	$	2		$	—	$	3,654		$	720		$	—		$	4,376

27

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following information should be read in conjunction with our Unaudited Condensed Consolidated Financial Statements and accompanying notes included in this quarterly report on Form 10-Q. The following information and such Unaudited Condensed Consolidated Financial Statements should also be read in conjunction with the audited financial statements and related notes, together with our discussion and analysis of financial position and results of operations, included in our Annual Report on Form 10-K.

Included in Management’s Discussion and Analysis are the following sections:

• Overview

• Acquisition

• Financial Measures

• Results of Operations

• Liquidity and Capital Resources

• Commitments and Off-Balance Sheet Arrangements

• Forward Looking Statements

Overview

We reported net income of $31.2 million, or $0.39 per common unit during the three months ended September 30, 2012 (“2012 Quarter”) compared to net income of $19.1 million or $0.27 per common unit during the three months ended September 30, 2011 (“2011 Quarter”). The significant factors benefiting net income were improved operating results by all of our business segments and a decrease in our income tax expense. The increases in net income were partially offset by increases in general and administrative expenses and interest costs. A more detailed discussion of our segment results and other costs is included below in “Results of Operations”.

Segment Margin (as described below in “Financial Measures”) increased by $13 million, or 25%, in the 2012 Quarter, as compared to the 2011 Quarter. This increase resulted from improvement in Segment Margin in our pipeline transportation, refinery services and supply and logistics segments of 45%, 6% and 25%, respectively. The contribution from our interests in certain Gulf of Mexico pipelines that we acquired in 2012 and higher crude oil tariff revenues were the primary factors increasing pipeline transportation segment margin. Results for our pipeline transportation segment were somewhat reduced during both quarters due to ongoing improvements at several dedicated fields. Improvements at those fields were substantially completed late in the 2012 Quarter. Our refinery services segment margin increased primarily as a result of increased NaHS sales volumes and operating efficiencies realized at several of our sour gas processing facilities as well as our favorable management of the acquisition and utilization of caustic soda in our, and our customers', operations. Our supply and logistics segment benefited from acquisitions and other growth initiatives completed in the second half of 2011 as well as higher volumes handled by our expanded trucking and barge fleets.

Available Cash before Reserves increased $8.8 million, or 24%, in the 2012 Quarter (as compared to the 2011 Quarter) to $45.9 million consistent with the increase in net income described above. See “Financial Measures” below for additional information on Available Cash before Reserves.

Distribution Increase

In October 2012, we declared our twenty-ninth consecutive increase in our quarterly distribution to our common unitholders relative to the third quarter of 2012. During that period, twenty-four of those quarterly increases have been 10% or greater year-over-year. In November 2012, we will pay a distribution of $0.4725 per unit representing a 10.5% increase from our distribution of $0.4275 per unit related to the third quarter of 2011. During the third quarter of 2012, we paid a distribution of $0.46 per unit related to the second quarter of 2012.

Acquisition

In January 2012, we acquired from Marathon Oil Company interests in several Gulf of Mexico crude oil pipeline systems. The acquired pipeline interests include a 28% interest in Poseidon Oil Pipeline Company, L.L.C. (or “Poseidon”), a 100% interest in Marathon Offshore Pipeline, LLC (subsequently re-named GEL Offshore Pipeline, LLC, or “GOPL”) and a 29% interest in Odyssey Pipeline L.L.C. (or “Odyssey”). GOPL owns a 23% interest in the Eugene Island crude oil pipeline system and a 100% interest in two smaller offshore pipelines. The purchase price, net of post-closing adjustments, was $205.6 million. We funded the purchase price with cash available under our credit facility.

This acquisition complements our existing infrastructure in the Gulf of Mexico and enhances our ability to provide capacity and market optionality to producers for their existing and future developments as well as our refining customers

28

onshore Texas and Louisiana. The Poseidon pipeline system is comprised of a 367-mile network of crude oil pipelines, varying in diameter from 16 to 24 inches, with capacity to deliver approximately 400,000 barrels per day of crude oil from developments in the central and western offshore Gulf of Mexico to other pipelines and terminals onshore and offshore Louisiana. Affiliates of Enterprise Products and Shell each own a 36% interest in Poseidon. An affiliate of Enterprise Products serves as the operator of Poseidon. The Eugene Island pipeline system is primarily comprised of a 183-mile network of crude oil pipelines, the main pipeline of which is 20 inches in diameter, with capacity to deliver approximately 200,000 barrels per day of crude oil from developments in the central Gulf of Mexico to other pipelines and terminals onshore Louisiana. Other owners in Eugene Island include affiliates of Exxon-Mobil, Chevron-Texaco, ConocoPhillips and Shell. An affiliate of Shell serves as the operator of Eugene Island. The Odyssey pipeline system is comprised of a 120-mile network of crude oil pipelines, varying in diameter from 12 to 20 inches, with capacity to deliver up to 300,000 barrels per day of crude oil from developments in the eastern Gulf of Mexico to other pipelines and terminals onshore Louisiana. An affiliate of Shell owns the remaining 71% interest in Odyssey, and an affiliate of Shell serves as the operator of Odyssey.

Financial Measures

In the discussions that follow, we will focus on our revenues, expenses and net income, as well as two measures that we use to manage the business and to review the results of our operations. Those two measures are Segment Margin and Available Cash before Reserves.

Segment Margin

We define Segment Margin as revenues less product costs, operating expenses (excluding non-cash charges, such as depreciation and amortization), and segment general and administrative expenses, plus our equity in distributable cash generated by our equity investees. In addition, our Segment Margin definition excludes the non-cash effects of our 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. A reconciliation of Segment Margin to income before income taxes is included in our segment disclosures in Note 9 to our Unaudited Condensed Consolidated Financial Statements.

Available Cash before Reserves

This quarterly report includes the financial measure of Available Cash before Reserves, which is a “non-GAAP” measure because it is not contemplated by or referenced in accounting principles generally accepted in the U.S., also referred to as GAAP. The accompanying schedule below provides a reconciliation of this non-GAAP financial measure to its most directly comparable GAAP financial measure. Our non-GAAP financial measure should not be considered as an alternative to GAAP measures such as net income, operating income, cash flow from operating activities or any other GAAP measure of liquidity or financial performance. We believe that investors benefit from having access to the same financial measures being utilized by management, lenders, analysts, and other market participants.

Available Cash before Reserves, also referred to as distributable cash flow, is commonly used as a supplemental financial measure by management and by external users of financial statements, such as investors, commercial banks, research analysts and rating agencies, to assess: (1) the financial performance of our assets without regard to financing methods, capital structures, or historical cost basis; (2) the ability of our assets to generate cash sufficient to pay interest costs and support our indebtedness; (3) our operating performance and return on capital as compared to those of other companies in the midstream energy industry, without regard to financing and capital structure; and (4) the viability of projects and the overall rates of return on alternative investment opportunities. Because Available Cash before Reserves excludes some items that affect net income or loss and because these measures may vary among other companies, the Available Cash before Reserves data presented in this Quarterly Report on Form 10-Q may not be comparable to similarly titled measures of other companies.

Available Cash before Reserves is a performance measure used by our management to compare cash flows generated by us to the cash distribution paid to our common unitholders. This is an important financial measure to our public unitholders since it is an indicator of our ability to provide a cash return on their investment. Specifically, this financial measure aids investors in determining whether or not we are generating cash flows at a level that can support a quarterly cash distribution to the partners. Lastly, Available Cash before Reserves is the quantitative standard used throughout the investment community with respect to publicly-traded partnerships.

Available Cash before Reserves is net income as adjusted for specific items, the most significant of which are the addition of non-cash expenses (such as depreciation and amortization), the substitution of distributable cash generated by our equity investees in lieu of our equity income attributable to our equity investees, the elimination of gains and losses on asset sales (except those from the sale of surplus assets) and unrealized gains and losses on derivative transactions not designated as

29

hedges for accounting purposes, the elimination of expenses related to acquiring or constructing assets that provide new sources of cash flows, and the subtraction of maintenance capital expenditures, which are expenditures that are necessary to sustain existing (but not to provide new sources of) cash flows.

Available Cash before Reserves for the periods presented below was as follows:

	Three Months Ended September 30,
	2012			2011
	(in thousands)
Net income	$	31,194		$	19,088
Depreciation and amortization	14,838			14,706
Cash received from direct financing leases not included in income	1,278			1,167
Cash effects of sales of certain assets	13			3,269
Effects of distributable cash generated by equity method investees not included in income	5,613			3,701
Cash effects of equity-based compensation plans	(466		)	(306		)
Non-cash equity-based compensation expense (benefit)	2,001			(930		)
Expenses related to acquiring or constructing assets that provide new sources of cash flow	228			1,008
Unrealized gain on derivative transactions excluding fair value hedges	(75		)	(4,355		)
Maintenance capital expenditures	(701		)	(2,244		)
Non-cash tax benefit	(8,717		)	(48		)
Other items, net	653			1,985
Available Cash before Reserves	$	45,859		$	37,041

Results of Operations

Revenues and Costs and Expenses

Our revenues for the 2012 Quarter increased $112.1 million, or 14% from the 2011 Quarter. Additionally, our costs and expenses increased $111.6 million, or 14% between the two periods.

Our revenues for the nine months ended September 30, 2012 increased $515.2 million, or 23% from the nine months ended September 30, 2011. Costs and expenses increased $499 million, or 23% between the two nine month periods.

The majority of our revenues and costs are derived from the purchase and sale of crude oil and petroleum products. The significant increase in our revenues and costs between the two third quarter and nine month periods is primarily attributable to increased volumes from our continuing operations and our acquisitions and, to a lesser extent, increases in the market prices for crude oil and petroleum products as described below.

Volumes increased in our supply and logistics segment by 30% quarter to quarter and 27% between the nine month periods as explained in our supply and logistics Segment Margin discussion below. The average closing prices for West Texas Intermediate ("WTI") crude oil on the New York Mercantile Exchange ("NYMEX") increased 3% to $92.22 per barrel in the third quarter of 2012, as compared to $89.76 per barrel in the third quarter of 2011. Average closing prices for WTI crude oil on the NYMEX were consistent between the nine month periods at approximately $96 per barrel.

Segment Margin

The contribution of each of our segments to total Segment Margin in the three and nine months ended September 30, 2012 and 2011 was as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
	(in thousands)				(in thousands)
Pipeline transportation	$	23,295	$	16,030	$	69,427	$	50,639
Refinery services	18,983		17,992		53,510		54,887
Supply and logistics	23,651		18,909		66,075		44,233
Total Segment Margin	$	65,929	$	52,931	$	189,012	$	149,759

30

Pipeline Transportation Segment

Operating results and volumetric data for our pipeline transportation segment are presented below.

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(in thousands)						(in thousands)
Crude oil tariffs and revenues from direct financing leases - onshore crude oil pipelines	$	8,297		$	6,788		$	22,400		$	17,988
Segment margin from offshore crude oil pipelines, including pro-rata share of distributable cash from equity investees	8,927			2,288			27,114			12,326
CO2 tariffs and revenues from direct financing leases of CO2 pipelines	6,662			6,808			19,700			19,666
Sales of crude oil pipeline loss allowance volumes	2,369			1,790			7,152			5,418
Onshore pipeline operating costs, excluding non-cash charges for equity-based compensation and other non-cash expenses	(4,461		)	(2,999		)	(11,384		)	(8,770		)
Payments received under direct financing leases not included in income	1,278			1,167			3,748			3,421
Other	223			188			697			590
Segment Margin	$	23,295		$	16,030		$	69,427		$	50,639
Volumetric Data (barrels/day unless otherwise noted):
Onshore crude oil pipelines:
Jay	22,841			17,720			19,931			16,499
Texas	52,767			44,149			50,327			46,020
Mississippi	17,942			20,884			18,377			20,883
Offshore crude oil pipelines:
CHOPS (1)	91,377			90,312			78,817			123,034
Poseidon (1) (2)	215,474			—			206,596			—
Odyssey (1) (2)	31,869			—			35,994			—
GOPL (2)	8,300			—			16,979			—
CO2 pipeline (Mcf/day):
Free State	188,165			192,041			177,527			166,302

(1) Volumes for our equity method investees are presented on a 100% basis.

(2) Acquired in January 2012.

Three Months Ended September 30, 2012 Compared with Three Months Ended September 30, 2011

Pipeline transportation Segment Margin for the 2012 Quarter increased $7.3 million, or 45%. The significant components of this change were as follows:

• Crude oil tariff revenues of onshore crude oil pipelines increased $1.5 million primarily due to upward tariff indexing of approximately 8.6% for our FERC-regulated pipelines effective in July 2012.

• Segment Margin from our offshore crude oil pipelines increased $6.6 million reflecting a $7.7 million contribution from our interests in the Gulf of Mexico pipelines that we acquired in 2012. The contribution to Segment Margin by CHOPS declined by $1.1 million from the 2011 Quarter due to ongoing improvements being made by producers at several connected fields. Improvements at those fields were substantially completed late in the 2012 Quarter.

• Onshore pipeline operating costs, excluding non-cash charges, increased $1.5 million due to pipeline integrity maintenance on the pipelines and employee compensation and related benefit costs.

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Nine Months EndedSeptember 30, 2012 Compared with Nine Months EndedSeptember 30, 2011.

Segment Margin for our pipeline transportation segment increased $18.8 million, or 37%, between the nine month periods. The significant components of this change were as follows:

• Crude oil tariff revenues of onshore crude oil pipelines increased $4.4 million primarily due to upward tariff indexing of 6.9% and 8.6% for our FERC-regulated pipelines effective in July 2011 and 2012, respectively.

• Segment Margin from our offshore crude oil pipelines increased $14.8 million reflecting a $22.3 million contribution from our interests in the Gulf of Mexico pipelines that we acquired in 2012. The increase was partially offset by a decline of $7.5 million in the contribution to Segment Margin by CHOPS. Volumes transported on CHOPS decreased approximately 44,000 barrels per day as a result of improvements being made by producers at several connected production fields. Improvements at those fields were substantially completed late in the 2012 Quarter.

• Revenues from sales of pipeline loss allowance volumes improved Segment Margin by $1.7 million due to an increase of approximately 13,225 barrels sold in the first nine months of 2012 compared to the first nine months of 2011.

• Onshore pipeline operating costs, excluding non-cash charges, increased $2.6 million due to pipeline integrity maintenance on the pipelines and employee compensation and related benefit costs.

Refinery Services Segment

Operating results for our refinery services segment were as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
Volumes sold (in Dry short tons "DST"):
NaHS volumes	34,372			33,396			107,321			106,709
NaOH (caustic soda) volumes	21,152			23,440			56,740			74,289
Total	55,524			56,836			164,061			180,998
Revenues (in thousands):
NaHS revenues	$	36,903		$	35,741		$	113,937		$	108,999
NaOH (caustic soda) revenues	11,936			11,430			32,211			33,673
Other revenues	1,539			3,811			5,178			9,227
Total external segment revenues	$	50,378		$	50,982		$	151,326		$	151,899
Segment Margin (in thousands)	$	18,983		$	17,992		$	53,510		$	54,887
Average index price for NaOH per DST (1)	$	579		$	540		$	566		$	492
Raw material and processing costs as % of segment revenues	46		%	44		%	48		%	43		%

(1) Source: Harriman Chemsult Ltd.

Three Months Ended September 30, 2012 Compared with Three Months Ended September 30, 2011

Refinery services Segment Margin for the 2012 Quarter increased$1 million, or 6%. The significant components of this fluctuation were as follows:

• NaHS revenues increased primarily as a function of the increase in the average index price for caustic soda and increased sales volumes. The pricing in our sales contracts for NaHS includes adjustments for fluctuations in commodity benchmarks, freight, labor, energy costs and government indexes. The frequency at which these adjustments are applied varies by contract, geographic region and supply point.

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• Our raw material costs related to NaHS increased correspondingly to the rise in the average index price for caustic soda, although operating efficiencies at several of our sour gas processing facilities, our favorable management of the acquisition and utilization of caustic soda in our, and our customers', operations, and our logistics management helped offset these costs.

• Caustic soda sales volumes decreased10%. Although caustic sales volumes may fluctuate, the contribution to Segment Margin from these sales is not a significant portion of our refinery services activities. Caustic soda is a key component in the provision of our sulfur-removal service, from which we receive the by-product NaHS. Consequently, we are a very large consumer of caustic soda. In addition, our economies of scale and logistics capabilities allow us to effectively purchase additional caustic soda for re-sale to third parties. Our ability to purchase caustic soda volumes is currently sufficient to meet the demands of our refinery services operations and third-party sales.

• Average index prices for caustic soda increased to $579 per DST in the third quarter of 2012 compared to $540 per DST during the third quarter of 2011. Those price movements affect the revenues and costs related to our sulfur removal services as well as our caustic soda sales activities. However, generally, changes in caustic soda prices do not materially affect Segment Margin attributable to our sulfur processing services because we usually pass those costs through to our NaHS sales customers. Additionally, our bulk purchase and storage capabilities related to caustic soda allow us to somewhat mitigate the effects of changes in index prices for caustic on our operating costs.

Nine Months EndedSeptember 30, 2012 Compared with Nine Months EndedSeptember 30, 2011

Refinery services Segment Margin decreased$1.4 million, or 3%, between the nine month periods. The significant components of this fluctuation were as follows:

• Our raw material costs related to NaHS increased correspondingly to the rise in the average index price for caustic soda. In addition, in the first half of 2012, longer than anticipated refinery turnarounds at some of our largest refinery service locations resulted in increased costs as a result of processing at less efficient locations to ensure uninterrupted supplies to our customers.

• NaHS revenues increased primarily as a function of the increase in the average index price for caustic soda. The pricing in our sales contracts for NaHS includes adjustments for fluctuations in commodity benchmarks, freight, labor, energy costs and government indexes. The frequency at which these adjustments are applied varies by contract, geographic region and supply point.

• Caustic soda sales volumes decreased24% primarily due to turnarounds at some of our refinery customers in the first half of 2012. Although caustic sales volumes may fluctuate, the contribution to Segment Margin from these sales is not a significant portion of our refinery services activities. Caustic soda is a key component in the provision of our sulfur-removal service, from which we receive the by-product NaHS. Consequently, we are a very large consumer of caustic soda. In addition, our economies of scale and logistics capabilities allow us to effectively purchase additional caustic soda for re-sale to third parties. Our ability to purchase caustic soda volumes is currently sufficient to meet the demands of our refinery services operations and third-party sales.

• Average index prices for caustic soda increased to $566 per DST in the first nine months of 2012 compared to $492 per DST during the first nine months of 2011. Those price movements affect the revenues and costs related to our sulfur removal services as well as our caustic soda sales activities. However, generally, changes in caustic soda prices do not materially affect Segment Margin attributable to our sulfur processing services because we usually pass those costs through to our NaHS sales customers. Additionally, our bulk purchase and storage capabilities related to caustic soda allow us to somewhat mitigate the effects of changes in index prices for caustic on our operating costs.

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Supply and Logistics Segment

Operating results from our supply and logistics segment were as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(in thousands)						(in thousands)
Supply and logistics revenue	$	875,193		$	765,714		$	2,597,809		$	2,091,854
Crude oil and products costs, excluding unrealized gains and losses from derivative transactions	(811,971		)	(714,710		)	(2,413,655		)	(1,965,687		)
Operating costs, excluding non-cash charges for equity-based compensation and other non-cash expenses	(39,927		)	(32,047		)	(117,846		)	(81,795		)
Other	356			(48		)	(233		)	(139		)
Segment Margin	$	23,651		$	18,909		$	66,075		$	44,233
Volumes of crude oil and petroleum products (barrels per day)	100,095			77,179			91,444			71,770

Three Months Ended September 30, 2012 Compared with Three Months Ended September 30, 2011

The average market prices of crude oil and petroleum products decreased 3% between the two quarterly periods; however that price volatility has a limited impact on our Segment Margin. Segment Margin for our supply and logistics segment increased by $4.7 million, or 25%, during the 2012 Quarter.

The increase in Segment Margin during the 2012 Quarter resulted primarily from the contribution of the black oil barge transportation assets that we acquired in August 2011 and February 2012 and increased volumes handled by our expanded trucking and barge fleets. Our total volumes of crude oil and refined products increased 30% as a result of these expansions. Our operating costs, excluding non-cash charges, increased25% between the two quarters due to our expanded trucking and barge fleets and increased utilization of such fleets.

Nine Months EndedSeptember 30, 2012 Compared with Nine Months EndedSeptember 30, 2011

Segment Margin for our supply and logistics segment increased$21.8 million, or 49%, between the nine month periods. Average market prices of crude oil and petroleum products were consistent at approximately $96 per barrel between the first nine months of 2011 and first nine months of 2012, however, as previously discussed, price volatility has a limited impact on our Segment Margin.

The increase in Segment Margin during the first nine months of 2012 resulted primarily from the contribution of the black oil barge transportation assets that we acquired in August 2011 and February 2012 and increased volumes handled by our expanded trucking and barge fleets. Our total volumes of crude oil and refined products increased by 27% as a result of these expansions. Our operating costs, excluding non-cash charges, increased44% between the two nine month periods due to our expanded trucking and barge fleets and increased utilization of such fleets.

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Other Costs, Interest, and Income Taxes

General and administrative expenses

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
	(in thousands)				(in thousands)
General and administrative expenses not separately identified below:
Corporate	$	5,615	$	5,367	$	16,769	$	14,291
Segment	2,905		2,308		8,011		6,653
Equity-based compensation plan expense	1,627		222		4,138		866
Third party costs related to business development activities and growth projects	228		1,008		1,016		3,529
Total general and administrative expenses	$	10,375	$	8,905	$	29,934	$	25,339

Routine corporate and segment general and administrative expenses increased between the three and nine month periods as a result of salary and benefits expenses associated with increases in personnel to support our growth. Additionally, increases in the market price of our common units affected expense related to our equity-based compensation plans. A decrease in third party costs related to business and growth transactions resulted in a decrease of approximately $0.8 million and $2.5 million, for the three and nine month periods, respectively.

Depreciation and amortization expense

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
	(in thousands)				(in thousands)
Depreciation expense	$	9,202	$	5,960	$	27,246	$	17,838
Amortization of intangible assets	4,520		7,721		15,390		22,367
Amortization of CO2 volumetric production payments	1,116		1,025		2,811		2,895
Total depreciation and amortization expense	$	14,838	$	14,706	$	45,447	$	43,100

Total depreciation and amortization expense increased $0.1 million and $2.3 million, between the quarterly and nine month periods, respectively, as a result of an increases in depreciation expense, offset by decreases in amortization of intangible assets. Depreciation expense increased$3.2 million and $9.4 million, over the same periods primarily as a result of our recent acquisitions, including the black oil barge transportation assets in August 2011 and February 2012. Amortization of intangible assets decreased$3.2 million and $7.0 million between the three and nine month periods, respectively, as we amortize our intangible assets over the period in which we expect them to contribute to our future cash flows. Generally, the amortization we record on those assets is greater in the initial years following their acquisition because our intangible assets are generally more valuable in the first years after an acquisition.

Interest expense, net

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
	(in thousands)						(in thousands)
Interest expense, credit facility (including commitment fees)	$	3,416		$	3,137		$	10,762		$	9,646
Interest expense, senior unsecured notes	6,938			5,032			19,688			14,930
Amortization of debt issuance costs and premium	825			792			2,655			2,102
Capitalized interest	(1,304		)	—			(2,394		)	—
Interest income	(2		)	(1		)	(14		)	(8		)
Net interest expense	$	9,873		$	8,960		$	30,697		$	26,670

Net interest expense increased$0.9 million between the quarterly periods and $4 million between the nine month periods primarily as a result of increased borrowings associated with acquisitions. Interest expense on our senior

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unsecured notes increased$1.9 million and $4.8 million, respectively, over the same periods as a result of issuing an additional $100 million of notes under the indenture in February 2012 to repay borrowings under our credit facility. Capitalized interest costs of $1.3 million and $2.4 million in the three and nine month periods, respectively, attributable to our growth capital expenditures and investments in the SEKCO pipeline joint venture (see below for more information) partially offset the increase in interest expense.

Income tax expense

Income tax expense decreased $8.7 million between the quarterly periods and $9.2 million between the nine month periods primarily due to the reversal of $8.2 million in uncertain tax positions as a result of tax audit settlements and the expiration of statutes of limitations.

A portion of our operations are owned by wholly-owned corporate subsidiaries that are taxable as corporations. As a result, a substantial portion of the income tax expense we record relates to the operations of those corporations, and will vary from period to period as a percentage of our income before taxes based on the percentage of our income or loss that is derived from those corporations. The balance of the income tax expense we record relates to state taxes imposed on our operations that are treated as income taxes under generally accepted accounting principles and foreign income taxes.

Other

Net income for the three months ended September 30, 2012 and 2011 included an unrealized gain on derivative positions of $0.1 million and $4.4 million, respectively. Net income for the nine months ended September 30, 2012 and 2011 included an unrealized gain on derivative positions of $1.3 million and $4.6 million, respectively. Those amounts are included in Supply and logistics product costs in the Unaudited Condensed Consolidated Statements of Operations and are not a component of Segment Margin.

Liquidity and Capital Resources

General

As of September 30, 2012, we had $504.4 million of borrowing capacity available under our $1 billion senior secured revolving credit facility. We anticipate that our future internally-generated funds and the funds available under our credit facility will allow us to meet our ordinary course capital needs. Our primary sources of liquidity have been cash flows from operations and borrowing availability under our credit facility.

Our primary cash requirements consist of:

• Working capital, primarily inventories;

• Routine operating expenses;

• Capital expansion and maintenance projects;

• Acquisitions of assets or businesses;

• Interest payments related to outstanding debt; and

• Quarterly cash distributions to our unitholders.

We continue to pursue a growth strategy that requires significant capital. In January 2012, we borrowed $205.6 million under our credit facility to acquire interests in several pipeline systems. See “Capital Expenditures and Business and Asset Acquisitions” below for more information related to our capital spending and acquisitions.

Capital Resources

Our ability to satisfy future capital needs will depend on our ability to raise substantial amounts of additional capital from time to time — including through equity and debt offerings (public and private), borrowings under our credit facility and other financing transactions—to implement our growth strategy successfully. No assurance can be made that we will be able to raise necessary funds on satisfactory terms.

In July 2012, we amended and restated our senior secured credit facility with a syndicate of banks to, among other things, increase the committed amount from $775 million to $1 billion and the accordion feature from $225 million to $300 million, giving us the ability to expand the size of the facility up to an aggregate of $1.3 billion for acquisitions or internal growth projects, subject to lender consent. The inventory financing sublimit tranche was increased from $125 million to $150 million, and the term of our credit facility was extended to July 25, 2017. This inventory tranche is designed to allow us to

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more efficiently finance crude oil and petroleum products inventory in the normal course of our operations, by allowing us to exclude the amount of inventory loans from our total outstanding indebtedness for purposes of determining our applicable interest rate. Our credit facility does not include a “borrowing base” limitation except with respect to our inventory loans.

The key terms for rates under our credit facility, which are dependent on our leverage ratio (as defined in the credit agreement), are as follows:

• The applicable margin varies from 1.75% to 2.75% on eurodollar borrowings and from 0.75% to 1.75% on alternate base rate borrowings.

•Letter of credit fees range from 1.75% to 2.75%.

• The commitment fee on the unused committed amount will range from 0.375% to 0.50%.

 We do not anticipate any of the lenders that participate in our credit facility being unable to satisfy their obligations under the credit facility.

In February 2012, we issued $100 million under our existing 7.875% senior unsecured notes indenture for which the net proceeds were used to repay borrowings under our credit facility. The notes were issued at 101% of face value at an effective interest rate of 7.682%. See Note 7 to our Unaudited Condensed Consolidated Financial Statements for more information.

In March 2012, we issued 5,750,000 Class A common units in a public offering at a price of $30.80 per unit. We received proceeds, net of underwriting discounts and offering costs, of $169.4 million from the offering. The net proceeds were used for general corporate purposes, including the repayment of borrowings under our credit facility. See Note 8 to our Unaudited Condensed Consolidated Financial Statements for more information.

At September 30, 2012, long-term debt totaled $833.9 million, consisting of $483 million outstanding under our credit facility (including $48.6 million borrowed under the inventory sublimit tranche) and a $350.9 million carrying amount of senior unsecured notes due in 2018.

Cash Flows from Operations

We generally utilize the cash flows we generate from our operations to fund our working capital needs. Excess funds that are generated are used to repay borrowings from our credit facility and to fund capital expenditures. Our operating cash flows can be impacted by changes in items of working capital, primarily variances in the carrying amount of inventory and the timing of payment of accounts payable and accrued liabilities related to capital expenditures.

We typically sell our crude oil in the same month in which we purchase it, and we do not rely on borrowings under our credit facility to pay for such crude oil purchases, other than inventory. During such periods, our accounts receivable and accounts payable generally move in tandem as we make payments and receive payments for the purchase and sale of oil. In our petroleum products activities, we buy products and typically either move the products to one of our storage facilities for further blending or we sell the product within days of our purchase. The cash requirements for these activities can result in short term increases and decreases in our borrowings under our credit facility. See Note 11 in our Unaudited Condensed Consolidated Financial Statements for information regarding changes in components of operating assets and liabilities for the nine months ended September 30, 2012 and 2011.

Net cash flows provided by our operating activities for the nine months ended September 30, 2012 were $142.9 million compared to $39.1 million for the nine months ended September 30, 2011. As discussed above, changes in the cash requirements related to payment for petroleum products or collection of receivables from the sale of inventory impact the cash provided by operating activities. Additionally, changes in the market prices for crude oil and petroleum products can result in fluctuations in our operating cash flows between periods as the cost to acquire a barrel of oil or products will require more or less cash. The increase in operating cash flow for the nine months ended September 30, 2012 compared to the same period in 2011 was primarily due to higher cash earnings and cash requirements to meet working capital needs.

Capital Expenditures and Distributions Paid to our Unitholders

We use cash primarily for our acquisition activities, internal growth projects and distributions we pay to our unitholders. We finance smaller internal growth projects and distributions primarily with cash generated by our operations. Acquisition activities and large internal growth projects have historically been funded with borrowings under our credit facility, equity issuances and the issuance of senior unsecured notes.

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Capital Expenditures and Business and Asset Acquisitions

A summary of our expenditures for fixed assets and other asset acquisitions for the nine months ended September 30, 2012 and 2011 is as follows:

	Nine Months Ended September 30,
	2012		2011
	(in thousands)
Capital expenditures for fixed and intangible assets:
Maintenance capital expenditures:
Pipeline transportation assets	$	261	$	231
Refinery services assets	799		1,219
Supply and logistics assets	1,660		1,935
Other assets	—		248
Total maintenance capital expenditures	2,720		3,633
Growth capital expenditures:
Pipeline transportation assets	37,184		3,033
Refinery services assets	1,496		102
Supply and logistics assets (1)	75,754		3,702
Information technology systems upgrade projects	1,175		3,516
Total growth capital expenditures	115,609		10,353
Total maintenance and growth capital expenditures	118,329		13,986
Capital expenditures for business combinations, net of liabilities assumed:
Offshore pipelines	205,576		—
Acquisition of FMT assets	—		143,489
Total business combinations capital expenditures	205,576		143,489
Capital expenditures related to equity investees(2)	57,072		—
Total capital expenditures	$	380,977	$	157,475

(1) Includes the purchase of barge assets for $30.6 million (see below for more information).

(2) Represents our investment in the SEKCO pipeline joint venture (see below for more information).

Expenditures for capital assets to grow the partnership distribution will depend on our access to debt and equity capital. We will look for opportunities to acquire assets from other parties that meet our criteria for stable cash flows.

Growth Capital Expenditures

In April 2011, we announced two projects to increase the services we provide to producers and refiners. We acquired three above-ground storage tanks located in Texas City, Texas and an existing barge dock at the same location, all approximately 1.5 miles from our existing Texas pipeline system. We also are constructing a truck station and tankage in West Columbia, Texas to provide incremental transportation service for the Eagle Ford Shale and other Texas production through our pipeline system to refining markets in the greater Houston/Texas City area. Once the refurbishment, tie-in and all interconnecting pipe are completed, estimated to be in the fourth quarter of 2012, we will be able to handle approximately 40,000 barrels per day of crude oil through the Texas City terminal. In addition, we have initiated construction of a 18-inch diameter loop of our existing crude oil pipeline into Texas City, supported by a term contract with one of our refining customers, which we expect will allow us to significantly expand our total service capabilities into the Texas City area by the second quarter of 2013.

During 2011, we also entered into an agreement to install a new sour gas processing facility at Holly Refining and Marketing’s refinery complex located in Tulsa, Oklahoma. The new facility, expected to be completed in the first quarter of 2013, will remove a portion of the sulfur from the crude oil refined at Holly’s complex and is expected to result in potential additional capacity of 24,000 DST per year of NaHS.

We anticipate the costs of the projects listed above to be approximately $80 million in total, of which we have spent approximately $56.8 million since inception in 2011. We expect that the remaining costs for the projects will be spent primarily in the fourth quarter of 2012.

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We anticipate spending approximately $33 million to upgrade our refinery facilities in Wyoming and to bring the related pipeline back in service. We spent $4.4 million related to these projects during the first nine months of 2012.

In August 2012 we completed construction on the first phase of a new crude-by-rail unloading terminal connected to our existing crude oil pipeline at Walnut Hill, Florida. This facility is capable of handling unit train shipments of oil for direct deliveries to an existing refinery customer and indirect deliveries (through third-party common carriers) to multiple other markets in the Southeast at the option of the shippers. We anticipate the second phase of the terminal, which includes a 100,000 barrel storage tank and related equipment, to be completed in the fourth quarter of 2012 and cost approximately $4.5 million.

In February 2012, we purchased seven barges from Florida Marine Transporters, which previously had been subleased to us in connection with the acquisition of the black oil barge assets in August 2011. The cost of the seven barges totaled $30.6 million, which was funded with our credit facility.

Capital Expenditures Related to Business Combinations and Equity Investees

In January 2012, we acquired from Marathon Oil Company interests in several Gulf of Mexico crude oil pipeline systems. The purchase price, net of post-closing adjustments, was $205.6 million. We account for our ownership interests in Poseidon and Odyssey under the equity method of accounting. We accounted for our acquisition of GOPL using the acquisition method. See Note 2 in our Unaudited Condensed Consolidated Financial Statements for more information.

In December 2011, we formed Southeast Keathley Canyon Pipeline Company, LLC (or SEKCO) with Enterprise Products to construct a deepwater pipeline serving the Lucius development area in southern Keathley Canyon of the Gulf of Mexico. The new pipeline is expected to begin service by mid-2014. We expect to spend approximately $200 million for our share of the pipeline construction through 2014 and to reimburse Enterprise Products for our portion of previously incurred costs. We expect to pay approximately $80 million in 2012, of which we paid $57.1 million during the first nine months of 2012. The anchor producers, which have executed long-term transportation agreements, are responsible for most cost overruns and other costs incurred associated with weather-related delays.

Distributions to Unitholders

On November 14, 2012, we will pay a distribution of $0.4725 per common unit totaling $38.4 million with respect to the third quarter of 2012 to common unitholders of record on November 1, 2012. This is the twenty-ninth consecutive quarter in which we have increased our quarterly distribution. Information on our recent distribution history is included in Note 8 to our Unaudited Condensed Consolidated Financial Statements.

Commitments and Off-Balance Sheet Arrangements

Contractual Obligations and Commercial Commitments

There have been no material changes to the commitments and obligations reflected in our Annual Report on Form 10-K for the year ended December 31, 2011.

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements, special purpose entities, or financing partnerships, other than as disclosed under “Contractual Obligations and Commercial Commitments” in our Annual Report on Form 10-K for the year ended December 31, 2011, nor do we have any debt or equity triggers based upon our unit or commodity prices.

Forward Looking Statements

The statements in this Quarterly Report on Form 10-Q that are not historical information may be “forward looking statements” as defined under federal law. All statements, other than historical facts, included in this document that address activities, events or developments that we expect or anticipate will or may occur in the future, including things such as plans for growth of the business, future capital expenditures, competitive strengths, goals, references to future goals or intentions and other such references are forward-looking statements. These forward-looking statements are identified as any statement that does not relate strictly to historical or current facts. They use words such as “anticipate,” “believe,” “continue,” “estimate,” “expect,” “forecast,” “goal,” “intend,” “may,” “could,” “plan,” “position,” “projection,” “strategy,” “should” or “will,” or the negative of those terms or other variations of them or by comparable terminology. In particular, statements, expressed or implied, concerning future actions, conditions or events or future operating results or the ability to generate sales, income or cash flow are forward-looking statements. Forward-looking statements are not guarantees of performance. They involve risks, uncertainties and assumptions. Future actions, conditions or events and future results of operations may differ materially from

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those expressed in these forward-looking statements. Many of the factors that will determine these results are beyond our ability or the ability of our affiliates to control or predict. Specific factors that could cause actual results to differ from those in the forward-looking statements include, among others:

• demand for, the supply of, our assumptions about, changes in forecast data for, and price trends related to crude oil, liquid petroleum, NaHS and caustic soda and CO2, all of which may be affected by economic activity, capital expenditures by energy producers, weather, alternative energy sources, international events, conservation and technological advances;

• throughput levels and rates;

• changes in, or challenges to, our tariff rates;

• our ability to successfully identify and close strategic acquisitions on acceptable terms (including obtaining third-party consents and waivers of preferential rights), develop or construct energy infrastructure assets, make cost saving changes in operations and integrate acquired assets or businesses into our existing operations;

• service interruptions in our pipeline transportation systems and processing operations;

• shut-downs or cutbacks at refineries, petrochemical plants, utilities or other businesses for which we transport crude oil, petroleum products, or CO2or to whom we sell such products;

• risks inherent in marine transportation and vessel operation, including accidents and discharge of pollutants;

• changes in laws and regulations to which we are subject, including tax withholding issues, accounting pronouncements, and safety, environmental and employment laws and regulations;

• the effects of production declines resulting from the suspension of drilling in the Gulf of Mexico and the effects of future laws and government regulation resulting from the Macondo accident and oil spill in the Gulf;

• planned capital expenditures and availability of capital resources to fund capital expenditures;

• our inability to borrow or otherwise access funds needed for operations, expansions or capital expenditures as a result of our credit agreement and the indenture governing our notes, which contain various affirmative and negative covenants;

• loss of key personnel;

• an increase in the competition that our operations encounter;

• cost and availability of insurance;

• hazards and operating risks that may not be covered fully by insurance;

• our financial and commodity hedging arrangements;

• changes in global economic conditions, including capital and credit markets conditions, inflation and interest rates;

• natural disasters, accidents or terrorism;

• changes in the financial condition of customers or counterparties;

• adverse rulings, judgments, or settlements in litigation or other legal or tax matters;

• the treatment of us as a corporation for federal income tax purposes or if we become subject to entity-level taxation for state tax purposes; and

• the potential that our internal controls may not be adequate, weaknesses may be discovered or remediation of any identified weaknesses may not be successful and the impact these could have on our unit price.

You should not put undue reliance on any forward-looking statements. When considering forward-looking statements, please review the risk factors described under “Risk Factors” discussed in Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2011 and any other risk factors contained in our Current Reports on Form 8-K that we may file from time to time with the SEC. Except as required by applicable securities laws, we do not intend to update these forward-looking statements and information.

Item 3. Quantitative and Qualitative Disclosures about Market Risk

The following should be read in conjunction with Quantitative and Qualitative Disclosures About Market Risk included under Item 7A in our 2011 Annual Report on Form 10-K. There have been no material changes that would affect the quantitative and qualitative disclosures provided therein. Also, see Note 12 to our Unaudited Condensed Consolidated Financial Statements for additional discussion related to derivative instruments and hedging activities.

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Item 4. Controls and Procedures

We maintain disclosure controls and procedures and internal controls designed to ensure that information required to be disclosed in our filings under the Securities Exchange Act of 1934 is recorded, processed, summarized, and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms. Our chief executive officer and chief financial officer, with the participation of our management, have evaluated our disclosure controls and procedures as of the end of the period covered by this Quarterly Report on Form 10-Q and have determined that such disclosure controls and procedures are effective in ensuring that material information required to be disclosed in this quarterly report is accumulated and communicated to them and our management to allow timely decisions regarding required disclosures.

There were no changes during the period covered by this report that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

Information with respect to this item has been incorporated by reference from our Annual Report on Form 10-K for the year ended December 31, 2011. There have been no material developments in legal proceedings since the filing of such Form 10-K.

Item 1A. Risk Factors

For additional information about our risk factors, see Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2011. On October 11, 2012, we filed a Current Report on Form 8-K that, among other things, included the risk factor set forth below. There have been no material changes to the risk factors since the filing of such Form 10-K and/or Form 8-K.

The Davison family exerts significant influence over us and may have conflicts of interest with us and may be permitted to favor its interests to the detriment of our other unitholders.

James E. Davison, Sr. and James E. Davison, Jr., each of whom is a director of our general partner, and certain of their family members and affiliates own approximately 17.2% of our Common Units - Class A and 76.9% of our Common Units - Class B. The Davison family is able to exert significant influence over us, including the ability to elect at least a majority of the members of our board of directors and the ability to control most matters requiring board approval, such as business strategies, mergers, business combinations, acquisitions or dispositions of significant assets, issuances of additional partnership securities, incurrence of debt or other financing and the payment of distributions. In addition, the continued existence of a controlling group may have the effect of making it difficult for, or may discourage or delay, a third party from seeking to acquire us, which may adversely affect the market price of our common units. Further, conflicts of interest may arise between us and other entities for which members of the Davison family serve as officers or directors. In resolving any conflicts that may arise, such members of the Davison family may favor the interests of another entity over our interests.

The Davison family owns, controls and has interests in diverse companies, some of which may (or could in the future) compete directly or indirectly with us. As a result, the Davison family's interests may not always be consistent with our interests or the interests of our other unitholders. The Davison family could also pursue acquisitions or business opportunities that may be complementary to our business. Our organizational documents allow the holders of our units (including affiliates, like the Davisons) to take advantage of such corporate opportunities without first presenting such opportunities to us. As a result, corporate opportunities that may benefit us may not be available to us in a timely manner, or at all. To the extent that conflicts of interest may arise among us and members of the Davison family, those conflicts may be resolved in a manner adverse to us or you. Other potential conflicts may involve, among others, the following situations:

• our general partner is allowed to take into account the interest of parties other than us, such as one or more of its affiliates, in resolving conflicts of interest;

• our general partner may limit its liability and reduce its fiduciary duties, while also restricting the remedies available to our unitholders for actions that, without such limitations, might constitute breaches of fiduciary duty;

• our general partner determines the amount and timing of asset purchases and sales, capital expenditures, borrowings, issuance of additional partnership securities, reimbursements and enforcement of obligations to the general partner and its affiliates, retention of counsel, accountants and service providers, and cash reserves, each of which can also affect the amount of cash that is distributed to our unitholders; and

41

• our general partner determines which costs incurred by it and its affiliates are reimbursable by us and the reimbursement of these costs and of any services provided by our general partner could adversely affect our ability to pay cash distributions to our unitholders.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

None.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

None.

42

Item 6. Exhibits.

(a) Exhibits

3.1	Certificate of Limited Partnership of Genesis Energy, L.P. (incorporated by reference to Exhibit 3.1 to Amendment No. 2 to Registration Statement on Form S-1, File No. 333-11545).
3.2	Amendment to the Certificate of Limited Partnership of Genesis Energy, L.P. (incorporated by reference to Exhibit 3.2 to Form 10-Q for the quarterly period ended June 30, 2011, File No. 011-12295).
3.3	Fifth Amended and Restated Agreement of Limited Partnership of Genesis Energy, L.P. (incorporated by reference to Exhibit 3.1 to Form 8-K dated January 3, 2011, File No. 001-12295).
3.4	Certificate of Conversion of Genesis Energy, Inc. a Delaware corporation, into Genesis Energy, LLC, a Delaware limited liability company (incorporated by reference to Exhibit 3.1 to Form 8-K dated January 7, 2009, File No. 001-12295).
3.5	Certificate of Formation of Genesis Energy, LLC (formerly Genesis Energy, Inc.) (incorporated by reference to Exhibit 3.2 to Form 8-K dated January 3, 2011, File No. 001-12295).
3.6	Second Amended and Restated Limited Liability Company Agreement of Genesis Energy, LLC dated December 28, 2010 (incorporated by reference to Exhibit 3.2 to Form 8-K dated January 3, 2011, File No. 001-12295).
4.1	Form of Unit Certificate of Genesis Energy, L.P. (incorporated by reference to Exhibit 4.1 to Form 10-K for the year ended December 31, 2007, File No. 001-12295).
10.1	Third Amended and Restated Credit Agreement, dated as of July 25, 2012, among Genesis Energy, L.P. as borrower, Wells Fargo Bank, National Association, as administrative agent, Bank of America, N.A. and Bank of Montreal as co-syndication agents, U.S. Bank National Association as documentation agent, and the lenders party thereto (incorporated by reference to Exhibit 10.1 to Form 8-K dated July 31, 2012, File No. 001-12295).

31.1 *	Certification by Chief Executive Officer Pursuant to Rule 13a-14(a) of the Securities Exchange Act of 1934.
31.2 *	Certification by Chief Financial Officer Pursuant to Rule 13a-14(a) of the Securities Exchange Act of 1934.
32 *	Certification by Chief Executive Officer and Chief Financial Officer Pursuant to Rule 13a-14(b) of the Securities Exchange Act of 1934.
101.INS *	XBRL Instance Document
101.SCH *	XBRL Schema Document
101.CAL *	XBRL Calculation Linkbase Document
101.LAB *	XBRL Label Linkbase Document
101.PRE *	XBRL Presentation Linkbase Document
101.DEF *	XBRL Definition Linkbase Document

* Filed herewith

43

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

	GENESIS ENERGY, L.P. (A Delaware Limited Partnership)
By:	GENESIS ENERGY, LLC, as General Partner

Date:	November 6, 2012	By:	/s/ ROBERT V. DEERE
			Robert V. Deere
			Chief Financial Officer

44

EX-31.1

Exhibit 31.1

CERTIFICATION

I, Grant E. Sims, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Genesis Energy, L.P.;

2. Based on my knowledge, this quarterly report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this quarterly report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and we have:

a. designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c. evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation, and

d. disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors:

a. all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b. any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	November 6, 2012	/s/ Grant E. Sims
		Grant E. Sims
		Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATION

I, Robert V. Deere, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Genesis Energy, L.P.;

2. Based on my knowledge, this quarterly report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this quarterly report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and we have:

a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation, and

d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors:

a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	November 6, 2012	/s/ Robert V. Deere
		Robert V. Deere
		Chief Financial Officer

EX-32

Exhibit 32

CERTIFICATION BY CHIEF EXECUTIVE OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of Genesis Energy, L.P. (the “Partnership”) for the period ended September 30, 2012 (the “Report”) filed with the Securities and Exchange Commission on the date hereof, the undersigned, Grant E. Sims, Chief Executive Officer and Robert V. Deere, Chief Financial Officer of Genesis Energy, LLC, the general partner of the Partnership, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) the Partnership’s Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 as amended; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.

November 6, 2012	/s/ Grant E. Sims
	Grant E. Sims
	Chief Executive Officer,
	Genesis Energy, LLC
	/s/ Robert V. Deere
	Robert V. Deere
	Chief Financial Officer,
	Genesis Energy, LLC

XML

Acquisitions (Schedule Of Selected Financial Information) (Details) (Gulf Of Mexico Crude Oil Pipeline Systems [Member], USD $) In Thousands, unless otherwise specified	3 Months Ended	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2012
Gulf Of Mexico Crude Oil Pipeline Systems [Member]
Business Acquisition [Line Items]
Revenues	$ 1,180	$ 4,334
Equity in earnings of equity investees	3,497	9,194
Net income	$ 3,950	$ 11,128

XML

Partners' Capital And Distributions (Narrative) (Details) (USD $) In Millions, except Share data, unless otherwise specified	3 Months Ended										9 Months Ended			9 Months Ended		9 Months Ended		0 Months Ended			9 Months Ended	3 Months Ended	9 Months Ended	3 Months Ended	9 Months Ended	3 Months Ended	9 Months Ended	3 Months Ended	9 Months Ended
	Sep. 30, 2012		Jun. 30, 2012		Mar. 31, 2012		Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Sep. 30, 2012	Sep. 30, 2011	Dec. 31, 2010	Sep. 30, 2012 Waiver Units Class 1 [Member]	Mar. 31, 2012 Waiver Units Class 1 [Member]	Sep. 30, 2012 Waiver Units Class 3 [Member]	Sep. 30, 2012 Waiver Units Class 4 [Member]	Mar. 28, 2012 Class A [Member]	Sep. 30, 2012 Class A [Member]	Sep. 30, 2012 Class B [Member]	Sep. 30, 2012 Waiver Units [Member]	Sep. 30, 2012 Class One [Member]	Sep. 30, 2012 Class One [Member]	Sep. 30, 2012 Class Two [Member]	Sep. 30, 2012 Class Two [Member]	Sep. 30, 2012 Class Three [Member]	Sep. 30, 2012 Class Three [Member]	Sep. 30, 2012 Class Four [Member]	Sep. 30, 2012 Class Four [Member]	Sep. 30, 2012 Waiver Units Class2 [Member]
Partners Capital And Distributions [Line Items]
Issuance of common units											5,750,000	7,350,000						5,750,000
Price per share of common units issued																		$ 30.80
Proceeds received from offering, net of costs																		$ 169.4
Common units, outstanding	81,202,752						71,965,062	71,965,000			81,202,752	71,965,000	64,615,000						81,162,755	39,997
Waiver units authorized																1,750,000	1,750,000													1,750,000
Waiver units issued														1,738,000		1,738,000	1,738,000													1,738,000
Conversion feature, minimum distribution coverage ratio																						1.1		1.1		1.1		1.1
Conversion feature threshold, quarterly distribution, minimum, per unit																							0.43		0.46		0.49		0.52
Waiver Units Class 1 Convertible Date					February 14, 2012	[1]
Distribution paid per common unit	$ 0.4725		$ 0.4600		$ 0.4500		$ 0.4400	$ 0.4275	$ 0.4150	$ 0.4075	$ 0.4725	$ 0.4275			$ 0.44															$ 0.46
Waiver units outstanding																5,214,099	5,214,099				3,476,466
Waiver Units Class 2 Convertible Date	August 14, 2012	[1]
Distribution Made to Member or Limited Partner, Distribution Date	November 14, 2012		August 14, 2012	[1]	May 15, 2012		February 14, 2012	November 14, 2011	August 12, 2011	May 13, 2011

[1] (1) This distribution will be paid to unitholders of record as of November 1, 2012.

XML

Equity Investees (Schedule Of Balance Sheet Information For Equity Investees) (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Equity Method Investments and Joint Ventures [Abstract]
Current assets	$ 65,250	$ 12,732
Fixed assets, net	760,788	441,894
Other assets	10,964	18,000
Total assets	837,002	472,626
Current liabilities	53,667	5,891
Other liabilities	118,226	8,536
Equity	665,109	458,199
Total liabilities and equity	$ 837,002	$ 472,626

XML

Condensed Consolidating Financial Information (Condensed Consolidating Balance Sheet) (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2011	Dec. 31, 2010
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	$ 15,461	$ 10,817	$ 4,376	$ 5,762
Other current assets	411,806	365,287
Total current assets	427,267	376,104
Fixed Assets, at cost	684,663	541,138
Less: Accumulated depreciation	(148,712)	(124,213)
Net fixed assets	535,951	416,925
Goodwill	325,046	325,046
Other assets, net	270,966	285,822
Equity investees	547,925	326,947
Investments in subsidiaries	0	0
TOTAL ASSETS	2,107,155	1,730,844
Current liabilities	318,379	249,428
Senior secured credit facility	483,000	409,300
SENIOR UNSECURED NOTES	350,924	250,000
Deferred tax liabilities	11,598	12,549
Other liabilities	15,321	16,929
Total liabilities	1,179,222	938,206
Partners' capital	927,933	792,638
TOTAL LIABILITIES AND PARTNERS' CAPITAL	2,107,155	1,730,844
Genesis Energy, L.P. (Parent And Co-Issuer) [Member]
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	11	3	2	1
Other current assets	744,217	597,966
Total current assets	744,228	597,969
Fixed Assets, at cost	0	0
Less: Accumulated depreciation	0	0
Net fixed assets	0	0
Goodwill	0	0
Other assets, net	19,152	14,773
Equity investees	0	0
Investments in subsidiaries	1,007,650	841,725
TOTAL ASSETS	1,771,030	1,454,467
Current liabilities	9,173	2,529
Senior secured credit facility	483,000	409,300
SENIOR UNSECURED NOTES	350,924	250,000
Deferred tax liabilities	0	0
Other liabilities	0	0
Total liabilities	843,097	661,829
Partners' capital	927,933	792,638
TOTAL LIABILITIES AND PARTNERS' CAPITAL	1,771,030	1,454,467
Genesis Energy Finance Corporation (Co-Issuer) [Member]
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	0	0	0	0
Other current assets	0	0
Total current assets	0	0
Fixed Assets, at cost	0	0
Less: Accumulated depreciation	0	0
Net fixed assets	0	0
Goodwill	0	0
Other assets, net	0	0
Equity investees	0	0
Investments in subsidiaries	0	0
TOTAL ASSETS	0	0
Current liabilities	0	0
Senior secured credit facility	0	0
SENIOR UNSECURED NOTES	0	0
Deferred tax liabilities	0	0
Other liabilities	0	0
Total liabilities	0	0
Partners' capital	0	0
TOTAL LIABILITIES AND PARTNERS' CAPITAL	0	0
Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	14,753	9,182	3,654	5,082
Other current assets	387,772	341,131
Total current assets	402,525	350,313
Fixed Assets, at cost	583,751	444,262
Less: Accumulated depreciation	(136,459)	(114,655)
Net fixed assets	447,292	329,607
Goodwill	325,046	325,046
Other assets, net	257,694	276,450
Equity investees	547,925	326,947
Investments in subsidiaries	100,005	96,303
TOTAL ASSETS	2,080,487	1,704,666
Current liabilities	1,047,542	835,013
Senior secured credit facility	0	0
SENIOR UNSECURED NOTES	0	0
Deferred tax liabilities	11,598	12,549
Other liabilities	12,850	14,673
Total liabilities	1,071,990	862,235
Partners' capital	1,008,497	842,431
TOTAL LIABILITIES AND PARTNERS' CAPITAL	2,080,487	1,704,666
Non-Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	697	1,632	720	679
Other current assets	38,521	31,897
Total current assets	39,218	33,529
Fixed Assets, at cost	100,912	96,876
Less: Accumulated depreciation	(12,253)	(9,558)
Net fixed assets	88,659	87,318
Goodwill	0	0
Other assets, net	158,875	162,373
Equity investees	0	0
Investments in subsidiaries	0	0
TOTAL ASSETS	286,752	283,220
Current liabilities	19,987	17,562
Senior secured credit facility	0	0
SENIOR UNSECURED NOTES	0	0
Deferred tax liabilities	0	0
Other liabilities	167,041	169,842
Total liabilities	187,028	187,404
Partners' capital	99,724	95,816
TOTAL LIABILITIES AND PARTNERS' CAPITAL	286,752	283,220
Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Cash and cash equivalents	0	0	0	0
Other current assets	(758,704)	(605,707)
Total current assets	(758,704)	(605,707)
Fixed Assets, at cost	0	0
Less: Accumulated depreciation	0	0
Net fixed assets	0	0
Goodwill	0	0
Other assets, net	(164,755)	(167,774)
Equity investees	0	0
Investments in subsidiaries	(1,107,655)	(938,028)
TOTAL ASSETS	(2,031,114)	(1,711,509)
Current liabilities	(758,323)	(605,676)
Senior secured credit facility	0	0
SENIOR UNSECURED NOTES	0	0
Deferred tax liabilities	0	0
Other liabilities	(164,570)	(167,586)
Total liabilities	(922,893)	(773,262)
Partners' capital	(1,108,221)	(938,247)
TOTAL LIABILITIES AND PARTNERS' CAPITAL	$ (2,031,114)	$ (1,711,509)

XML

Partners' Capital And Distributions (Distributions) (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended
	Sep. 30, 2012	Jun. 30, 2012		Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011
Partners' Capital Notes [Abstract]
Date Paid	November 14, 2012	August 14, 2012	[1]	May 15, 2012	February 14, 2012	November 14, 2011	August 12, 2011	May 13, 2011
Per Unit Amount	$ 0.4725	$ 0.4600		$ 0.4500	$ 0.4400	$ 0.4275	$ 0.4150	$ 0.4075
Total Amount	$ 38,368	$ 36,554		$ 35,759	$ 31,677	$ 30,777	$ 29,878	$ 26,343

[1] (1) This distribution will be paid to unitholders of record as of November 1, 2012.

XML

Equity Investees (Narrative) (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Equity Method Investments and Joint Ventures [Abstract]
Unamortized excess cost amount	$ 236.6	$ 97.8

XML

Derivatives (Tables)

9 Months Ended

Sep. 30, 2012

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule Of Outstanding Derivatives Entered Into To Hedge Inventory Or Fixed Price Purchase Commitments

	Sell (Short) Contracts		Buy (Long) Contracts
Not qualifying or not designated as hedges under accounting rules:
Crude oil futures:
Contract volumes (1,000 bbls)	59		25
Weighted average contract price per bbl	$	92.69	$	92.19
Crude oil LLS/WTI swap:
Contract volumes (1,000 bbls)	100		—
Weighted average contract price per bbl	$	18.63	$	—
Heating oil futures:
Contract volumes (1,000 bbls)	94		66
Weighted average contract price per gal	$	3.12	$	3.16
#6 Fuel oil futures:
Contract volumes (1,000 bbls)	640		200
Weighted average contract price per bbl	$	97.59	$	98.05
Crude oil options:
Contract volumes (1,000 bbls)	360		105
Weighted average premium received	$	1.69	$	0.54
Heating oil options:
Contract volumes (1,000 bbls)	10		—
Weighted average premium received	$	0.08	$	—

Schedule Of Fair Value Of Derivative Assets And Liabilities

	Unaudited Condensed Consolidated Balance Sheets Location	Fair Value
		September 30, 2012				December 31, 2011
Asset Derivatives:
Commodity derivatives - futures and call options:
Undesignated hedges	Current Assets - Other	$	178			$	306
Total asset derivatives		$	178			$	306
Liability Derivatives:
Commodity derivatives - futures and call options:
Undesignated hedges	Current Assets - Other	$	(1,440	)	(1)	$	(2,820	)	(1)
Total liability derivatives		$	(1,440	)		$	(2,820	)

(1) These derivative liabilities have been funded with margin deposits recorded in our Unaudited Condensed Consolidated Balance Sheets under Current Assets - Other.

Schedule Of Effect On Operating Results

		Amount of Gain (Loss) Recognized in Income
	Unaudited Condensed Consolidated Statements of Operations Location	Three Months Ended September 30,					Nine Months Ended September 30,
		2012			2011		2012			2011
Commodity derivatives - futures and call options:
Contracts designated as hedges under accounting guidance	Supply and logistics product costs	$	—		$	—	$	—		$	(173	)
Contracts not considered hedges under accounting guidance	Supply and logistics product costs	(5,817		)	2,587		(2,959		)	(11,050		)
Total commodity derivatives		$	(5,817	)	$	2,587	$	(2,959	)	$	(11,223	)

XML

Business Segment Information (Schedule Of Total Assets By Reportable Segment) (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]
Total consolidated assets	$ 2,107,155	$ 1,730,844
Pipeline Transportation [Member]
Segment Reporting Information [Line Items]
Total consolidated assets	870,966	594,728
Refinery Services [Member]
Segment Reporting Information [Line Items]
Total consolidated assets	413,888	426,993
Supply And Logistics [Member]
Segment Reporting Information [Line Items]
Total consolidated assets	774,002	659,576
Other Assets [Member]
Segment Reporting Information [Line Items]
Total consolidated assets	$ 48,299	$ 49,547

XML

Condensed Consolidating Financial Information (Condensed Consolidating Statement Of Operations) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Condensed Financial Statements, Captions [Line Items]
Supply and logistics	$ 875,193	$ 765,714	$ 2,597,809	$ 2,091,854
Refinery services	47,977	48,392	144,342	145,301
Pipeline transportation services	19,164	16,094	55,794	45,633
Total revenues	942,334	830,200	2,797,945	2,282,788
Supply and logistics costs	852,849	743,833	2,531,980	2,044,554
Refinery services operating costs	29,243	30,136	91,072	89,986
Pipeline transportation operating costs	5,911	3,988	15,995	12,414
General and administrative	10,375	8,905	29,934	25,339
Depreciation and amortization	14,838	14,706	45,447	43,100
Total costs and expenses	913,216	801,568	2,714,428	2,215,393
OPERATING INCOME	29,118	28,632	83,517	67,395
Equity in earnings of subsidiaries	0	0	0	0
Equity in earnings of equity investees	3,432	(412)	7,971	3,377
Interest (expense) income, net	(9,873)	(8,960)	(30,697)	(26,670)
Income before income taxes	22,677	19,260	60,791	44,102
Income tax (expense) benefit	8,517	(172)	8,591	(626)
NET INCOME	31,194	19,088	69,382	43,476
Genesis Energy, L.P. (Parent And Co-Issuer) [Member]
Condensed Financial Statements, Captions [Line Items]
Supply and logistics	0	0	0	0
Refinery services	0	0	0	0
Pipeline transportation services	0	0	0	0
Total revenues	0	0	0	0
Supply and logistics costs	0	0	0	0
Refinery services operating costs	0	0	0	0
Pipeline transportation operating costs	0	0	0	0
General and administrative	0	0	0	0
Depreciation and amortization	0	0	0	0
Total costs and expenses	0	0	0	0
OPERATING INCOME	0	0	0	0
Equity in earnings of subsidiaries	41,052	28,032	100,011	70,092
Equity in earnings of equity investees	0	0	0	0
Interest (expense) income, net	(9,858)	(8,944)	(30,629)	(26,616)
Income before income taxes	31,194	19,088	69,382	43,476
Income tax (expense) benefit	0	0	0	0
NET INCOME	31,194	19,088	69,382	43,476
Genesis Energy Finance Corporation (Co-Issuer) [Member]
Condensed Financial Statements, Captions [Line Items]
Supply and logistics	0	0	0	0
Refinery services	0	0	0	0
Pipeline transportation services	0	0	0	0
Total revenues	0	0	0	0
Supply and logistics costs	0	0	0	0
Refinery services operating costs	0	0	0	0
Pipeline transportation operating costs	0	0	0	0
General and administrative	0	0	0	0
Depreciation and amortization	0	0	0	0
Total costs and expenses	0	0	0	0
OPERATING INCOME	0	0	0	0
Equity in earnings of subsidiaries	0	0	0	0
Equity in earnings of equity investees	0	0	0	0
Interest (expense) income, net	0	0	0	0
Income before income taxes	0	0	0	0
Income tax (expense) benefit	0	0	0	0
NET INCOME	0	0	0	0
Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Supply and logistics	869,726	765,714	2,579,102	2,091,854
Refinery services	48,809	48,700	142,716	142,992
Pipeline transportation services	12,596	9,388	36,381	26,292
Total revenues	931,131	823,802	2,758,199	2,261,138
Supply and logistics costs	852,009	743,833	2,525,474	2,044,554
Refinery services operating costs	29,339	30,448	89,155	88,641
Pipeline transportation operating costs	5,661	3,818	15,351	11,937
General and administrative	10,343	8,905	29,842	25,339
Depreciation and amortization	13,940	14,057	42,759	41,153
Total costs and expenses	911,292	801,061	2,702,581	2,211,624
OPERATING INCOME	19,839	22,741	55,618	49,514
Equity in earnings of subsidiaries	5,738	1,945	15,869	5,238
Equity in earnings of equity investees	3,432	(412)	7,971	3,377
Interest (expense) income, net	4,119	4,226	12,414	12,726
Income before income taxes	33,128	28,500	91,872	70,855
Income tax (expense) benefit	8,509	(233)	8,630	(467)
NET INCOME	41,637	28,267	100,502	70,388
Non-Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Supply and logistics	31,113	0	95,451	0
Refinery services	4,367	3,805	13,756	12,953
Pipeline transportation services	6,568	6,706	19,413	19,341
Total revenues	42,048	10,511	128,620	32,294
Supply and logistics costs	26,488	0	83,250	0
Refinery services operating costs	4,565	3,612	13,701	11,836
Pipeline transportation operating costs	250	170	644	477
General and administrative	32	0	92	0
Depreciation and amortization	898	649	2,688	1,947
Total costs and expenses	32,233	4,431	100,375	14,260
OPERATING INCOME	9,815	6,080	28,245	18,034
Equity in earnings of subsidiaries	0	0	0	0
Equity in earnings of equity investees	0	0	0	0
Interest (expense) income, net	(4,134)	(4,242)	(12,482)	(12,780)
Income before income taxes	5,681	1,838	15,763	5,254
Income tax (expense) benefit	8	61	(39)	(159)
NET INCOME	5,689	1,899	15,724	5,095
Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Supply and logistics	(25,646)	0	(76,744)	0
Refinery services	(5,199)	(4,113)	(12,130)	(10,644)
Pipeline transportation services	0	0	0	0
Total revenues	(30,845)	(4,113)	(88,874)	(10,644)
Supply and logistics costs	(25,648)	0	(76,744)	0
Refinery services operating costs	(4,661)	(3,924)	(11,784)	(10,491)
Pipeline transportation operating costs	0	0	0	0
General and administrative	0	0	0	0
Depreciation and amortization	0	0	0	0
Total costs and expenses	(30,309)	(3,924)	(88,528)	(10,491)
OPERATING INCOME	(536)	(189)	(346)	(153)
Equity in earnings of subsidiaries	(46,790)	(29,977)	(115,880)	(75,330)
Equity in earnings of equity investees	0	0	0	0
Interest (expense) income, net	0	0	0	0
Income before income taxes	(47,326)	(30,166)	(116,226)	(75,483)
Income tax (expense) benefit	0	0	0	0
NET INCOME	$ (47,326)	$ (30,166)	$ (116,226)	$ (75,483)

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Fixed Assets And Asset Retirement Obligations (Tables)

9 Months Ended

Sep. 30, 2012

Fixed Assets And Asset Retirement Obligations [Abstract]

Schedule Of Fixed Assets

	September 30, 2012			December 31, 2011
Pipelines and related assets	$	218,155		$	167,865
Machinery and equipment	63,091			46,233
Transportation equipment	20,280			21,732
Marine vessels	297,416			262,216
Land, buildings and improvements	14,037			13,140
Office equipment, furniture and fixtures	4,487			3,778
Construction in progress	53,135			14,236
Other	14,062			11,938
Fixed assets, at cost	684,663			541,138
Less: Accumulated depreciation	(148,712		)	(124,213		)
Net fixed assets	$	535,951		$	416,925

Depreciation Expense

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
Depreciation expense	$	9,202	$	5,960	$	27,246	$	17,838

Schedule Of Reconciliation Of Liability For Asset Retirement Obligations

December 31, 2011	$	5,900
Liabilities incurred and assumed in the current period	5,995
Accretion expense	600
September 30, 2012	$	12,495

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Intangible Assets (Schedule Of Components Of Intangible Assets) (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross Carrying Amount	$ 255,846	$ 254,671
Intangible assets, Accumulated Amortization	176,706	161,315
Intangible assets, Carrying Value	79,140	93,356
Refinery Services Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross Carrying Amount	94,654	94,654
Intangible assets, Accumulated Amortization	67,403	62,111
Intangible assets, Carrying Value	27,251	32,543
Refinery Services Licensing Agreements [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross Carrying Amount	38,678	38,678
Intangible assets, Accumulated Amortization	22,038	19,476
Intangible assets, Carrying Value	16,640	19,202
Refinery Services Supplier Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross Carrying Amount	36,469	36,469
Intangible assets, Accumulated Amortization	35,878	34,105
Intangible assets, Carrying Value	591	2,364
Refinery Services Segment Total [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross Carrying Amount	169,801	169,801
Intangible assets, Accumulated Amortization	125,319	115,692
Intangible assets, Carrying Value	44,482	54,109
Supply And Logistics Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross Carrying Amount	35,430	35,430
Intangible assets, Accumulated Amortization	25,698	23,584
Intangible assets, Carrying Value	9,732	11,846
Supply And Logistics Intangibles Associated With Lease [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross Carrying Amount	13,260	13,260
Intangible assets, Accumulated Amortization	2,447	2,092
Intangible assets, Carrying Value	10,813	11,168
Supply And Logistics Trade Names [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross Carrying Amount	18,888	18,888
Intangible assets, Accumulated Amortization	18,888	17,048
Intangible assets, Carrying Value	0	1,840
Supply And Logistics Segment Total [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross Carrying Amount	67,578	67,578
Intangible assets, Accumulated Amortization	47,033	42,724
Intangible assets, Carrying Value	20,545	24,854
Other [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross Carrying Amount	18,467	17,292
Intangible assets, Accumulated Amortization	4,354	2,899
Intangible assets, Carrying Value	$ 14,113	$ 14,393

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Fixed Assets And Asset Retirement Obligations (Narrative) (Details) (USD $) In Millions, unless otherwise specified	Jan. 03, 2012
Fixed Assets And Asset Retirement Obligations [Abstract]
Asset retirement obligation assumed in acquisition of GOPL	$ 5.9

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Acquisitions (Narrative) (Details) (USD $) In Millions, unless otherwise specified		9 Months Ended
	Jul. 20, 2011	Sep. 30, 2012 Gulf Of Mexico Crude Oil Pipeline Systems [Member]	Jan. 03, 2012 Gulf Of Mexico Crude Oil Pipeline Systems [Member]	Aug. 09, 2011 Fmt Black Oil Barge Transportation Business [Member] Barges push_boats	Aug. 09, 2011 Fmt Black Oil Barge Transportation Business Fuel Inventory And Other Cost [Member]	Jan. 03, 2012 FMT Lease [Member]	Aug. 09, 2011 FMT Lease [Member] Barges	Jan. 03, 2012 Genesis Energy Interest In Poseidon [Member]	Jan. 03, 2012 Genesis Energy Interest In GOPL [Member]	Jan. 03, 2012 Genesis Energy Interest In Odyssey [Member]	Jan. 03, 2012 GOPL Interest In Eugene Island Crude Oil Pipeline System [Member]	Jan. 03, 2012 GOPL Interest In Two Small Offshore Pipelines [Member] Other Offshore Pipelines [Member] push_boats	Sep. 30, 2012 Poseidon [Member] mi	Sep. 30, 2012 Eugene Island Pipeline System [Member] mi in	Sep. 30, 2012 Odyssey [Member] mi	Sep. 30, 2012 Maximum [Member] Poseidon [Member] in	Sep. 30, 2012 Maximum [Member] Odyssey [Member] in	Sep. 30, 2012 Minimum [Member] Poseidon [Member] in	Sep. 30, 2012 Minimum [Member] Odyssey [Member] in
Business Acquisition [Line Items]
Percentage of equity interest acquired								28.00%	100.00%	29.00%	23.00%	100.00%
Effective date of acquisition		January 2012
Purchase price, net of post-closing adjustments of acquired entity			$ 205.6	$ 143.5	$ 2.5	$ 30.6
Number of small offshore pipelines acquired												2
Pipeline capacity, barrels per day													400,000	200,000	300,000
Pipeline length, in miles													367	183	120
Pipeline diameter, in inches														20		24	20	16	12
Business Acquisition, Barges Acquired				30			7
Business Acquisition, Push Boats Acquired				14
Equity Issuance, Amount	$ 185

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Debt (Narrative) (Details) (USD $)		9 Months Ended		9 Months Ended										9 Months Ended
	Jul. 25, 2012 Inventory Sublimit [Member]	Sep. 30, 2012 Senior Secured Credit Facility [Member]	Jul. 25, 2012 Senior Secured Credit Facility [Member]	Sep. 30, 2012 Senior Unsecured Notes [Member]	Jul. 25, 2012 Accordion Feature [Member]	Sep. 30, 2012 Senior Unsecured Notes [Member]	Feb. 01, 2012 Senior Unsecured Notes [Member]	Sep. 30, 2012 Senior Secured Credit Facility [Member]	Sep. 30, 2012 Senior Secured Credit Facility [Member] Letters Of Credit [Member]	Sep. 30, 2012 Inventory Sublimit [Member] Senior Secured Credit Facility [Member]	Sep. 30, 2012 Senior Secured Credit Facility [Member]	Sep. 30, 2012 Inventory Sublimit [Member]	Jul. 25, 2012 Amended Facility [Member]	Sep. 30, 2012 Minimum [Member]	Sep. 30, 2012 Maximum [Member]	Jul. 25, 2012 Accordion Feature [Member]
Debt Instrument [Line Items]
Credit facility, amount outstanding								$ 483,000,000		$ 48,600,000
Credit facility, maximum borrowing capacity	125,000,000		775,000,000		225,000,000				100,000,000			150,000,000	1,000,000,000			300,000,000
Credit facility, aggregate maximum borrowing capacity											1,300,000,000
Letters of credit, outstanding amount									12,600,000
Credit facility and senior unsecured notes, maturity dates		Jul. 25, 2017		Dec. 15, 2018
Eurodollar Borrowings Margin														1.75%	2.75%
Alternate Base Rate Borrowings Margin														0.75%	1.75%
Letter of Credit, Fee Percentage														1.75%	2.75%
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage														0.375%	0.50%
Total amount available for borrowings under credit facility								504,400,000
Senior unsecured notes, principal amount						$ 350,000,000	$ 100,000,000
Senior unsecured notes, stated rate						7.875%
Senior unsecured notes, percentage of face value							101.00%
Senior unsecured notes, effective interest rate							7.682%

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Fair-Value Measurements (Placement Of Assets And Liabilities Within The Fair Value Hierarchy Levels) (Details) (Commodity Derivatives [Member], USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	$ 178	$ 306
Liabilities Fair Value	(1,440)	(2,820)
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	0	0
Liabilities Fair Value	0	0
Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Fair Value	0	0
Liabilities Fair Value	$ 0	$ 0

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Supplemental Cash Flow Information (Narrative) (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011
Supplemental Cash Flow Elements [Abstract]
Payments of interest and commitment fees	$ 24.4	$ 20.3
Incurred liabilities for fixed and intangible asset additions	4.8	1.3
Other Asset Additions Incurred but Not yet Paid	$ 0.6

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Equity Investees (Consolidated Financial Statements Related To Equity Investees) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Equity Method Investments and Joint Ventures [Abstract]
Genesis' share of operating earnings	$ 5,978	$ 729	$ 15,611	$ 6,800
Amortization of excess purchase price	(2,546)	(1,141)	(7,640)	(3,423)
Net equity in earnings (losses)	3,432	(412)	7,971	3,377
Distributions received	$ 9,045	$ 3,289	$ 27,069	$ 15,302

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Inventories

9 Months Ended

Sep. 30, 2012

Inventory Disclosure [Abstract]

Inventories

3. Inventories

The major components of inventories were as follows:

	September 30, 2012		December 31, 2011
Petroleum products	$	41,076	$	70,769
Crude oil	12,014		11,701
Caustic soda	6,829		11,312
NaHS	7,376		7,337
Other	3		5
Total	$	67,298	$	101,124

Inventories are valued at the lower of cost or market. At September 30, 2012 and December 31, 2011, market values of our inventories exceeded recorded costs.

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Supplemental Cash Flow Information (Net Changes In Components Of Operating Assets And Liabilities) (Details) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011
Supplemental Cash Flow Elements [Abstract]
(Increase) decrease in Accounts receivable	$ (80,789)	$ (52,355)
(Increase) decrease in Inventories	33,826	(34,757)
(Increase) decrease in Other current assets	1,846	1,515
Increase (decrease) in Accounts payable	57,851	16,953
Increase (decrease) in Accrued liabilities	6,144	17,906
Net changes in components of operating assets and liabilities	$ 18,878	$ (50,738)

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Fixed Assets And Asset Retirement Obligations (Schedule Of Fixed Assets) (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Fixed Assets, at cost	$ 684,663	$ 541,138
Less: Accumulated depreciation	(148,712)	(124,213)
Net fixed assets	535,951	416,925
Pipelines And Related Assets [Member]
Fixed Assets, at cost	218,155	167,865
Machinery And Equipment [Member]
Fixed Assets, at cost	63,091	46,233
Transportation Equipment [Member]
Fixed Assets, at cost	20,280	21,732
Marine Vessels [Member]
Fixed Assets, at cost	297,416	262,216
Land, Buildings And Improvements [Member]
Fixed Assets, at cost	14,037	13,140
Office Equipment, Furniture And Fixtures [Member]
Fixed Assets, at cost	4,487	3,778
Construction In Progress [Member]
Fixed Assets, at cost	53,135	14,236
Property, Plant And Equipment, Other Types [Member]
Fixed Assets, at cost	$ 14,062	$ 11,938

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Partners' Capital And Distributions (Tables)

9 Months Ended

Sep. 30, 2012

Partners' Capital Notes [Abstract]

Distributions

We paid or will pay the following distributions in 2011 and 2012:

Distribution For	Date Paid		Per Unit Amount		Total Amount
2011
1st Quarter	May 13, 2011		$	0.4075	$	26,343
2nd Quarter	August 12, 2011		$	0.4150	$	29,878
3rd Quarter	November 14, 2011		$	0.4275	$	30,777
4th Quarter	February 14, 2012		$	0.4400	$	31,677
2012
1st Quarter	May 15, 2012		$	0.4500	$	35,759
2nd Quarter	August 14, 2012		$	0.4600	$	36,554
3rd Quarter	November 14, 2012	(1)	$	0.4725	$	38,368

(1) This distribution will be paid to unitholders of record as of November 1, 2012.

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Debt (Tables)

9 Months Ended

Sep. 30, 2012

Debt Disclosure [Abstract]

Schedule Of Obligations Under Debt Arrangements

Our obligations under debt arrangements consisted of the following:

	September 30, 2012		December 31, 2011
Senior secured credit facility	$	483,000	$	409,300
7.875% senior unsecured notes (including unamortized premium of $924 and $0 in 2012 and 2011, respectively)	350,924		250,000
Total long-term debt	$	833,924	$	659,300

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Business Segment Information (Schedule Of Segment Information) (Details) (USD $)	3 Months Ended				9 Months Ended				3 Months Ended	9 Months Ended		3 Months Ended				9 Months Ended				3 Months Ended				9 Months Ended				3 Months Ended				9 Months Ended
	Sep. 30, 2012		Sep. 30, 2011		Sep. 30, 2012		Sep. 30, 2011		Sep. 30, 2012 S E K C O [Member]	Sep. 30, 2012 S E K C O [Member]	Sep. 30, 2012 Barge Assets [Member]	Sep. 30, 2012 Pipeline Transportation [Member]		Sep. 30, 2011 Pipeline Transportation [Member]		Sep. 30, 2012 Pipeline Transportation [Member]		Sep. 30, 2011 Pipeline Transportation [Member]		Sep. 30, 2012 Refinery Services [Member]		Sep. 30, 2011 Refinery Services [Member]		Sep. 30, 2012 Refinery Services [Member]		Sep. 30, 2011 Refinery Services [Member]		Sep. 30, 2012 Supply And Logistics [Member]		Sep. 30, 2011 Supply And Logistics [Member]		Sep. 30, 2012 Supply And Logistics [Member]		Sep. 30, 2011 Supply And Logistics [Member]		Jan. 03, 2012 Gulf Of Mexico Crude Oil Pipeline Systems [Member]
Segment Reporting Information [Line Items]
Segment margin	$ 65,929,000	[1]	$ 52,931,000	[1]	$ 189,012,000	[1]	$ 149,759,000	[1]				$ 23,295,000	[1]	$ 16,030,000	[1]	$ 69,427,000	[1]	$ 50,639,000	[1]	$ 18,983,000	[1]	$ 17,992,000	[1]	$ 53,510,000	[1]	$ 54,887,000	[1]	$ 23,651,000	[1]	$ 18,909,000	[1]	$ 66,075,000	[1]	$ 44,233,000	[1]
Capital expenditures	37,199,000	[2]	149,433,000	[2]	379,802,000	[2]	153,711,000	[2]	5,700,000	57,100,000	30,600,000	21,764,000	[2]	1,582,000	[2]	300,093,000	[2]	3,264,000	[2]	1,025,000	[2]	852,000	[2]	2,295,000	[2]	1,321,000	[2]	14,410,000	[2]	146,999,000	[2]	77,414,000	[2]	149,126,000	[2]
External customers	942,334,000		830,200,000		2,797,945,000		2,282,788,000					16,190,000		12,658,000		44,564,000		37,302,000		50,378,000		50,982,000		151,326,000		151,899,000		875,766,000		766,560,000		2,602,055,000		2,093,587,000
Intersegment	0	[3]	0	[3]	0	[3]	0	[3]				2,974,000	[3]	3,436,000	[3]	11,230,000	[3]	8,331,000	[3]	(2,401,000)	[3]	(2,590,000)	[3]	(6,984,000)	[3]	(6,598,000)	[3]	(573,000)	[3]	(846,000)	[3]	(4,246,000)	[3]	(1,733,000)	[3]
Total revenues	942,334,000		830,200,000		2,797,945,000		2,282,788,000					19,164,000		16,094,000		55,794,000		45,633,000		47,977,000		48,392,000		144,342,000		145,301,000		875,193,000		765,714,000		2,597,809,000		2,091,854,000
Acquisition of interests																																				$ 205,600,000

[1] A reconciliation of Segment Margin to income before income taxes for the periods presented is as follows: Three Months EndedSeptember 30, Nine Months EndedSeptember 30, 2012 2011 2012 2011Segment Margin$65,929 $52,931 $189,012 $149,759Corporate general and administrative expenses(9,428) (8,194) (26,756) (23,267)Depreciation and amortization(14,838) (14,706) (45,447) (43,100)Interest expense(9,873) (8,960) (30,697) (26,670)Distributable cash from equity investees in excess of equity in earnings(5,613) (3,701) (19,098) (11,925)Non-cash items not included in segment margin(2,222) 3,061 (2,475) 2,729Cash payments from direct financing leases in excess of earnings(1,278) (1,171) (3,748) (3,424)Income before income taxes$22,677 $19,260 $60,791 $44,102

[2] Capital expenditures include maintenance and growth capital expenditures, such as fixed asset additions (including enhancements to existing facilities and construction of internal growth projects) as well as acquisitions of businesses and interests in equity investees. Capital spending in our pipeline transportation segment included $5.7 million and $57.1 million during the three and nine months ended September 30, 2012, respectively, representing capital contributions to our SEKCO equity investee to fund our share of the construction costs for its pipeline. For the nine months ended September 30, 2012, capital spending in our pipeline transportation segment also included $205.6 million for the acquisition of interests in several Gulf of Mexico pipelines. For the nine months ended September 30, 2012, capital spending in our supply and logistics segment also included $30.6 million for the purchase of barge assets

[3] Intersegment sales were conducted under terms that we believe were no more or less favorable than then-existing market conditions.

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Fixed Assets And Asset Retirement Obligations (Schedule Of Reconciliation Of Liability For Asset Retirement Obligations) (Details) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2012
Fixed Assets And Asset Retirement Obligations [Abstract]
Asset retirement obligations, beginning balance	$ 5,900
Liabilities incurred and assumed in the current period	5,995
Accretion expense	600
Asset retirement obligations, ending balance	$ 12,495

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Business Segment Information (Tables)

9 Months Ended

Sep. 30, 2012

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment [Table Text Block]

	Pipeline Transportation		Refinery Services			Supply & Logistics			Total
Three Months Ended September 30, 2012
Segment margin (a)	$	23,295	$	18,983		$	23,651		$	65,929
Capital expenditures (b)	$	21,764	$	1,025		$	14,410		$	37,199
Revenues:
External customers	$	16,190	$	50,378		$	875,766		$	942,334
Intersegment (c)	2,974		(2,401		)	(573		)	—
Total revenues of reportable segments	$	19,164	$	47,977		$	875,193		$	942,334
Three Months Ended September 30, 2011
Segment margin (a)	$	16,030	$	17,992		$	18,909		$	52,931
Capital expenditures (b)	$	1,582	$	852		$	146,999		$	149,433
Revenues:
External customers	$	12,658	$	50,982		$	766,560		$	830,200
Intersegment (c)	3,436		(2,590		)	(846		)	—
Total revenues of reportable segments	$	16,094	$	48,392		$	765,714		$	830,200
Nine Months Ended September 30, 2012
Segment margin (a)	$	69,427	$	53,510		$	66,075		$	189,012
Capital expenditures (b)	$	300,093	$	2,295		$	77,414		$	379,802
Revenues:
External customers	$	44,564	$	151,326		$	2,602,055		$	2,797,945
Intersegment (c)	11,230		(6,984		)	(4,246		)	—
Total revenues of reportable segments	$	55,794	$	144,342		$	2,597,809		$	2,797,945
Nine Months Ended September 30, 2011
Segment margin (a)	$	50,639	$	54,887		$	44,233		$	149,759
Capital expenditures (b)	$	3,264	$	1,321		$	149,126		$	153,711
Revenues:
External customers	$	37,302	$	151,899		$	2,093,587		$	2,282,788
Intersegment (c)	8,331		(6,598		)	(1,733		)	—
Total revenues of reportable segments	$	45,633	$	145,301		$	2,091,854		$	2,282,788

Total assets by reportable segment were as follows:

	September 30, 2012		December 31, 2011
Pipeline transportation	$	870,966	$	594,728
Refinery services	413,888		426,993
Supply and logistics	774,002		659,576
Other assets	48,299		49,547
Total consolidated assets	$	2,107,155	$	1,730,844

(a) A reconciliation of Segment Margin to income before income taxes for the periods presented is as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
Segment Margin	$	65,929		$	52,931		$	189,012		$	149,759
Corporate general and administrative expenses	(9,428		)	(8,194		)	(26,756		)	(23,267		)
Depreciation and amortization	(14,838		)	(14,706		)	(45,447		)	(43,100		)
Interest expense	(9,873		)	(8,960		)	(30,697		)	(26,670		)
Distributable cash from equity investees in excess of equity in earnings	(5,613		)	(3,701		)	(19,098		)	(11,925		)
Non-cash items not included in segment margin	(2,222		)	3,061			(2,475		)	2,729
Cash payments from direct financing leases in excess of earnings	(1,278		)	(1,171		)	(3,748		)	(3,424		)
Income before income taxes	$	22,677		$	19,260		$	60,791		$	44,102

(b) Capital expenditures include maintenance and growth capital expenditures, such as fixed asset additions (including enhancements to existing facilities and construction of internal growth projects) as well as acquisitions of businesses and interests in equity investees. Capital spending in our pipeline transportation segment included $5.7 million and $57.1 million during the three and nine months ended September 30, 2012, respectively, representing capital contributions to our SEKCO equity investee to fund our share of the construction costs for its pipeline. For the nine months ended September 30, 2012, capital spending in our pipeline transportation segment also included $205.6 million for the acquisition of interests in several Gulf of Mexico pipelines. For the nine months ended September 30, 2012, capital spending in our supply and logistics segment also included $30.6 million for the purchase of barge assets.

(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 [Table Text Block]

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
Segment Margin	$	65,929		$	52,931		$	189,012		$	149,759
Corporate general and administrative expenses	(9,428		)	(8,194		)	(26,756		)	(23,267		)
Depreciation and amortization	(14,838		)	(14,706		)	(45,447		)	(43,100		)
Interest expense	(9,873		)	(8,960		)	(30,697		)	(26,670		)
Distributable cash from equity investees in excess of equity in earnings	(5,613		)	(3,701		)	(19,098		)	(11,925		)
Non-cash items not included in segment margin	(2,222		)	3,061			(2,475		)	2,729
Cash payments from direct financing leases in excess of earnings	(1,278		)	(1,171		)	(3,748		)	(3,424		)
Income before income taxes	$	22,677		$	19,260		$	60,791		$	44,102

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Transactions With Related Parties (Tables)

9 Months Ended

Sep. 30, 2012

Related Party Transactions [Abstract]

Schedule Of Transactions With Related Parties

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
Revenues:
Petroleum products sales to an affiliate of the Quintana Group (1)	$	6,376	$	5,948	$	21,142	$	27,202
Sales of CO2 to Sandhill Group, LLC (2)	838		946		2,111		1,921
Petroleum products sales to Davison family businesses (1)	326		737		1,012		1,224
Costs and expenses:
Marine operating fuel and expenses provided by an affiliate of the Quintana Group (1)	1,980		902		6,181		2,722
Amounts paid to our CEO in connection with the use of his aircraft	150		166		450		166

(1) The Quintana Group, a private equity fund based in Houston, Texas, owned 10% of our Class A common units and 74% of our Class B common units at September 30, 2012. The Davison family owned 15% of our Class A common units at September 30, 2012. The Quintana Group monetized all of its remaining investment in us on October 5, 2012. Substantially in connection with that transaction, certain members of the Davison family, collectively, increased their investment in us to 17.2% of our Class A common units and 76.9% of our Class B units. Soley for financial statement disclosure purposes, we will continue to treat the Davison family and their affiliates as related parties.

(2) We own a 50% interest in Sandhill Group, LLC.

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Acquisitions

9 Months Ended

Sep. 30, 2012

Business Combinations [Abstract]

Acquisitions

2. Acquisitions

Interests in Gulf of Mexico Crude Oil Pipeline Systems

On January 3, 2012, we acquired from Marathon Oil Company interests in several Gulf of Mexico crude oil pipeline systems. The acquired pipeline interests include a 28% interest in Poseidon Oil Pipeline Company, L.L.C. (or “Poseidon”), a 100% interest in Marathon Offshore Pipeline, LLC (subsequently re-named GEL Offshore Pipeline, LLC, or “GOPL”) and a 29% interest in Odyssey Pipeline L.L.C. (or “Odyssey”). GOPL owns a 23% interest in the Eugene Island crude oil pipeline system and a 100% interest in two smaller offshore pipelines. The purchase price, net of post-closing adjustments, was $205.6 million. We funded the purchase price with cash available under our credit facility. We account for our interests in Poseidon and Odyssey under the equity method of accounting. We have recorded the assets acquired and liabilities assumed of GOPL in the Unaudited Condensed Consolidated Financial Statements at their estimated fair values on a preliminary basis. Management developed these preliminary fair values and we do not expect any material adjustments to these preliminary purchase price allocations as a result of the final valuation.

The preliminary allocation of the purchase price is summarized as follows:

Property and equipment	$	28,456
Equity investees	182,993
Asset retirement obligation assumed	(5,873		)
Total allocation	$	205,576

The Poseidon pipeline system is comprised of a 367-mile network of crude oil pipelines, varying in diameter from 16 to 24 inches, with capacity to deliver approximately 400,000 barrels per day of crude oil from developments in the central and western offshore Gulf of Mexico to other pipelines and terminals onshore and offshore Louisiana. The Eugene Island pipeline system is primarily comprised of a 183-mile network of crude oil pipelines, the main pipeline of which is 20 inches in diameter, with capacity to deliver approximately 200,000 barrels per day of crude oil from developments in the central Gulf of Mexico to other pipelines and terminals onshore Louisiana. The Odyssey pipeline system is comprised of a 120-mile network of crude oil pipelines, varying in diameter from 12 to 20 inches, with capacity to deliver up to 300,000 barrels per day of crude oil from developments in the eastern Gulf of Mexico to other pipelines and terminals onshore Louisiana.

Our Unaudited Condensed Consolidated Financial Statements include the results of the acquired pipeline interests since the effective closing date of the acquisition in January 2012. The following table presents selected financial information included in our Unaudited Condensed Consolidated Financial Statements for the three and nine months ended September 30, 2012:

	Three Months Ended September 30,		Nine Months Ended September 30,
	2012
Revenues	$	1,180	$	4,334
Equity in earnings of equity investees	$	3,497	$	9,194
Net income	$	3,950	$	11,128

The table below presents selected unaudited pro forma financial information for the three and nine months ended September 30, 2011 incorporating the historical results of the acquired pipeline interests. The pro forma financial information below has been prepared as if the acquisition had been completed at the beginning of the prior year and is based upon assumptions deemed appropriate by us and may not be indicative of actual results.

	Three Months Ended September 30,		Nine Months Ended September 30,
	2011
Pro forma earnings data:
Revenues	$	831,956	$	2,288,056
Equity in earnings of equity investees	$	2,605	$	11,963
Net income	$	20,903	$	48,941
Basic and diluted earnings per unit:
As reported net income per unit	$	0.27	$	0.65
Pro forma net income per unit	$	0.30	$	0.74
As reported units outstanding	70,447		66,580
Pro forma units outstanding	70,447		66,580

FMT Black Oil Barge Transportation Business

In August 2011, we completed the acquisition of the black oil barge transportation business of Florida Marine Transporters, Inc. and its affiliates (“FMT”). The purchase price was $143.5 million (including $2.5 million for fuel inventory and other costs). The acquired business was comprised of 30 barges (seven of which were initially sub-leased under terms similar to those of an existing FMT lease, which we subsequently purchased in February 2012 for $30.6 million) and 14 push/tow boats which transport heavy refined products, primarily serving refineries and storage terminals along the Gulf Coast, Intracoastal Canal and western river systems of the United States, including the Red, Ouachita and Mississippi Rivers. The August 2011 acquisition and related transaction costs were funded with a portion of the net proceeds from the July 2011 public offering of our common units, whereby we raised approximately $185 million in net proceeds of equity capital. The February 2012 vessels purchase was funded with cash available under our credit facility.

The financial results of the acquired business are included in our supply and logistics segment from the date of the acquisition.

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Supplemental Cash Flow Information (Tables)

9 Months Ended

Sep. 30, 2012

Supplemental Cash Flow Elements [Abstract]

Net Changes In Components Of Operating Assets And Liabilities

	Nine Months Ended September 30,
	2012			2011
(Increase) decrease in:
Accounts receivable	$	(80,789	)	$	(52,355	)
Inventories	33,826			(34,757		)
Other current assets	1,846			1,515
Increase (decrease) in:
Accounts payable	57,851			16,953
Accrued liabilities	6,144			17,906
Net changes in components of operating assets and liabilities	$	18,878		$	(50,738	)

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Acquisitions (Schedule Of Pro Forma Financial Information) (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Business Acquisition [Line Items]
As reported net income per unit	$ 0.39	$ 0.27	$ 0.90	$ 0.65
As reported units outstanding	79,901	70,447	77,410	66,580
Gulf Of Mexico Crude Oil Pipeline Systems [Member]
Business Acquisition [Line Items]
Revenues		$ 831,956		$ 2,288,056
Equity in earnings of equity investees		2,605		11,963
Net income		$ 20,903		$ 48,941
As reported net income per unit		$ 0.27		$ 0.65
Pro forma net income per unit		$ 0.30		$ 0.74
As reported units outstanding		70,447		66,580
Pro forma units outstanding		70,447		66,580

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Debt (Schedule Of Obligations Under Debt Arrangements) (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Debt Instrument [Line Items]
Senior secured credit facility	$ 483,000	$ 409,300
Senior unsecured notes	350,924	250,000
Total long-term debt	833,924	659,300
7.875% Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Senior unsecured notes	350,924	250,000
Senior unsecured notes, stated rate	7.875%
Senior unsecured notes, unamortized premium	$ 924	$ 0

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Condensed Consolidating Financial Information (Condensed Consolidating Statement Of Cash Flows) (Details) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	$ 142,938	$ 39,146
Payments to acquire fixed and intangible assets	(116,702)	(15,157)
Cash distributions received from equity investees - return of investment	10,918	8,577
Investments in equity investees	(57,072)	(194)
Acquisitions	(205,576)	(143,489)
Repayments on loan to non-guarantor subsidiary	0	0
Proceeds from asset sales	667	4,444
Other, net	(1,012)	129
Net cash used in investing activities	(368,777)	(145,690)
Borrowings on senior secured credit facility	1,407,000	571,700
Repayments on senior secured credit facility	(1,333,300)	(563,800)
Proceeds from issuance of senior unsecured notes, including premium	101,000	0
Debt issuance costs	(7,109)	(3,018)
Issuance of ownership interests to partners for cash	169,421	184,969
Distributions to partners/owners	(104,008)	(82,067)
Other, net	(2,521)	(2,626)
Net cash provided by financing activities	230,483	105,158
Net increase (decrease) in cash and cash equivalents	4,644	(1,386)
Cash and cash equivalents at beginning of period	10,817	5,762
Cash and cash equivalents at end of period	15,461	4,376
Genesis Energy, L.P. (Parent And Co-Issuer) [Member]
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	(91,453)	(4,881)
Payments to acquire fixed and intangible assets	0	0
Cash distributions received from equity investees - return of investment	27,878	82,067
Investments in equity investees	(169,421)	(184,969)
Acquisitions	0	0
Repayments on loan to non-guarantor subsidiary	0	0
Proceeds from asset sales	0	0
Other, net	0	0
Net cash used in investing activities	(141,543)	(102,902)
Borrowings on senior secured credit facility	1,407,000	571,700
Repayments on senior secured credit facility	(1,333,300)	(563,800)
Proceeds from issuance of senior unsecured notes, including premium	101,000
Debt issuance costs	(7,109)	(3,018)
Issuance of ownership interests to partners for cash	169,421	184,969
Distributions to partners/owners	(104,008)	(82,067)
Other, net	0	0
Net cash provided by financing activities	233,004	107,784
Net increase (decrease) in cash and cash equivalents	8	1
Cash and cash equivalents at beginning of period	3	1
Cash and cash equivalents at end of period	11	2
Genesis Energy Finance Corporation (Co-Issuer) [Member]
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	0
Acquisitions	0	0
Repayments on loan to non-guarantor subsidiary	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, including premium	0
Debt issuance costs	0	0
Issuance of ownership interests to partners for cash	0	0
Distributions to partners/owners	0	0
Other, net	0	0
Net cash provided by financing activities	0	0
Net increase (decrease) 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
Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	304,617	41,160
Payments to acquire fixed and intangible assets	(112,665)	(15,060)
Cash distributions received from equity investees - return of investment	10,918	8,577
Investments in equity investees	(57,072)	(194)
Acquisitions	(205,576)	(143,489)
Repayments on loan to non-guarantor subsidiary	3,019	2,729
Proceeds from asset sales	667	4,444
Other, net	(1,012)	129
Net cash used in investing activities	(361,721)	(142,864)
Borrowings on senior secured credit facility	0	0
Repayments on senior secured credit facility	0	0
Proceeds from issuance of senior unsecured notes, including premium	0
Debt issuance costs	0	0
Issuance of ownership interests to partners for cash	169,421	184,969
Distributions to partners/owners	(104,008)	(82,067)
Other, net	(2,738)	(2,626)
Net cash provided by financing activities	62,675	100,276
Net increase (decrease) in cash and cash equivalents	5,571	(1,428)
Cash and cash equivalents at beginning of period	9,182	5,082
Cash and cash equivalents at end of period	14,753	3,654
Non-Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	17,700	2,844
Payments to acquire fixed and intangible assets	(4,037)	(97)
Cash distributions received from equity investees - return of investment	0	0
Investments in equity investees	0	0
Acquisitions	0	0
Repayments on loan to non-guarantor subsidiary	0	0
Proceeds from asset sales	0	0
Other, net	0	0
Net cash used in investing activities	(4,037)	(97)
Borrowings on senior secured credit facility	0	0
Repayments on senior secured credit facility	0	0
Proceeds from issuance of senior unsecured notes, including premium	0
Debt issuance costs	0	0
Issuance of ownership interests to partners for cash	0	0
Distributions to partners/owners	(11,819)	0
Other, net	(2,779)	(2,706)
Net cash provided by financing activities	(14,598)	(2,706)
Net increase (decrease) in cash and cash equivalents	(935)	41
Cash and cash equivalents at beginning of period	1,632	679
Cash and cash equivalents at end of period	697	720
Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	(87,926)	23
Payments to acquire fixed and intangible assets	0	0
Cash distributions received from equity investees - return of investment	(27,878)	(82,067)
Investments in equity investees	169,421	184,969
Acquisitions	0	0
Repayments on loan to non-guarantor subsidiary	(3,019)	(2,729)
Proceeds from asset sales	0	0
Other, net	0	0
Net cash used in investing activities	138,524	100,173
Borrowings on senior secured credit facility	0	0
Repayments on senior secured credit facility	0	0
Proceeds from issuance of senior unsecured notes, including premium	0
Debt issuance costs	0	0
Issuance of ownership interests to partners for cash	(169,421)	(184,969)
Distributions to partners/owners	115,827	82,067
Other, net	2,996	2,706
Net cash provided by financing activities	(50,598)	(100,196)
Net increase (decrease) 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

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Condensed Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
CURRENT ASSETS:
Cash and cash equivalents	$ 15,461	$ 10,817
Accounts receivable-trade, net	318,892	237,989
Inventories	67,298	101,124
Other	25,616	26,174
Total current assets	427,267	376,104
FIXED ASSETS, at cost	684,663	541,138
Less: Accumulated depreciation	(148,712)	(124,213)
Net fixed assets	535,951	416,925
NET INVESTMENT IN DIRECT FINANCING LEASES, net of unearned income	158,698	162,460
EQUITY INVESTEES	547,925	326,947
INTANGIBLE ASSETS, net of amortization	79,140	93,356
GOODWILL	325,046	325,046
OTHER ASSETS, net of amortization	33,128	30,006
TOTAL ASSETS	2,107,155	1,730,844
CURRENT LIABILITIES:
Accounts payable-trade	254,688	199,357
Accrued liabilities	63,691	50,071
Total current liabilities	318,379	249,428
SENIOR SECURED CREDIT FACILITY	483,000	409,300
SENIOR UNSECURED NOTES	350,924	250,000
DEFERRED TAX LIABILITIES	11,598	12,549
OTHER LONG-TERM LIABILITIES	15,321	16,929
COMMITMENTS AND CONTINGENCIES (Note 14)
PARTNERS' CAPITAL:
Common unitholders, 81,202,752 and 71,965,062 units issued and outstanding at September 30, 2012 and December 31, 2011, respectively	927,933	792,638
TOTAL LIABILITIES AND PARTNERS' CAPITAL	$ 2,107,155	$ 1,730,844

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Fixed Assets And Asset Retirement Obligations Depreciation Expense (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Property, Plant and Equipment [Line Items]
Depreciation expense	$ 9,202	$ 5,960	$ 27,246	$ 17,838

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Condensed Consolidated Statements Of Cash Flows (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$ 69,382	$ 43,476
Adjustments to reconcile net income to net cash provided by operating activities -
Depreciation and amortization	45,447	43,100
Amortization of debt issuance costs and premium	2,655	2,102
Amortization of unearned income and initial direct costs on direct financing leases	(12,641)	(12,968)
Payments received under direct financing leases	16,389	16,389
Equity in earnings of investments in equity investees	(7,971)	(3,377)
Cash distributions of earnings of equity investees	16,151	6,725
Non-cash effect of equity-based compensation plans	4,617	(1,505)
Deferred and other tax liabilities	(9,156)	(27)
Unrealized gains on derivative transactions	(1,251)	(4,370)
Other, net	438	339
Net changes in components of operating assets and liabilities, (See Note 11)	18,878	(50,738)
Net cash provided by operating activities	142,938	39,146
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	(116,702)	(15,157)
Cash distributions received from equity investees - return of investment	10,918	8,577
Investments in equity investees	(57,072)	(194)
Acquisitions	(205,576)	(143,489)
Proceeds from asset sales	667	4,444
Other, net	(1,012)	129
Net cash used in investing activities	(368,777)	(145,690)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	1,407,000	571,700
Repayments on senior secured credit facility	(1,333,300)	(563,800)
Proceeds from issuance of senior unsecured notes, including premium	101,000	0
Debt issuance costs	(7,109)	(3,018)
Issuance of common units for cash, net	169,421	184,969
Distributions to common unitholders	(104,008)	(82,067)
Other, net	(2,521)	(2,626)
Net cash provided by financing activities	230,483	105,158
Net increase (decrease) in cash and cash equivalents	4,644	(1,386)
Cash and cash equivalents at beginning of period	10,817	5,762
Cash and cash equivalents at end of period	$ 15,461	$ 4,376

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Transactions With Related Parties (Narrative) (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Quintana Group [Member]
Related Party Transaction [Line Items]
Due from related parties	$ 1.2	$ 1.9
Due to related parties	0.1
Sandhill Group, LLC [Member]
Related Party Transaction [Line Items]
Due from related parties	$ 0.3	$ 0.2

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Condensed Consolidating Financial Information (Tables)

9 Months Ended

Sep. 30, 2012

Condensed Consolidating Financial Information [Abstract]

Condensed Consolidating Balance Sheet

Unaudited Condensed Consolidating Balance Sheet

September 30, 2012

	Genesis Energy, L.P. (Parent and Co-Issuer)		Genesis Energy Finance Corporation (Co-Issuer)		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Genesis Energy, L.P. Consolidated
ASSETS
Current assets:
Cash and cash equivalents	$	11	$	—	$	14,753		$	697		$	—		$	15,461
Other current assets	744,217		—		387,772			38,521			(758,704		)	411,806
Total current assets	744,228		—		402,525			39,218			(758,704		)	427,267
Fixed assets, at cost	—		—		583,751			100,912			—			684,663
Less: Accumulated depreciation	—		—		(136,459		)	(12,253		)	—			(148,712		)
Net fixed assets	—		—		447,292			88,659			—			535,951
Goodwill	—		—		325,046			—			—			325,046
Other assets, net	19,152		—		257,694			158,875			(164,755		)	270,966
Equity investees	—		—		547,925			—			—			547,925
Investments in subsidiaries	1,007,650		—		100,005			—			(1,107,655		)	—
Total assets	$	1,771,030	$	—	$	2,080,487		$	286,752		$	(2,031,114	)	$	2,107,155
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities	$	9,173	$	—	$	1,047,542		$	19,987		$	(758,323	)	$	318,379
Senior secured credit facility	483,000		—		—			—			—			483,000
Senior unsecured notes	350,924		—		—			—			—			350,924
Deferred tax liabilities	—		—		11,598			—			—			11,598
Other liabilities	—		—		12,850			167,041			(164,570		)	15,321
Total liabilities	843,097		—		1,071,990			187,028			(922,893		)	1,179,222
Partners’ capital	927,933		—		1,008,497			99,724			(1,108,221		)	927,933
Total liabilities and partners’ capital	$	1,771,030	$	—	$	2,080,487		$	286,752		$	(2,031,114	)	$	2,107,155

Unaudited Condensed Consolidating Balance Sheet

December 31, 2011

	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	$	3	$	—	$	9,182		$	1,632		$	—		$	10,817
Other current assets	597,966		—		341,131			31,897			(605,707		)	365,287
Total current assets	597,969		—		350,313			33,529			(605,707		)	376,104
Fixed assets, at cost	—		—		444,262			96,876			—			541,138
Less: Accumulated depreciation	—		—		(114,655		)	(9,558		)	—			(124,213		)
Net fixed assets	—		—		329,607			87,318			—			416,925
Goodwill	—		—		325,046			—			—			325,046
Other assets, net	14,773		—		276,450			162,373			(167,774		)	285,822
Equity investees	—		—		326,947			—			—			326,947
Investments in subsidiaries	841,725		—		96,303			—			(938,028		)	—
Total assets	$	1,454,467	$	—	$	1,704,666		$	283,220		$	(1,711,509	)	$	1,730,844
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities	$	2,529	$	—	$	835,013		$	17,562		$	(605,676	)	$	249,428
Senior secured credit facility	409,300		—		—			—			—			409,300
Senior unsecured notes	250,000		—		—			—			—			250,000
Deferred tax liabilities	—		—		12,549			—			—			12,549
Other liabilities	—		—		14,673			169,842			(167,586		)	16,929
Total liabilities	661,829		—		862,235			187,404			(773,262		)	938,206
Partners’ capital	792,638		—		842,431			95,816			(938,247		)	792,638
Total liabilities and partners’ capital	$	1,454,467	$	—	$	1,704,666		$	283,220		$	(1,711,509	)	$	1,730,844

Condensed Consolidating Statement Of Operations

Unaudited Condensed Consolidating Statement of Operations

Three Months Ended September 30, 2012

	Genesis Energy, L.P. (Parent and Co-Issuer)			Genesis Energy Finance Corporation (Co-Issuer)		Guarantor Subsidiaries		Non-Guarantor Subsidiaries			Eliminations			Genesis Energy, L.P. Consolidated
REVENUES:
Supply and logistics	$	—		$	—	$	869,726	$	31,113		$	(25,646	)	$	875,193
Refinery services	—			—		48,809		4,367			(5,199		)	47,977
Pipeline transportation services	—			—		12,596		6,568			—			19,164
Total revenues	—			—		931,131		42,048			(30,845		)	942,334
COSTS AND EXPENSES:
Supply and logistics costs	—			—		852,009		26,488			(25,648		)	852,849
Refinery services operating costs	—			—		29,339		4,565			(4,661		)	29,243
Pipeline transportation operating costs	—			—		5,661		250			—			5,911
General and administrative	—			—		10,343		32			—			10,375
Depreciation and amortization	—			—		13,940		898			—			14,838
Total costs and expenses	—			—		911,292		32,233			(30,309		)	913,216
OPERATING INCOME	—			—		19,839		9,815			(536		)	29,118
Equity in earnings of subsidiaries	41,052			—		5,738		—			(46,790		)	—
Equity in earnings of equity investees	—			—		3,432		—			—			3,432
Interest (expense) income, net	(9,858		)	—		4,119		(4,134		)	—			(9,873		)
Income before income taxes	31,194			—		33,128		5,681			(47,326		)	22,677
Income tax benefit	—			—		8,509		8			—			8,517
NET INCOME	$	31,194		$	—	$	41,637	$	5,689		$	(47,326	)	$	31,194

Unaudited Condensed Consolidating Statement of Operations

Three Months Ended September 30, 2011

	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:
Supply and logistics	$	—		$	—	$	765,714		$	—		$	—		$	765,714
Refinery services	—			—		48,700			3,805			(4,113		)	48,392
Pipeline transportation services	—			—		9,388			6,706			—			16,094
Total revenues	—			—		823,802			10,511			(4,113		)	830,200
COSTS AND EXPENSES:
Supply and logistics costs	—			—		743,833			—			—			743,833
Refinery services operating costs	—			—		30,448			3,612			(3,924		)	30,136
Pipeline transportation operating costs	—			—		3,818			170			—			3,988
General and administrative	—			—		8,905			—			—			8,905
Depreciation and amortization	—			—		14,057			649			—			14,706
Total costs and expenses	—			—		801,061			4,431			(3,924		)	801,568
OPERATING INCOME	—			—		22,741			6,080			(189		)	28,632
Equity in losses of subsidiaries	28,032			—		1,945			—			(29,977		)	—
Equity in earnings of equity investees	—			—		(412		)	—			—			(412		)
Interest (expense) income, net	(8,944		)	—		4,226			(4,242		)	—			(8,960		)
Income before income taxes	19,088			—		28,500			1,838			(30,166		)	19,260
Income tax (expense) benefit	—			—		(233		)	61			—			(172		)
NET INCOME	$	19,088		$	—	$	28,267		$	1,899		$	(30,166	)	$	19,088

Unaudited Condensed Consolidating Statement of Operations

Nine Months Ended September 30, 2012

	Genesis Energy, L.P. (Parent and Co-Issuer)			Genesis Energy Finance Corporation (Co-Issuer)		Guarantor Subsidiaries		Non-Guarantor Subsidiaries			Eliminations			Genesis Energy, L.P. Consolidated
REVENUES:
Supply and logistics	$	—		$	—	$	2,579,102	$	95,451		$	(76,744	)	$	2,597,809
Refinery services	—			—		142,716		13,756			(12,130		)	144,342
Pipeline transportation services	—			—		36,381		19,413			—			55,794
Total revenues	—			—		2,758,199		128,620			(88,874		)	2,797,945
COSTS AND EXPENSES:
Supply and logistics costs	—			—		2,525,474		83,250			(76,744		)	2,531,980
Refinery services operating costs	—			—		89,155		13,701			(11,784		)	91,072
Pipeline transportation operating costs	—			—		15,351		644			—			15,995
General and administrative	—			—		29,842		92			—			29,934
Depreciation and amortization	—			—		42,759		2,688			—			45,447
Total costs and expenses	—			—		2,702,581		100,375			(88,528		)	2,714,428
OPERATING INCOME	—			—		55,618		28,245			(346		)	83,517
Equity in earnings of subsidiaries	100,011			—		15,869		—			(115,880		)	—
Equity in earnings of equity investees	—			—		7,971		—			—			7,971
Interest (expense) income, net	(30,629		)	—		12,414		(12,482		)	—			(30,697		)
Income before income taxes	69,382			—		91,872		15,763			(116,226		)	60,791
Income tax benefit (expense)	—			—		8,630		(39		)	—			8,591
NET INCOME	$	69,382		$	—	$	100,502	$	15,724		$	(116,226	)	$	69,382

Unaudited Condensed Consolidating Statement of Operations

Nine Months Ended September 30, 2011

	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:
Supply and logistics	$	—		$	—	$	2,091,854		$	—		$	—		$	2,091,854
Refinery services	—			—		142,992			12,953			(10,644		)	145,301
Pipeline transportation services	—			—		26,292			19,341			—			45,633
Total revenues	—			—		2,261,138			32,294			(10,644		)	2,282,788
COSTS AND EXPENSES:
Supply and logistics costs	—			—		2,044,554			—			—			2,044,554
Refinery services operating costs	—			—		88,641			11,836			(10,491		)	89,986
Pipeline transportation operating costs	—			—		11,937			477			—			12,414
General and administrative	—			—		25,339			—			—			25,339
Depreciation and amortization	—			—		41,153			1,947			—			43,100
Total costs and expenses	—			—		2,211,624			14,260			(10,491		)	2,215,393
OPERATING INCOME	—			—		49,514			18,034			(153		)	67,395
Equity in earnings of subsidiaries	70,092			—		5,238			—			(75,330		)	—
Equity in earnings of equity investees	—			—		3,377			—			—			3,377
Interest (expense) income, net	(26,616		)	—		12,726			(12,780		)	—			(26,670		)
Income before income taxes	43,476			—		70,855			5,254			(75,483		)	44,102
Income tax expense	—			—		(467		)	(159		)	—			(626		)
NET INCOME	$	43,476		$	—	$	70,388		$	5,095		$	(75,483	)	$	43,476

Condensed Consolidating Statements Of Cash Flows

Unaudited Condensed Consolidating Statement of Cash Flows

Nine Months Ended September 30, 2012

	Genesis Energy, L.P. (Parent and Co-Issuer)			Genesis Energy Finance Corporation (Co-Issuer)		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Genesis Energy, L.P. Consolidated
Net cash (used in) provided by operating activities	$	(91,453	)	$	—	$	304,617		$	17,700		$	(87,926	)	$	142,938
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	—			—		(112,665		)	(4,037		)	—			(116,702		)
Cash distributions received from equity investees - return of investment	27,878			—		10,918			—			(27,878		)	10,918
Investments in equity investees	(169,421		)	—		(57,072		)	—			169,421			(57,072		)
Acquisitions	—			—		(205,576		)	—			—			(205,576		)
Repayments on loan to non-guarantor subsidiary	—			—		3,019			—			(3,019		)	—
Proceeds from asset sales	—			—		667			—			—			667
Other, net	—			—		(1,012		)	—			—			(1,012		)
Net cash used in investing activities	(141,543		)	—		(361,721		)	(4,037		)	138,524			(368,777		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	1,407,000			—		—			—			—			1,407,000
Repayments on senior secured credit facility	(1,333,300		)	—		—			—			—			(1,333,300		)
Proceeds from issuance of senior unsecured notes, including premium	101,000			—		—			—			—			101,000
Debt issuance costs	(7,109		)	—		—			—			—			(7,109		)
Issuance of common units for cash, net	169,421			—		169,421			—			(169,421		)	169,421
Distributions to partners/owners	(104,008		)	—		(104,008		)	(11,819		)	115,827			(104,008		)
Other, net	—			—		(2,738		)	(2,779		)	2,996			(2,521		)
Net cash provided by (used in) financing activities	233,004			—		62,675			(14,598		)	(50,598		)	230,483
Net increase (decrease) in cash and cash equivalents	8			—		5,571			(935		)	—			4,644
Cash and cash equivalents at beginning of period	3			—		9,182			1,632			—			10,817
Cash and cash equivalents at end of period	$	11		$	—	$	14,753		$	697		$	—		$	15,461

Unaudited Condensed Consolidating Statement of Cash Flows

Nine Months Ended September 30, 2011

	Genesis Energy, L.P. (Parent and Co-Issuer)			Genesis Energy Finance Corporation (Co-Issuer)		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Genesis Energy, L.P. Consolidated
Net cash (used in) provided by operating activities	$	(4,881	)	$	—	$	41,160		$	2,844		$	23		$	39,146
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	—			—		(15,060		)	(97		)	—			(15,157		)
Cash distributions received from equity investees - return of investment	82,067			—		8,577			—			(82,067		)	8,577
Investments in equity investees	(184,969		)	—		(194		)	—			184,969			(194		)
Acquisitions	—			—		(143,489		)	—			—			(143,489		)
Repayments on loan to non-guarantor subsidiary	—			—		2,729			—			(2,729		)	—
Proceeds from asset sales	—			—		4,444			—			—			4,444
Other, net	—			—		129			—			—			129
Net cash used in investing activities	(102,902		)	—		(142,864		)	(97		)	100,173			(145,690		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	571,700			—		—			—			—			571,700
Repayments on senior secured credit facility	(563,800		)	—		—			—			—			(563,800		)
Debt issuance costs	(3,018		)	—		—			—			—			(3,018		)
Distributions to partners/owners	(82,067		)	—		(82,067		)	—			82,067			(82,067		)
Issuance of common units for cash, net	184,969			—		184,969			—			(184,969		)	184,969
Other, net	—			—		(2,626		)	(2,706		)	2,706			(2,626		)
Net cash provided by (used in) financing activities	107,784			—		100,276			(2,706		)	(100,196		)	105,158
Net increase (decrease) in cash and cash equivalents	1			—		(1,428		)	41			—			(1,386		)
Cash and cash equivalents at beginning of period	1			—		5,082			679			—			5,762
Cash and cash equivalents at end of period	$	2		$	—	$	3,654		$	720		$	—		$	4,376

XML

Derivatives (Schedule Of Effect On Operating Results) (Details) (Total Commodity Derivatives [Member], USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income, Supply & Logistics Product Costs	$ (5,817)	$ 2,587	$ (2,959)	$ (11,223)
Designated As Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income, Supply & Logistics Product Costs	0	0	0	(173)
Not Designated As Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income, Supply & Logistics Product Costs	$ (5,817)	$ 2,587	$ (2,959)	$ (11,050)

XML

Condensed Consolidating Financial Information

9 Months Ended

Sep. 30, 2012

Condensed Consolidating Financial Information [Abstract]

Condensed Consolidating Financial Information

16. Condensed Consolidating Financial Information

Our $350 million aggregate principal amount of senior unsecured notes co-issued by Genesis Energy, L.P. and Genesis Energy Finance Corporation are fully and unconditionally guaranteed jointly and severally by all of Genesis Energy, L.P.’s 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. Each subsidiary guarantor and the subsidiary co-issuer are 100% owned, directly or indirectly, by Genesis Energy, L.P. See Note 7 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

September 30, 2012

	Genesis Energy, L.P. (Parent and Co-Issuer)		Genesis Energy Finance Corporation (Co-Issuer)		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Genesis Energy, L.P. Consolidated
ASSETS
Current assets:
Cash and cash equivalents	$	11	$	—	$	14,753		$	697		$	—		$	15,461
Other current assets	744,217		—		387,772			38,521			(758,704		)	411,806
Total current assets	744,228		—		402,525			39,218			(758,704		)	427,267
Fixed assets, at cost	—		—		583,751			100,912			—			684,663
Less: Accumulated depreciation	—		—		(136,459		)	(12,253		)	—			(148,712		)
Net fixed assets	—		—		447,292			88,659			—			535,951
Goodwill	—		—		325,046			—			—			325,046
Other assets, net	19,152		—		257,694			158,875			(164,755		)	270,966
Equity investees	—		—		547,925			—			—			547,925
Investments in subsidiaries	1,007,650		—		100,005			—			(1,107,655		)	—
Total assets	$	1,771,030	$	—	$	2,080,487		$	286,752		$	(2,031,114	)	$	2,107,155
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities	$	9,173	$	—	$	1,047,542		$	19,987		$	(758,323	)	$	318,379
Senior secured credit facility	483,000		—		—			—			—			483,000
Senior unsecured notes	350,924		—		—			—			—			350,924
Deferred tax liabilities	—		—		11,598			—			—			11,598
Other liabilities	—		—		12,850			167,041			(164,570		)	15,321
Total liabilities	843,097		—		1,071,990			187,028			(922,893		)	1,179,222
Partners’ capital	927,933		—		1,008,497			99,724			(1,108,221		)	927,933
Total liabilities and partners’ capital	$	1,771,030	$	—	$	2,080,487		$	286,752		$	(2,031,114	)	$	2,107,155

Unaudited Condensed Consolidating Balance Sheet

December 31, 2011

	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	$	3	$	—	$	9,182		$	1,632		$	—		$	10,817
Other current assets	597,966		—		341,131			31,897			(605,707		)	365,287
Total current assets	597,969		—		350,313			33,529			(605,707		)	376,104
Fixed assets, at cost	—		—		444,262			96,876			—			541,138
Less: Accumulated depreciation	—		—		(114,655		)	(9,558		)	—			(124,213		)
Net fixed assets	—		—		329,607			87,318			—			416,925
Goodwill	—		—		325,046			—			—			325,046
Other assets, net	14,773		—		276,450			162,373			(167,774		)	285,822
Equity investees	—		—		326,947			—			—			326,947
Investments in subsidiaries	841,725		—		96,303			—			(938,028		)	—
Total assets	$	1,454,467	$	—	$	1,704,666		$	283,220		$	(1,711,509	)	$	1,730,844
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities	$	2,529	$	—	$	835,013		$	17,562		$	(605,676	)	$	249,428
Senior secured credit facility	409,300		—		—			—			—			409,300
Senior unsecured notes	250,000		—		—			—			—			250,000
Deferred tax liabilities	—		—		12,549			—			—			12,549
Other liabilities	—		—		14,673			169,842			(167,586		)	16,929
Total liabilities	661,829		—		862,235			187,404			(773,262		)	938,206
Partners’ capital	792,638		—		842,431			95,816			(938,247		)	792,638
Total liabilities and partners’ capital	$	1,454,467	$	—	$	1,704,666		$	283,220		$	(1,711,509	)	$	1,730,844

Unaudited Condensed Consolidating Statement of Operations

Three Months Ended September 30, 2012

	Genesis Energy, L.P. (Parent and Co-Issuer)			Genesis Energy Finance Corporation (Co-Issuer)		Guarantor Subsidiaries		Non-Guarantor Subsidiaries			Eliminations			Genesis Energy, L.P. Consolidated
REVENUES:
Supply and logistics	$	—		$	—	$	869,726	$	31,113		$	(25,646	)	$	875,193
Refinery services	—			—		48,809		4,367			(5,199		)	47,977
Pipeline transportation services	—			—		12,596		6,568			—			19,164
Total revenues	—			—		931,131		42,048			(30,845		)	942,334
COSTS AND EXPENSES:
Supply and logistics costs	—			—		852,009		26,488			(25,648		)	852,849
Refinery services operating costs	—			—		29,339		4,565			(4,661		)	29,243
Pipeline transportation operating costs	—			—		5,661		250			—			5,911
General and administrative	—			—		10,343		32			—			10,375
Depreciation and amortization	—			—		13,940		898			—			14,838
Total costs and expenses	—			—		911,292		32,233			(30,309		)	913,216
OPERATING INCOME	—			—		19,839		9,815			(536		)	29,118
Equity in earnings of subsidiaries	41,052			—		5,738		—			(46,790		)	—
Equity in earnings of equity investees	—			—		3,432		—			—			3,432
Interest (expense) income, net	(9,858		)	—		4,119		(4,134		)	—			(9,873		)
Income before income taxes	31,194			—		33,128		5,681			(47,326		)	22,677
Income tax benefit	—			—		8,509		8			—			8,517
NET INCOME	$	31,194		$	—	$	41,637	$	5,689		$	(47,326	)	$	31,194

Unaudited Condensed Consolidating Statement of Operations

Three Months Ended September 30, 2011

	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:
Supply and logistics	$	—		$	—	$	765,714		$	—		$	—		$	765,714
Refinery services	—			—		48,700			3,805			(4,113		)	48,392
Pipeline transportation services	—			—		9,388			6,706			—			16,094
Total revenues	—			—		823,802			10,511			(4,113		)	830,200
COSTS AND EXPENSES:
Supply and logistics costs	—			—		743,833			—			—			743,833
Refinery services operating costs	—			—		30,448			3,612			(3,924		)	30,136
Pipeline transportation operating costs	—			—		3,818			170			—			3,988
General and administrative	—			—		8,905			—			—			8,905
Depreciation and amortization	—			—		14,057			649			—			14,706
Total costs and expenses	—			—		801,061			4,431			(3,924		)	801,568
OPERATING INCOME	—			—		22,741			6,080			(189		)	28,632
Equity in losses of subsidiaries	28,032			—		1,945			—			(29,977		)	—
Equity in earnings of equity investees	—			—		(412		)	—			—			(412		)
Interest (expense) income, net	(8,944		)	—		4,226			(4,242		)	—			(8,960		)
Income before income taxes	19,088			—		28,500			1,838			(30,166		)	19,260
Income tax (expense) benefit	—			—		(233		)	61			—			(172		)
NET INCOME	$	19,088		$	—	$	28,267		$	1,899		$	(30,166	)	$	19,088

Unaudited Condensed Consolidating Statement of Operations

Nine Months Ended September 30, 2012

	Genesis Energy, L.P. (Parent and Co-Issuer)			Genesis Energy Finance Corporation (Co-Issuer)		Guarantor Subsidiaries		Non-Guarantor Subsidiaries			Eliminations			Genesis Energy, L.P. Consolidated
REVENUES:
Supply and logistics	$	—		$	—	$	2,579,102	$	95,451		$	(76,744	)	$	2,597,809
Refinery services	—			—		142,716		13,756			(12,130		)	144,342
Pipeline transportation services	—			—		36,381		19,413			—			55,794
Total revenues	—			—		2,758,199		128,620			(88,874		)	2,797,945
COSTS AND EXPENSES:
Supply and logistics costs	—			—		2,525,474		83,250			(76,744		)	2,531,980
Refinery services operating costs	—			—		89,155		13,701			(11,784		)	91,072
Pipeline transportation operating costs	—			—		15,351		644			—			15,995
General and administrative	—			—		29,842		92			—			29,934
Depreciation and amortization	—			—		42,759		2,688			—			45,447
Total costs and expenses	—			—		2,702,581		100,375			(88,528		)	2,714,428
OPERATING INCOME	—			—		55,618		28,245			(346		)	83,517
Equity in earnings of subsidiaries	100,011			—		15,869		—			(115,880		)	—
Equity in earnings of equity investees	—			—		7,971		—			—			7,971
Interest (expense) income, net	(30,629		)	—		12,414		(12,482		)	—			(30,697		)
Income before income taxes	69,382			—		91,872		15,763			(116,226		)	60,791
Income tax benefit (expense)	—			—		8,630		(39		)	—			8,591
NET INCOME	$	69,382		$	—	$	100,502	$	15,724		$	(116,226	)	$	69,382

Unaudited Condensed Consolidating Statement of Operations

Nine Months Ended September 30, 2011

	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:
Supply and logistics	$	—		$	—	$	2,091,854		$	—		$	—		$	2,091,854
Refinery services	—			—		142,992			12,953			(10,644		)	145,301
Pipeline transportation services	—			—		26,292			19,341			—			45,633
Total revenues	—			—		2,261,138			32,294			(10,644		)	2,282,788
COSTS AND EXPENSES:
Supply and logistics costs	—			—		2,044,554			—			—			2,044,554
Refinery services operating costs	—			—		88,641			11,836			(10,491		)	89,986
Pipeline transportation operating costs	—			—		11,937			477			—			12,414
General and administrative	—			—		25,339			—			—			25,339
Depreciation and amortization	—			—		41,153			1,947			—			43,100
Total costs and expenses	—			—		2,211,624			14,260			(10,491		)	2,215,393
OPERATING INCOME	—			—		49,514			18,034			(153		)	67,395
Equity in earnings of subsidiaries	70,092			—		5,238			—			(75,330		)	—
Equity in earnings of equity investees	—			—		3,377			—			—			3,377
Interest (expense) income, net	(26,616		)	—		12,726			(12,780		)	—			(26,670		)
Income before income taxes	43,476			—		70,855			5,254			(75,483		)	44,102
Income tax expense	—			—		(467		)	(159		)	—			(626		)
NET INCOME	$	43,476		$	—	$	70,388		$	5,095		$	(75,483	)	$	43,476

Unaudited Condensed Consolidating Statement of Cash Flows

Nine Months Ended September 30, 2012

	Genesis Energy, L.P. (Parent and Co-Issuer)			Genesis Energy Finance Corporation (Co-Issuer)		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Genesis Energy, L.P. Consolidated
Net cash (used in) provided by operating activities	$	(91,453	)	$	—	$	304,617		$	17,700		$	(87,926	)	$	142,938
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	—			—		(112,665		)	(4,037		)	—			(116,702		)
Cash distributions received from equity investees - return of investment	27,878			—		10,918			—			(27,878		)	10,918
Investments in equity investees	(169,421		)	—		(57,072		)	—			169,421			(57,072		)
Acquisitions	—			—		(205,576		)	—			—			(205,576		)
Repayments on loan to non-guarantor subsidiary	—			—		3,019			—			(3,019		)	—
Proceeds from asset sales	—			—		667			—			—			667
Other, net	—			—		(1,012		)	—			—			(1,012		)
Net cash used in investing activities	(141,543		)	—		(361,721		)	(4,037		)	138,524			(368,777		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	1,407,000			—		—			—			—			1,407,000
Repayments on senior secured credit facility	(1,333,300		)	—		—			—			—			(1,333,300		)
Proceeds from issuance of senior unsecured notes, including premium	101,000			—		—			—			—			101,000
Debt issuance costs	(7,109		)	—		—			—			—			(7,109		)
Issuance of common units for cash, net	169,421			—		169,421			—			(169,421		)	169,421
Distributions to partners/owners	(104,008		)	—		(104,008		)	(11,819		)	115,827			(104,008		)
Other, net	—			—		(2,738		)	(2,779		)	2,996			(2,521		)
Net cash provided by (used in) financing activities	233,004			—		62,675			(14,598		)	(50,598		)	230,483
Net increase (decrease) in cash and cash equivalents	8			—		5,571			(935		)	—			4,644
Cash and cash equivalents at beginning of period	3			—		9,182			1,632			—			10,817
Cash and cash equivalents at end of period	$	11		$	—	$	14,753		$	697		$	—		$	15,461

Unaudited Condensed Consolidating Statement of Cash Flows

Nine Months Ended September 30, 2011

	Genesis Energy, L.P. (Parent and Co-Issuer)			Genesis Energy Finance Corporation (Co-Issuer)		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Eliminations			Genesis Energy, L.P. Consolidated
Net cash (used in) provided by operating activities	$	(4,881	)	$	—	$	41,160		$	2,844		$	23		$	39,146
CASH FLOWS FROM INVESTING ACTIVITIES:
Payments to acquire fixed and intangible assets	—			—		(15,060		)	(97		)	—			(15,157		)
Cash distributions received from equity investees - return of investment	82,067			—		8,577			—			(82,067		)	8,577
Investments in equity investees	(184,969		)	—		(194		)	—			184,969			(194		)
Acquisitions	—			—		(143,489		)	—			—			(143,489		)
Repayments on loan to non-guarantor subsidiary	—			—		2,729			—			(2,729		)	—
Proceeds from asset sales	—			—		4,444			—			—			4,444
Other, net	—			—		129			—			—			129
Net cash used in investing activities	(102,902		)	—		(142,864		)	(97		)	100,173			(145,690		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on senior secured credit facility	571,700			—		—			—			—			571,700
Repayments on senior secured credit facility	(563,800		)	—		—			—			—			(563,800		)
Debt issuance costs	(3,018		)	—		—			—			—			(3,018		)
Distributions to partners/owners	(82,067		)	—		(82,067		)	—			82,067			(82,067		)
Issuance of common units for cash, net	184,969			—		184,969			—			(184,969		)	184,969
Other, net	—			—		(2,626		)	(2,706		)	2,706			(2,626		)
Net cash provided by (used in) financing activities	107,784			—		100,276			(2,706		)	(100,196		)	105,158
Net increase (decrease) in cash and cash equivalents	1			—		(1,428		)	41			—			(1,386		)
Cash and cash equivalents at beginning of period	1			—		5,082			679			—			5,762
Cash and cash equivalents at end of period	$	2		$	—	$	3,654		$	720		$	—		$	4,376

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Organization And Basis Of Presentation And Consolidation (Details)	9 Months Ended
	Sep. 30, 2012
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Limited Partners' ownership percentage	100.00%

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Inventories (Tables)

9 Months Ended

Sep. 30, 2012

Inventory Disclosure [Abstract]

Schedule Of Major Components Of Inventories

	September 30, 2012		December 31, 2011
Petroleum products	$	41,076	$	70,769
Crude oil	12,014		11,701
Caustic soda	6,829		11,312
NaHS	7,376		7,337
Other	3		5
Total	$	67,298	$	101,124

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Income Taxes (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2012
15. Income Taxes [Abstract]
Unrecognized Tax Benefits	$ 8.2

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Organization And Basis Of Presentation And Consolidation

9 Months Ended

Sep. 30, 2012

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization And Basis Of Presentation And Consolidation

1. Organization and Basis of Presentation and Consolidation

Organization

We are a limited partnership focused on the midstream segment of the oil and gas industry in the Gulf Coast region of the United States, primarily Texas, Louisiana, Arkansas, Mississippi, Alabama, Florida and in the Gulf of Mexico. We have a diverse portfolio of assets, including pipelines, refinery-related plants, storage tanks and terminals, barges and trucks. We were formed in 1996 and are owned 100% by our limited partners. Genesis Energy, LLC, our general partner, is a wholly-owned subsidiary. Our general partner has sole responsibility for conducting our business and managing our operations. We conduct our operations and own our operating assets through our subsidiaries and joint ventures. We manage our businesses through the following three divisions that constitute our reportable segments:

• Pipeline transportation of interstate, intrastate and offshore crude oil, and, to a lesser extent, carbon dioxide (or "CO₂");

• Refinery services involving processing of high sulfur (or “sour”) gas streams for refineries to remove the sulfur and selling the related by-product, sodium hydrosulfide (or “NaHS”, commonly pronounced "nash"); and

• Supply and logistics services, which include terminaling, blending, storing, marketing, and transporting crude oil and petroleum products and, on a smaller scale, CO₂.

Basis of Presentation and Consolidation

The accompanying Unaudited Condensed Consolidated Financial Statements include Genesis Energy, L.P. and its subsidiaries, including Genesis Energy, LLC, our general partner.

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, 2011.

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.

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Condensed Consolidated Balance Sheets (Parenthetical)	Sep. 30, 2012	Dec. 31, 2011
Statement of Financial Position [Abstract]
Common units, issued	81,202,752	71,965,062
Common units, outstanding	81,202,752	71,965,062

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Supplemental Cash Flow Information

9 Months Ended

Sep. 30, 2012

Supplemental Cash Flow Elements [Abstract]

Supplemental Cash Flow Information

11. Supplemental Cash Flow Information

The following table provides information regarding the net changes in components of operating assets and liabilities.

	Nine Months Ended September 30,
	2012			2011
(Increase) decrease in:
Accounts receivable	$	(80,789	)	$	(52,355	)
Inventories	33,826			(34,757		)
Other current assets	1,846			1,515
Increase (decrease) in:
Accounts payable	57,851			16,953
Accrued liabilities	6,144			17,906
Net changes in components of operating assets and liabilities	$	18,878		$	(50,738	)

Payments of interest and commitment fees were $24.4 million and $20.3 million for the nine months ended September 30, 2012 and 2011, respectively.

At September 30, 2012 and 2011, we had incurred liabilities for fixed and intangible asset additions totaling $4.8 million and $1.3 million, respectively, that had not been paid at the end of the third 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.

At September 30, 2012, we had incurred liabilities for other asset additions totaling $0.6 million that had not been paid at the end of the third quarter, and, therefore, were not included in the caption "Other, net" under Cash Flows from Investing Activities in the Unaudited Condensed Consolidated Statements of Cash Flows.

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Document And Entity Information	9 Months Ended
	Sep. 30, 2012	Nov. 01, 2012
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2012
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q3
Entity Registrant Name	GENESIS ENERGY LP
Entity Central Index Key	0001022321
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		81,162,755
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes

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Derivatives

9 Months Ended

Sep. 30, 2012

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives

12. Derivatives

Commodity Derivatives

We have exposure to commodity price changes related to our inventory and purchase commitments. We utilize derivative instruments (primarily futures and options contracts traded on the NYMEX) to hedge our exposure to commodity prices, primarily of crude oil, fuel oil and petroleum products. Our decision as to whether to designate derivative instruments as fair value hedges for accounting purposes relates to our expectations of the length of time we expect to have the commodity price exposure and our expectations as to whether the derivative contract will qualify as highly effective under accounting guidance in limiting our exposure to commodity price risk. Most of the petroleum products, including fuel oil that we supply, cannot be hedged with a high degree of effectiveness with derivative contracts available on the NYMEX; therefore, we do not designate derivative contracts utilized to limit our price risk related to these products as hedges for accounting purposes. Typically we utilize crude oil and other petroleum products futures and option contracts to limit our exposure to the effect of fluctuations in petroleum products prices on the future sale of our inventory or commitments to purchase petroleum products, and we recognize any changes in fair value of the derivative contracts as increases or decreases in our cost of sales. The recognition of changes in fair value of the derivative contracts not designated as hedges for accounting purposes can occur in reporting periods that do not coincide with the recognition of gain or loss on the actual transaction being hedged. Therefore we will, on occasion, report gains or losses in one period that will be partially offset by gains or losses in a future period when the hedged transaction is completed.

In accordance with NYMEX requirements, we fund the margin associated with our loss positions on commodity derivative contracts traded on the NYMEX. The amount of the margin is adjusted daily based on the fair value of the commodity contracts. The margin requirements are intended to mitigate a party’s exposure to market volatility and the associated contracting party risk. We offset fair value amounts recorded for our NYMEX derivative contracts against margin funding as required by the NYMEX in Current Assets - Other in our Unaudited Condensed Consolidated Balance Sheets.

At September 30, 2012, we had the following outstanding derivative commodity futures and options contracts that were entered into to economically hedge inventory or fixed price purchase commitments. We had no outstanding derivative contracts that were designated as hedges under accounting rules.

	Sell (Short) Contracts		Buy (Long) Contracts
Not qualifying or not designated as hedges under accounting rules:
Crude oil futures:
Contract volumes (1,000 bbls)	59		25
Weighted average contract price per bbl	$	92.69	$	92.19
Crude oil LLS/WTI swap:
Contract volumes (1,000 bbls)	100		—
Weighted average contract price per bbl	$	18.63	$	—
Heating oil futures:
Contract volumes (1,000 bbls)	94		66
Weighted average contract price per gal	$	3.12	$	3.16
#6 Fuel oil futures:
Contract volumes (1,000 bbls)	640		200
Weighted average contract price per bbl	$	97.59	$	98.05
Crude oil options:
Contract volumes (1,000 bbls)	360		105
Weighted average premium received	$	1.69	$	0.54
Heating oil options:
Contract volumes (1,000 bbls)	10		—
Weighted average premium received	$	0.08	$	—

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 September 30, 2012 and December 31, 2011:

Fair Value of Derivative Assets and Liabilities

	Unaudited Condensed Consolidated Balance Sheets Location	Fair Value
		September 30, 2012				December 31, 2011
Asset Derivatives:
Commodity derivatives - futures and call options:
Undesignated hedges	Current Assets - Other	$	178			$	306
Total asset derivatives		$	178			$	306
Liability Derivatives:
Commodity derivatives - futures and call options:
Undesignated hedges	Current Assets - Other	$	(1,440	)	(1)	$	(2,820	)	(1)
Total liability derivatives		$	(1,440	)		$	(2,820	)

(1) These derivative liabilities have been funded with margin deposits recorded in our Unaudited Condensed Consolidated Balance Sheets under Current Assets - Other.

Effect on Operating Results

		Amount of Gain (Loss) Recognized in Income
	Unaudited Condensed Consolidated Statements of Operations Location	Three Months Ended September 30,					Nine Months Ended September 30,
		2012			2011		2012			2011
Commodity derivatives - futures and call options:
Contracts designated as hedges under accounting guidance	Supply and logistics product costs	$	—		$	—	$	—		$	(173	)
Contracts not considered hedges under accounting guidance	Supply and logistics product costs	(5,817		)	2,587		(2,959		)	(11,050		)
Total commodity derivatives		$	(5,817	)	$	2,587	$	(2,959	)	$	(11,223	)

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Condensed Consolidated Statements Of Operations (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
REVENUES:
Supply and logistics	$ 875,193	$ 765,714	$ 2,597,809	$ 2,091,854
Refinery services	47,977	48,392	144,342	145,301
Pipeline transportation services	19,164	16,094	55,794	45,633
Total revenues	942,334	830,200	2,797,945	2,282,788
COSTS AND EXPENSES:
Supply and logistics product costs	811,896	710,355	2,412,404	1,961,038
Supply and logistics operating costs	40,953	33,478	119,576	83,516
Refinery services operating costs	29,243	30,136	91,072	89,986
Pipeline transportation operating costs	5,911	3,988	15,995	12,414
General and administrative	10,375	8,905	29,934	25,339
Depreciation and amortization	14,838	14,706	45,447	43,100
Total costs and expenses	913,216	801,568	2,714,428	2,215,393
OPERATING INCOME	29,118	28,632	83,517	67,395
Equity in earnings (losses) of equity investees	3,432	(412)	7,971	3,377
Interest expense	(9,873)	(8,960)	(30,697)	(26,670)
Income before income taxes	22,677	19,260	60,791	44,102
Income tax benefit (expense)	8,517	(172)	8,591	(626)
NET INCOME	$ 31,194	$ 19,088	$ 69,382	$ 43,476
NET INCOME PER COMMON UNIT:
Basic and Diluted	$ 0.39	$ 0.27	$ 0.90	$ 0.65
WEIGHTED AVERAGE OUTSTANDING COMMON UNITS:
Basic and Diluted	79,901	70,447	77,410	66,580

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Intangible Assets

9 Months Ended

Sep. 30, 2012

Intangible Assets, Net (Excluding Goodwill) [Abstract]

Intangible Assets

6. Intangible Assets

The following table summarizes the components of our intangible assets at the dates indicated:

	September 30, 2012						December 31, 2011
	Gross Carrying Amount		Accumulated Amortization		Carrying Value		Gross Carrying Amount		Accumulated Amortization		Carrying Value
Refinery Services:
Customer relationships	$	94,654	$	67,403	$	27,251	$	94,654	$	62,111	$	32,543
Licensing agreements	38,678		22,038		16,640		38,678		19,476		19,202
Supplier relationships	36,469		35,878		591		36,469		34,105		2,364
Segment total	169,801		125,319		44,482		169,801		115,692		54,109
Supply & Logistics:
Customer relationships	35,430		25,698		9,732		35,430		23,584		11,846
Intangibles associated with lease	13,260		2,447		10,813		13,260		2,092		11,168
Trade names	18,888		18,888		—		18,888		17,048		1,840
Segment total	67,578		47,033		20,545		67,578		42,724		24,854
Other	18,467		4,354		14,113		17,292		2,899		14,393
Total	$	255,846	$	176,706	$	79,140	$	254,671	$	161,315	$	93,356

Our amortization expense for the periods presented was as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
Amortization expense	$	4,520	$	7,721	$	15,390	$	22,367

We estimate that our amortization expense for the next five years will be as follows:

Remainder of	2012	$	4,520
	2013	$	14,597
	2014	$	12,297
	2015	$	10,489
	2016	$	9,028

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Equity Investees

9 Months Ended

Sep. 30, 2012

Equity Method Investments and Joint Ventures [Abstract]

Equity Investees

5. 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 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 September 30, 2012 and December 31, 2011, the unamortized excess cost amounts totaled $236.6 million and $97.8 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 September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
Genesis’ share of operating earnings	$	5,978		$	729		$	15,611		$	6,800
Amortization of excess purchase price	(2,546		)	(1,141		)	(7,640		)	(3,423		)
Net equity in earnings (losses)	$	3,432		$	(412	)	$	7,971		$	3,377
Distributions received	$	9,045		$	3,289		$	27,069		$	15,302

The following tables present the combined unaudited balance sheet and income statement information (on a 100% basis) of our equity investees:

	September 30, 2012		December 31, 2011
Balance Sheet Information:
Assets
Current assets	$	65,250	$	12,732
Fixed assets, net	760,788		441,894
Other assets	10,964		18,000
Total assets	$	837,002	$	472,626
Liabilities and equity
Current liabilities	$	53,667	$	5,891
Other liabilities	118,226		8,536
Equity	665,109		458,199
Total liabilities and equity	$	837,002	$	472,626

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
Income Statement Information:
Revenues	$	39,799	$	7,975	$	113,769	$	32,819
Operating income	$	19,810	$	576	$	53,597	$	11,768
Net income	$	19,196	$	576	$	51,553	$	11,778

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Acquisitions (Tables)

9 Months Ended

Sep. 30, 2012

Business Combinations [Abstract]

Schedule of Purchase Price Allocation

The preliminary allocation of the purchase price is summarized as follows:

Property and equipment	$	28,456
Equity investees	182,993
Asset retirement obligation assumed	(5,873		)
Total allocation	$	205,576

Schedule Of Selected Financial Information

	Three Months Ended September 30,		Nine Months Ended September 30,
	2012
Revenues	$	1,180	$	4,334
Equity in earnings of equity investees	$	3,497	$	9,194
Net income	$	3,950	$	11,128

Schedule Of Pro Forma Financial Information

	Three Months Ended September 30,		Nine Months Ended September 30,
	2011
Pro forma earnings data:
Revenues	$	831,956	$	2,288,056
Equity in earnings of equity investees	$	2,605	$	11,963
Net income	$	20,903	$	48,941
Basic and diluted earnings per unit:
As reported net income per unit	$	0.27	$	0.65
Pro forma net income per unit	$	0.30	$	0.74
As reported units outstanding	70,447		66,580
Pro forma units outstanding	70,447		66,580

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Fair-Value Measurements

9 Months Ended

Sep. 30, 2012

Fair Value Disclosures [Abstract]

Fair-Value Measurements

13. 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;

(2) Level 2 fair values are based on pricing inputs other than quoted prices in active markets 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 at the dates indicated.

	Fair Value at							Fair Value at
	September 30, 2012							December 31, 2011
Recurring Fair Value Measures	Level 1			Level 2		Level 3		Level 1			Level 2		Level 3
Commodity derivatives:
Assets	$	178		$	—	$	—	$	306		$	—	$	—
Liabilities	$	(1,440	)	$	—	$	—	$	(2,820	)	$	—	$	—

Our commodity derivatives include exchange-traded futures and exchange-traded options contracts. The fair value of these exchange-traded derivative contracts is based on unadjusted quoted prices in active markets and is, therefore, included in Level 1 of the fair value hierarchy.

See Note 12 for additional information on our derivative instruments.

Nonfinancial Assets and Liabilities

We utilize fair value on a non-recurring basis to perform impairment tests as required on our property, plant and equipment, goodwill and intangible assets. Assets and liabilities acquired in business combinations are recorded at their fair value as of the date of acquisition. The inputs used to determine such fair value are primarily based upon internally developed cash flow models and would generally be classified in Level 3, in the event that we were required to measure and record such assets within our Unaudited Condensed Consolidated Financial Statements. Additionally, we use fair value to determine the inception value of our asset retirement obligations. The inputs used to determine such fair value are primarily based upon costs incurred historically for similar work, as well as estimates from independent third parties for costs that would be incurred to restore leased property to the contractually stipulated condition, and would generally be classified in Level 3.

Other Fair Value Measurements

We believe the debt outstanding under our credit facility approximates fair value as the stated rate of interest approximates current market rates for similar instruments with comparable maturities. At September 30, 2012, our senior unsecured notes had a carrying value of $351 million and a fair value of $371.4 million, compared to $250 million and $253.1 million, respectively, at December 31, 2011. 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.

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Business Segment Information

9 Months Ended

Sep. 30, 2012

Segment Reporting [Abstract]

Business Segment Information

9. Business Segment Information

Our operations consist of three operating segments:

(1) Pipeline Transportation – interstate, intrastate and offshore crude oil, and to a lesser extent, CO₂;

(2) Refinery Services – processing high sulfur (or “sour”) gas streams as part of refining operations to remove the sulfur and selling the related by-product, NaHS and;

(3) Supply and Logistics – terminaling, blending, storing, marketing, and transporting crude oil and petroleum products (primarily fuel oil, asphalt, and other heavy refined products) and, on a smaller scale, CO₂.

Substantially all of our revenues are derived from, and substantially all of our assets are located in, the United States.

We define Segment Margin as revenues less product costs, operating expenses (excluding non-cash charges, such as depreciation and amortization), and segment general and administrative expenses, plus our equity in distributable cash generated by our equity investees. In addition, our Segment Margin definition excludes the non-cash effects of our 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:

	Pipeline Transportation		Refinery Services			Supply & Logistics			Total
Three Months Ended September 30, 2012
Segment margin (a)	$	23,295	$	18,983		$	23,651		$	65,929
Capital expenditures (b)	$	21,764	$	1,025		$	14,410		$	37,199
Revenues:
External customers	$	16,190	$	50,378		$	875,766		$	942,334
Intersegment (c)	2,974		(2,401		)	(573		)	—
Total revenues of reportable segments	$	19,164	$	47,977		$	875,193		$	942,334
Three Months Ended September 30, 2011
Segment margin (a)	$	16,030	$	17,992		$	18,909		$	52,931
Capital expenditures (b)	$	1,582	$	852		$	146,999		$	149,433
Revenues:
External customers	$	12,658	$	50,982		$	766,560		$	830,200
Intersegment (c)	3,436		(2,590		)	(846		)	—
Total revenues of reportable segments	$	16,094	$	48,392		$	765,714		$	830,200
Nine Months Ended September 30, 2012
Segment margin (a)	$	69,427	$	53,510		$	66,075		$	189,012
Capital expenditures (b)	$	300,093	$	2,295		$	77,414		$	379,802
Revenues:
External customers	$	44,564	$	151,326		$	2,602,055		$	2,797,945
Intersegment (c)	11,230		(6,984		)	(4,246		)	—
Total revenues of reportable segments	$	55,794	$	144,342		$	2,597,809		$	2,797,945
Nine Months Ended September 30, 2011
Segment margin (a)	$	50,639	$	54,887		$	44,233		$	149,759
Capital expenditures (b)	$	3,264	$	1,321		$	149,126		$	153,711
Revenues:
External customers	$	37,302	$	151,899		$	2,093,587		$	2,282,788
Intersegment (c)	8,331		(6,598		)	(1,733		)	—
Total revenues of reportable segments	$	45,633	$	145,301		$	2,091,854		$	2,282,788

Total assets by reportable segment were as follows:

	September 30, 2012		December 31, 2011
Pipeline transportation	$	870,966	$	594,728
Refinery services	413,888		426,993
Supply and logistics	774,002		659,576
Other assets	48,299		49,547
Total consolidated assets	$	2,107,155	$	1,730,844

(a) A reconciliation of Segment Margin to income before income taxes for the periods presented is as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
Segment Margin	$	65,929		$	52,931		$	189,012		$	149,759
Corporate general and administrative expenses	(9,428		)	(8,194		)	(26,756		)	(23,267		)
Depreciation and amortization	(14,838		)	(14,706		)	(45,447		)	(43,100		)
Interest expense	(9,873		)	(8,960		)	(30,697		)	(26,670		)
Distributable cash from equity investees in excess of equity in earnings	(5,613		)	(3,701		)	(19,098		)	(11,925		)
Non-cash items not included in segment margin	(2,222		)	3,061			(2,475		)	2,729
Cash payments from direct financing leases in excess of earnings	(1,278		)	(1,171		)	(3,748		)	(3,424		)
Income before income taxes	$	22,677		$	19,260		$	60,791		$	44,102

(b) Capital expenditures include maintenance and growth capital expenditures, such as fixed asset additions (including enhancements to existing facilities and construction of internal growth projects) as well as acquisitions of businesses and interests in equity investees. Capital spending in our pipeline transportation segment included $5.7 million and $57.1 million during the three and nine months ended September 30, 2012, respectively, representing capital contributions to our SEKCO equity investee to fund our share of the construction costs for its pipeline. For the nine months ended September 30, 2012, capital spending in our pipeline transportation segment also included $205.6 million for the acquisition of interests in several Gulf of Mexico pipelines. For the nine months ended September 30, 2012, capital spending in our supply and logistics segment also included $30.6 million for the purchase of barge assets.

(c) Intersegment sales were conducted under terms that we believe were no more or less favorable than then-existing market conditions.

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Transactions With Related Parties (Schedule Of Transactions With Related Parties) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended				9 Months Ended				3 Months Ended				9 Months Ended				3 Months Ended				9 Months Ended				3 Months Ended		9 Months Ended			9 Months Ended	0 Months Ended	9 Months Ended		0 Months Ended
	Sep. 30, 2012 Quintana Group [Member]		Sep. 30, 2011 Quintana Group [Member]		Sep. 30, 2012 Quintana Group [Member]		Sep. 30, 2011 Quintana Group [Member]		Sep. 30, 2012 Sandhill Group, LLC [Member]		Sep. 30, 2011 Sandhill Group, LLC [Member]		Sep. 30, 2012 Sandhill Group, LLC [Member]		Sep. 30, 2011 Sandhill Group, LLC [Member]		Sep. 30, 2012 Davison [Member]		Sep. 30, 2011 Davison [Member]		Sep. 30, 2012 Davison [Member]		Sep. 30, 2011 Davison [Member]		Sep. 30, 2012 Chief Executive Officer [Member]	Sep. 30, 2011 Chief Executive Officer [Member]	Sep. 30, 2012 Chief Executive Officer [Member]	Sep. 30, 2011 Chief Executive Officer [Member]	Sep. 30, 2012 Genesis Energy Interest In Sandhill Group, LLC [Member]	Sep. 30, 2012 Class A [Member] Quintana Group [Member]	Oct. 06, 2012 Class A [Member] Davison [Member]	Sep. 30, 2012 Class A [Member] Davison [Member]	Sep. 30, 2012 Class B [Member] Quintana Group [Member]	Oct. 06, 2012 Class B [Member] Davison [Member]
Related Party Transaction [Line Items]
Related party transaction, expenses	$ 1,980	[1]	$ 902	[1]	$ 6,181	[1]	$ 2,722	[1]																	$ 150	$ 166	$ 450	$ 166
Related party transaction, revenues	$ 6,376	[1]	$ 5,948	[1]	$ 21,142	[1]	$ 27,202	[1]	$ 838	[2]	$ 946	[2]	$ 2,111	[2]	$ 1,921	[2]	$ 326	[1]	$ 737	[1]	$ 1,012	[1]	$ 1,224	[1]
Percentage of common units owned by affiliated companies																														10.00%	17.20%	15.00%	74.00%	76.90%
Percentage of interest held																													50.00%

[1] The Quintana Group, a private equity fund based in Houston, Texas, owned 10% of our Class A common units and 74% of our Class B common units at September 30, 2012. The Davison family owned 15% of our Class A common units at September 30, 2012. The Quintana Group monetized all of its remaining investment in us on October 5, 2012. Substantially in connection with that transaction, certain members of the Davison family, collectively, increased their investment in us to 17.2% of our Class A common units and 76.9% of our Class B units. Soley for financial statement disclosure purposes, we will continue to treat the Davison family and their affiliates as related parties.

[2] We own a 50% interest in Sandhill Group, LLC.

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Debt

9 Months Ended

Sep. 30, 2012

Debt Disclosure [Abstract]

Debt

7. Debt

Our obligations under debt arrangements consisted of the following:

	September 30, 2012		December 31, 2011
Senior secured credit facility	$	483,000	$	409,300
7.875% senior unsecured notes (including unamortized premium of $924 and $0 in 2012 and 2011, respectively)	350,924		250,000
Total long-term debt	$	833,924	$	659,300

As of September 30, 2012, we were in compliance with the financial covenants contained in our credit agreement and senior unsecured notes indenture.

Senior Secured Credit Facility

In July 2012, we amended and restated our senior secured credit facility with a syndicate of banks to, among other things, increase the committed amount from $775 million to $1 billion and the accordion feature from $225 million to $300 million, giving us the ability to expand the size of the facility up to an aggregate $1.3 billion for acquisitions or internal growth projects, subject to lender consent. The inventory financing sublimit tranche was increased from $125 million to $150 million, and the term of our credit facility was extended to July 25, 2017.

The key terms for rates under our credit facility, which are dependent on our leverage ratio (as defined in the credit agreement), are as follows:

• The applicable margin varies from 1.75% to 2.75% on eurodollar borrowings and from 0.75% to 1.75% on alternate base rate borrowings.

•Letter of credit fees range from 1.75% to 2.75%.

• The commitment fee on the unused committed amount will range from 0.375% to 0.50%.

At September 30, 2012, we had $483 million borrowed under our credit facility, with $48.6 million of the borrowed amount designated as a loan under the inventory sublimit. The credit agreement allows up to $100 million of the capacity to be used for letters of credit, of which $12.6 million was outstanding at September 30, 2012. 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 September 30, 2012 was $504.4 million.

Senior Unsecured Notes Issuance

On February 1, 2012, we issued an additional $100 million of aggregate principal amount of senior unsecured notes under our existing 7.875% senior unsecured notes due 2018 indenture. The notes were issued at 101% of face value at an effective interest rate of 7.682%. The notes have the same terms and conditions as the notes previously issued under the indenture. The issuance increased the total aggregate principal amount under the indenture to $350 million. The net proceeds were used to repay borrowings under our credit facility.

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Partners' Capital And Distributions

9 Months Ended

Sep. 30, 2012

Partners' Capital Notes [Abstract]

Partners' Capital And Distributions

8. Partners’ Capital and Distributions

On March 28, 2012, we issued 5,750,000 Class A common units in a public offering at a price of $30.80 per unit. We received proceeds, net of underwriting discounts and offering costs, of $169.4 million from the offering. The net proceeds were used for general corporate purposes, including the repayment of borrowings under our credit facility. At September 30, 2012, our outstanding common units consisted of 81,162,755 Class A units and 39,997 Class B units.

Waiver Units

Our waiver units are non-voting securities entitled to a minimal preferential quarterly distribution. At issuance our waiver units were comprised of four classes (designated Class 1, Class 2, Class 3 and Class 4) of 1,738,000 units. The waiver units in each class are convertible into Class A common units in the calendar quarter at a 1:1 conversion rate during which each of our common units receives a specified minimum quarterly distribution and our distribution coverage ratio (after giving effect to the then convertible waiver units) would be at least 1.1 times. The minimum distribution per common unit required for conversion is $0.43 (Class 1), $0.46 (Class 2), $0.49 (Class 3) and $0.52 (Class 4).

On February 14, 2012, our Class 1 waiver units became convertible as we paid a distribution of $0.44 per common unit and satisfied the conversion coverage ratio requirement. All Class 1 waiver units were converted into common units by March 31, 2012.

On August 14, 2012, our Class 2 waiver units became convertible as we paid a distribution of $0.46 per common unit and satisfied the conversion coverage ratio requirement. All Class 2 waiver units were converted into common units by September 30, 2012.

At September 30, 2012, we had 3,476,466 waiver units outstanding comprised of the last two classes.

Distributions

We paid or will pay the following distributions in 2011 and 2012:

Distribution For	Date Paid		Per Unit Amount		Total Amount
2011
1st Quarter	May 13, 2011		$	0.4075	$	26,343
2nd Quarter	August 12, 2011		$	0.4150	$	29,878
3rd Quarter	November 14, 2011		$	0.4275	$	30,777
4th Quarter	February 14, 2012		$	0.4400	$	31,677
2012
1st Quarter	May 15, 2012		$	0.4500	$	35,759
2nd Quarter	August 14, 2012		$	0.4600	$	36,554
3rd Quarter	November 14, 2012	(1)	$	0.4725	$	38,368

(1) This distribution will be paid to unitholders of record as of November 1, 2012.

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Transactions With Related Parties

9 Months Ended

Sep. 30, 2012

Related Party Transactions [Abstract]

Transactions With Related Parties

10. 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 September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
Revenues:
Petroleum products sales to an affiliate of the Quintana Group (1)	$	6,376	$	5,948	$	21,142	$	27,202
Sales of CO2 to Sandhill Group, LLC (2)	838		946		2,111		1,921
Petroleum products sales to Davison family businesses (1)	326		737		1,012		1,224
Costs and expenses:
Marine operating fuel and expenses provided by an affiliate of the Quintana Group (1)	1,980		902		6,181		2,722
Amounts paid to our CEO in connection with the use of his aircraft	150		166		450		166

(1) The Quintana Group, a private equity fund based in Houston, Texas, owned 10% of our Class A common units and 74% of our Class B common units at September 30, 2012. The Davison family owned 15% of our Class A common units at September 30, 2012. The Quintana Group monetized all of its remaining investment in us on October 5, 2012. Substantially in connection with that transaction, certain members of the Davison family, collectively, increased their investment in us to 17.2% of our Class A common units and 76.9% of our Class B units. Soley for financial statement disclosure purposes, we will continue to treat the Davison family and their affiliates as related parties.

(2) We own a 50% interest in Sandhill Group, LLC.

Amounts due to and from Related Parties

At September 30, 2012 and December 31, 2011, an affiliate of the Quintana Group owed us $1.2 million and $1.9 million, respectively, for petroleum product sales. We owed such affiliate $0.1 million at September 30, 2012 and December 31, 2011, respectively, for marine related costs. Sandhill Group, LLC owed us $0.3 million and $0.2 million at September 30, 2012 and December 31, 2011, respectively, for purchases of CO₂.

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Derivatives (Schedule Of Fair Value Of Derivative Assets And Liabilities) (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012		Dec. 31, 2011
Derivatives, Fair Value [Line Items]
Asset Derivatives	$ 178		$ 306
Liability Derivatives	(1,440)		(2,820)
Other Current Assets [Member] | Total Commodity Derivatives [Member] | Not Designated As Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	178		306
Liability Derivatives	$ (1,440)	[1]	$ (2,820)	[1]

[1] These derivative liabilities have been funded with margin deposits recorded in our Unaudited Condensed Consolidated Balance Sheets under Current Assets - Other.

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Fair-Value Measurements (Narrative) (Details) (USD $)	Sep. 30, 2012	Dec. 31, 2011
Fair Value Disclosures [Abstract]
Senior unsecured notes	$ 350,924,000	$ 250,000,000
Long-term Debt, Fair Value	$ 371,400,000	$ 253,100,000

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Derivatives (Schedule Of Outstanding Derivatives Entered Into To Hedge Inventory Or Fixed Price Purchase Commitments) (Details) (Not Designated As Hedging Instrument [Member], USD $) In Thousands, unless otherwise specified	Sep. 30, 2012
Sell (Short) Contracts [Member] | Crude Oil Futures [Member]
Derivative [Line Items]
Contract volumes (1,000 bbls)	$ 59
Weighted average contract price per bbl	92.69
Sell (Short) Contracts [Member] | Crude Oil Swap [Member] [Domain]
Derivative [Line Items]
Contract volumes (1,000 bbls)	100
Weighted average contract price per bbl	18.63
Sell (Short) Contracts [Member] | Heating Oil Futures [Member]
Derivative [Line Items]
Contract volumes (1,000 bbls)	94
Weighted average contract price per gal	3.12
Sell (Short) Contracts [Member] | Fuel Oil Futures [Member]
Derivative [Line Items]
Contract volumes (1,000 bbls)	640
Weighted average contract price per bbl	97.59
Sell (Short) Contracts [Member] | Crude Oil Options [Member]
Derivative [Line Items]
Contract volumes (1,000 bbls)	360
Weighted average premium received	1.69
Sell (Short) Contracts [Member] | Heating Oil Options [Member]
Derivative [Line Items]
Contract volumes (1,000 bbls)	10
Weighted average premium received	0.08
Buy (Long) Contracts [Member] | Crude Oil Futures [Member]
Derivative [Line Items]
Contract volumes (1,000 bbls)	25
Weighted average contract price per bbl	92.19
Buy (Long) Contracts [Member] | Crude Oil Swap [Member] [Domain]
Derivative [Line Items]
Contract volumes (1,000 bbls)	0
Weighted average contract price per bbl	0
Buy (Long) Contracts [Member] | Heating Oil Futures [Member]
Derivative [Line Items]
Contract volumes (1,000 bbls)	66
Weighted average contract price per gal	3.16
Buy (Long) Contracts [Member] | Fuel Oil Futures [Member]
Derivative [Line Items]
Contract volumes (1,000 bbls)	200
Weighted average contract price per bbl	98.05
Buy (Long) Contracts [Member] | Crude Oil Options [Member]
Derivative [Line Items]
Contract volumes (1,000 bbls)	105
Weighted average premium received	0.54
Buy (Long) Contracts [Member] | Heating Oil Options [Member]
Derivative [Line Items]
Contract volumes (1,000 bbls)	$ 0
Weighted average premium received	0.00

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Fair-Value Measurements (Tables)

9 Months Ended

Sep. 30, 2012

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 at the dates indicated.

	Fair Value at							Fair Value at
	September 30, 2012							December 31, 2011
Recurring Fair Value Measures	Level 1			Level 2		Level 3		Level 1			Level 2		Level 3
Commodity derivatives:
Assets	$	178		$	—	$	—	$	306		$	—	$	—
Liabilities	$	(1,440	)	$	—	$	—	$	(2,820	)	$	—	$	—

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Intangible Assets (Schedule of Amortization and Future Amortization Expense) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Amortization expense on intangible assets	$ 4,520	$ 7,721	$ 15,390	$ 22,367
Estimated amortization expense, remainder of 2012			4,520
Estimated amortization expense, 2013			14,597
Estimated amortization expense, 2014			12,297
Estimated amortization expense, 2015			10,489
Estimated amortization expense, 2016			$ 9,028

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Income Taxes

9 Months Ended

Sep. 30, 2012

Income Taxes [Abstract]

Income Tax Disclosure [Text Block]

15. Income Taxes

In the third quarter of 2012, we reversed $8.2 million of uncertain tax positions and recognized an income tax benefit in the Unaudited Condensed Consolidated Statements of Operations as a result of tax audit settlements and the expiration of statutes of limitations. These uncertain tax positions were included in Other Long-Term Liabilities in our Unaudited Condensed Consolidated Balance Sheets.

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Equity Investees (Tables)

9 Months Ended

Sep. 30, 2012

Equity Method Investments and Joint Ventures [Abstract]

Consolidated Financial Statements Related To Equity Investees

	Three Months Ended September 30,						Nine Months Ended September 30,
	2012			2011			2012			2011
Genesis’ share of operating earnings	$	5,978		$	729		$	15,611		$	6,800
Amortization of excess purchase price	(2,546		)	(1,141		)	(7,640		)	(3,423		)
Net equity in earnings (losses)	$	3,432		$	(412	)	$	7,971		$	3,377
Distributions received	$	9,045		$	3,289		$	27,069		$	15,302

Schedule Of Balance Sheet Information For Equity Investees

	September 30, 2012		December 31, 2011
Balance Sheet Information:
Assets
Current assets	$	65,250	$	12,732
Fixed assets, net	760,788		441,894
Other assets	10,964		18,000
Total assets	$	837,002	$	472,626
Liabilities and equity
Current liabilities	$	53,667	$	5,891
Other liabilities	118,226		8,536
Equity	665,109		458,199
Total liabilities and equity	$	837,002	$	472,626

Schedule Of Operations For Equity Investees

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
Income Statement Information:
Revenues	$	39,799	$	7,975	$	113,769	$	32,819
Operating income	$	19,810	$	576	$	53,597	$	11,768
Net income	$	19,196	$	576	$	51,553	$	11,778

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Equity Investees (Schedule Of Operations For Equity Investees) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Equity Method Investments and Joint Ventures [Abstract]
Revenues	$ 39,799	$ 7,975	$ 113,769	$ 32,819
Operating income	19,810	576	53,597	11,768
Net income	$ 19,196	$ 576	$ 51,553	$ 11,778

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Inventories (Schedule Of Major Components Of Inventories) (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Inventory Disclosure [Abstract]
Petroleum products	$ 41,076	$ 70,769
Crude oil	12,014	11,701
Caustic soda	6,829	11,312
NaHS	7,376	7,337
Other	3	5
Total	$ 67,298	$ 101,124

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Condensed Consolidated Statements Of Partners' Capital (USD $) In Thousands, except Share data, unless otherwise specified	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011
Statement of Partners' Capital [Abstract]
Partners' capital, January 1, units	71,965,062	64,615,000
Partners' capital, January 1, value	$ 792,638	$ 669,264
Net income	69,382	43,476
Cash distributions	(104,008)	(82,067)
Issuance of common units for cash, net, units	5,750,000	7,350,000
Issuance of common units for cash, net, value	169,421	184,969
Conversion of waiver units, units	3,476,000
Conversion of waiver units, value	0
Other, units	12,000
Other, value	500
Partners' capital, September 30, units	81,202,752	71,965,000
Partners' capital, September 30, value	$ 927,933	$ 815,642

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Fixed Assets And Asset Retirement Obligations

9 Months Ended

Sep. 30, 2012

Fixed Assets And Asset Retirement Obligations [Abstract]

Fixed Assets And Asset Retirement Obligations

4. Fixed Assets and Asset Retirement Obligations

Fixed Assets

Fixed assets consisted of the following:

	September 30, 2012			December 31, 2011
Pipelines and related assets	$	218,155		$	167,865
Machinery and equipment	63,091			46,233
Transportation equipment	20,280			21,732
Marine vessels	297,416			262,216
Land, buildings and improvements	14,037			13,140
Office equipment, furniture and fixtures	4,487			3,778
Construction in progress	53,135			14,236
Other	14,062			11,938
Fixed assets, at cost	684,663			541,138
Less: Accumulated depreciation	(148,712		)	(124,213		)
Net fixed assets	$	535,951		$	416,925

Our depreciation expense for the periods presented was as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
Depreciation expense	$	9,202	$	5,960	$	27,246	$	17,838

Asset Retirement Obligations

A reconciliation of our liability for asset retirement obligations is as follows:

December 31, 2011	$	5,900
Liabilities incurred and assumed in the current period	5,995
Accretion expense	600
September 30, 2012	$	12,495

We assumed asset retirement obligations of $5.9 million related to pipelines in connection with our acquisition of GOPL. See Note 2 for information related to our acquisitions.

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Business Segment Information (Reconciliation Of Segment Margin To (Loss) Income Before Income Taxes) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2012		Sep. 30, 2011		Sep. 30, 2012		Sep. 30, 2011
Segment Reporting [Abstract]
Segment margin	$ 65,929	[1]	$ 52,931	[1]	$ 189,012	[1]	$ 149,759	[1]
Corporate general and administrative expenses	(9,428)		(8,194)		(26,756)		(23,267)
Depreciation and amortization	(14,838)		(14,706)		(45,447)		(43,100)
Interest expense	(9,873)		(8,960)		(30,697)		(26,670)
Distributable cash from equity investees in excess of equity in earnings	(5,613)		(3,701)		(19,098)		(11,925)
Non-cash items not included in segment margin	(2,222)		3,061		(2,475)		2,729
Cash payments from direct financing leases in excess of earnings	(1,278)		(1,171)		(3,748)		(3,424)
Income before income taxes	$ 22,677		$ 19,260		$ 60,791		$ 44,102

[1] A reconciliation of Segment Margin to income before income taxes for the periods presented is as follows: Three Months EndedSeptember 30, Nine Months EndedSeptember 30, 2012 2011 2012 2011Segment Margin$65,929 $52,931 $189,012 $149,759Corporate general and administrative expenses(9,428) (8,194) (26,756) (23,267)Depreciation and amortization(14,838) (14,706) (45,447) (43,100)Interest expense(9,873) (8,960) (30,697) (26,670)Distributable cash from equity investees in excess of equity in earnings(5,613) (3,701) (19,098) (11,925)Non-cash items not included in segment margin(2,222) 3,061 (2,475) 2,729Cash payments from direct financing leases in excess of earnings(1,278) (1,171) (3,748) (3,424)Income before income taxes$22,677 $19,260 $60,791 $44,102

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Condensed Consolidating Financial Information (Narrative) (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2012
Condensed Financial Statements, Captions [Line Items]
Guarantor Obligations, Current Carrying Value	350
Genesis NEJD Pipeline, LLC [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of equity interest	100.00%
Genesis Energy L P Interest in Subsidiary Guarantors [Member]
Condensed Financial Statements, Captions [Line Items]
Percentage of equity interest	100.00%

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Intangible Assets (Tables)

9 Months Ended

Sep. 30, 2012

Intangible Assets, Net (Excluding Goodwill) [Abstract]

Schedule Of Components Of Intangible Assets

	September 30, 2012						December 31, 2011
	Gross Carrying Amount		Accumulated Amortization		Carrying Value		Gross Carrying Amount		Accumulated Amortization		Carrying Value
Refinery Services:
Customer relationships	$	94,654	$	67,403	$	27,251	$	94,654	$	62,111	$	32,543
Licensing agreements	38,678		22,038		16,640		38,678		19,476		19,202
Supplier relationships	36,469		35,878		591		36,469		34,105		2,364
Segment total	169,801		125,319		44,482		169,801		115,692		54,109
Supply & Logistics:
Customer relationships	35,430		25,698		9,732		35,430		23,584		11,846
Intangibles associated with lease	13,260		2,447		10,813		13,260		2,092		11,168
Trade names	18,888		18,888		—		18,888		17,048		1,840
Segment total	67,578		47,033		20,545		67,578		42,724		24,854
Other	18,467		4,354		14,113		17,292		2,899		14,393
Total	$	255,846	$	176,706	$	79,140	$	254,671	$	161,315	$	93,356

Amortization Expense

	Three Months Ended September 30,				Nine Months Ended September 30,
	2012		2011		2012		2011
Amortization expense	$	4,520	$	7,721	$	15,390	$	22,367

Schedule of Expected Amortization Expense

Remainder of	2012	$	4,520
	2013	$	14,597
	2014	$	12,297
	2015	$	10,489
	2016	$	9,028

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Acquisitions Acquisitions (Schedule of Purchase Price Allocation) (Details) (USD $) In Thousands, unless otherwise specified	Jan. 03, 2012
Business Acquisition [Line Items]
Asset retirement obligation assumed	$ (5,900)
Gulf Of Mexico Crude Oil Pipeline Systems [Member]
Business Acquisition [Line Items]
Property and equipment	28,456
Equity investees	182,993
Asset retirement obligation assumed	(5,873)
Total allocation	$ 205,576

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Contingencies

9 Months Ended

Sep. 30, 2012

Commitments and Contingencies Disclosure [Abstract]

Contingencies

14. Contingencies

We are subject to various environmental laws and regulations. Policies and procedures are in place to monitor compliance and to detect and address any material releases of crude oil from our pipelines or other facilities; however, no assurance can be made that such environmental releases may not substantially affect our business.

We are subject to lawsuits in the normal course of business, as well as examinations 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.