Calumet Specialty Products Partners (CLMT) 10-Q 8 Nov 13 2013 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2013	Nov. 08, 2013
Document and Entity Information [Abstract]	'	'
Entity Registrant Name	'Calumet Specialty Products Partners, L.P.	'
Entity Central Index Key	'0001340122	'
Document Type	'10-Q	'
Document Period End Date	30-Sep-13	'
Amendment Flag	'false	'
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'Q3	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	69,317,278

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$133.90	$32.20
Accounts receivable:	'	'
Trade	294.9	219.3
Other	7.1	7.5
Total accounts receivable	302	226.8
Inventories	559.7	553.6
Derivative assets	22.9	3.1
Prepaid expenses and other current assets	10.7	10.3
Deposits	2.7	7.9
Total current assets	1,031.90	833.9
Property, plant and equipment, net	1,118.70	986.9
Investment in unconsolidated affiliate	19.5	1.9
Goodwill	197.9	187
Other intangible assets, net	178	197.1
Other noncurrent assets, net	95	46.2
Total assets	2,641	2,253
Current liabilities:	'	'
Accounts payable	454.5	333.4
Accrued interest payable	28.8	23.5
Accrued salaries, wages and benefits	13.3	20.1
Accrued income taxes payable	0	27.6
Other taxes payable	22.1	13.7
Other current liabilities	28.9	8.3
Current portion of long-term debt	0.5	0.8
Derivative liabilities	2.2	48
Total current liabilities	550.3	475.4
Pension and postretirement benefit obligations	21.1	24
Other long-term liabilities	1	1.1
Long-term debt, less current portion	863.8	862.7
Total liabilities	1,436.20	1,363.20
Commitments and contingencies	'	'
Partners’ capital:	'	'
Limited partners’ interest (69,317,278 and 57,529,778 units issued and outstanding at September 30, 2013 and December 31, 2012, respectively)	1,145.90	884.8
General partner’s interest	37.7	30.5
Accumulated other comprehensive income (loss)	21.2	-25.5
Total partners’ capital	1,204.80	889.8
Total liabilities and partners’ capital	$2,641	$2,253

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (Limited Partner [Member])	Sep. 30, 2013	Dec. 31, 2012
Limited Partner [Member]	'	'
Limited partners’ interest (69,317,278 and 57,529,778 units issued and outstanding at September 30, 2013 and December 31, 2012, respectively)	69,317,278	57,529,778
Limited partners’ interest (69,317,278 and 57,529,778 units issued and outstanding at September 30, 2013 and December 31, 2012, respectively)	69,317,278	57,529,778

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Operations (Unaudited) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Income Statement [Abstract]	'	'	'	'
Sales	$1,505.50	$1,179.80	$4,178.30	$3,436.40
Cost of sales	-1,443.40	-1,021.40	-3,880.80	-3,064.90
Gross profit	62.1	158.4	297.5	371.5
Operating costs and expenses:	'	'	'	'
Selling	13.9	15	46.7	26.7
General and administrative	15.8	12.8	59.9	41.3
Transportation	34.9	28.4	104.1	80.9
Taxes other than income taxes	3.7	1.8	9.7	5.4
Other	12.8	1.6	14.4	4.9
Operating income (loss)	-19	98.8	62.7	212.3
Other income (expense):	'	'	'	'
Interest expense	-24.2	-24.2	-73.7	-61.2
Realized gain (loss) on derivative instruments	4.2	-10.1	5.4	20.5
Unrealized gain (loss) on derivative instruments	2.4	-22.1	22.9	-11.3
Other	1.9	0.2	2.2	0.3
Total other expense	-15.7	-56.2	-43.2	-51.7
Net income (loss) before income taxes	-34.7	42.6	19.5	160.6
Income tax expense	-0.1	-0.2	-0.5	-0.6
Net income (loss)	-34.8	42.4	19	160
Allocation of net income (loss):	'	'	'	'
Net income (loss)	-34.8	42.4	19	160
Less:	'	'	'	'
General partner’s interest in net income (loss)	-0.7	0.8	0.4	3.2
General partner’s incentive distribution rights	3.8	1.7	10.9	3.3
Non-vested share based payments	0	0.2	0.2	0.9
Net income (loss) available to limited partners	($37.90)	$39.70	$7.50	$152.60
Weighted average limited partner units outstanding:	'	'	'	'
Basic	69,626,650	57,745,806	67,367,326	54,826,636
Diluted	69,626,650	57,825,603	67,553,709	54,866,915
Limited partners’ interest basic and diluted net income (loss) per unit	($0.54)	$0.69	$0.11	$2.78
Cash distributions declared per limited partner unit	$0.69	$0.59	$2.02	$1.68

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Comprehensive Income (Loss) (Unaudited) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Statement of Comprehensive Income [Abstract]	'	'	'	'
Net income (loss)	($34.80)	$42.40	$19	$160
Cash flow hedges:	'	'	'	'
Cash flow hedge (gain) loss reclassified to net income (loss)	-5.6	41.8	4.4	137.8
Change in fair value of cash flow hedges	14.1	-83.4	41.3	-236.3
Defined benefit pension and retiree health benefit plans	0.1	1	1	1.3
Total other comprehensive income (loss)	8.6	-40.6	46.7	-97.2
Comprehensive income (loss) attributable to partners’ capital	($26.20)	$1.80	$65.70	$62.80

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements of Partners' Capital (Unaudited) (USD $)	Total	Accumulated Other Comprehensive Income (Loss)	General Partner	Limited Partners
In Millions
Beginning Balance at Dec. 31, 2012	$889.80	($25.50)	$30.50	$884.80
Other comprehensive income	46.7	46.7	0	0
Net income (loss)	19	0	11.3	7.7
Common units repurchased for phantom unit grants	-5	0	0	-5
Amortization of vested phantom units	2.4	0	0	2.4
Issuances of phantom units, net of repurchases for taxes	-0.3	0	0	-0.3
Proceeds from public offerings of common units, net	392.5	0	0	392.5
Contributions from Calumet GP, LLC	8.4	0	8.4	0
Distributions to partners	-148.7	0	-12.5	-136.2
Ending Balance at Sep. 30, 2013	$1,204.80	$21.20	$37.70	$1,145.90

Condensed_Consolidated_Stateme3

Condensed Consolidated Statements of Cash Flows (Unaudited) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Operating activities	'	'
Net income (loss)	$19	$160
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation and amortization	88.2	63.9
Amortization of turnaround costs	10.9	10.3
Non-cash interest expense	5.2	4.4
Provision for doubtful accounts	0.6	0.3
Unrealized (gain) loss on derivative instruments	-22.9	11.3
Non-cash equity based compensation	3.4	5.1
Other non-cash activities	14.5	1.1
Changes in assets and liabilities:	'	'
Accounts receivable	-75.8	-32.4
Inventories	10.9	33.7
Prepaid expenses and other current assets	-0.3	-1.6
Derivative activity	3	0.9
Turnaround costs	-62.9	-14.1
Deposits	5.2	-1.8
Other assets	0.1	0
Accounts payable	121.7	26.8
Accrued interest payable	5.3	20.3
Accrued salaries, wages and benefits	-5.8	2.3
Accrued income taxes payable	-27.6	0.1
Other taxes payable	8.4	3.3
Other liabilities	11.6	2.9
Pension and postretirement benefit obligations	-2.4	-7.4
Net cash provided by operating activities	110.3	289.4
Investing activities	'	'
Additions to property, plant and equipment	-114.1	-36.7
Cash paid for acquisitions, net of cash acquired	-124.1	-379
Investment in unconsolidated affiliate	-17.8	0
Proceeds from sale of property, plant and equipment	0	1.9
Net cash used in investing activities	-256	-413.8
Financing activities	'	'
Proceeds from borrowings — revolving credit facility	731.9	1,147.80
Repayments of borrowings — revolving credit facility	-731.9	-1,147.80
Payments on capital lease obligations	-0.9	-1.2
Proceeds from other financing obligations	3.5	0
Proceeds from senior notes offering	0	270.2
Debt issuance costs	0	-7.5
Proceeds from public offerings of common units, net	392.5	146.6
Contributions from Calumet GP, LLC	8.4	3.1
Common units repurchased and taxes paid for phantom unit grants	-7.1	-2.1
Distributions to partners	-149	-94.2
Net cash provided by financing activities	247.4	314.9
Net increase in cash and cash equivalents	101.7	190.5
Cash and cash equivalents at beginning of period	32.2	0
Cash and cash equivalents at end of period	133.9	190.5
Supplemental disclosure of noncash financing and investing activities	'	'
Equipment acquired under capital lease	$0	$5.80

Description_of_the_Business

Description of the Business	9 Months Ended
	Sep. 30, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Description of the Business	'
	Calumet Specialty Products Partners, L.P. (the “Company”) is a Delaware limited partnership. The general partner of the Company is Calumet GP, LLC, a Delaware limited liability company. As of September 30, 2013, the Company had 69,317,278 limited partner common units and 1,414,638 general partner equivalent units outstanding. The general partner owns 2% of the Company and all of the incentive distribution rights (as defined in the Company’s partnership agreement), while the remaining 98% is owned by limited partners. The general partner employs all of the Company’s employees and the Company reimburses the general partner for certain expenses. The Company is engaged in the production and marketing of crude oil-based specialty products including lubricating oils, white mineral oils, solvents, petrolatums, waxes, asphalt and fuel and fuel related products including gasoline, diesel, jet fuel and heavy fuel oils. The Company is also engaged in the resale of purchased crude oil to third party customers. The Company owns facilities located in Shreveport, Louisiana (“Shreveport” and “Calumet Packaging” (formerly “TruSouth”)); Superior, Wisconsin (“Superior”); San Antonio, Texas (“San Antonio”); Great Falls, Montana (“Montana”); Princeton, Louisiana (“Princeton”); Cotton Valley, Louisiana (“Cotton Valley”); Karns City, Pennsylvania (“Karns City”); Dickinson, Texas (“Dickinson”); Louisiana, Missouri (“Missouri”) and Porter, Texas (“Royal Purple”) and terminals located in Burnham, Illinois (“Burnham”); Rhinelander, Wisconsin (“Rhinelander”); Crookston, Minnesota (“Crookston”) and Proctor, Minnesota (“Duluth”).
	The unaudited condensed consolidated financial statements of the Company as of September 30, 2013 and for the three and nine months ended September 30, 2013 and 2012 included herein have been prepared, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”). Certain information and disclosures normally included in the consolidated financial statements prepared in accordance with generally accepted accounting principles (“GAAP”) in the United States of America (the “U.S.”) have been condensed or omitted pursuant to such rules and regulations, although the Company believes that the following disclosures are adequate to make the information presented not misleading. These unaudited condensed consolidated financial statements reflect all adjustments that, in the opinion of management, are necessary to present fairly the results of operations for the interim periods presented. All adjustments are of a normal nature, unless otherwise disclosed. The results of operations for the three and nine months ended September 30, 2013 are not necessarily indicative of the results that may be expected for the year ending December 31, 2013. These unaudited condensed consolidated financial statements should be read in conjunction with the Company’s 2012 Annual Report.

New_and_Recently_Adopted_Accou

New and Recently Adopted Accounting Pronouncements	9 Months Ended
	Sep. 30, 2013
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]	'
New Accounting Pronouncements, Policy	'
	In December 2011, the Financial Accounting Standards Board (“FASB”) issued ASU No. 2011-11, Balance Sheet (Topic 210) — Disclosures about Offsetting Assets and Liabilities (“ASU 2011-11”). ASU 2011-11 requires entities to disclose information about offsetting and related arrangements to enable financial statement users to understand the effect of such arrangements on the balance sheet. Entities are required to disclose both gross information and net information about financial instruments and derivative instruments that are either offset in the balance sheet or subject to an enforceable master netting arrangement or similar agreement, irrespective of whether they are offset. In January 2013, the FASB issued ASU No. 2013-01, Balance Sheet Topic (210) — Clarifying the Scope of Disclosures About Offsetting Assets and Liabilities (“ASU 2013-01”), which clarifies the scope of the offsetting disclosures and addresses any unintended consequences. Amendments to ASU 2011-11, as superseded by ASU 2013-01, are effective for the first reporting period (including interim periods) beginning on or after January 1, 2013 and should be applied retrospectively for any period presented. The adoption of ASU 2013-01 and ASU 2011-11 concerns presentation and disclosure only.
	In October 2012, the FASB issued ASU No. 2012-04, Technical Corrections and Improvements (“ASU 2012-04”). ASU 2012-04 covers a wide range of topics in the Accounting Standards Codification. These amendments include technical corrections and improvements to the Accounting Standards Codification and conforming amendments related to fair value measurements. ASU 2012-04 is effective for fiscal periods beginning after December 15, 2012. The adoption of ASU 2012-04 did not have an impact on the Company’s consolidated financial statements.
	In February 2013, the FASB issued ASU No. 2013-02, Comprehensive Income (Topic 220) — Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income (“ASU 2013-02”). ASU 2013-02 requires entities to report either on the statement of operations or disclose in the footnotes to the consolidated financial statements the effects on earnings from items that are reclassified out of comprehensive income. For amounts that are not required to be reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures that provide additional details about those amounts. ASU 2013-02 is effective prospectively for the first reporting period after December 15, 2012 with early adoption permitted. The adoption of ASU 2013-02 concerns presentation and disclosure only.
	In February 2013, the FASB issued ASU No. 2013-04, Liabilities (Topic 405) — Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation Is Fixed at the Reporting Date (“ASU 2013-04”). ASU 2013-04 provides guidance for the recognition, measurement and disclosure of obligations resulting from joint and several liability arrangements from which the total amount of the obligation within the scope of this guidance is fixed at the reporting date. ASU 2013-04 is effective for fiscal periods, (including interim periods), beginning after December 15, 2013 and should be applied retrospectively. The Company is currently evaluating the impacts of the adoption of ASU 2013-04 on its consolidated financial statements.

Acquisitions

Acquisitions	9 Months Ended
	Sep. 30, 2013
Business Combinations [Abstract]	'
Acquisitions	'
	Missouri Acquisition
	On January 3, 2012, the Company completed the acquisition of the aviation and refrigerant lubricants business (a polyolester based synthetic lubricants business) of Hercules Incorporated, a subsidiary of Ashland, Inc., including a manufacturing facility located in Louisiana, Missouri for aggregate consideration of approximately $19.6 million (“Missouri Acquisition”). The Missouri Acquisition was financed with borrowings under the Company’s revolving credit facility and cash on hand. The Company believes the Missouri Acquisition provides greater diversity to its specialty products segment. The assets acquired and results of operations have been included in the Company’s condensed consolidated balance sheets and the Company’s unaudited condensed consolidated statements of operations since the date of acquisition. In connection with the Missouri Acquisition, the Company incurred no acquisition costs during the three months ended September 30, 2012 and $0.5 million during the nine months ended September 30, 2012, which are reflected in general and administrative expenses in the unaudited condensed consolidated statements of operations.
	The Company recorded $1.5 million of goodwill as a result of the Missouri Acquisition, all of which was recorded within the Company’s specialty products segment. Goodwill recognized in the acquisition relates primarily to enhancing the Company’s strategic platform for expansion in its specialty products segment. The allocation of the aggregate purchase price to assets acquired is as follows (in millions):
		Allocation of Purchase Price
	Inventories	$	2.7
	Property, plant and equipment	10
	Goodwill	1.5
	Other intangible assets	5.4
	Total purchase price	$	19.6
	The component of the intangible assets listed in the table above as of January 3, 2012, based upon a third party appraisal, was as follows (in millions):
		Amount			Life (Years)
	Customer relationships	$	5.4		20
	Calumet Packaging Acquisition
	On January 6, 2012, the Company completed the acquisition of all of the outstanding membership interests of TruSouth Oil, LLC (“TruSouth”), a specialty petroleum packaging and distribution company located in Shreveport, Louisiana for aggregate consideration of approximately $26.9 million, net of cash acquired (“Calumet Packaging Acquisition”). The Calumet Packaging Acquisition was financed with borrowings under the Company’s revolving credit facility. Immediately prior to its acquisition by the Company, TruSouth was owned in part by affiliates of the Company’s general partner. The Company believes the Calumet Packaging Acquisition provides greater diversity to its specialty products segment. The assets acquired and liabilities assumed have been included in the Company’s condensed consolidated balance sheets and results of operations have been included in the Company’s unaudited condensed consolidated statements of operations since the date of acquisition. In connection with the Calumet Packaging Acquisition, the Company incurred no acquisition costs during the three months ended September 30, 2012 and approximately $0.2 million during the nine months ended September 30, 2012, which are reflected in general and administrative expenses in the unaudited condensed consolidated statements of operations.
	The Company recorded $0.4 million of goodwill as a result of the Calumet Packaging Acquisition, all of which was recorded within the Company’s specialty products segment. Goodwill recognized in the acquisition relates primarily to enhancing the Company’s strategic platform for expansion in its specialty products segment. The allocation of the aggregate purchase price to assets acquired and liabilities assumed is as follows (in millions):
		Allocation of Purchase Price
	Accounts receivable	$	5.2
	Inventories	8
	Prepaid expenses and other current assets	0.3
	Property, plant and equipment	17.7
	Goodwill	0.4
	Other intangible assets	2.6
	Accounts payable	(2.7		)
	Accrued salaries, wages and benefits	(0.2		)
	Other current liabilities	(0.9		)
	Long-term debt	(3.5		)
	Total purchase price, net of cash acquired	$	26.9
	The components of intangible assets listed in the table above as of January 6, 2012, based upon a third party appraisal, were as follows (in millions):
		Amount			Life (Years)
	Customer relationships	$	1.8		16
	Tradenames	0.7			9
	Non-competition agreements	0.1			2
	Total	$	2.6
	Weighted average amortization period				14
	Royal Purple Acquisition
	On July 3, 2012, the Company completed the acquisition of Royal Purple, Inc. (“Royal Purple”), a Texas corporation which was converted into a Delaware limited liability company at closing, for aggregate consideration of approximately $331.2 million, net of cash acquired (“Royal Purple Acquisition”). Royal Purple is a leading independent formulator and marketer of premium industrial and consumer lubricants to a diverse customer base across several large markets including oil and gas, chemicals and refining, power generation, manufacturing and transportation, food and drug manufacturing and automotive aftermarket. The Royal Purple Acquisition was financed with net proceeds of $262.6 million from the Company’s June 2012 private placement of 9 5/8% senior notes due August 1, 2020 and cash on hand. The Company believes the Royal Purple Acquisition increases its position in the specialty lubricants market, expands its geographic reach, increases its asset diversity and enhances its specialty products segment. The assets acquired and liabilities assumed have been included in the Company’s condensed consolidated balance sheets and results of operations have been included in the Company’s unaudited condensed consolidated statements of operations since the date of acquisition. In connection with the Royal Purple Acquisition, during the three and nine months ended September 30, 2012, the Company incurred approximately $0.3 million and $0.4 million, respectively, of acquisition costs, which are reflected in general and administrative expenses in the unaudited condensed consolidated statements of operations.
	The Company recorded $109.2 million of goodwill as a result of the Royal Purple Acquisition, all of which was recorded within the Company’s specialty products segment. Goodwill recognized in the acquisition relates primarily to enhancing the Company’s strategic platform for expansion in its specialty products segment.
	The allocation of the aggregate purchase price to assets acquired and liabilities assumed is as follows (in millions):
		Allocation of Purchase Price
	Accounts receivable	$	15.2
	Inventories	19.3
	Prepaid expenses and other current assets	0.2
	Property, plant and equipment	10.6
	Goodwill	109.2
	Other intangible assets	183.4
	Accounts payable	(3.8		)
	Accrued salaries, wages and benefits	(1.7		)
	Taxes payable	(0.2		)
	Other current liabilities	(1.0		)
	Total purchase price, net of cash acquired	$	331.2
	The components of intangible assets listed in the table above as of July 3, 2012, based upon a third party appraisal, were as follows (in millions):
		Amount			Life (Years)
	Customer relationships	$	118.7		20
	Tradenames	14.8			Indefinite
	Tradenames	5.7			10
	Trade secrets	44.2			12
	Total	$	183.4
	Weighted average amortization period				18
	Montana Acquisition
	On October 1, 2012, the Company completed the acquisition from Connacher Oil and Gas Limited (“Connacher”) of all the shares of common stock of Montana Refining Company, Inc. (“Montana”) and an insignificant affiliated company for aggregate consideration of approximately $191.6 million, net of cash acquired (“Montana Acquisition”). Montana produces gasoline, diesel, jet fuel and asphalt, which are marketed primarily into local markets in Washington, Montana, Idaho and Alberta, Canada. The Montana Acquisition was funded primarily with cash on hand with the balance through borrowings under the Company’s revolving credit facility. The Company believes the Montana Acquisition further diversifies its crude oil feedstock slate, operating asset base and geographic presence. The assets acquired and liabilities assumed and results of operations have been included in the Company’s condensed consolidated balance sheets and unaudited condensed consolidated statements of operations since the date of acquisition. In connection with the Montana Acquisition, the Company incurred no acquisition costs during the three months ended September 30, 2013 and approximately $0.1 million during the nine months ended September 30, 2013, which are reflected in general and administrative expenses in the unaudited condensed consolidated statements of operations.
	Immediately after closing the Montana Acquisition, the Company converted Montana Refining Company, Inc. into a Delaware limited liability company, Calumet Montana Refining, LLC. This conversion resulted in the recognition of a current income tax liability of approximately $27.6 million, which was paid during the nine months ended September 30, 2013, and was offset by the derecognition of a deferred tax liability for a comparable amount assumed in connection with the acquisition.
	The Company recorded $27.6 million of goodwill as a result of the Montana Acquisition, all of which was recorded within the Company’s fuel products segment. Goodwill recognized in the acquisition relates primarily to enhancing the Company’s strategic platform for expansion in its fuel products segment.
	The allocation of the aggregate purchase price to assets acquired and liabilities assumed is as follows (in millions):
	Allocation of Purchase Price
Accounts receivable	$	29
Inventories	43.7
Prepaid expenses and other current assets	23.1
Deposits	0.3
Property, plant and equipment	125.9
Goodwill	27.6
Other noncurrent assets, net	0.3
Accounts payable	(8.4		)
Accrued salaries, wages and benefits	(1.4		)
Deferred income tax liability	(27.6		)
Accrued income taxes payable	(15.6		)
Other taxes payable	(3.0		)
Other current liabilities	(0.1		)
Pension and postretirement benefit obligations	(2.2		)
Total purchase price, net of cash acquired	$	191.6
San Antonio Acquisition
On January 2, 2013, the Company completed the acquisition of NuStar Energy L.P.’s (“NuStar”) San Antonio, Texas refinery, together with related assets and the assumption of certain liabilities and obligations (“San Antonio Acquisition”). Total consideration for the San Antonio Acquisition was approximately $117.9 million, net of cash acquired and excluding certain purchase price adjustments. The refinery has total crude oil throughput capacity of 14,500 bpd and primarily produces jet fuel, diesel, other fuel products and specialty solvents. The San Antonio Acquisition was funded with borrowings under the Company’s revolving credit facility with the balance through cash on hand. The Company believes the San Antonio Acquisition further diversifies the Company’s crude oil feedstock slate, operating asset base and geographic presence. The assets acquired and results of operations have been included in the Company’s condensed consolidated balance sheets and unaudited condensed consolidated statements of operations since the date of acquisition. In connection with the San Antonio Acquisition, the Company incurred no acquisition costs during the three months ended September 30, 2013 and approximately $0.5 million during the nine months ended September 30, 2013, which are reflected in general and administrative expenses in the unaudited condensed consolidated statements of operations.
The Company recorded $5.7 million of goodwill as a result of the San Antonio Acquisition, all of which was recorded within the Company’s fuel products segment. Goodwill recognized in the acquisition relates primarily to enhancing the Company’s strategic platform for expansion in its fuel products segment.
The San Antonio Acquisition purchase price allocation has not yet been finalized due to the timing of the closing of the acquisition. The final determination of fair value for certain assets and liabilities will be completed as soon as the information necessary to complete the analysis is obtained. The preliminary allocation of the aggregate purchase price to assets acquired and liabilities assumed is as follows (in millions):
	Allocation of Purchase Price
Inventories	$	17
Property, plant and equipment, net	100.7
Goodwill	5.7
Accrued salaries, wages and benefits	(0.1		)
Other current liabilities	(5.4		)
Total purchase price, net of cash acquired	$	117.9
Crude Oil Logistics Acquisition
On August 9, 2013, the Company completed the acquisition of seven crude oil loading facilities and related assets in North Dakota and Montana from Murphy Oil USA, Inc. (“Murphy”) for aggregate consideration of approximately $6.2 million (“Crude Oil Logistics Acquisition”). The Crude Oil Logistics Acquisition was funded with cash on hand. As part of this acquisition, the Company assumed pipeline space on the Enbridge Pipeline System (“Enbridge Pipeline”) previously held by Murphy. The Company will have the ability to transport crude oil directly from the point of lease, into the Company’s newly acquired crude oil loading facilities and then onto the Enbridge Pipeline where it can be routed to the Company’s refineries and/or third party customers. As part of this transaction, the Company and Murphy jointly consented to terminate an existing crude oil purchase agreement (“Murphy Crude Oil Supply Agreement”) wherein Murphy supplied the Company’s Superior refinery with up to 10,000 barrels per day of crude oil. In connection with the Crude Oil Logistics Acquisition, during the three and nine months ended September 30, 2013, the Company incurred acquisition costs of approximately $0.2 million, which are reflected in general and administrative expenses in the unaudited condensed consolidated statements of operations.
The preliminary allocation of the aggregate purchase price to assets acquired was primarily comprised of $0.9 million of property, plant and equipment, net and $5.2 million of goodwill, all of which was recorded within the Company’s fuel products segment. Goodwill recognized in the acquisition relates primarily to enhancing the Company’s crude oil gathering operations to support the Superior refinery.
Results of Sales and Earnings
The following financial information reflects sales and operating income of the Royal Purple, Montana and San Antonio Acquisitions that are included in the unaudited condensed consolidated statements of operations for the three and nine months ended September 30, 2013 (in millions):
	Three Months Ended September 30, 2013			Nine Months Ended September 30, 2013
Sales	$	276.6		$	810.5
Operating income	$	2.7		$	28.2
Pro Forma Financial Information (Unaudited)
The following unaudited pro forma financial information reflects the unaudited condensed consolidated results of operations of the Company as if the Royal Purple, Montana and San Antonio Acquisitions had taken place on January 1, 2012 (in millions, except for per unit data):
	Three Months Ended September 30, 2012			Nine Months Ended September 30, 2012
Sales	$	1,463.60		$	4,255.40
Net income	$	54.1		$	168.5
Limited partners’ interest net income per unit — basic	$	0.73		$	2.31
Limited partners’ interest net income per unit — diluted	$	0.74		$	2.31
The Company’s historical financial information was adjusted to give effect to the pro forma events that were directly attributable to the Royal Purple, Montana and San Antonio Acquisitions. This unaudited pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of results of operations that would have been achieved had the pro forma events taken place on the dates indicated, or the future consolidated results of operations of the combined company.
Fair Value Measurements of Acquisitions
The fair value of the property, plant and equipment and intangible assets are based upon the discounted cash flow method that involves inputs that are not observable in the market (Level 3). Goodwill assigned represents the amount of consideration transferred in excess of the fair value assigned to individual assets acquired and liabilities assumed.

Inventories

Inventories	9 Months Ended
	Sep. 30, 2013
Inventory Disclosure [Abstract]	'
Inventories	'
	The cost of inventory is recorded using the last-in, first-out (LIFO) method. An actual valuation of inventory under the LIFO method can be made only at the end of each year based on the inventory levels and costs at that time. Accordingly, interim LIFO calculations are based on management’s estimates of expected year-end inventory levels and costs and are subject to the final year-end LIFO inventory valuation. Costs include crude oil and other feedstocks, labor, processing costs and refining overhead costs. Inventories are valued at the lower of cost or market value. The replacement cost of these inventories, based on current market values, would have been $91.5 million and $38.3 million higher as of September 30, 2013 and December 31, 2012, respectively.
	Inventories consist of the following (in millions):
		September 30, 2013		December 31, 2012
	Raw materials	$	124.5	$	85.4
	Work in process	122.3		119.5
	Finished goods	312.9		348.7
		$	559.7	$	553.6
	Under the LIFO method, the most recently incurred costs are charged to cost of sales and inventories are valued at the earliest acquisition costs.

Joint_Venture

Joint Venture	9 Months Ended
	Sep. 30, 2013
Equity Method Investments and Joint Ventures [Abstract]	'
Joint Venture	'
	On February 7, 2013, the Company entered into a joint venture agreement with MDU Resources Group, Inc. (“MDU”) to develop, build and operate a diesel refinery in southwestern North Dakota. The joint venture is named Dakota Prairie Refining, LLC. The refinery’s total construction cost is estimated at approximately $300.0 million. The capitalization of the joint venture is expected to be funded through contributions of $150.0 million from MDU and $75.0 million from the Company and proceeds of $75.0 million from an unsecured syndicated term loan facility with the joint venture as the borrower. The term loan facility was funded in April 2013. Funding for the project will occur over the course of the construction period, with the majority of the direct funding by the Company expected to occur in 2014. The diesel refinery is expected to be operational in the fourth quarter of 2014. The joint venture will allocate profits on a 50%/50% basis to the Company and MDU. The joint venture will be governed by a board of managers comprised of representatives from both the Company and MDU. MDU will provide a portion of the crude oil supply to the refinery, as well as natural gas and electricity utility services. The Company will provide refinery operations, crude oil procurement and refined product marketing expertise to the joint venture.
	The Company accounts for its ownership in its joint venture under the equity method of accounting. As of September 30, 2013, the Company has an investment of $19.5 million in Dakota Prairie Refining, LLC primarily related to the development of the refinery.

Other_Noncurrent_Assets

Other Noncurrent Assets	9 Months Ended
	Sep. 30, 2013
Other Assets, Noncurrent [Abstract]	'
Schedule of Other Assets, Noncurrent [Table Text Block]	'
	Other noncurrent assets primarily include deferred debt issuance costs and turnaround costs. Turnaround costs represent capitalized costs associated with the Company’s periodic major maintenance and repairs and were $66.3 million and $14.3 million as of September 30, 2013 and December 31, 2012, respectively. The Company capitalizes these costs and amortizes the costs on a straight-line basis over the lives of the turnaround assets. These amounts are net of accumulated amortization of $22.0 million and $17.8 million at September 30, 2013 and December 31, 2012, respectively.

Commitments_and_Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	From time to time, the Company is a party to certain claims and litigation incidental to its business, including claims made by various taxation and regulatory authorities, such as the EPA, various state environmental regulatory bodies, the Internal Revenue Service, various state and local departments of revenue and the federal Occupational Safety and Health Administration (“OSHA”), as the result of audits or reviews of the Company’s business. In addition, the Company has property, business interruption, general liability and various other insurance policies that may result in certain losses or expenditures being reimbursed to the Company.
	Environmental
	The Company operates crude oil and specialty hydrocarbon refining and terminal operations, which are subject to stringent and complex federal, state, regional and local laws and regulations governing worker health and safety, the discharge of materials into the environment and environmental protection. These laws and regulations impose obligations that are applicable to the Company’s operations, such as requiring the acquisition of permits to conduct regulated activities, restricting the manner in which the Company may release materials into the environment, requiring remedial activities or capital expenditures to mitigate pollution from former or current operations, requiring the application of specific health and safety criteria addressing worker protection and imposing substantial liabilities for pollution resulting from its operations. Certain of these laws impose joint and several, strict liability for costs required to remediate and restore sites where petroleum hydrocarbons, wastes, or other materials have been released or disposed.
	In addition, new laws and regulations, new interpretations of existing laws and regulations, increased governmental enforcement or other developments could require the Company to make additional unforeseen expenditures. Many of these laws and regulations are becoming increasingly stringent, and the cost of compliance with these requirements can be expected to increase over time. For example, on September 12, 2012, the EPA published final amendments to the New Source Performance Standards (“NSPS”) for petroleum refineries, including standards for emissions of nitrogen oxides from process heaters and work practice standards and monitoring requirements for flares. The Company is currently evaluating the effect that the NSPS rule may have on its refinery operations.
	Voluntary remediation of subsurface contamination is in process at certain of the Company’s refinery sites. The remedial projects are being overseen by the appropriate state agencies. Based on current investigative and remedial activities, the Company believes that the groundwater contamination at these refineries can be controlled or remedied without having a material adverse effect on the Company’s financial condition. However, such costs are often unpredictable and, therefore, there can be no assurance that the future costs will not become material.
	San Antonio Refinery
	In connection with the San Antonio Acquisition, the Company agreed to indemnify NuStar from any environmental liabilities associated with the San Antonio refinery, except for any governmental penalties or fines that may result from NuStar’s actions or inactions during NuStar’s 20 month period of ownership of the San Antonio refinery. Anadarko Petroleum Corporation (“Anadarko”) and Age Refining, Inc. (“Age Refining”), a third party that has since entered bankruptcy, are subject to a 1995 Agreed Order from the Texas Natural Resource Conservation Commission, now known as the Texas Commission on Environmental Quality (“TCEQ”), pursuant to which Anadarko and Age Refining are obligated to assess and remediate contamination at the San Antonio refinery. The Company is not a party to this Agreed Order. The Company is in discussions with both TCEQ and Anadarko over how best to address pre-existing contamination at the San Antonio refinery.
	Montana Refinery
	In connection with the Montana Acquisition (see Note 3), the Company became a party to an existing 2002 Refinery Initiative consent decree (“Montana Consent Decree”) with the EPA and the Montana Department of Environmental Quality(“MDEQ”). The material obligations imposed by the Montana Consent Decree have been completed. Periodic reporting is the primary current obligation under the Montana Consent Decree. On September 27, 2012, Montana Refining Company, Inc. received a final Corrective Action Order on Consent, replacing the refinery’s previous hazardous waste permit. This Corrective Action Order on Consent governs the investigation and remediation of contamination at the Montana refinery. The Company believes the majority of damages related to such contamination at the Montana refinery are covered by a contractual indemnity provided by Holly Corporation (“Holly”), the owner and operator of the Montana refinery prior to its acquisition by Connacher, under an asset purchase agreement between Holly and Connacher, pursuant to which Connacher acquired the Montana refinery. Under this asset purchase agreement, Holly agreed to indemnify Connacher and Montana Refining Company, Inc. for environmental conditions arising under Holly’s ownership and operation of the Montana refinery, and existing as of the date of sale to Connacher. As a result of the Montana Acquisition, the Company’s liability is limited under the asset purchase agreement between Holly and Connacher and the costs to be covered by the Company are not believed to be material at this time. Some of these costs covered by the Company will be voluntary to prepare the expansion area in conjunction with the Company’s planned capacity expansion at the Montana refinery. Prior to the Montana Acquisition, Holly had reimbursed Connacher in accordance with the contractual indemnity for remedial actions related to such contamination at the Montana refinery.
	Superior Refinery
	In connection with the Superior Acquisition, the Company became a party to an existing consent decree (“Superior Consent Decree”) with the EPA and the Wisconsin Department of Natural Resources (“WDNR”) that applies, in part, to its Superior refinery. Under the Superior Consent Decree, the Company will have to complete certain reductions in air emissions at the Superior refinery as well as report upon certain emissions from the facility to the EPA and the WDNR. The Company currently estimates costs of approximately $0.9 million to make known equipment upgrades and conduct other discrete tasks in compliance with the Superior Consent Decree. Failure to perform required tasks under the Superior Consent Decree could result in the imposition of stipulated penalties, which could be significant. In addition, the Company may have to pursue certain additional environmental and safety-related projects at the Superior refinery including, but not limited to: (i) installing process equipment pursuant to applicable EPA fuel content regulations; (ii) purchasing emission credits on an interim basis until such time as any process equipment that may be required under the EPA fuel content regulations is installed and operational; (iii) performing monitoring of historical contamination at the facility; (iv) upgrading treatment equipment or possibly pursuing other remedies, as necessary, to satisfy new effluent discharge limits under a federal Clean Water Act permit renewal that is pending and (v) pursuing various voluntary programs at the Superior refinery, including removing asbestos-containing materials or enhancing process safety or other maintenance practices. Completion of these additional projects will result in the Company incurring additional costs, which could be substantial. For the three months ended September 30, 2013 and 2012, the Company incurred approximately $0.5 million and $0.6 million, respectively, of costs related to installing process equipment pursuant to the EPA fuel content regulations. For the nine months ended September 30, 2013 and 2012, the Company incurred approximately $0.7 million and $2.1 million, respectively, of costs related to installing process equipment pursuant to the EPA fuel content regulations.
	On June 29, 2012, the EPA issued a Finding of Violation/Notice of Violation to the Superior refinery, which included a proposed penalty amount of $0.1 million. This finding is in response to information provided to the EPA by the Company in response to an information request. The EPA alleges that the efficiency of the flares at the Superior refinery is lower than regulatory requirements. The Company is contesting the allegations and attended an informal conference with the EPA held September 12, 2012. The Company does not believe that the resolution of these allegations will have a material adverse effect on the Company’s financial results or operations.
	The Company is contractually indemnified by Murphy Oil Corporation (“Murphy Oil”) under an asset purchase agreement between the Company and Murphy Oil for specified environmental liabilities arising from the operations of the Superior refinery including: (i) certain obligations arising out of the Superior Consent Decree (including payment of a civil penalty required under the Superior Consent Decree), (ii) certain liabilities arising in connection with Murphy Oil’s transport of certain wastes and other materials to specified offsite real properties for disposal or recycling prior to the Superior Acquisition and (iii) certain liabilities for certain third party actions, suits or proceedings alleging exposure, prior to the Superior Acquisition, of an individual to wastes or other materials at the specified on-site real property, which wastes or other materials were spilled, released, emitted or discharged by Murphy Oil. The Company believes contractual indemnity by Murphy Oil for such specified environmental liabilities is unlimited in duration and not subject to any monetary deductibles or maximums. The Company was also contractually indemnified by Murphy Oil under the asset purchase agreement until October 1, 2013 for liabilities arising from breaches of certain environmental representations and warranties made by Murphy Oil, subject to a maximum liability of $22.0 million, for which the Company was required to contribute up to the first $6.6 million. The amount of any damages payable by Murphy Oil pursuant to the contractual indemnities under the asset purchase agreement were net of any amount recoverable under an environmental insurance policy that the Company obtained in connection with the Superior Acquisition, which named the Company and Murphy Oil as insureds and covers environmental conditions existing at the Superior refinery prior to the Superior Acquisition.
	Shreveport, Cotton Valley and Princeton Refineries
	On December 23, 2010, the Company entered into a settlement agreement with the Louisiana Department of Environmental Quality (“LDEQ”) under LDEQ’s “Small Refinery and Single Site Refinery Initiative,” covering the Shreveport, Princeton and Cotton Valley refineries. This settlement agreement became effective on January 31, 2012. The settlement agreement, termed the “Global Settlement,” resolved alleged violations of the federal Clean Air Act and federal Clean Water Act regulations prior to December 31, 2010. Among other things, the Company agreed to complete beneficial environmental programs and implement emissions reduction projects at the Company’s Shreveport, Cotton Valley and Princeton refineries on an agreed-upon schedule. During the three months ended September 30, 2013 and 2012, the Company incurred approximately $0.3 million and $0.1 million, respectively, of such expenditures. During the nine months ended September 30, 2013 and 2012, the Company incurred approximately $4.8 million and $2.2 million, respectively, of such expenditures and estimates additional expenditures of approximately $6.0 million to $8.0 million of capital expenditures and expenditures related to additional personnel and environmental studies over the next three years as a result of the implementation of these requirements. These capital investment requirements are incorporated into the Company’s annual capital expenditures budgets and the Company does not expect any additional capital expenditures as a result of the required audits or required operational changes included in the Global Settlement to have a material adverse effect on the Company’s financial results or operations.
	In August 2011, the EPA conducted an inspection of the Shreveport refinery’s Risk Management Program compliance. An inspection report dated October 20, 2011 was transmitted to the Shreveport refinery. The Company submitted supplemental information to the EPA, which was followed by a site visit from EPA personnel. On September 12, 2013, the EPA issued a revised draft Consent Agreement and Final Order to the Shreveport refinery, which included a proposed civil penalty of $0.3 million.
	The Company is contractually indemnified by Shell Oil Company (“Shell”), as successor to Pennzoil-Quaker State Company and Atlas Processing Company under an asset purchase agreement between the Company and Shell, for specified environmental liabilities arising from the operations of the Shreveport refinery prior to the Company’s acquisition of the facility. The contractual indemnity is believed by the Company to be unlimited in amount and duration, but requires the Company to contribute up to $1.0 million of the first $5.0 million of indemnified costs for certain of the specified environmental liabilities.
	Current and former owners of a property in Bossier Parish, Louisiana, filed a lawsuit in March 2006 against the Company and other defendants, including Chevron USA, Inc. (“Chevron”), Legacy Resources Co., L.P. (“Legacy”) and Exxon Mobil Corporation (“Exxon Mobil”), alleging damage from salt water and other environmental contamination on the property arising from historical oil field production on the property. Oil field exploration and production on the property began in the 1920’s by predecessors of Exxon Mobil. The Company received an assignment of certain mineral leases for portions of the property in 1993 from an affiliate of Texaco, prior to Texaco’s merger with Chevron. The Company then assigned those mineral leases to Legacy. The mineral lease assignments include indemnity provisions obligating the assignees to provide certain indemnities to the assignors. The Company, Chevron, Legacy and the plaintiffs are participating in mediation in an attempt to settle the litigation.
	Occupational Health and Safety
	The Company is subject to various laws and regulations relating to occupational health and safety, including OSHA and comparable state laws. These laws and regulations strictly govern the protection of the health and safety of employees. In addition, OSHA’s hazard communication standard requires that information be maintained about hazardous materials used or produced in the Company’s operations and that this information be provided to employees, contractors, state and local government authorities and customers. The Company maintains safety and training programs as part of its ongoing efforts to ensure compliance with applicable laws and regulations. The Company conducts periodic audits of Process Safety Management (“PSM”) systems at each of its locations subject to the PSM standard as well as a quality system that meets the requirements of the ISO-9001-2008 Standard. The integrity of the Company’s ISO-9001-2008 Standard certification is maintained through surveillance audits by its registrar at regular intervals designed to ensure adherence to the standards. The Company’s compliance with applicable health and safety laws and regulations has required, and continues to require, substantial expenditures. Changes in occupational safety and health laws and regulations or a finding of non-compliance with current laws and regulations could result in additional capital expenditures or operating expenses, as well as civil penalties and, in the event of a serious injury or fatality, criminal charges.
	The Company has completed studies to assess the adequacy of its PSM practices at its Shreveport refinery with respect to certain consensus codes and standards. During the three months ended September 30, 2013 and 2012, the Company incurred approximately $0.8 million and $0.2 million, respectively, of related capital expenditures. During the nine months ended September 30, 2013 and 2012, the Company incurred approximately $2.8 million and $0.5 million, respectively, of related capital expenditures and expects to incur additional capital expenditures of approximately $1.0 million during the last quarter of 2013 to address OSHA compliance issues identified in these studies. The Company expects these capital expenditures will enhance its equipment such that the equipment maintains compliance with applicable consensus codes and standards.
	In the first quarter of 2011, OSHA conducted an inspection of the Cotton Valley refinery’s PSM program under OSHA’s National Emphasis Program. On March 14, 2011, OSHA issued a Citation and Notification of Penalty (the “Cotton Valley Citation”) to the Company as a result of the Cotton Valley inspection, which included a proposed penalty amount of $0.2 million. The Company has contested the Cotton Valley Citation and associated penalty and is currently in negotiations with OSHA to reach a settlement allowing an extended abatement period for a new refinery flare system study and for completion of facility site modifications, including relocation and hardening of structures.
	Labor Matters
	The Company has employees covered by various collective bargaining agreements. The Cotton Valley and Dickinson collective bargaining agreements were ratified on March 21, 2013 and April 1, 2013, respectively, and both will expire on March 31, 2016. The Shreveport collective bargaining agreement was ratified on April 30, 2013 and will expire on April 30, 2016.
	Standby Letters of Credit
	The Company has agreements with various financial institutions for standby letters of credit which have been issued to vendors. As of September 30, 2013 and December 31, 2012, the Company had outstanding standby letters of credit of $140.5 million and $222.4 million, respectively, under its senior secured revolving credit facility (the “revolving credit facility”). Refer to Note 8 for additional information regarding the Company’s revolving credit facility. The maximum amount of letters of credit the Company could issue at September 30, 2013 and December 31, 2012 under its revolving credit facility is subject to borrowing base limitations, with a maximum letter of credit sublimit equal to $680.0 million, which is the greater of (i) $400.0 million and (ii) 80% of revolver commitments in effect ($850.0 million at September 30, 2013 and December 31, 2012).
	As of September 30, 2013 and December 31, 2012, the Company had availability to issue letters of credit of $477.1 million and $355.1 million, respectively, under its revolving credit facility. As of December 31, 2012, the outstanding standby letters of credit issued under the revolving credit facility included a $25.0 million letter of credit issued to a hedging counterparty to support a portion of its fuel products hedging program.

LongTerm_Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
Long-Term Debt	'
	Long-term debt consisted of the following (in millions):
		September 30,			December 31,
		2013			2012
	Borrowings under amended and restated senior secured revolving credit agreement with third-party lenders, interest payments monthly, borrowings due June 2016	$	—		$	—
	Borrowings under 2019 Notes, interest at a fixed rate of 9.375%, interest payments semiannually, borrowings due May 2019, effective interest rate of 9.94% for the nine months ended September 30, 2013	600			600
	Borrowings under 2020 Notes, interest at a fixed rate of 9.625%, interest payments semiannually, borrowings due August 2020, effective interest rate of 10.02% for the nine months ended September 30, 2013	275			275
	Capital lease obligations, at various interest rates, interest and principal payments monthly through January 2027	4.9			5.5
	Less unamortized discounts	(15.6		)	(17.0		)
	Total long-term debt	864.3			863.5
	Less current portion of long-term debt	0.5			0.8
		$	863.8		$	862.7
	9 5/8% Senior Notes
	On June 29, 2012, in connection with the Royal Purple Acquisition, the Company issued and sold $275.0 million in aggregate principal amount of 9 5/8% of senior notes due August 1, 2020 (the “2020 Notes”) in a private placement pursuant to Section 4(a)(2) of the Securities Act of 1933, as amended (the “Securities Act”), to eligible purchasers at a discounted price of 98.25 percent of par. The 2020 Notes were resold to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to persons outside the United States pursuant to Regulation S under the Securities Act. The Company received net proceeds of $262.6 million, net of discount, underwriters’ fees and expenses, which the Company used to fund a portion of the purchase price of the Royal Purple Acquisition. Refer to Note 3 for additional information regarding the Royal Purple Acquisition.
	Interest on the 2020 Notes is paid semiannually in arrears on February 1 and August 1 of each year, beginning on February 1, 2013. The 2020 Notes will mature on August 1, 2020, unless redeemed prior to maturity. The 2020 Notes are jointly and severally guaranteed on a senior unsecured basis by all of the Company’s current operating subsidiaries and certain of the Company’s future operating subsidiaries, with the exception of Calumet Finance Corp. (100%-owned Delaware corporation that is minor and was organized for the sole purpose of being a co-issuer of certain of the Company’s indebtedness, including the 2020 Notes). The operating subsidiaries may not sell or otherwise dispose of all or substantially all of their properties or assets to, or consolidate with or merge into, another company if such a sale would cause a default under the indenture governing the 2020 Notes.
	The indenture governing the 2020 Notes contains covenants that, among other things, restrict the Company’s ability and the ability of certain of the Company’s subsidiaries to: (i) sell assets; (ii) pay distributions on, redeem or repurchase the Company’s common units or redeem or repurchase its subordinated debt; (iii) make investments; (iv) incur or guarantee additional indebtedness or issue preferred units; (v) create or incur certain liens; (vi) enter into agreements that restrict distributions or other payments from the Company’s restricted subsidiaries to the Company; (vii) consolidate, merge or transfer all or substantially all of the Company’s assets; (viii) engage in transactions with affiliates and (ix) create unrestricted subsidiaries. These covenants are subject to important exceptions and qualifications. At any time when the 2020 Notes are rated investment grade by both Moody’s Investors Service, Inc. and Standard & Poor’s Ratings Services and no Default or Event of Default, each as defined in the indenture governing the 2020 Notes, has occurred and is continuing, many of these covenants will be suspended.
	Upon the occurrence of certain change of control events, each holder of the 2020 Notes will have the right to require that the Company repurchase all or a portion of such holder’s 2020 Notes in cash at a purchase price equal to 101% of the principal amount thereof, plus any accrued and unpaid interest to the date of repurchase.
	On December 4, 2012, the Company filed an exchange offer registration statement for the 2020 Notes with the SEC, which was declared effective on June 27, 2013. The exchange offer was completed on July 26, 2013, thereby fulfilling all of the requirements of the 2020 Notes registration rights agreement.
	9 3/8% Senior Notes
	On April 21, 2011, in connection with the restructuring of the majority of its outstanding long-term debt, the Company issued and sold $400.0 million in aggregate principal amount of 9 3/8% of senior notes due May 1, 2019 (the “2019 Notes issued in April 2011”) in a private placement pursuant to Section 4(a)(2) of the Securities Act to eligible purchasers at par. The 2019 Notes issued in April 2011 were resold to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to persons outside the United States pursuant to Regulation S under the Securities Act. The Company received proceeds of $389.0 million net of underwriters’ fees and expenses, which the Company used to repay in full borrowings outstanding under its prior term loan, as well as all accrued interest and fees, and for general partnership purposes.
	On September 19, 2011, in connection with the Superior Acquisition, the Company issued and sold $200.0 million in aggregate principal amount of 9 3/8% of senior notes due May 1, 2019 (the “2019 Notes issued in September 2011”) in a private placement pursuant to Section 4(a)(2) under the Securities Act to eligible purchasers at a discounted price of 93 percent of par. The 2019 Notes issued in September 2011 were resold to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to persons outside the United States pursuant to Regulation S under the Securities Act. The Company received proceeds of $180.3 million net of discount, underwriters’ fees and expenses, which the Company used to fund a portion of the purchase price of the Superior Acquisition. Because the terms of the 2019 Notes issued in September 2011 are substantially identical to the terms of the 2019 Notes issued in April 2011, in this Quarterly Report, the Company collectively refers to the 2019 Notes issued in April 2011 and the 2019 Notes issued in September 2011 as the “2019 Notes.”
	Interest on the 2019 Notes is paid semiannually in arrears on May 1 and November 1 of each year, beginning on November 1, 2011. The 2019 Notes will mature on May 1, 2019, unless redeemed prior to maturity. The 2019 Notes are jointly and severally guaranteed on a senior unsecured basis by all of the Company’s current operating subsidiaries and certain of the Company’s future operating subsidiaries, with the exception of Calumet Finance Corp. (100%-owned Delaware corporation that is minor and was organized for the sole purpose of being a co-issuer of certain of the Company’s indebtedness, including the 2019 Notes). The operating subsidiaries may not sell or otherwise dispose of all or substantially all of their properties or assets to, or consolidate with or merge into, another company if such a sale would cause a default under the indentures governing the 2019 Notes.
	The indentures governing the 2019 Notes contain covenants that, among other things, restrict the Company’s ability and the ability of certain of the Company’s subsidiaries to: (i) sell assets; (ii) pay distributions on, redeem or repurchase the Company’s common units or redeem or repurchase its subordinated debt; (iii) make investments; (iv) incur or guarantee additional indebtedness or issue preferred units; (v) create or incur certain liens; (vi) enter into agreements that restrict distributions or other payments from the Company’s restricted subsidiaries to the Company; (vii) consolidate, merge or transfer all or substantially all of the Company’s assets; (viii) engage in transactions with affiliates and (ix) create unrestricted subsidiaries. These covenants are subject to important exceptions and qualifications. At any time when the 2019 Notes are rated investment grade by both Moody’s Investors Service, Inc. and Standard & Poor’s Ratings Services and no Default or Event of Default, each as defined in the indentures governing the 2019 Notes, has occurred and is continuing, many of these covenants will be suspended.
	Upon the occurrence of certain change of control events, each holder of the 2019 Notes will have the right to require that the Company repurchase all or a portion of such holder’s 2019 Notes in cash at a purchase price equal to 101% of the principal amount thereof, plus any accrued and unpaid interest to the date of repurchase.
	On December 16, 2011, the Company filed exchange offer registration statements for the 2019 Notes with the SEC, which were declared effective on January 3, 2012. The exchange offers were completed on February 2, 2012, thereby fulfilling all of the requirements of the 2019 Notes registration rights agreements by the specified dates.
	Amended and Restated Senior Secured Revolving Credit Facility
	The Company has an $850.0 million senior secured revolving credit facility, which is its primary source of liquidity for cash needs in excess of cash generated from operations. The revolving credit facility matures in June 2016 and currently bears interest at a rate equal to prime plus a basis points margin or LIBOR plus a basis points margin, at the Company’s option. As of September 30, 2013, the margin was 100 basis points for prime and 225 basis points for LIBOR; however, the margin can fluctuate quarterly based on the Company’s average availability for additional borrowings under the revolving credit facility in the preceding calendar quarter.
	In addition to paying interest monthly on outstanding borrowings under the revolving credit facility, the Company is required to pay a commitment fee to the lenders under the revolving credit facility with respect to the unutilized commitments thereunder at a rate equal to 0.375% to 0.50% per annum depending on the average daily available unused borrowing capacity. The Company also pays a customary letter of credit fee, including a fronting fee of 0.125% per annum of the stated amount of each outstanding letter of credit, and customary agency fees.
	The borrowing capacity at September 30, 2013 under the revolving credit facility was $617.6 million. As of September 30, 2013, the Company had no outstanding borrowings under the revolving credit facility and outstanding standby letters of credit of $140.5 million, leaving $477.1 million available for additional borrowings based on specified availability limitations. Lenders under the revolving credit facility have a first priority lien on the Company’s cash, accounts receivable, inventory and certain other personal property.
	The revolving credit facility contains various covenants that limit, among other things, the Company’s ability to: incur indebtedness; grant liens; dispose of certain assets; make certain acquisitions and investments; redeem or prepay other debt or make other restricted payments such as distributions to unitholders; enter into transactions with affiliates and enter into a merger, consolidation or sale of assets. Further, the revolving credit facility contains one springing financial covenant which provides that only if the Company’s availability under the revolving credit facility falls below the greater of (i) 12.5% of the lesser of (a) the Borrowing Base (as defined in the revolving credit agreement) (without giving effect to the LC Reserve (as defined in the revolving credit agreement)) and (b) the credit agreement commitments then in effect and (ii) $46.4 million, (as increased, upon the effectiveness of the increase in the maximum availability under the revolving credit facility, by the same percentage as the percentage increase in the revolving credit agreement commitments), then the Company will be required to maintain as of the end of each fiscal quarter a Fixed Charge Coverage Ratio (as defined in the revolving credit agreement) of at least 1.0 to 1.0. As of September 30, 2013, the Company’s Fixed Charge Coverage Ratio was 2.8 to 1.0.
	As of September 30, 2013, the Company was in compliance with all covenants under the revolving credit facility.
	Maturities of Long-Term Debt
	As of September 30, 2013, maturities of the Company’s long-term debt are as follows (in millions):
	Year	Maturity
	2013	$	0.2
	2014	0.4
	2015	0.3
	2016	0.3
	2017	0.4
	Thereafter	878.3
	Total	$	879.9

Derivatives

Derivatives	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivatives	'
	The Company is exposed to price risks due to fluctuations in the price of crude oil, refined products (primarily in the Company’s fuel products segment) and natural gas. The Company uses various strategies to reduce its exposure to commodity price risk. The Company does not attempt to eliminate all of the Company’s risk as the costs of such actions are believed to be too high in relation to the risk posed to the Company’s future cash flows, earnings and liquidity. The strategies to reduce the Company’s risk utilize both physical forward contracts and financially settled derivative instruments, such as swaps, futures and options, to attempt to reduce the Company’s exposure with respect to:
	•	crude oil purchases and sales;
	•	fuel product sales and purchases;
	•	natural gas purchases; and
	•	fluctuations in the value of crude oil between geographic regions and between the different types of crude oil such as NYMEX WTI, Light Louisiana Sweet (“LLS”), Western Canadian Select (“WCS”), Mixed Sweet Blend (“MSW”) and ICE Brent (“Brent”).
	The Company does not hold or issue derivative instruments for trading purposes.
	The Company recognizes all derivative instruments at their fair values (see Note 10) as either current assets or current liabilities on the condensed consolidated balance sheets. Fair value includes any premiums paid or received and unrealized gains and losses. Fair value does not include any amounts receivable from or payable to counterparties, or collateral provided to counterparties. Derivative asset and liability amounts with the same counterparty are netted against each other for financial reporting purposes. The Company’s financial results are subject to the possibility that changes in a derivative’s fair value could result in significant ineffectiveness and potentially no longer qualify it for hedge accounting. The following tables summarize the Company’s gross fair values of its derivative instruments, presenting the impact of offsetting derivative assets and liabilities on the Company’s condensed consolidated balance sheets as of September 30, 2013 and December 31, 2012 (in millions):
		30-Sep-13												31-Dec-12
		Gross Amounts of Recognized Assets				Gross Amounts Offset in the Condensed Consolidated Balance Sheets				Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets				Gross Amounts of Recognized Assets				Gross Amounts Offset in the Condensed Consolidated Balance Sheets			Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets
	Derivative instruments designated as hedges:
	Fuel products segment:
	Crude oil swaps	$	47.1			$	(10.5	)		$	36.6			$	24.9			$	(14.4	)	$	10.5
	Gasoline swaps	—				—				—				5.2				(4.9		)	0.3
	Diesel swaps	12.5				(22.3		)		(9.8		)		7				(14.9		)	(7.9		)
	Jet fuel swaps	1.6				(5.6		)		(4.0		)		8				(7.8		)	0.2
	Total derivative instruments designated as hedges	61.2				(38.4		)		22.8				45.1				(42.0		)	3.1
	Derivative instruments not designated as hedges:
	Fuel products segment:
	Crude oil swaps	2.2				(0.9		)		1.3				0.1				(0.1		)	—
	Crude oil basis swaps	—				(3.1		)		(3.1		)		0.1				(0.1		)	—
	Gasoline swaps	0.2				(0.1		)		0.1				—				—			—
	Diesel swaps	3.6				(0.7		)		2.9				5.1				(5.1		)	—
	Jet fuel swaps	0.4				(0.2		)		0.2				—				—			—
	Specialty products segment:
	Crude oil swaps	—				—				—				1.6				(1.6		)	—
	Natural gas swaps	0.1				(1.4		)		(1.3		)		—				—			—
	Total derivative instruments not designated as hedges	6.5				(6.4		)		0.1				6.9				(6.9		)	—
	Total derivative instruments	$	67.7			$	(44.8	)		$	22.9			$	52			$	(48.9	)	$	3.1
		30-Sep-13												31-Dec-12
		Gross Amounts of Recognized Liabilities				Gross Amounts Offset in the Condensed Consolidated Balance Sheets				Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets				Gross Amounts of Recognized Liabilities				Gross Amounts Offset in the Condensed Consolidated Balance Sheets			Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets
	Derivative instruments designated as hedges:
	Fuel products segment:
	Crude oil swaps	$	(8.8	)		$	10.5			$	1.7			$	(41.1	)		$	14.4		$	(26.7	)
	Gasoline swaps	—				—				—				(2.8		)		4.9			2.1
	Diesel swaps	(22.9		)		22.3				(0.6		)		(25.2		)		14.9			(10.3		)
	Jet fuel swaps	(5.6		)		5.6				—				(10.1		)		7.8			(2.3		)
	Total derivative instruments designated as hedges	(37.3		)		38.4				1.1				(79.2		)		42			(37.2		)
	Derivative instruments not designated as hedges:
	Fuel products segment:
	Crude oil swaps	(1.1		)		0.9				(0.2		)		(10.8		)		0.1			(10.7		)
	Crude oil basis swaps	(5.3		)		3.1				(2.2		)		(3.5		)		0.1			(3.4		)
	Gasoline swaps	(0.1		)		0.1				—				(2.2		)		—			(2.2		)
	Diesel swaps	(0.3		)		0.7				0.4				(1.2		)		5.1			3.9
	Jet fuel swaps	0.1				0.2				0.3				—				—			—
	Specialty products segment:
	Crude oil swaps	—				—				—				—				1.6			1.6
	Natural gas swaps	(3.0		)		1.4				(1.6		)		—				—			—
	Total derivative instruments not designated as hedges	(9.7		)		6.4				(3.3		)		(17.7		)		6.9			(10.8		)
	Total derivative instruments	$	(47.0	)		$	44.8			$	(2.2	)		$	(96.9	)		$	48.9		$	(48.0	)
	The Company accounts for certain derivatives hedging purchases of crude oil and sales of gasoline, diesel and jet fuel as cash flow hedges. The derivatives hedging sales and purchases are recorded to sales and cost of sales, respectively, in the unaudited condensed consolidated statements of operations upon recording the related hedged transaction in sales or cost of sales. The derivatives designated as hedging payments of interest are recorded in interest expense in the unaudited condensed consolidated statements of operations upon payment of interest. The Company assesses, both at inception of the hedge and on an ongoing basis, whether the derivatives that are used in hedging transactions are highly effective in offsetting changes in cash flows of hedged items. Periodically, the Company may enter into crude oil and fuel product basis swaps to more effectively hedge its crude oil purchases and fuel products sales. These derivatives can be combined with a swap contract in order to create a more effective hedge. The Company has entered into crude oil basis swaps for 2013 that do not qualify as cash flow hedges for accounting purposes as they were not entered into simultaneously with a corresponding NYMEX WTI derivative contract.
	To the extent a derivative instrument designated as a hedge is determined to be effective as a cash flow hedge of an exposure to changes in the fair value of a future transaction, the change in fair value of the derivative is deferred in accumulated other comprehensive income (loss), a component of partners’ capital in the condensed consolidated balance sheets, until the underlying transaction hedged is recognized in the unaudited condensed consolidated statements of operations. Hedge accounting is discontinued when it is determined that a derivative no longer qualifies as an effective hedge or when it is no longer probable that the hedged forecasted transaction will occur. When hedge accounting is discontinued because the derivative instrument no longer qualifies as an effective cash flow hedge, the derivative instrument is subject to the mark-to-market method of accounting prospectively. Changes in the mark-to-market fair value of the derivative instrument are recorded to unrealized gain (loss) on derivative instruments in the unaudited condensed consolidated statements of operations. Unrealized gains and losses related to discontinued cash flow hedges that were previously accumulated in accumulated other comprehensive income (loss) will remain in accumulated other comprehensive income (loss) until the underlying transaction is reflected in earnings, unless it is probable that the hedged forecasted transaction will not occur, at which time, associated deferred amounts in accumulated other comprehensive income (loss) are immediately recognized in unrealized gain (loss) on derivative instruments.
	Effective January 1, 2012, hedge accounting was discontinued prospectively for certain crude oil derivative instruments when it was determined that they were no longer highly effective in offsetting changes in the cash flows associated with crude oil purchases at the Company’s Superior refinery due to the volatility in crude oil pricing differentials between heavy crude oil and NYMEX WTI. Effective April 1, 2012, hedge accounting was discontinued prospectively for certain gasoline and diesel derivative instruments associated with gasoline and diesel sales at the Company’s Superior refinery. The discontinuance of hedge accounting on these derivative instruments has caused the Company to recognize the following gains and losses in realized gain (loss) on derivative instruments and unrealized gain (loss) in the unaudited condensed consolidated statements of operations for the three and nine months ended September 30, 2013 and 2012 (in millions):
		Three Months Ended September 30,								Nine Months Ended September 30,
		2013				2012				2013				2012
	Realized gain (loss) on derivative instruments	$	1.6			$	(4.8	)		$	(2.6	)		$	49.7
	Unrealized gain (loss) on derivative instruments	$	1.3			$	(35.0	)		$	8.7			$	(6.8	)
	The amount reclassified from accumulated other comprehensive income (loss) into earnings, as a result of the discontinuance of hedge accounting for certain jet fuel derivative instruments because it was no longer probable that the original forecasted transaction would occur by the end of the originally specified time period, caused the Company to recognize derivative losses of $0.7 million and $1.7 million in realized gain (loss) on derivative instruments in the unaudited condensed consolidated statements of operations for the three and nine months ended September 30, 2012, respectively.
	For derivative instruments not designated as cash flow hedges and the portion of any cash flow hedge that is determined to be ineffective, the change in fair value of the asset or liability for the period is recorded to unrealized gain (loss) on derivative instruments in the unaudited condensed consolidated statements of operations. Upon the settlement of a derivative not designated as a cash flow hedge, the gain or loss at settlement is recorded to realized gain (loss) on derivative instruments in the unaudited condensed consolidated statements of operations. Ineffectiveness is inherent in the hedging of crude oil and fuel products. Due to the volatility in the markets for crude oil and fuel products, the Company is unable to predict the amount of ineffectiveness each period, determined on a derivative by derivative basis or in the aggregate for a specific commodity, and has the potential for the future loss of hedge accounting. Ineffectiveness and the loss of hedge accounting has resulted in increased volatility in the Company’s financial results. However, even though certain derivative instruments may not qualify for hedge accounting, the Company intends to continue to utilize such instruments as management believes such derivative instruments continue to provide the Company with the opportunity to more effectively stabilize cash flows.
	The Company recorded the following amounts in its condensed consolidated balance sheets, unaudited condensed consolidated statements of operations, unaudited condensed consolidated statements of comprehensive income (loss) and unaudited condensed consolidated statements of partners’ capital as of, and for the three months ended September 30, 2013 and 2012 related to its derivative instruments that were designated as cash flow hedges (in millions):
		Amount of Gain (Loss) Recognized in Accumulated Other Comprehensive Income (Loss) on Derivatives (Effective Portion)								Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) into Net Income (Loss) (Effective Portion)										Amount of Gain (Loss) Recognized in Net Income (Loss) on Derivatives (Ineffective Portion)
		Three Months Ended								Location of Gain (Loss)		Three Months Ended								Location of Gain (Loss)	Three Months Ended
		September 30,										September 30,									September 30,
	Type of Derivative	2013				2012						2013				2012					2013			2012
Fuel products segment:
Crude oil swaps	$	59.2			$	13			Cost of sales		$	11.1			$	8			Unrealized/ Realized	$	11.3		$	34.1
Gasoline swaps	(0.3		)		8.9				Sales		(0.1		)		—				Unrealized/ Realized	(0.6		)	(23.1		)
Diesel swaps	(33.1		)		(49.3		)		Sales		(4.4		)		(29.2		)		Unrealized/ Realized	(0.6		)	(1.2		)
Jet fuel swaps	(11.7		)		(56.0		)		Sales		(0.2		)		(20.4		)		Unrealized/ Realized	(0.5		)	(4.5		)
Specialty products segment:
Crude oil swaps	—				—				Cost of sales		(0.8		)		(0.2		)		Unrealized/ Realized	—			—
Total	$	14.1			$	(83.4	)				$	5.6			$	(41.8	)			$	9.6		$	5.3
The Company recorded the following gains (losses) in its unaudited condensed consolidated statements of operations for the three months ended September 30, 2013 and 2012 related to its derivative instruments not designated as cash flow hedges (in millions):
	Amount of Gain (Loss) Recognized in Realized Gain (Loss) on Derivative Instruments								Amount of Gain (Loss) Recognized in Unrealized Gain (Loss) on Derivative Instruments
	Three Months Ended								Three Months Ended
	September 30,								September 30,
Type of Derivative	2013				2012				2013				2012
Fuel products segment:
Crude oil swaps	$	2			$	(8.9	)		$	2.7			$	40.2
Crude oil basis swaps	(0.2		)		—				(7.2		)		—
Gasoline swaps	—				2.4				(0.4		)		(40.9		)
Diesel swaps	0.9				2.8				(1.1		)		(34.2		)
Jet fuel swaps	0.7				(0.6		)		0.5				0.5
Specialty products segment:
Crude oil swaps	0.1				—				(0.1		)		1
Natural gas swaps	—				(1.4		)		(0.9		)		1.6
Interest rate swaps	—				(0.1		)		—				0.1
Total	$	3.5			$	(5.8	)		$	(6.5	)		$	(31.7	)
The Company recorded the following amounts in its condensed consolidated balance sheets, unaudited condensed consolidated statements of operations, unaudited condensed consolidated statements of other comprehensive income (loss) and its unaudited condensed consolidated statements of partners’ capital as of, and for the nine months ended September 30, 2013 and 2012 related to its derivative instruments that were designated as cash flow hedges (in millions):
	Amount of Gain (Loss) Recognized in Accumulated Other Comprehensive Income (Loss) on Derivatives (Effective Portion)								Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) into Net Income (Loss) (Effective Portion)										Amount of Gain (Loss) Recognized in Net Income (Loss) on Derivatives (Ineffective Portion)
	Nine Months Ended								Location of Gain (Loss)		Nine Months Ended								Location of Gain (Loss)	Nine Months Ended
	September 30,										September 30,									September 30,
Type of Derivative	2013				2012						2013				2012					2013			2012
Fuel products segment:
Crude oil swaps	$	32.5			$	(85.9	)		Cost of sales		$	(2.5	)		$	42.6			Unrealized/ Realized	$	(16.5	)	$	84
Gasoline swaps	(0.7		)		(31.3		)		Sales		(0.2		)		(39.2		)		Unrealized/ Realized	(1.2		)	(38.4		)
Diesel swaps	8.5				(70.7		)		Sales		(3.0		)		(52.0		)		Unrealized/ Realized	(3.9		)	(3.0		)
Jet fuel swaps	1				(48.4		)		Sales		1.8				(89.0		)		Unrealized/ Realized	6			(2.6		)
Specialty products segment:
Crude oil swaps	—				—				Cost of sales		(0.5		)		(0.2		)		Unrealized/ Realized	—			—
Total	$	41.3			$	(236.3	)				$	(4.4	)		$	(137.8	)			$	(15.6	)	$	40
The Company recorded the following gains (losses) in its unaudited condensed consolidated statements of operations for the nine months ended September 30, 2013 and 2012 related to its derivative instruments not designated as cash flow hedges (in millions):
	Amount of Gain (Loss) Recognized in Realized Gain (Loss) on Derivative Instruments								Amount of Gain (Loss) Recognized in Unrealized Gain (Loss) on Derivative Instruments
	Nine Months Ended								Nine Months Ended
	September 30,								September 30,
Type of Derivative	2013				2012				2013				2012
Fuel products segment:
Crude oil swaps	$	(6.8	)		$	(16.2	)		$	42.5			$	(40.0	)
Crude oil basis swaps	7.3				—				(1.9		)		—
Gasoline swaps	2.9				13.8				(0.4		)		(1.1		)
Diesel swaps	6.4				8				(4.5		)		6.7
Jet fuel swaps	0.7				(1.7		)		0.4				—
Specialty products segment:
Crude oil swaps	1.8				—				(1.6		)		1.6
Natural gas swaps	—				(4.9		)		(2.9		)		2.7
Interest rate swaps	—				(0.7		)		—				1
Total	$	12.3			$	(1.7	)		$	31.6			$	(29.1	)
The cash flow impact of the Company’s derivative activities is classified primarily as a change in derivative activity in the operating activities section in the unaudited condensed consolidated statements of cash flows.
The Company is exposed to credit risk in the event of nonperformance by its counterparties on these derivative transactions. The Company does not expect nonperformance on any derivative instruments, however, no assurances can be provided. The Company’s credit exposure related to these derivative instruments is represented by the fair value of contracts reported as derivative assets. As of September 30, 2013, the Company had seven counterparties, in which derivatives held were net assets, totaling $22.9 million. As of December 31, 2012, the Company had two counterparties, in which the derivatives held were net assets, totaling $3.1 million. To manage credit risk, the Company selects and periodically reviews counterparties based on credit ratings. The Company primarily executes its derivative instruments with large financial institutions that have ratings of at least Baa2 and A- by Moody’s and S&P, respectively. In the event of default, the Company would potentially be subject to losses on derivative instruments with mark to market gains. The Company requires collateral from its counterparties when the fair value of the derivatives exceeds agreed upon thresholds in its master derivative contracts with these counterparties. No such collateral was held by the Company as of September 30, 2013 or December 31, 2012. The Company’s contracts with these counterparties allow for netting of derivative instruments executed under each contract. Collateral received from counterparties is reported in other current liabilities, and collateral held by counterparties is reported in deposits, on the Company’s condensed consolidated balance sheets and is not netted against derivative assets or liabilities. As of September 30, 2013, the Company had provided its counterparties with no collateral. As of December 31, 2012, the Company had provided its counterparties with no collateral except for a $25.0 million letter of credit provided to one counterparty to support crack spread hedging. For financial reporting purposes, the Company does not offset the collateral provided to a counterparty against the fair value of its obligation to that counterparty. Any outstanding collateral is released to the Company upon settlement of the related derivative instrument liability.
Certain of the Company’s outstanding derivative instruments are subject to credit support agreements with the applicable counterparties which contain provisions setting certain credit thresholds above which the Company may be required to post agreed-upon collateral, such as cash or letters of credit, with the counterparty to the extent that the Company’s mark-to-market net liability, if any, on all outstanding derivatives exceeds the credit threshold amount per such credit support agreement. In certain cases, the Company’s credit threshold is dependent upon the Company’s maintenance of certain corporate credit ratings with Moody’s and S&P. In the event that the Company’s corporate credit rating is lowered below specified levels by Moody’s and S&P, such counterparties would have the right to reduce the applicable threshold to zero and demand full collateralization of the Company’s net liability position on outstanding derivative instruments. As of September 30, 2013 and December 31, 2012, there was a net asset of $5.0 million and a net liability $7.5 million, respectively, associated with the Company’s outstanding derivative instruments subject to such requirements. In addition, the majority of the credit support agreements covering the Company’s outstanding derivative instruments also contain a general provision stating that if the Company experiences a material adverse change in its business, in the reasonable discretion of the counterparty, the Company’s credit threshold could be lowered by such counterparty. The Company does not expect that it will experience a material adverse change in its business.
The effective portion of the cash flow hedges classified in accumulated other comprehensive income was $31.7 million as of September 30, 2013. The effective portion of the cash flow hedges classified in accumulated other comprehensive loss was $14.0 million as of December 31, 2012. Absent a change in the fair market value of the underlying transactions, the following other comprehensive income (loss) at September 30, 2013 will be reclassified to earnings by December 31, 2016 with balances being recognized as follows (in millions):
Year	Accumulated Other Comprehensive Income (Loss)
2013	$	21.4
2014	9.9
2015	(0.8		)
2016	1.2
Total	$	31.7
Based on fair values as of September 30, 2013, the Company expects to reclassify $30.2 million of net gains on derivative instruments from accumulated other comprehensive income to earnings during the next twelve months due to actual crude oil purchases and diesel and jet fuel sales. However, the amounts actually realized will be dependent on the fair values as of the dates of settlement.
Crude Oil Swap Contracts — Specialty Products Segment
At September 30, 2013, the Company did not have any crude oil derivatives related to future crude oil purchases in its specialty products segment.
At December 31, 2012, the Company had purchased a crude oil swap for 200,000 barrels in the second quarter of 2012 related to future crude oil purchases in its specialty products segment, which was not designated as a cash flow hedge. The Company subsequently sold a crude oil derivative swap in the third quarter of 2012, and the net impact of these two derivatives was a net gain of $1.6 million that was recorded to unrealized loss on derivative instruments in the consolidated statements of operations for the year ended December 31, 2012. This gain was realized in January 2013 upon settlement and was recorded to realized gain on derivative instruments in the unaudited condensed consolidated statements of operations.
Natural Gas Swap Contracts — Specialty Products Segment
At September 30, 2013, the Company had the following derivatives related to natural gas purchases in its specialty products segment, none of which are designated as cash flow hedges:
Natural Gas Swap Contracts by Expiration Dates	MMBtu			$/MMBtu
Fourth Quarter 2013	1,250,000			$	4.12
Calendar Year 2014	3,100,000			4.16
Calendar Year 2015	3,500,000			4.27
Calendar Year 2016	2,700,000			4.42
Calendar Year 2017	1,000,000			4.29
Totals	11,550,000
Average price				$	4.26
At December 31, 2012, the Company did not have any natural gas derivatives related to future natural gas purchases in its specialty products segment.
Crude Oil Contracts — Fuel Products Segment
Crude Oil Swap Contracts
At September 30, 2013, the Company had the following derivatives related to crude oil purchases in its fuel products segment, all of which are designated as cash flow hedges:
Crude Oil Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Swap ($/Bbl)
Fourth Quarter 2013	1,104,000			12,000			$	93.41
Calendar Year 2014	6,068,500			16,626			89.93
Calendar Year 2015	5,329,000			14,600			89.08
Calendar Year 2016	1,098,000			3,000			85.12
Totals	13,599,500
Average price							$	89.49
At September 30, 2013, the Company had the following derivatives related to crude oil purchases in its fuel products segment, none of which are designated as cash flow hedges:
Crude Oil Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Swap ($/Bbl)
Fourth Quarter 2013	368,000			4,000			$	96.58
Calendar Year 2014	411,000			1,126			95.21
Calendar Year 2015	637,500			1,747			89.89
Totals	1,416,500
Average price							$	93.17
At September 30, 2013, the Company had the following derivatives to sell crude oil in its fuel products segment, none of which are designated as cash flow hedges:
Crude Oil Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
Fourth Quarter 2013	92,000			1,000			$	102.3
Totals	92,000
Average price							$	102.3
At December 31, 2012, the Company had the following derivatives related to crude oil purchases in its fuel products segment, all of which are designated as cash flow hedges:
Crude Oil Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Swap ($/Bbl)
First Quarter 2013	1,665,000			18,500			$	101.67
Second Quarter 2013	1,911,000			21,000			100.22
Third Quarter 2013	1,426,000			15,500			95.62
Fourth Quarter 2013	1,104,000			12,000			93.41
Calendar Year 2014	5,110,000			14,000			89.47
Calendar Year 2015	4,781,500			13,100			89.49
Totals	15,997,500
Average price							$	92.85
At December 31, 2012, the Company had the following derivatives related to crude oil purchases in its fuel products segment, none of which are designated as cash flow hedges:
Crude Oil Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Swap ($/Bbl)
First Quarter 2013	630,000			7,000			$	101.34
Second Quarter 2013	455,000			5,000			98.56
Third Quarter 2013	368,000			4,000			96.58
Fourth Quarter 2013	368,000			4,000			96.58
Totals	1,821,000
Average price							$	98.72
Crude Oil Basis Swap Contracts
During 2012 and 2013, the Company entered into crude oil basis swaps to mitigate the risk of future changes in pricing differentials between Canadian heavy crude oil and NYMEX WTI, pricing differentials between LLS and NYMEX WTI and pricing differentials between MSW and NYMEX WTI. At September 30, 2013, the Company had the following derivatives related to crude oil basis swaps in its fuel products segment, none of which are designated as cash flow hedges:
Crude Oil Basis Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Differential to NYMEX WTI ($/Bbl)
Fourth Quarter 2013	794,000			8,630			$	(17.92	)
Totals	794,000
Average price							$	(17.92	)
At December 31, 2012, the Company had the following derivatives related to crude oil basis swaps in its fuel products segment, none of which are designated as cash flow hedges:
Crude Oil Basis Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Differential to NYMEX WTI ($/Bbl)
First Quarter 2013	180,000			2,000			$	(23.75	)
Second Quarter 2013	364,000			4,000			(27.38		)
Third Quarter 2013	184,000			2,000			(23.75		)
Fourth Quarter 2013	184,000			2,000			(23.75		)
Totals	912,000
Average differential							$	(25.20	)
During the third quarter of 2013, the Company entered into crude oil basis swaps for 250,000 barrels related to future crude oil purchases and sales to mitigate the risk of future changes in pricing differentials between Brent and NYMEX WTI on the Company’s reselling of crude oil. The net impact of these derivative instruments, none of which are designated as cash flow hedges, was a net gain of $0.1 million that has been recorded to unrealized gain (loss) on derivative instruments in the unaudited condensed consolidated statements of operations for the three and nine months ended September 30, 2013. The net impact of these derivative instruments will be realized upon settlement in the fourth quarter of 2013 and will be recorded to realized gain (loss) on derivative instruments in the consolidated statements of operations.
At December 31, 2012, the Company did not have any crude oil basis swaps related to future crude oil purchases and sales to mitigate the risk of future changes in pricing differentials between Brent and NYMEX WTI.
Fuel Products Swap Contracts — Fuel Products Segment
Diesel Swap Contracts
At September 30, 2013, the Company had the following derivatives related to diesel sales in its fuel products segment, all of which are designated as cash flow hedges:
Diesel Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
Fourth Quarter 2013	828,000			9,000			$	120.82
Calendar Year 2014	4,793,500			13,133			116.88
Calendar Year 2015	4,781,500			13,100			115.81
Calendar Year 2016	1,098,000			3,000			111.93
Totals	11,501,000
Average price							$	116.25
At September 30, 2013, the Company had the following derivatives related to diesel sales in its fuel products segment, none of which are designated as cash flow hedges:
Diesel Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
Fourth Quarter 2013	276,000			3,000			$	124.17
Calendar Year 2014	501,000			1,373			122.49
Calendar Year 2015	637,500			1,747			118.16
Totals	1,414,500
Average price							$	120.87
At December 31, 2012, the Company had the following derivatives related to diesel sales in its fuel products segment, all of which are designated as cash flow hedges:
Diesel Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
Second Quarter 2013	546,000			6,000			$	122.74
Third Quarter 2013	874,000			9,500			122.23
Fourth Quarter 2013	828,000			9,000			120.82
Calendar Year 2014	3,835,000			10,507			116
Calendar Year 2015	4,781,500			13,100			115.81
Totals	10,864,500
Average price							$	117.13
At December 31, 2012, the Company had the following derivatives related to diesel sales in its fuel products segment, none of which are designated as cash flow hedges:
Diesel Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
First Quarter 2013	540,000			6,000			$	130.57
Second Quarter 2013	364,000			4,000			126.82
Third Quarter 2013	276,000			3,000			124.17
Fourth Quarter 2013	276,000			3,000			124.17
Totals	1,456,000
Average price							$	127.2
Jet Fuel Swap Contracts
At September 30, 2013, the Company had the following derivatives related to jet fuel sales in its fuel products segment, all of which are designated as cash flow hedges:
Jet Fuel Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
Fourth Quarter 2013	276,000			3,000			$	122.36
Calendar Year 2014	1,275,000			3,493			116.64
Calendar Year 2015	547,500			1,500			112.51
Totals	2,098,500
Average price							$	116.31
At September 30, 2013, the Company had the following derivatives to purchase jet fuel in its fuel products segment, none of which are designated as cash flow hedges:
Jet Fuel Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Swap ($/Bbl)
Calendar Year 2014	90,000			247			$	116.71
Totals	90,000
Average price							$	116.71
At December 31, 2012, the Company had the following derivatives related to jet fuel sales in its fuel products segment, all of which are designated as cash flow hedges:
Jet Fuel Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
First Quarter 2013	1,035,000			11,500			$	127.39
Second Quarter 2013	819,000			9,000			129.2
Third Quarter 2013	368,000			4,000			125.13
Fourth Quarter 2013	276,000			3,000			122.36
Calendar Year 2014	1,275,000			3,493			116.64
Totals	3,773,000
Average price							$	123.56
Gasoline Swap Contracts
At September 30, 2013, the Company did not have derivatives related to gasoline sales in its fuel products segment designated as cash flow hedges.
At September 30, 2013, the Company had the following derivatives related to gasoline sales in its fuel products segment, none of which are designated as cash flow hedges:
Gasoline Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
Fourth Quarter 2013	92,000			1,000			$	105.5
Totals	92,000
Average price							$	105.5
At September 30, 2013, the Company had the following derivatives related to gasoline purchases in its fuel products segment, none of which are designated as cash flow hedges:
Gasoline Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Swap ($/Bbl)
Fourth Quarter 2013	92,000			1,000			$	105
Totals	92,000
Average price							$	105
At December 31, 2012, the Company had the following derivatives related to gasoline sales in its fuel products segment, all of which are designated as cash flow hedges:
Gasoline Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
First Quarter 2013	630,000			7,000			$	113.59
Second Quarter 2013	546,000			6,000			116.32
Third Quarter 2013	184,000			2,000			114.73
Totals	1,360,000
Average price							$	114.84
At December 31, 2012, the Company had the following derivatives related to gasoline sales in its fuel products segment, none of which are designated as cash flow hedges:
Gasoline Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
First Quarter 2013	90,000			1,000			$	105.5
Second Quarter 2013	91,000			1,000			105.5
Third Quarter 2013	92,000			1,000			105.5
Fourth Quarter 2013	92,000			1,000			105.5
Totals	365,000
Average price							$	105.5
At December 31, 2012, the Company did not have any derivatives related to gasoline purchases in its fuel products segment designated as cash flow hedges.

Fair_Value_Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	The Company uses a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value. Observable inputs are from sources independent of the Company. Unobservable inputs reflect the Company’s assumptions about the factors market participants would use in valuing the asset or liability developed based upon the best information available in the circumstances. These tiers include the following:
	•Level 1—inputs include observable unadjusted quoted prices in active markets for identical assets or liabilities
	•Level 2—inputs include other than quoted prices in active markets that are either directly or indirectly observable
	•Level 3—inputs include unobservable inputs in which little or no market data exists; therefore requiring an entity to develop its own assumptions
	In determining fair value, the Company uses various valuation techniques and prioritizes the use of observable inputs. The availability of observable inputs varies from instrument to instrument and depends on a variety of factors including the type of instrument, whether the instrument is actively traded and other characteristics particular to the instrument. For many financial instruments, pricing inputs are readily observable in the market, the valuation methodology used is widely accepted by market participants and the valuation does not require significant management judgment. For other financial instruments, pricing inputs are less observable in the marketplace and may require management judgment.
	Recurring Fair Value Measurements
	Derivative Assets and Liabilities
	Derivative instruments are reported in the accompanying unaudited condensed consolidated financial statements at fair value. The Company’s derivative instruments consist of over-the-counter (“OTC”) contracts, which are not traded on a public exchange. Substantially all of the Company’s derivative instruments are with counterparties that have long-term credit ratings of at least Baa2 and A- by Moody’s and S&P, respectively.
	To estimate the fair values of the Company’s derivative instruments, the Company uses the market approach. Under this approach, the fair values of the Company’s derivative instruments for crude oil, crude oil basis, gasoline, diesel, jet fuel, natural gas and interest rates are determined primarily based on inputs that are readily available in public markets or can be derived from information available in publicly quoted markets. Generally, the Company obtains this data through surveying its counterparties and performing various analytical tests to validate the data. In situations where the Company obtains inputs via quotes from its counterparties, it verifies the reasonableness of these quotes via similar quotes from another counterparty as of each date for which financial statements are prepared. The Company also includes an adjustment for non-performance risk in the recognized measure of fair value of all of the Company’s derivative instruments. The adjustment reflects the full credit default spread (“CDS”) applied to a net exposure by counterparty. When the Company is in a net asset position it uses its counterparty’s CDS, or a peer group’s estimated CDS when a CDS for the counterparty is not available. The Company uses its own peer group’s estimated CDS when it is in a net liability position. As a result of applying the applicable CDS at September 30, 2013, the Company’s asset was reduced by approximately $0.1 million and the liability was reduced by less than $0.1 million. As a result of applying the CDS at December 31, 2012, the Company’s asset was reduced by approximately $0.1 million and the liability was reduced by approximately $0.2 million.
	Based on the use of various unobservable inputs, principally non-performance risk and unobservable inputs in forward years for crude oil, crude oil basis, gasoline, jet fuel, diesel and natural gas, the Company has categorized these derivative instruments as Level 3. Significant increases (decreases) in any of those unobservable inputs in isolation would result in a significantly lower (higher) fair value measurement. The Company has consistently applied these valuation techniques in all periods presented and believes it has obtained the most accurate information available for the types of derivative instruments it holds. See Note 9 for further information on derivative instruments.
	Pension Assets
	Pension assets are reported at fair value in the accompanying unaudited condensed consolidated financial statements. At September 30, 2013, the Company’s investments associated with its Pension Plan (as such term is hereinafter defined) primarily consist of (i) cash and cash equivalents and (ii) mutual funds. The mutual funds are categorized as Level 2 because inputs used in their valuation are not quoted prices in active markets that are indirectly observable and are valued at the net asset value (“NAV”) of shares in each fund held by the Pension Plan at quarter end as provided by the third party administrator. See Note 12 for further information on pension assets.
	Liability Awards
	Unit based compensation liability awards are awards that are expected to be settled in cash on their vesting dates, rather than in equity units (“Liability Awards”). The Liability Awards are categorized as Level 1 because the fair value of the Company’s Liability Awards are based on the quoted closing unit price as of each balance sheet date.
	Renewable Identification Numbers Obligation
	The Company’s RINs obligation (“RINs Obligation”) represents a liability for the purchase of RINs to satisfy the EPA requirement to blend biofuels into the fuel products it produces pursuant to the EPA’s Renewable Fuel Standard. RINs are assigned to biofuels produced in the U.S. as required by the EPA. The EPA sets annual quotas for the percentage of biofuels that must be blended into transportation fuels consumed in the U.S., and as a producer of motor fuels from petroleum, the Company is required to blend biofuels into the fuel products it produces at a rate that will meet the EPA’s annual quota. To the extent the Company is unable to blend biofuels at that rate, it must purchase RINs in the open market to satisfy the annual requirement. The Company’s RINs Obligation is based on the amount of RINs it must purchase and the price of those RINs as of the balance sheet date. The RINs Obligation is categorized as Level 2 and is measured at fair value using the market approach based on quoted prices from an independent pricing service.
	Hierarchy of Recurring Fair Value Measurements
	The Company’s recurring assets and liabilities measured at fair value at September 30, 2013 and December 31, 2012 were as follows (in millions):
		30-Sep-13												31-Dec-12
		Level 1			Level 2			Level 3			Total			Level 1			Level 2			Level 3			Total
	Assets:
	Derivative assets:
	Crude oil swaps	$	—		$	—		$	37.9		$	37.9		$	—		$	—		$	10.5		$	10.5
	Crude oil basis swaps	—			—			(3.1		)	(3.1		)	—			—			—			—
	Gasoline swaps	—			—			0.1			0.1			—			—			0.3			0.3
	Diesel swaps	—			—			(6.9		)	(6.9		)	—			—			(7.9		)	(7.9		)
	Jet fuel swaps	—			—			(3.8		)	(3.8		)	—			—			0.2			0.2
	Natural gas swaps	—			—			(1.3		)	(1.3		)	—			—			—			—
	Total derivative assets	—			—			22.9			22.9			—			—			3.1			3.1
	Pension plan investments	0.2			44.1			—			44.3			38.9			2.7			—			41.6
	Total recurring assets at fair value	$	0.2		$	44.1		$	22.9		$	67.2		$	38.9		$	2.7		$	3.1		$	44.7
	Liabilities:
	Derivative liabilities:
	Crude oil swaps	$	—		$	—		$	1.5		$	1.5		$	—		$	—		$	(35.8	)	$	(35.8	)
	Crude oil basis swaps	—			—			(2.2		)	(2.2		)	—			—			(3.4		)	(3.4		)
	Gasoline swaps	—			—			—			—			—			—			(0.1		)	(0.1		)
	Diesel swaps	—			—			(0.2		)	(0.2		)	—			—			(6.4		)	(6.4		)
	Jet fuel swaps	—			—			0.3			0.3			—			—			(2.3		)	(2.3		)
	Natural gas swaps	—			—			(1.6		)	(1.6		)	—			—			—			—
	Total derivative liabilities	—			—			(2.2		)	(2.2		)	—			—			(48.0		)	(48.0		)
	RINs Obligation	—			(10.9		)	—			(10.9		)	—			(0.8		)	—			(0.8		)
	Liability Awards	(3.0		)	—			—			(3.0		)	(2.2		)	—			—			(2.2		)
	Total recurring liabilities at fair value	$	(3.0	)	$	(10.9	)	$	(2.2	)	$	(16.1	)	$	(2.2	)	$	(0.8	)	$	(48.0	)	$	(51.0	)
	The table below sets forth a summary of net changes in fair value of the Company’s Level 3 financial assets and liabilities for the nine months ended September 30, 2013 and 2012 (in millions):
		Nine Months Ended
		September 30,
		2013			2012
	Fair value at January 1,	$	(44.9	)	$	14.9
	Realized gain on derivative instruments	(5.4		)	(20.5		)
	Unrealized gain (loss) on derivative instruments	22.9			(11.3		)
	Change in fair value of cash flow hedges	41.3			(236.3		)
	Settlements	6.8			157.4
	Transfers in (out) of Level 3	—			—
	Fair value at September 30,	$	20.7		$	(95.8	)
	Total gain (loss) included in net income attributable to changes in unrealized gain (loss) relating to financial assets and liabilities held as of September 30,	$	22.9		$	(11.3	)
	All settlements from derivative instruments that are deemed “effective” and were designated as cash flow hedges are included in sales for gasoline, diesel and jet fuel derivatives, and cost of sales for crude oil and natural gas derivatives in the unaudited condensed consolidated statements of operations in the period that the hedged cash flow occurs. Any “ineffectiveness” associated with these settled derivative instruments is recorded in earnings in realized gain (loss) on derivative instruments in the unaudited condensed consolidated statements of operations. All settlements from derivative instruments not designated as cash flow hedges are recorded in realized gain (loss) on derivative instruments in the unaudited condensed consolidated statements of operations. See Note 9 for further information on derivative instruments.
	Nonrecurring Fair Value Measurements
	Certain nonfinancial assets and liabilities are measured at fair value on a nonrecurring basis and are subject to fair value adjustments in certain circumstances, such as when there is evidence of impairment. Assets and liabilities acquired in business combinations are recorded at their fair value as of the date of acquisition. Refer to Note 3 for the fair values of assets acquired and liabilities assumed in connection with the Missouri, Calumet Packaging, Royal Purple, Montana, San Antonio and Crude Oil Logistics Acquisitions.
	The Company reviews for goodwill impairment annually on October 1 and whenever events or changes in circumstances indicate its carrying value may not be recoverable. The fair value of the reporting units is determined using the income approach. The income approach focuses on the income-producing capability of an asset, measuring the current value of the asset by calculating the present value of its future economic benefits such as cash earnings, cost savings, corporate tax structure and product offerings. Value indications are developed by discounting expected cash flows to their present value at a rate of return that incorporates the risk-free rate for the use of funds, the expected rate of inflation and risks associated with the reporting unit. These assets would generally be classified within Level 3, in the event that the Company was required to measure and record such assets at fair value within its unaudited condensed consolidated financial statements.
	The Company periodically evaluates the carrying value of long-lived assets to be held and used, including definite-lived intangible assets and property plant and equipment, when events or circumstances warrant such a review. Fair value is determined primarily using anticipated cash flows assumed by a market participant discounted at a rate commensurate with the risk involved and these assets would generally be classified within Level 3 in the event that the Company were required to measure and record such assets at fair value within its unaudited condensed consolidated financial statements.
	Estimated Fair Value of Financial Instruments
	Cash
	The carrying value of cash is considered to be representative of its fair value.
Debt
The estimated fair value of long-term debt at September 30, 2013 and December 31, 2012 consists primarily of the 2019 Notes and 2020 Notes. The fair values of the Company’s 2019 Notes were based upon quoted market prices in an active market and are classified as Level 1. The fair values of the Company’s 2020 Notes were based upon quoted market prices in an active market and are classified as Level 1 at September 30, 2013. The fair values of the Company’s 2020 Notes were based upon directly observable inputs and were classified as Level 2 at December 31, 2012. The carrying value of borrowings, if any, under the Company’s revolving credit facility approximates its fair value as determined by discounted cash flows and is classified as Level 3. Capital lease obligations approximate their fair values as determined by discounted cash flows and are classified as Level 3. See Note 8 for further information on long-term debt.
The Company’s carrying and estimated fair value of the Company’s financial instruments, carried at adjusted historical cost, at September 30, 2013 and December 31, 2012 were as follows (in millions):
	30-Sep-13						31-Dec-12
	Fair Value			Carrying Value			Fair Value			Carrying Value
Financial Instrument:
2019 Notes	$	663.8		$	588.7		$	658.8		$	587.6
2020 Notes	$	308		$	270.7		$	301.8		$	270.4
Revolving credit facility	$	—		$	—		$	—		$	—
Capital lease and other obligations	$	4.9		$	4.9		$	5.5		$	5.5

Partners_Capital

Partners' Capital	9 Months Ended
	Sep. 30, 2013
Equity [Abstract]	'
Partners' Capital	'
	On January 8, 2013, the Company completed a public offering of its common units in which it sold 5,750,000 common units, including the overallotment option of 750,000 common units, to the underwriters of the offering at a price to the public of $31.81 per common unit. The proceeds received by the Company from this offering (net of underwriting discounts, commissions and expenses but before its general partner’s capital contribution) were $175.2 million and were used to repay borrowings under its revolving credit facility and for general partnership purposes. Underwriting discounts totaled $7.4 million. The Company’s general partner contributed $3.8 million to maintain its 2% general partner interest.
	On April 1, 2013, the Company completed a public offering of its common units in which it sold 5,250,000 common units to the underwriters of the offering at a price to the public of $37.50 per common unit. On April 4, 2013, the overallotment option of 787,500 common units was exercised by the underwriters in full. The proceeds received by the Company from this offering (net of underwriting discounts, commissions and expenses but before its general partner’s capital contribution) were $217.3 million and were used for general partnership purposes. Underwriting discounts totaled $9.1 million. The Company’s general partner contributed $4.6 million to maintain its 2% general partner interest.
	The Company’s distribution policy is defined in its partnership agreement. For the three months ended September 30, 2013 and 2012, the Company made distributions of $52.6 million and $35.9 million, respectively, to its partners. For the nine months ended September 30, 2013 and 2012, the Company made distributions of $149.0 million and $94.2 million, respectively, to its partners.
	For the three months ended September 30, 2013 and 2012, the general partner was allocated $3.8 million and $1.7 million, respectively, in incentive distribution rights. For the nine months ended September 30, 2013 and 2012, the general partner was allocated $10.9 million and $3.3 million, respectively, in incentive distributions rights.

Employee_Benefit_Plans

Employee Benefit Plans	9 Months Ended
	Sep. 30, 2013
Compensation and Retirement Disclosure [Abstract]	'
Employee Benefit Plans	'
	The components of net periodic pension and other postretirement benefits cost (credit) for the three months ended September 30, 2013 and 2012 were as follows (in millions):
		For the Three Months Ended September 30,
		2013					2012
		Pension Benefits			Other Post Retirement Employee Benefits		Pension Benefits			Other Post Retirement Employee Benefits
	Service cost	$	0.1		$	—	$	0.3		$	—
	Interest cost	0.6			—		0.6			—
	Expected return on assets	(1.2		)	—		(0.5		)	—
	Amortization of net loss	0.1			—		0.1			—
	Curtailment gain	—			—		(0.2		)	(7.0		)
	Net periodic benefit cost (credit)	$	(0.4	)	$	—	$	0.3		$	(7.0	)
	The components of net periodic pension and other postretirement benefits cost (credit) for the nine months ended September 30, 2013 and 2012 were as follows (in millions):
		For the Nine Months Ended September 30,
		2013					2012
		Pension Benefits			Other Post Retirement Employee Benefits		Pension Benefits			Other Post Retirement Employee Benefits
	Service cost	$	0.3		$	—	$	0.8		$	0.2
	Interest cost	1.8			—		1.8			0.2
	Expected return on assets	(2.2		)	—		(1.7		)	—
	Amortization of net loss	0.5			—		0.4			—
	Curtailment gain	—			—		(0.2		)	(7.0		)
	Net periodic benefit cost (credit)	$	0.4		$	—	$	1.1		$	(6.6	)
	The Company’s investments associated with its Pension Plan primarily consist of (i) cash and cash equivalents and (ii) mutual funds. The mutual funds are categorized as Level 2 because inputs used in their valuation are not quoted prices in active markets that are indirectly observable and are valued at the NAV of the shares in each fund held by the Pension Plan at quarter end as provided by the third party administrator. The mutual funds provide the Company with the ability to redeem its interests on a daily basis.
	See Note 10 for the definition of Levels 1, 2 and 3. The Company’s Pension Plan assets measured at fair value at September 30, 2013 and December 31, 2012 were as follows (in millions):
		30-Sep-13					31-Dec-12
		Level 1			Level 2		Level 1			Level 2
	Cash and cash equivalents	$	0.2		$	—	$	19.3		$	—
	Equity	—			10		5.9			—
	Foreign equities	—			10		2.3			—
	Commingled fund	—			—		—			2.7
	Balanced fund	—			—		3			—
	Fixed income	—			24.1		8.4			—
		$	0.2		$	44.1	$	38.9		$	2.7
	Investment Fund Strategies
	Equity funds include funds that invest in U.S. common and preferred stocks. Foreign equity funds invest in securities issued by companies listed on international stock exchanges. Certain funds have value and growth objectives and managers may attempt to profit from security mispricing in equity markets to meet these objectives. Short term investments (including commercial paper, certificates of deposits and government repurchase agreements) and derivatives may be used for hedging purposes to limit exposure to various risk factors.
	Fixed income funds invest in U.S. dollar-denominated, investment grade bonds, including U.S. Treasury and government agency securities, corporate bonds and mortgage and asset-backed securities. These funds may also invest in any combination of non-investment grade bonds, non-U.S. dollar denominated bonds and bonds issued by issuers in emerging capital markets. Short term investments (including commercial paper, certificates of deposits and government repurchase agreements) and derivatives may be used for hedging purposes to limit exposure to various risk factors.

Accumulated_Other_Comprehensiv

Accumulated Other Comprehensive Income (Loss)	9 Months Ended
	Sep. 30, 2013
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]	'
Accumulated Other Comprehensive Income (Loss)	'
	The table below sets forth a summary of reclassification adjustments out of accumulated other comprehensive income (loss) in the Company’s unaudited condensed consolidated statements of operations for the three and nine months ended September 30, 2013 (in millions):
	Components of Accumulated Other Comprehensive Income (Loss)		Amount Reclassified From Accumulated Other Comprehensive Income (Loss)						Location of Gain (Loss)
			For the Three Months Ended			For the Nine Months Ended
			30-Sep-13			30-Sep-13
	Derivative gains (losses) reflected in gross profit
			$	(4.7	)	$	(1.4	)	Sales
			10.3			(3.0		)	Cost of sales
			$	5.6		$	(4.4	)	Total
	Amortization of defined benefit pension and postretirement health benefit plans:
	Amortization of net loss		$	(0.1	)	$	(0.5	)	-1
			$	(0.1	)	$	(0.5	)	Total
	________________________
	-1	This accumulated other comprehensive income (loss) component is included in the computation of net periodic pension cost. See Note 12 for additional details.

Earnings_Per_Unit

Earnings Per Unit	9 Months Ended
	Sep. 30, 2013
Earnings Per Unit [Abstract]	'
Earnings per unit	'
	The following table sets forth the computation of basic and diluted earnings per limited partner unit for the three and nine months ended September 30, 2013 and 2012 (in millions, except unit and per unit data):
		Three Months Ended					Nine Months Ended
		September 30,					September 30,
		2013			2012		2013		2012
	Numerator for basic and diluted earnings per limited partner unit:
	Net income (loss)	$	(34.8	)	$	42.4	$	19	$	160
	General partner’s interest in net income (loss)	(0.7		)	0.8		0.4		3.2
	General partner’s incentive distribution rights	3.8			1.7		10.9		3.3
	Non-vested share based payments	—			0.2		0.2		0.9
	Net income (loss) available to limited partners	$	(37.9	)	$	39.7	$	7.5	$	152.6
	Denominator for basic and diluted earnings per limited partner unit:
	Basic weighted average limited partner units outstanding	69,626,650			57,745,806		67,367,326		54,826,636
	Effect of dilutive securities:
	Participating securities — phantom units	—			79,797		186,383		40,279
	Diluted weighted average limited partner units outstanding (1)	69,626,650			57,825,603		67,553,709		54,866,915
	Limited partners’ interest basic and diluted net income (loss) per unit	$	(0.54	)	$	0.69	$	0.11	$	2.78
	_____________
	(1) Total diluted weighted average limited partner units outstanding excludes any potentially dilutive shares for the three months ended September 30, 2013.

Segments_and_Related_Informati

Segments and Related Information	9 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]	'
Segments and Related Information	'
	a. Segment Reporting
	The Company has two reportable segments: specialty products and fuel products. The specialty products segment produces a variety of lubricating oils, solvents, waxes, synthetic lubricants, asphalt and other by-products. These products are sold to customers who purchase these products primarily as raw material components for basic automotive, industrial and consumer goods. The specialty products segment also blends and markets through the Company’s brand Royal Purple. The fuel products segment produces a variety of fuel and fuel-related products including gasoline, diesel, jet fuel and heavy fuel oils. The Company is also engaged in the resale of purchased crude oil to third party customers. The Company sells the majority of the fuel products it produces to markets located in Arkansas, Canada, Idaho, Iowa, Louisiana, Michigan, Minnesota, Montana, North Dakota, South Dakota, Texas and Wisconsin. The Company also has the ability to ship additional fuel products to the Midwest region and the northern states bordering Canada through the Enterprise and Magellan pipelines should the need arise. The assets and results of the operations from such assets acquired as a result of the Montana Acquisition have been included in both the specialty products and fuel products segments since the date of acquisition, October 1, 2012. The assets and results of the operations from such assets acquired as a result of the San Antonio and Crude Oil Logistics Acquisitions have been included in the fuel products segment since their dates of acquisition, January 2, 2013 and August 9, 2013, respectively. The assets and results of operations from these assets acquired as a result of the Missouri, Calumet Packaging and Royal Purple Acquisitions have been included in the specialty products segment since their dates of acquisition, January 3, 2012, January 6, 2012 and July 3, 2012, respectively.
	The accounting policies of the segments are the same as those described in the summary of significant accounting policies as disclosed in Note 2 — “Summary of Significant Accounting Policies” in Part II, Item 8 “Financial Statements and Supplementary Data” of the Company’s 2012 Annual Report. The Company evaluates segment performance based on operating income (loss). The Company accounts for intersegment sales and transfers at cost plus a specified mark-up. Reportable segment information is as follows (in millions):
	Three Months Ended September 30, 2013	Specialty Products			Fuel Products				Combined Segments				Eliminations			Consolidated Total
	Sales:
	External customers	$	591.8		$	913.7			$	1,505.50			$	—		$	1,505.50
	Intersegment sales	—			22.5				22.5				(22.5		)	—
	Total sales	$	591.8		$	936.2			$	1,528.00			$	(22.5	)	$	1,505.50
	Depreciation and amortization	$	20.5		$	13.8			$	34.3			$	—		$	34.3
	Operating loss	$	(15.2	)	$	(3.8	)		$	(19.0	)		$	—		$	(19.0	)
	Reconciling items to net loss:
	Interest expense															(24.2		)
	Gain on derivative instruments															6.6
	Other															1.9
	Income tax expense															(0.1		)
	Net loss															$	(34.8	)
	Three Months Ended September 30, 2012	Specialty Products			Fuel Products				Combined Segments				Eliminations			Consolidated Total
	Sales:
	External customers	$	587.1		$	592.7			$	1,179.80			$	—		$	1,179.80
	Intersegment sales	275.2			14.8				290				(290.0		)	—
	Total sales	$	862.3		$	607.5			$	1,469.80			$	(290.0	)	$	1,179.80
	Depreciation and amortization	$	23.1		$	4.6			$	27.7			$	—		$	27.7
	Operating income	$	36		$	62.8			$	98.8			$	—		$	98.8
	Reconciling items to net income:
	Interest expense															(24.2		)
	Loss on derivative instruments															(32.2		)
	Other															0.2
	Income tax expense															(0.2		)
	Net income															$	42.4
	Nine Months Ended September 30, 2013	Specialty Products			Fuel Products				Combined Segments				Eliminations			Consolidated Total
	Sales:
	External customers	$	1,676.10		$	2,502.20			$	4,178.30			$	—		$	4,178.30
	Intersegment sales	—			71				71				(71.0		)	—
	Total sales	$	1,676.10		$	2,573.20			$	4,249.30			$	(71.0	)	$	4,178.30
	Depreciation and amortization	$	67.9		$	31.2			$	99.1			$	—		$	99.1
	Operating income	$	5.6		$	57.1			$	62.7			$	—		$	62.7
	Reconciling items to net income:
	Interest expense															(73.7		)
	Gain on derivative instruments															28.3
	Other															2.2
	Income tax expense															(0.5		)
	Net income															$	19
	Nine Months Ended September 30, 2012	Specialty Products			Fuel Products				Combined Segments				Eliminations			Consolidated Total
	Sales:
	External customers	$	1,722.00		$	1,714.40			$	3,436.40			$	—		$	3,436.40
	Intersegment sales	872.3			37				909.3				(909.3		)	—
	Total sales	$	2,594.30		$	1,751.40			$	4,345.70			$	(909.3	)	$	3,436.40
	Depreciation and amortization	$	60.5		$	13.7			$	74.2			—			$	74.2
	Operating income	$	114.7		$	97.6			$	212.3			—			$	212.3
	Reconciling items to net income:
	Interest expense															(61.2		)
	Gain on derivative instruments															9.2
	Other															0.3
	Income tax expense															(0.6		)
	Net income															$	160
	b. Geographic Information
	International sales accounted for less than 10% of consolidated sales in each of the three and nine months ended September 30, 2013 and 2012. All of the Company’s long-lived assets are domestically located.
	c. Product Information
	The Company offers specialty products primarily in six general categories consisting of lubricating oils, solvents, waxes, packaged and synthetic specialty products, fuels and asphalt and other by-products. Fuel products primarily consist of gasoline, diesel, jet fuel and heavy fuel oils. The following table sets forth the major product category sales for the three months ended September 30, 2013 and 2012 (in millions):
		Three Months Ended September 30,
		2013						2012
	Specialty products:
	Lubricating oils	$	201.5		13	%		$	237			20	%
Solvents	127.5			8	%		120.4				10	%
Waxes	36.2			2	%		37.3				3	%
Packaged and synthetic specialty products	59.9			4	%		58.5				5	%
Fuels	0.3			—	%		0.3				1	%
Asphalt and other by-products	166.4			12	%		133.6				11	%
Total	$	591.8		39	%		$	587.1			50	%
Fuel products:
Gasoline	413.2			27	%		302.9				26	%
Diesel	347.8			23	%		217.8				19	%
Jet fuel	41.5			3	%		37.1				3	%
Heavy fuel oils and other	111.2			8	%		34.9				2	%
Total	$	913.7		61	%		$	592.7			50	%
Consolidated sales	$	1,505.50		100	%		$	1,179.80			100	%
The following table sets forth the major product category sales for the nine months ended September 30, 2013 and 2012 (in millions):
	Nine Months Ended September 30,
	2013						2012
Specialty products:
Lubricating oils	$	649.6		16	%		$	795.2			23	%
Solvents	387.2			9	%		377.9				11	%
Waxes	102.4			2	%		109.2				3	%
Packaged and synthetic specialty products	185			4	%		116.1				3	%
Fuels	1.2			—	%		1.7				—	%
Asphalt and other by-products	350.7			9	%		321.9				9	%
Total	$	1,676.10		40	%		$	1,722.00			49	%
Fuel products:
Gasoline	1,084.10			26	%		841.2				24	%
Diesel	956.3			23	%		657.9				20	%
Jet fuel	149.9			4	%		125.3				4	%
Heavy fuel oils and other	311.9			7	%		90				3	%
Total	$	2,502.20		60	%		$	1,714.40			51	%
Consolidated sales	$	4,178.30		100	%		$	3,436.40			100	%
d. Major Customers
During the three and nine months ended September 30, 2013 and 2012, the Company had no customer that represented 10% or greater of consolidated sales.

Subsequent_Events

Subsequent Events	9 Months Ended
	Sep. 30, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	On October 16, 2013, the Company entered into a definitive agreement with TexStar Midstream Logistics, L.P. (“TexStar”) under which TexStar will construct, own and operate a 30,000 bpd crude oil pipeline system that will supply crude oil to the Company’s San Antonio refinery. Under the terms of the 15 year agreement, TexStar has committed to install and operate the Karnes North Pipeline System (“KNPS”), a pipeline that will transport crude oil from Karnes City, Texas to the San Antonio refinery’s Elmendorf, Texas terminal, a key supply hub for the Company’s San Antonio refinery. The San Antonio refinery expects to receive deliveries of at least 10,000 bpd of crude oil through the KNPS-Elmendorf terminal supply route once the pipeline comes into service during the fourth quarter 2014.
	On October 22, 2013, the Company declared a quarterly cash distribution of $0.685 per unit on all outstanding common units, or approximately $52.6 million (including the general partner’s incentive distribution rights) in aggregate, for the quarter ended September 30, 2013. The distribution will be paid on November 14, 2013 to unitholders of record as of the close of business on November 4, 2013. This quarterly distribution of $0.685 per unit equates to $2.74 per unit per year, or approximately $210.4 million (including the general partner’s incentive distribution rights) in aggregate on an annualized basis.
	The fair value of the Company’s derivatives decreased by approximately $23.0 million subsequent to September 30, 2013 to a net liability of approximately $2.0 million. The fair value of the Company’s long-term debt, excluding capital leases, has increased by approximately $6.0 million subsequent to September 30, 2013

Acquisitions_Tables

Acquisitions (Tables)	9 Months Ended
	Sep. 30, 2013
Business Acquisition [Line Items]	'
Unaudited pro forma financial information	'
	Results of Sales and Earnings
	The following financial information reflects sales and operating income of the Royal Purple, Montana and San Antonio Acquisitions that are included in the unaudited condensed consolidated statements of operations for the three and nine months ended September 30, 2013 (in millions):
		Three Months Ended September 30, 2013			Nine Months Ended September 30, 2013
	Sales	$	276.6		$	810.5
	Operating income	$	2.7		$	28.2
	Pro Forma Financial Information (Unaudited)
	The following unaudited pro forma financial information reflects the unaudited condensed consolidated results of operations of the Company as if the Royal Purple, Montana and San Antonio Acquisitions had taken place on January 1, 2012 (in millions, except for per unit data):
		Three Months Ended September 30, 2012			Nine Months Ended September 30, 2012
	Sales	$	1,463.60		$	4,255.40
	Net income	$	54.1		$	168.5
	Limited partners’ interest net income per unit — basic	$	0.73		$	2.31
	Limited partners’ interest net income per unit — diluted	$	0.74		$	2.31
Missouri Acquisition [Member]	'
Business Acquisition [Line Items]	'
Purchase Price Allocation	'
	The allocation of the aggregate purchase price to assets acquired is as follows (in millions):
		Allocation of Purchase Price
	Inventories	$	2.7
	Property, plant and equipment	10
	Goodwill	1.5
	Other intangible assets	5.4
	Total purchase price	$	19.6
Components of intangible asset	'
	The component of the intangible assets listed in the table above as of January 3, 2012, based upon a third party appraisal, was as follows (in millions):
		Amount			Life (Years)
	Customer relationships	$	5.4		20
Calumet Packaging Acquisition [Member]	'
Business Acquisition [Line Items]	'
Purchase Price Allocation	'
	The allocation of the aggregate purchase price to assets acquired and liabilities assumed is as follows (in millions):
		Allocation of Purchase Price
	Accounts receivable	$	5.2
	Inventories	8
	Prepaid expenses and other current assets	0.3
	Property, plant and equipment	17.7
	Goodwill	0.4
	Other intangible assets	2.6
	Accounts payable	(2.7		)
	Accrued salaries, wages and benefits	(0.2		)
	Other current liabilities	(0.9		)
	Long-term debt	(3.5		)
	Total purchase price, net of cash acquired	$	26.9
Components of intangible asset	'
	The components of intangible assets listed in the table above as of January 6, 2012, based upon a third party appraisal, were as follows (in millions):
		Amount			Life (Years)
	Customer relationships	$	1.8		16
	Tradenames	0.7			9
	Non-competition agreements	0.1			2
	Total	$	2.6
	Weighted average amortization period				14
Royal Purple Acquisition [Member]	'
Business Acquisition [Line Items]	'
Purchase Price Allocation	'
	The allocation of the aggregate purchase price to assets acquired and liabilities assumed is as follows (in millions):
		Allocation of Purchase Price
	Accounts receivable	$	15.2
	Inventories	19.3
	Prepaid expenses and other current assets	0.2
	Property, plant and equipment	10.6
	Goodwill	109.2
	Other intangible assets	183.4
	Accounts payable	(3.8		)
	Accrued salaries, wages and benefits	(1.7		)
	Taxes payable	(0.2		)
	Other current liabilities	(1.0		)
	Total purchase price, net of cash acquired	$	331.2
Components of intangible asset	'
	The components of intangible assets listed in the table above as of July 3, 2012, based upon a third party appraisal, were as follows (in millions):
		Amount			Life (Years)
	Customer relationships	$	118.7		20
	Tradenames	14.8			Indefinite
	Tradenames	5.7			10
	Trade secrets	44.2			12
	Total	$	183.4
	Weighted average amortization period				18
Montana Refining Company, Inc. [Member]	'
Business Acquisition [Line Items]	'
Purchase Price Allocation	'
	The allocation of the aggregate purchase price to assets acquired and liabilities assumed is as follows (in millions):
		Allocation of Purchase Price
	Accounts receivable	$	29
	Inventories	43.7
	Prepaid expenses and other current assets	23.1
	Deposits	0.3
	Property, plant and equipment	125.9
	Goodwill	27.6
	Other noncurrent assets, net	0.3
	Accounts payable	(8.4		)
	Accrued salaries, wages and benefits	(1.4		)
	Deferred income tax liability	(27.6		)
	Accrued income taxes payable	(15.6		)
	Other taxes payable	(3.0		)
	Other current liabilities	(0.1		)
	Pension and postretirement benefit obligations	(2.2		)
	Total purchase price, net of cash acquired	$	191.6
San Antonio Acquisition [Member]	'
Business Acquisition [Line Items]	'
Purchase Price Allocation	'
	The preliminary allocation of the aggregate purchase price to assets acquired and liabilities assumed is as follows (in millions):
		Allocation of Purchase Price
	Inventories	$	17
	Property, plant and equipment, net	100.7
	Goodwill	5.7
	Accrued salaries, wages and benefits	(0.1		)
	Other current liabilities	(5.4		)
	Total purchase price, net of cash acquired	$	117.9

Inventories_Tables

Inventories (Tables)	9 Months Ended
	Sep. 30, 2013
Inventory Disclosure [Abstract]	'
Inventories	'
	Inventories consist of the following (in millions):
		September 30, 2013		December 31, 2012
	Raw materials	$	124.5	$	85.4
	Work in process	122.3		119.5
	Finished goods	312.9		348.7
		$	559.7	$	553.6

LongTerm_Debt_Tables

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
Summary of long-term debt	'
	Long-term debt consisted of the following (in millions):
		September 30,			December 31,
		2013			2012
	Borrowings under amended and restated senior secured revolving credit agreement with third-party lenders, interest payments monthly, borrowings due June 2016	$	—		$	—
	Borrowings under 2019 Notes, interest at a fixed rate of 9.375%, interest payments semiannually, borrowings due May 2019, effective interest rate of 9.94% for the nine months ended September 30, 2013	600			600
	Borrowings under 2020 Notes, interest at a fixed rate of 9.625%, interest payments semiannually, borrowings due August 2020, effective interest rate of 10.02% for the nine months ended September 30, 2013	275			275
	Capital lease obligations, at various interest rates, interest and principal payments monthly through January 2027	4.9			5.5
	Less unamortized discounts	(15.6		)	(17.0		)
	Total long-term debt	864.3			863.5
	Less current portion of long-term debt	0.5			0.8
		$	863.8		$	862.7
Maturities of long-term debt	'
	As of September 30, 2013, maturities of the Company’s long-term debt are as follows (in millions):
	Year	Maturity
	2013	$	0.2
	2014	0.4
	2015	0.3
	2016	0.3
	2017	0.4
	Thereafter	878.3
	Total	$	879.9

Derivatives_Tables

Derivatives (Tables)	9 Months Ended
	Sep. 30, 2013
Derivative [Line Items]	'
Ofsetting Assets	'
	The following tables summarize the Company’s gross fair values of its derivative instruments, presenting the impact of offsetting derivative assets and liabilities on the Company’s condensed consolidated balance sheets as of September 30, 2013 and December 31, 2012 (in millions):
		30-Sep-13												31-Dec-12
		Gross Amounts of Recognized Assets				Gross Amounts Offset in the Condensed Consolidated Balance Sheets				Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets				Gross Amounts of Recognized Assets				Gross Amounts Offset in the Condensed Consolidated Balance Sheets			Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets
	Derivative instruments designated as hedges:
	Fuel products segment:
	Crude oil swaps	$	47.1			$	(10.5	)		$	36.6			$	24.9			$	(14.4	)	$	10.5
	Gasoline swaps	—				—				—				5.2				(4.9		)	0.3
	Diesel swaps	12.5				(22.3		)		(9.8		)		7				(14.9		)	(7.9		)
	Jet fuel swaps	1.6				(5.6		)		(4.0		)		8				(7.8		)	0.2
	Total derivative instruments designated as hedges	61.2				(38.4		)		22.8				45.1				(42.0		)	3.1
	Derivative instruments not designated as hedges:
	Fuel products segment:
	Crude oil swaps	2.2				(0.9		)		1.3				0.1				(0.1		)	—
	Crude oil basis swaps	—				(3.1		)		(3.1		)		0.1				(0.1		)	—
	Gasoline swaps	0.2				(0.1		)		0.1				—				—			—
	Diesel swaps	3.6				(0.7		)		2.9				5.1				(5.1		)	—
	Jet fuel swaps	0.4				(0.2		)		0.2				—				—			—
	Specialty products segment:
	Crude oil swaps	—				—				—				1.6				(1.6		)	—
	Natural gas swaps	0.1				(1.4		)		(1.3		)		—				—			—
	Total derivative instruments not designated as hedges	6.5				(6.4		)		0.1				6.9				(6.9		)	—
	Total derivative instruments	$	67.7			$	(44.8	)		$	22.9			$	52			$	(48.9	)	$	3.1
Offsetting Liabilities	'
		30-Sep-13												31-Dec-12
		Gross Amounts of Recognized Liabilities				Gross Amounts Offset in the Condensed Consolidated Balance Sheets				Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets				Gross Amounts of Recognized Liabilities				Gross Amounts Offset in the Condensed Consolidated Balance Sheets			Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets
	Derivative instruments designated as hedges:
	Fuel products segment:
	Crude oil swaps	$	(8.8	)		$	10.5			$	1.7			$	(41.1	)		$	14.4		$	(26.7	)
	Gasoline swaps	—				—				—				(2.8		)		4.9			2.1
	Diesel swaps	(22.9		)		22.3				(0.6		)		(25.2		)		14.9			(10.3		)
	Jet fuel swaps	(5.6		)		5.6				—				(10.1		)		7.8			(2.3		)
	Total derivative instruments designated as hedges	(37.3		)		38.4				1.1				(79.2		)		42			(37.2		)
	Derivative instruments not designated as hedges:
	Fuel products segment:
	Crude oil swaps	(1.1		)		0.9				(0.2		)		(10.8		)		0.1			(10.7		)
	Crude oil basis swaps	(5.3		)		3.1				(2.2		)		(3.5		)		0.1			(3.4		)
	Gasoline swaps	(0.1		)		0.1				—				(2.2		)		—			(2.2		)
	Diesel swaps	(0.3		)		0.7				0.4				(1.2		)		5.1			3.9
	Jet fuel swaps	0.1				0.2				0.3				—				—			—
	Specialty products segment:
	Crude oil swaps	—				—				—				—				1.6			1.6
	Natural gas swaps	(3.0		)		1.4				(1.6		)		—				—			—
	Total derivative instruments not designated as hedges	(9.7		)		6.4				(3.3		)		(17.7		)		6.9			(10.8		)
	Total derivative instruments	$	(47.0	)		$	44.8			$	(2.2	)		$	(96.9	)		$	48.9		$	(48.0	)
Schedule of Gains and Losses Due to the Discontinuance of Hedge Accounting	'
		Three Months Ended September 30,								Nine Months Ended September 30,
		2013				2012				2013				2012
	Realized gain (loss) on derivative instruments	$	1.6			$	(4.8	)		$	(2.6	)		$	49.7
	Unrealized gain (loss) on derivative instruments	$	1.3			$	(35.0	)		$	8.7			$	(6.8	)
Derivative Instruments, Gain (Loss) by Hedging Relationship, by Income Statement Location, by Derivative Instrument Risk	'
	The Company recorded the following amounts in its condensed consolidated balance sheets, unaudited condensed consolidated statements of operations, unaudited condensed consolidated statements of comprehensive income (loss) and unaudited condensed consolidated statements of partners’ capital as of, and for the three months ended September 30, 2013 and 2012 related to its derivative instruments that were designated as cash flow hedges (in millions):
		Amount of Gain (Loss) Recognized in Accumulated Other Comprehensive Income (Loss) on Derivatives (Effective Portion)								Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) into Net Income (Loss) (Effective Portion)										Amount of Gain (Loss) Recognized in Net Income (Loss) on Derivatives (Ineffective Portion)
		Three Months Ended								Location of Gain (Loss)		Three Months Ended								Location of Gain (Loss)	Three Months Ended
		September 30,										September 30,									September 30,
	Type of Derivative	2013				2012						2013				2012					2013			2012
	Fuel products segment:
	Crude oil swaps	$	59.2			$	13			Cost of sales		$	11.1			$	8			Unrealized/ Realized	$	11.3		$	34.1
	Gasoline swaps	(0.3		)		8.9				Sales		(0.1		)		—				Unrealized/ Realized	(0.6		)	(23.1		)
	Diesel swaps	(33.1		)		(49.3		)		Sales		(4.4		)		(29.2		)		Unrealized/ Realized	(0.6		)	(1.2		)
	Jet fuel swaps	(11.7		)		(56.0		)		Sales		(0.2		)		(20.4		)		Unrealized/ Realized	(0.5		)	(4.5		)
	Specialty products segment:
	Crude oil swaps	—				—				Cost of sales		(0.8		)		(0.2		)		Unrealized/ Realized	—			—
	Total	$	14.1			$	(83.4	)				$	5.6			$	(41.8	)			$	9.6		$	5.3
	The Company recorded the following gains (losses) in its unaudited condensed consolidated statements of operations for the three months ended September 30, 2013 and 2012 related to its derivative instruments not designated as cash flow hedges (in millions):
		Amount of Gain (Loss) Recognized in Realized Gain (Loss) on Derivative Instruments								Amount of Gain (Loss) Recognized in Unrealized Gain (Loss) on Derivative Instruments
		Three Months Ended								Three Months Ended
		September 30,								September 30,
	Type of Derivative	2013				2012				2013				2012
	Fuel products segment:
	Crude oil swaps	$	2			$	(8.9	)		$	2.7			$	40.2
	Crude oil basis swaps	(0.2		)		—				(7.2		)		—
	Gasoline swaps	—				2.4				(0.4		)		(40.9		)
	Diesel swaps	0.9				2.8				(1.1		)		(34.2		)
	Jet fuel swaps	0.7				(0.6		)		0.5				0.5
	Specialty products segment:
	Crude oil swaps	0.1				—				(0.1		)		1
	Natural gas swaps	—				(1.4		)		(0.9		)		1.6
	Interest rate swaps	—				(0.1		)		—				0.1
	Total	$	3.5			$	(5.8	)		$	(6.5	)		$	(31.7	)
	The Company recorded the following amounts in its condensed consolidated balance sheets, unaudited condensed consolidated statements of operations, unaudited condensed consolidated statements of other comprehensive income (loss) and its unaudited condensed consolidated statements of partners’ capital as of, and for the nine months ended September 30, 2013 and 2012 related to its derivative instruments that were designated as cash flow hedges (in millions):
		Amount of Gain (Loss) Recognized in Accumulated Other Comprehensive Income (Loss) on Derivatives (Effective Portion)								Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) into Net Income (Loss) (Effective Portion)										Amount of Gain (Loss) Recognized in Net Income (Loss) on Derivatives (Ineffective Portion)
		Nine Months Ended								Location of Gain (Loss)		Nine Months Ended								Location of Gain (Loss)	Nine Months Ended
		September 30,										September 30,									September 30,
	Type of Derivative	2013				2012						2013				2012					2013			2012
	Fuel products segment:
	Crude oil swaps	$	32.5			$	(85.9	)		Cost of sales		$	(2.5	)		$	42.6			Unrealized/ Realized	$	(16.5	)	$	84
	Gasoline swaps	(0.7		)		(31.3		)		Sales		(0.2		)		(39.2		)		Unrealized/ Realized	(1.2		)	(38.4		)
	Diesel swaps	8.5				(70.7		)		Sales		(3.0		)		(52.0		)		Unrealized/ Realized	(3.9		)	(3.0		)
	Jet fuel swaps	1				(48.4		)		Sales		1.8				(89.0		)		Unrealized/ Realized	6			(2.6		)
	Specialty products segment:
	Crude oil swaps	—				—				Cost of sales		(0.5		)		(0.2		)		Unrealized/ Realized	—			—
	Total	$	41.3			$	(236.3	)				$	(4.4	)		$	(137.8	)			$	(15.6	)	$	40
	The Company recorded the following gains (losses) in its unaudited condensed consolidated statements of operations for the nine months ended September 30, 2013 and 2012 related to its derivative instruments not designated as cash flow hedges (in millions):
		Amount of Gain (Loss) Recognized in Realized Gain (Loss) on Derivative Instruments								Amount of Gain (Loss) Recognized in Unrealized Gain (Loss) on Derivative Instruments
		Nine Months Ended								Nine Months Ended
		September 30,								September 30,
	Type of Derivative	2013				2012				2013				2012
	Fuel products segment:
	Crude oil swaps	$	(6.8	)		$	(16.2	)		$	42.5			$	(40.0	)
	Crude oil basis swaps	7.3				—				(1.9		)		—
	Gasoline swaps	2.9				13.8				(0.4		)		(1.1		)
	Diesel swaps	6.4				8				(4.5		)		6.7
	Jet fuel swaps	0.7				(1.7		)		0.4				—
	Specialty products segment:
	Crude oil swaps	1.8				—				(1.6		)		1.6
	Natural gas swaps	—				(4.9		)		(2.9		)		2.7
	Interest rate swaps	—				(0.7		)		—				1
	Total	$	12.3			$	(1.7	)		$	31.6			$	(29.1	)
Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss)	'
	The effective portion of the cash flow hedges classified in accumulated other comprehensive income was $31.7 million as of September 30, 2013. The effective portion of the cash flow hedges classified in accumulated other comprehensive loss was $14.0 million as of December 31, 2012. Absent a change in the fair market value of the underlying transactions, the following other comprehensive income (loss) at September 30, 2013 will be reclassified to earnings by December 31, 2016 with balances being recognized as follows (in millions):
	Year	Accumulated Other Comprehensive Income (Loss)
	2013	$	21.4
	2014	9.9
	2015	(0.8		)
	2016	1.2
	Total	$	31.7
	Based on fair values as of September 30, 2013, the Company expects to reclassify $30.2 million of net gains on derivative instruments from accumulated other comprehensive income to earnings during the next twelve months due to actual crude oil purchases and diesel and jet fuel sales. However, the amounts actually realized will be dependent on the fair values as of the dates of settlement.
Specialty Product [Member] | Natural Gas Swap Contracts [Member]	'
Derivative [Line Items]	'
Schedule of Outstanding Derivative Positions	'
	Natural Gas Swap Contracts — Specialty Products Segment
	At September 30, 2013, the Company had the following derivatives related to natural gas purchases in its specialty products segment, none of which are designated as cash flow hedges:
	Natural Gas Swap Contracts by Expiration Dates	MMBtu			$/MMBtu
	Fourth Quarter 2013	1,250,000			$	4.12
	Calendar Year 2014	3,100,000			4.16
	Calendar Year 2015	3,500,000			4.27
	Calendar Year 2016	2,700,000			4.42
	Calendar Year 2017	1,000,000			4.29
	Totals	11,550,000
	Average price				$	4.26
	At December 31, 2012, the Company did not have any natural gas derivatives related to future natural gas purchases in its specialty products segment.
Fuel Product [Member] | Crude Oil Swaps [Member]	'
Derivative [Line Items]	'
Schedule of Outstanding Derivative Positions	'
	Crude Oil Swap Contracts
	At September 30, 2013, the Company had the following derivatives related to crude oil purchases in its fuel products segment, all of which are designated as cash flow hedges:
	Crude Oil Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Swap ($/Bbl)
	Fourth Quarter 2013	1,104,000			12,000			$	93.41
	Calendar Year 2014	6,068,500			16,626			89.93
	Calendar Year 2015	5,329,000			14,600			89.08
	Calendar Year 2016	1,098,000			3,000			85.12
	Totals	13,599,500
	Average price							$	89.49
	At September 30, 2013, the Company had the following derivatives related to crude oil purchases in its fuel products segment, none of which are designated as cash flow hedges:
	Crude Oil Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Swap ($/Bbl)
	Fourth Quarter 2013	368,000			4,000			$	96.58
	Calendar Year 2014	411,000			1,126			95.21
	Calendar Year 2015	637,500			1,747			89.89
	Totals	1,416,500
	Average price							$	93.17
	At September 30, 2013, the Company had the following derivatives to sell crude oil in its fuel products segment, none of which are designated as cash flow hedges:
	Crude Oil Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
	Fourth Quarter 2013	92,000			1,000			$	102.3
	Totals	92,000
	Average price							$	102.3
	At December 31, 2012, the Company had the following derivatives related to crude oil purchases in its fuel products segment, all of which are designated as cash flow hedges:
	Crude Oil Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Swap ($/Bbl)
	First Quarter 2013	1,665,000			18,500			$	101.67
	Second Quarter 2013	1,911,000			21,000			100.22
	Third Quarter 2013	1,426,000			15,500			95.62
	Fourth Quarter 2013	1,104,000			12,000			93.41
	Calendar Year 2014	5,110,000			14,000			89.47
	Calendar Year 2015	4,781,500			13,100			89.49
	Totals	15,997,500
	Average price							$	92.85
	At December 31, 2012, the Company had the following derivatives related to crude oil purchases in its fuel products segment, none of which are designated as cash flow hedges:
	Crude Oil Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Swap ($/Bbl)
	First Quarter 2013	630,000			7,000			$	101.34
	Second Quarter 2013	455,000			5,000			98.56
	Third Quarter 2013	368,000			4,000			96.58
	Fourth Quarter 2013	368,000			4,000			96.58
	Totals	1,821,000
	Average price							$	98.72
Fuel Product [Member] | Crude Oil Basis Swaps [Member]	'
Derivative [Line Items]	'
Schedule of Outstanding Derivative Positions	'
	Crude Oil Basis Swap Contracts
	During 2012 and 2013, the Company entered into crude oil basis swaps to mitigate the risk of future changes in pricing differentials between Canadian heavy crude oil and NYMEX WTI, pricing differentials between LLS and NYMEX WTI and pricing differentials between MSW and NYMEX WTI. At September 30, 2013, the Company had the following derivatives related to crude oil basis swaps in its fuel products segment, none of which are designated as cash flow hedges:
	Crude Oil Basis Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Differential to NYMEX WTI ($/Bbl)
	Fourth Quarter 2013	794,000			8,630			$	(17.92	)
	Totals	794,000
	Average price							$	(17.92	)
	At December 31, 2012, the Company had the following derivatives related to crude oil basis swaps in its fuel products segment, none of which are designated as cash flow hedges:
	Crude Oil Basis Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Differential to NYMEX WTI ($/Bbl)
	First Quarter 2013	180,000			2,000			$	(23.75	)
	Second Quarter 2013	364,000			4,000			(27.38		)
	Third Quarter 2013	184,000			2,000			(23.75		)
	Fourth Quarter 2013	184,000			2,000			(23.75		)
	Totals	912,000
	Average differential							$	(25.20	)
	During the third quarter of 2013, the Company entered into crude oil basis swaps for 250,000 barrels related to future crude oil purchases and sales to mitigate the risk of future changes in pricing differentials between Brent and NYMEX WTI on the Company’s reselling of crude oil. The net impact of these derivative instruments, none of which are designated as cash flow hedges, was a net gain of $0.1 million that has been recorded to unrealized gain (loss) on derivative instruments in the unaudited condensed consolidated statements of operations for the three and nine months ended September 30, 2013. The net impact of these derivative instruments will be realized upon settlement in the fourth quarter of 2013 and will be recorded to realized gain (loss) on derivative instruments in the consolidated statements of operations.
	At December 31, 2012, the Company did not have any crude oil basis swaps related to future crude oil purchases and sales to mitigate the risk of future changes in pricing differentials between Brent and NYMEX WTI.
Fuel Product [Member] | Diesel Swaps [Member]	'
Derivative [Line Items]	'
Schedule of Outstanding Derivative Positions	'
	Diesel Swap Contracts
	At September 30, 2013, the Company had the following derivatives related to diesel sales in its fuel products segment, all of which are designated as cash flow hedges:
	Diesel Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
	Fourth Quarter 2013	828,000			9,000			$	120.82
	Calendar Year 2014	4,793,500			13,133			116.88
	Calendar Year 2015	4,781,500			13,100			115.81
	Calendar Year 2016	1,098,000			3,000			111.93
	Totals	11,501,000
	Average price							$	116.25
	At September 30, 2013, the Company had the following derivatives related to diesel sales in its fuel products segment, none of which are designated as cash flow hedges:
	Diesel Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
	Fourth Quarter 2013	276,000			3,000			$	124.17
	Calendar Year 2014	501,000			1,373			122.49
	Calendar Year 2015	637,500			1,747			118.16
	Totals	1,414,500
	Average price							$	120.87
	At December 31, 2012, the Company had the following derivatives related to diesel sales in its fuel products segment, all of which are designated as cash flow hedges:
	Diesel Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
	Second Quarter 2013	546,000			6,000			$	122.74
	Third Quarter 2013	874,000			9,500			122.23
	Fourth Quarter 2013	828,000			9,000			120.82
	Calendar Year 2014	3,835,000			10,507			116
	Calendar Year 2015	4,781,500			13,100			115.81
	Totals	10,864,500
	Average price							$	117.13
	At December 31, 2012, the Company had the following derivatives related to diesel sales in its fuel products segment, none of which are designated as cash flow hedges:
	Diesel Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
	First Quarter 2013	540,000			6,000			$	130.57
	Second Quarter 2013	364,000			4,000			126.82
	Third Quarter 2013	276,000			3,000			124.17
	Fourth Quarter 2013	276,000			3,000			124.17
	Totals	1,456,000
	Average price							$	127.2
Fuel Product [Member] | Jet Fuel Swap Contracts [Member]	'
Derivative [Line Items]	'
Schedule of Outstanding Derivative Positions	'
	Jet Fuel Swap Contracts
	At September 30, 2013, the Company had the following derivatives related to jet fuel sales in its fuel products segment, all of which are designated as cash flow hedges:
	Jet Fuel Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
	Fourth Quarter 2013	276,000			3,000			$	122.36
	Calendar Year 2014	1,275,000			3,493			116.64
	Calendar Year 2015	547,500			1,500			112.51
	Totals	2,098,500
	Average price							$	116.31
	At September 30, 2013, the Company had the following derivatives to purchase jet fuel in its fuel products segment, none of which are designated as cash flow hedges:
	Jet Fuel Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Swap ($/Bbl)
	Calendar Year 2014	90,000			247			$	116.71
	Totals	90,000
	Average price							$	116.71
	At December 31, 2012, the Company had the following derivatives related to jet fuel sales in its fuel products segment, all of which are designated as cash flow hedges:
	Jet Fuel Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
	First Quarter 2013	1,035,000			11,500			$	127.39
	Second Quarter 2013	819,000			9,000			129.2
	Third Quarter 2013	368,000			4,000			125.13
	Fourth Quarter 2013	276,000			3,000			122.36
	Calendar Year 2014	1,275,000			3,493			116.64
	Totals	3,773,000
	Average price							$	123.56
Fuel Product [Member] | Gasoline Swap Contracts [Member]	'
Derivative [Line Items]	'
Schedule of Outstanding Derivative Positions	'
	Gasoline Swap Contracts
	At September 30, 2013, the Company did not have derivatives related to gasoline sales in its fuel products segment designated as cash flow hedges.
	At September 30, 2013, the Company had the following derivatives related to gasoline sales in its fuel products segment, none of which are designated as cash flow hedges:
	Gasoline Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
	Fourth Quarter 2013	92,000			1,000			$	105.5
	Totals	92,000
	Average price							$	105.5
	At September 30, 2013, the Company had the following derivatives related to gasoline purchases in its fuel products segment, none of which are designated as cash flow hedges:
	Gasoline Swap Contracts by Expiration Dates	Barrels Purchased			BPD			Average Swap ($/Bbl)
	Fourth Quarter 2013	92,000			1,000			$	105
	Totals	92,000
	Average price							$	105
	At December 31, 2012, the Company had the following derivatives related to gasoline sales in its fuel products segment, all of which are designated as cash flow hedges:
	Gasoline Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
	First Quarter 2013	630,000			7,000			$	113.59
	Second Quarter 2013	546,000			6,000			116.32
	Third Quarter 2013	184,000			2,000			114.73
	Totals	1,360,000
	Average price							$	114.84
	At December 31, 2012, the Company had the following derivatives related to gasoline sales in its fuel products segment, none of which are designated as cash flow hedges:
	Gasoline Swap Contracts by Expiration Dates	Barrels Sold			BPD			Average Swap ($/Bbl)
	First Quarter 2013	90,000			1,000			$	105.5
	Second Quarter 2013	91,000			1,000			105.5
	Third Quarter 2013	92,000			1,000			105.5
	Fourth Quarter 2013	92,000			1,000			105.5
	Totals	365,000
	Average price							$	105.5
	At December 31, 2012, the Company did not have any derivatives related to gasoline purchases in its fuel products segment designated as cash flow hedges.

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
Hierarchy of Recurring Fair Value Measurements	'
	The Company’s recurring assets and liabilities measured at fair value at September 30, 2013 and December 31, 2012 were as follows (in millions):
		30-Sep-13												31-Dec-12
		Level 1			Level 2			Level 3			Total			Level 1			Level 2			Level 3			Total
	Assets:
	Derivative assets:
	Crude oil swaps	$	—		$	—		$	37.9		$	37.9		$	—		$	—		$	10.5		$	10.5
	Crude oil basis swaps	—			—			(3.1		)	(3.1		)	—			—			—			—
	Gasoline swaps	—			—			0.1			0.1			—			—			0.3			0.3
	Diesel swaps	—			—			(6.9		)	(6.9		)	—			—			(7.9		)	(7.9		)
	Jet fuel swaps	—			—			(3.8		)	(3.8		)	—			—			0.2			0.2
	Natural gas swaps	—			—			(1.3		)	(1.3		)	—			—			—			—
	Total derivative assets	—			—			22.9			22.9			—			—			3.1			3.1
	Pension plan investments	0.2			44.1			—			44.3			38.9			2.7			—			41.6
	Total recurring assets at fair value	$	0.2		$	44.1		$	22.9		$	67.2		$	38.9		$	2.7		$	3.1		$	44.7
	Liabilities:
	Derivative liabilities:
	Crude oil swaps	$	—		$	—		$	1.5		$	1.5		$	—		$	—		$	(35.8	)	$	(35.8	)
	Crude oil basis swaps	—			—			(2.2		)	(2.2		)	—			—			(3.4		)	(3.4		)
	Gasoline swaps	—			—			—			—			—			—			(0.1		)	(0.1		)
	Diesel swaps	—			—			(0.2		)	(0.2		)	—			—			(6.4		)	(6.4		)
	Jet fuel swaps	—			—			0.3			0.3			—			—			(2.3		)	(2.3		)
	Natural gas swaps	—			—			(1.6		)	(1.6		)	—			—			—			—
	Total derivative liabilities	—			—			(2.2		)	(2.2		)	—			—			(48.0		)	(48.0		)
	RINs Obligation	—			(10.9		)	—			(10.9		)	—			(0.8		)	—			(0.8		)
	Liability Awards	(3.0		)	—			—			(3.0		)	(2.2		)	—			—			(2.2		)
	Total recurring liabilities at fair value	$	(3.0	)	$	(10.9	)	$	(2.2	)	$	(16.1	)	$	(2.2	)	$	(0.8	)	$	(48.0	)	$	(51.0	)
Summary of Net Changes in Fair Value of the Company's Level 3 Financial Assets and Liabilities	'
	The table below sets forth a summary of net changes in fair value of the Company’s Level 3 financial assets and liabilities for the nine months ended September 30, 2013 and 2012 (in millions):
		Nine Months Ended
		September 30,
		2013			2012
	Fair value at January 1,	$	(44.9	)	$	14.9
	Realized gain on derivative instruments	(5.4		)	(20.5		)
	Unrealized gain (loss) on derivative instruments	22.9			(11.3		)
	Change in fair value of cash flow hedges	41.3			(236.3		)
	Settlements	6.8			157.4
	Transfers in (out) of Level 3	—			—
	Fair value at September 30,	$	20.7		$	(95.8	)
	Total gain (loss) included in net income attributable to changes in unrealized gain (loss) relating to financial assets and liabilities held as of September 30,	$	22.9		$	(11.3	)
Carrying and Estimated Fair Value of the Company's Financial Instruments, Carried at Adjusted Historical Cost	'
	The Company’s carrying and estimated fair value of the Company’s financial instruments, carried at adjusted historical cost, at September 30, 2013 and December 31, 2012 were as follows (in millions):
		30-Sep-13						31-Dec-12
		Fair Value			Carrying Value			Fair Value			Carrying Value
	Financial Instrument:
	2019 Notes	$	663.8		$	588.7		$	658.8		$	587.6
	2020 Notes	$	308		$	270.7		$	301.8		$	270.4
	Revolving credit facility	$	—		$	—		$	—		$	—
	Capital lease and other obligations	$	4.9		$	4.9		$	5.5		$	5.5

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	9 Months Ended
	Sep. 30, 2013
Compensation and Retirement Disclosure [Abstract]	'
Components of net periodic pension and other post retirement benefits cost	'
	The components of net periodic pension and other postretirement benefits cost (credit) for the three months ended September 30, 2013 and 2012 were as follows (in millions):
		For the Three Months Ended September 30,
		2013					2012
		Pension Benefits			Other Post Retirement Employee Benefits		Pension Benefits			Other Post Retirement Employee Benefits
	Service cost	$	0.1		$	—	$	0.3		$	—
	Interest cost	0.6			—		0.6			—
	Expected return on assets	(1.2		)	—		(0.5		)	—
	Amortization of net loss	0.1			—		0.1			—
	Curtailment gain	—			—		(0.2		)	(7.0		)
	Net periodic benefit cost (credit)	$	(0.4	)	$	—	$	0.3		$	(7.0	)
	The components of net periodic pension and other postretirement benefits cost (credit) for the nine months ended September 30, 2013 and 2012 were as follows (in millions):
		For the Nine Months Ended September 30,
		2013					2012
		Pension Benefits			Other Post Retirement Employee Benefits		Pension Benefits			Other Post Retirement Employee Benefits
	Service cost	$	0.3		$	—	$	0.8		$	0.2
	Interest cost	1.8			—		1.8			0.2
	Expected return on assets	(2.2		)	—		(1.7		)	—
	Amortization of net loss	0.5			—		0.4			—
	Curtailment gain	—			—		(0.2		)	(7.0		)
	Net periodic benefit cost (credit)	$	0.4		$	—	$	1.1		$	(6.6	)
Schedule of Pension Plan assets measured at fair value	'
	The Company’s Pension Plan assets measured at fair value at September 30, 2013 and December 31, 2012 were as follows (in millions):
		30-Sep-13					31-Dec-12
		Level 1			Level 2		Level 1			Level 2
	Cash and cash equivalents	$	0.2		$	—	$	19.3		$	—
	Equity	—			10		5.9			—
	Foreign equities	—			10		2.3			—
	Commingled fund	—			—		—			2.7
	Balanced fund	—			—		3			—
	Fixed income	—			24.1		8.4			—
		$	0.2		$	44.1	$	38.9		$	2.7

Accumulated_Other_Comprehensiv1

Accumulated Other Comprehensive Income (Tables)	9 Months Ended
	Sep. 30, 2013
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]	'
Reclassification out of Accumulated Other Comprehensive Income (Loss)	'
	The table below sets forth a summary of reclassification adjustments out of accumulated other comprehensive income (loss) in the Company’s unaudited condensed consolidated statements of operations for the three and nine months ended September 30, 2013 (in millions):
	Components of Accumulated Other Comprehensive Income (Loss)		Amount Reclassified From Accumulated Other Comprehensive Income (Loss)						Location of Gain (Loss)
			For the Three Months Ended			For the Nine Months Ended
			30-Sep-13			30-Sep-13
	Derivative gains (losses) reflected in gross profit
			$	(4.7	)	$	(1.4	)	Sales
			10.3			(3.0		)	Cost of sales
			$	5.6		$	(4.4	)	Total
	Amortization of defined benefit pension and postretirement health benefit plans:
	Amortization of net loss		$	(0.1	)	$	(0.5	)	-1
			$	(0.1	)	$	(0.5	)	Total
	________________________
	-1	This accumulated other comprehensive income (loss) component is included in the computation of net periodic pension cost. See Note 12 for additional details.

Earnings_Per_Unit_Tables

Earnings Per Unit (Tables)	9 Months Ended
	Sep. 30, 2013
Earnings Per Unit [Abstract]	'
Computation of basic and diluted earnings per limited partner unit	'
	The following table sets forth the computation of basic and diluted earnings per limited partner unit for the three and nine months ended September 30, 2013 and 2012 (in millions, except unit and per unit data):
		Three Months Ended					Nine Months Ended
		September 30,					September 30,
		2013			2012		2013		2012
	Numerator for basic and diluted earnings per limited partner unit:
	Net income (loss)	$	(34.8	)	$	42.4	$	19	$	160
	General partner’s interest in net income (loss)	(0.7		)	0.8		0.4		3.2
	General partner’s incentive distribution rights	3.8			1.7		10.9		3.3
	Non-vested share based payments	—			0.2		0.2		0.9
	Net income (loss) available to limited partners	$	(37.9	)	$	39.7	$	7.5	$	152.6
	Denominator for basic and diluted earnings per limited partner unit:
	Basic weighted average limited partner units outstanding	69,626,650			57,745,806		67,367,326		54,826,636
	Effect of dilutive securities:
	Participating securities — phantom units	—			79,797		186,383		40,279
	Diluted weighted average limited partner units outstanding (1)	69,626,650			57,825,603		67,553,709		54,866,915
	Limited partners’ interest basic and diluted net income (loss) per unit	$	(0.54	)	$	0.69	$	0.11	$	2.78

Segments_and_Related_Informati1

Segments and Related Information (Tables)	9 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]	'
Reportable segment information	'
	The Company accounts for intersegment sales and transfers at cost plus a specified mark-up. Reportable segment information is as follows (in millions):
	Three Months Ended September 30, 2013	Specialty Products			Fuel Products				Combined Segments				Eliminations			Consolidated Total
	Sales:
	External customers	$	591.8		$	913.7			$	1,505.50			$	—		$	1,505.50
	Intersegment sales	—			22.5				22.5				(22.5		)	—
	Total sales	$	591.8		$	936.2			$	1,528.00			$	(22.5	)	$	1,505.50
	Depreciation and amortization	$	20.5		$	13.8			$	34.3			$	—		$	34.3
	Operating loss	$	(15.2	)	$	(3.8	)		$	(19.0	)		$	—		$	(19.0	)
	Reconciling items to net loss:
	Interest expense															(24.2		)
	Gain on derivative instruments															6.6
	Other															1.9
	Income tax expense															(0.1		)
	Net loss															$	(34.8	)
	Three Months Ended September 30, 2012	Specialty Products			Fuel Products				Combined Segments				Eliminations			Consolidated Total
	Sales:
	External customers	$	587.1		$	592.7			$	1,179.80			$	—		$	1,179.80
	Intersegment sales	275.2			14.8				290				(290.0		)	—
	Total sales	$	862.3		$	607.5			$	1,469.80			$	(290.0	)	$	1,179.80
	Depreciation and amortization	$	23.1		$	4.6			$	27.7			$	—		$	27.7
	Operating income	$	36		$	62.8			$	98.8			$	—		$	98.8
	Reconciling items to net income:
	Interest expense															(24.2		)
	Loss on derivative instruments															(32.2		)
	Other															0.2
	Income tax expense															(0.2		)
	Net income															$	42.4
	Nine Months Ended September 30, 2013	Specialty Products			Fuel Products				Combined Segments				Eliminations			Consolidated Total
	Sales:
	External customers	$	1,676.10		$	2,502.20			$	4,178.30			$	—		$	4,178.30
	Intersegment sales	—			71				71				(71.0		)	—
	Total sales	$	1,676.10		$	2,573.20			$	4,249.30			$	(71.0	)	$	4,178.30
	Depreciation and amortization	$	67.9		$	31.2			$	99.1			$	—		$	99.1
	Operating income	$	5.6		$	57.1			$	62.7			$	—		$	62.7
	Reconciling items to net income:
	Interest expense															(73.7		)
	Gain on derivative instruments															28.3
	Other															2.2
	Income tax expense															(0.5		)
	Net income															$	19
	Nine Months Ended September 30, 2012	Specialty Products			Fuel Products				Combined Segments				Eliminations			Consolidated Total
	Sales:
	External customers	$	1,722.00		$	1,714.40			$	3,436.40			$	—		$	3,436.40
	Intersegment sales	872.3			37				909.3				(909.3		)	—
	Total sales	$	2,594.30		$	1,751.40			$	4,345.70			$	(909.3	)	$	3,436.40
	Depreciation and amortization	$	60.5		$	13.7			$	74.2			—			$	74.2
	Operating income	$	114.7		$	97.6			$	212.3			—			$	212.3
	Reconciling items to net income:
	Interest expense															(61.2		)
	Gain on derivative instruments															9.2
	Other															0.3
	Income tax expense															(0.6		)
	Net income															$	160
Major product category sales	'
	The following table sets forth the major product category sales for the three months ended September 30, 2013 and 2012 (in millions):
		Three Months Ended September 30,
		2013						2012
	Specialty products:
	Lubricating oils	$	201.5		13	%		$	237			20	%
	Solvents	127.5			8	%		120.4				10	%
	Waxes	36.2			2	%		37.3				3	%
	Packaged and synthetic specialty products	59.9			4	%		58.5				5	%
	Fuels	0.3			—	%		0.3				1	%
	Asphalt and other by-products	166.4			12	%		133.6				11	%
	Total	$	591.8		39	%		$	587.1			50	%
	Fuel products:
	Gasoline	413.2			27	%		302.9				26	%
	Diesel	347.8			23	%		217.8				19	%
	Jet fuel	41.5			3	%		37.1				3	%
	Heavy fuel oils and other	111.2			8	%		34.9				2	%
	Total	$	913.7		61	%		$	592.7			50	%
	Consolidated sales	$	1,505.50		100	%		$	1,179.80			100	%
	The following table sets forth the major product category sales for the nine months ended September 30, 2013 and 2012 (in millions):
		Nine Months Ended September 30,
		2013						2012
	Specialty products:
	Lubricating oils	$	649.6		16	%		$	795.2			23	%
	Solvents	387.2			9	%		377.9				11	%
	Waxes	102.4			2	%		109.2				3	%
	Packaged and synthetic specialty products	185			4	%		116.1				3	%
	Fuels	1.2			—	%		1.7				—	%
	Asphalt and other by-products	350.7			9	%		321.9				9	%
	Total	$	1,676.10		40	%		$	1,722.00			49	%
	Fuel products:
	Gasoline	1,084.10			26	%		841.2				24	%
	Diesel	956.3			23	%		657.9				20	%
	Jet fuel	149.9			4	%		125.3				4	%
	Heavy fuel oils and other	311.9			7	%		90				3	%
	Total	$	2,502.20		60	%		$	1,714.40			51	%
	Consolidated sales	$	4,178.30		100	%		$	3,436.40			100	%

Description_of_the_Business_De

Description of the Business (Details)	9 Months Ended
	Sep. 30, 2013	Dec. 31, 2012
Limited Partners	'	'
Limited Partners' Capital Account, Units Issued	69,317,278	57,529,778
Limited Partners' Capital Account, Units Outstanding	69,317,278	57,529,778
Ownership Percentage	98.00%	'
General partner [Member]	'	'
Number of units	1,414,638	'
Ownership Percentage	2.00%	'

Acquisitions_Details

Acquisitions (Details) (USD $)	Jan. 03, 2012	Jan. 06, 2012	Jul. 03, 2012	Oct. 01, 2012	Jan. 02, 2013	Aug. 08, 2013
In Millions, unless otherwise specified	Missouri Acquisition [Member]	Calumet Packaging Acquisition [Member]	Royal Purple Acquisition [Member]	Montana Refining Company, Inc. [Member]	San Antonio Acquisition [Member]	Crude Oil Logistics Acquisition [Member]
Business Acquisition [Line Items]	'	'	'	'	'	'
Accounts receivable	'	$5.20	$15.20	$29	'	'
Inventories	2.7	8	19.3	43.7	17	'
Prepaid expenses and other current assets	'	0.3	0.2	23.1	'	'
Deposits	'	'	'	0.3	'	'
Property, plant and equipment	10	17.7	10.6	125.9	100.7	0.9
Goodwill	1.5	0.4	109.2	27.6	5.7	5.2
Other intangible assets	5.4	2.6	183.4	'	'	'
Other noncurrent assets, net	'	'	'	0.3	'	'
Accounts payable	'	-2.7	-3.8	-8.4	'	'
Accrued salaries, wages, and benefits	'	-0.2	-1.7	-1.4	-0.1	'
Accrued income taxes payable	'	'	'	-15.6	'	'
Taxes payable	'	'	-0.2	'	'	'
Other taxes payable	'	'	'	-3	'	'
Other current liabilities	'	-0.9	-1	-0.1	-5.4	'
Deferred income tax liability	'	'	'	-27.6	'	'
Pension and postretirement benefit obligations	'	'	'	-2.2	'	'
Long-term debt	'	-3.5	'	'	'	'
Total purchase price, net of cash acquired	$19.60	$26.90	$331.20	$191.60	$117.90	$6.20

Acquisitions_Details_1

Acquisitions (Details 1) (USD $)

9 Months Ended

9 Months Ended

9 Months Ended

9 Months Ended

9 Months Ended

9 Months Ended

9 Months Ended

9 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Jan. 03, 2012

Sep. 30, 2013

Jan. 06, 2012

Sep. 30, 2013

Jan. 06, 2012

Sep. 30, 2013

Jan. 06, 2012

Sep. 30, 2013

Jan. 06, 2012

Sep. 30, 2013

Jul. 03, 2012

Sep. 30, 2013

Jul. 03, 2012

Sep. 30, 2013

Jul. 03, 2012

Sep. 30, 2013

Jul. 03, 2012

Jul. 03, 2012

Missouri Acquisition [Member]

Missouri Acquisition [Member]

Calumet Packaging Acquisition [Member]

Calumet Packaging Acquisition [Member]

Calumet Packaging Acquisition [Member]

Calumet Packaging Acquisition [Member]

Calumet Packaging Acquisition [Member]

Calumet Packaging Acquisition [Member]

Calumet Packaging Acquisition [Member]

Calumet Packaging Acquisition [Member]

Royal Purple Acquisition [Member]

Royal Purple Acquisition [Member]

Royal Purple Acquisition [Member]

Royal Purple Acquisition [Member]

Royal Purple Acquisition [Member]

Royal Purple Acquisition [Member]

Royal Purple Acquisition [Member]

Royal Purple Acquisition [Member]

Royal Purple Acquisition [Member]

Customer relationships [Member]

Customer relationships [Member]

Customer relationships [Member]

Customer relationships [Member]

Tradenames [Member]

Tradenames [Member]

Non-competition agreements [Member]

Non-competition agreements [Member]

Customer relationships [Member]

Customer relationships [Member]

Tradenames [Member]

Tradenames [Member]

Trade secrets [Member]

Trade secrets [Member]

Trade Names [Member]

Component of intangible asset

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount

'

$5.40

'

$2.60

'

$1.80

'

$0.70

'

$0.10

'

$183.40

'

$118.70

'

$5.70

'

$44.20

$14.80

Life

'20 years

'

'14 years

'

'16 years

'

'9 years

'

'2 years

'

'18 years

'

'20 years

'

'10 years

'

'12 years

'

'

Acquisitions_Details_2

Acquisitions (Details 2) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Result of Sales and Operating Income [Abstract]	'	'	'	'
Sales	$276.60	'	$810.50	'
Operating income	2.7	'	28.2	'
Business Combination, Pro Forma Information [Abstract]	'	'	'	'
Sales	'	1,463.60	'	4,255.40
Net income	'	$54.10	'	$168.50
Limited partners' interest net income per unit - basic	'	$0.73	'	$2.31
Limited partners' interest net income per unit - diluted	'	$0.74	'	$2.31

Acquisitions_Details_Textual

Acquisitions (Details Textual) (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

3 Months Ended

0 Months Ended

3 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Jan. 02, 2013

Sep. 30, 2013

Aug. 09, 2013

Jun. 29, 2012

Jun. 29, 2012

Sep. 30, 2013

Missouri Acquisition [Member]

Missouri Acquisition [Member]

Calumet Packaging Acquisition [Member]

Calumet Packaging Acquisition [Member]

Royal Purple Acquisition [Member]

Royal Purple Acquisition [Member]

Montana Refining Company, Inc. [Member]

Montana Refining Company, Inc. [Member]

San Antonio Acquisition [Member]

San Antonio Acquisition [Member]

San Antonio Acquisition [Member]

Crude Oil Logistics Acquisition [Member]

Crude Oil Logistics Acquisition [Member]

9 5/8% Notes

9 5/8% Notes

9 5/8% Notes

Royal Purple Acquisition [Member]

Royal Purple Acquisition [Member]

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition costs

$0

$0.50

$0

$0.20

$0.30

$0.40

$0

$0.10

$0

$0.50

'

$0.20

'

'

'

'

Proceeds from debt

'

'

'

'

'

'

'

'

'

'

'

'

'

$262.60

$262.60

'

Senior secured revolving agreement due date

'

'

'

'

'

'

'

'

'

'

'

'

'

1-Aug-20

'

1-Aug-20

Production capacity

'

'

'

'

'

'

'

'

'

'

14,500

'

10,000

'

'

'

Inventories_Details

Inventories (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Inventories	'	'
Raw materials	$124.50	$85.40
Work in process	122.3	119.5
Finished goods	312.9	348.7
Inventories total	$559.70	$553.60

Inventories_Details_Textual

Inventories (Details Textual) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Inventory Disclosure [Abstract]	'	'
Higher replacement cost of inventories, based on current market values	$91.50	$38.30
LIFO Inventory Related Text	'last-in, first-out (LIFO)	'

Joint_Venture_Details

Joint Venture (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012	Feb. 07, 2013	Feb. 07, 2013	Feb. 07, 2013
In Millions, unless otherwise specified			Dakota Prairie Refining, LLC [Member]	Dakota Prairie Refining, LLC [Member]	Dakota Prairie Refining, LLC [Member]
				MDU Resources Group, Inc. [Member]	Proceeds From Term Loan [Member]
Schedule of Equity Method Investments [Line Items]	'	'	'	'	'
Diesel refinery construction cost	'	'	$300	'	'
Contribution amount funded	'	'	75	150	75
Equity Method Investment, Profit Sharing Percentage	'	'	50.00%	'	'
Investment in unconsolidated affiliate	$19.50	$1.90	'	'	'

Other_Noncurrent_Assets_Detail

Other Noncurrent Assets (Details Textual) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Other Assets, Noncurrent [Abstract]	'	'
Turnaround Costs, Net	$66.30	$14.30
Accumulated Amortization of Turnaround Costs	$22	$17.80

Commitments_and_Contingencies_

Commitments and Contingencies (Details Textual) (USD $)

3 Months Ended

9 Months Ended

0 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Jun. 29, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 12, 2013

Sep. 30, 2013

WDNR-Superior [Member]

WDNR-Superior [Member]

WDNR-Superior [Member]

WDNR-Superior [Member]

EPA [Member]

Superior Acquisition [Member]

LDEQ-Shreveport, Cotton Valley & Princeton [Member]

LDEQ-Shreveport, Cotton Valley & Princeton [Member]

LDEQ-Shreveport, Cotton Valley & Princeton [Member]

LDEQ-Shreveport, Cotton Valley & Princeton [Member]

LDEQ-Shreveport, Cotton Valley & Princeton [Member]

LDEQ-Shreveport, Cotton Valley & Princeton [Member]

shreveport [Member]

shreveport [Member]

shreveport [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Commitments and Contingencies (Textual) [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimates costs of equipment upgrades and conduct other discrete

'

'

$0.90

'

'

'

'

'

'

'

'

'

'

'

'

Environmental Remediation Expense

0.5

0.6

0.7

2.1

'

'

0.3

0.1

4.8

2.2

'

'

'

'

'

Payments for Environmental Liabilities

'

'

'

'

0.1

'

'

'

'

'

'

'

'

'

'

Expected Environmental Capital Expenditures

'

'

'

'

'

'

'

'

'

'

8

6

'

'

'

Indemnification Liability Maximum

'

'

'

'

'

22

'

'

'

'

'

'

'

'

'

Environmental Settlement

'

'

'

'

'

'

'

'

23-Dec-10

'

'

'

'

'

'

Specified environmental liabilities first required to contribute up to

'

'

'

'

'

6.6

'

'

'

'

'

'

'

'

1

Specified Environmental Liabilities First

'

'

'

'

'

'

'

'

'

'

'

'

5

'

'

Settlement agreement with the LDEQ

'

'

'

'

'

'

'

'

31-Jan-12

'

'

'

'

'

'

Proposed penalty

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.30

'

Commitments_and_Contingencies_1

Commitments and Contingencies (Details Textual 1) (Occupational Safety and Health Administration [Member], USD $)	0 Months Ended	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Mar. 14, 2011	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Occupational Safety and Health Administration [Member]	'	'	'	'	'
Loss Contingencies [Line Items]	'	'	'	'	'
Standard Certification	'	'	'	'ISO-9001-2008	'
Environmental Remediation Expense	'	$0.80	$0.20	$2.80	$0.50
Expected Environmental Capital Expenditures	'	'	'	1	'
Notification of Penalty	14-Mar-11	'	'	'	'
Proposed Penalty	$0.20	'	'	'	'

Commitments_and_Contingencies_2

Commitments and Contingencies (Details Textual 2) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Loss Contingencies [Line Items]	'	'
Letters of credit issued to a hedging counterparty	'	$25
Revolving Credit Facility	'	'
Loss Contingencies [Line Items]	'	'
Letters of credit outstanding amount	140.5	222.4
Availability to issue letters of credit	477.1	355.1
Revolving Credit Facility | Maximum [Member]	'	'
Debt Disclosure [Abstract]	'	'
Letter of credit sublimit percentage	80.00%	80.00%
Letter of credit sublimit	680	680
Senior secured revolving credit facility	850	850
Revolving Credit Facility | Minimum [Member]	'	'
Debt Disclosure [Abstract]	'	'
Letter of credit sublimit	400	400
Standby Letters of Credit [Member]	'	'
Loss Contingencies [Line Items]	'	'
Letters of credit issued to a hedging counterparty	$0	$25

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Debt Instrument [Line Items]	'	'
Capital lease obligations at vaious rates, interest and principal payment monthly through January 2027	1-Jan-27	'
Summary of Long-term debt	'	'
Total long-term debt	$864.30	$863.50
Less current portion of long-term debt	0.5	0.8
Long-term Debt, Excluding Current Maturities	863.8	862.7
Revolving Credit Facility	'	'
Summary of Long-term debt	'	'
Line of Credit Facility, Amount Outstanding	0	0
Borrowings under 2019 Notes, interest at a fixed rate of 9.375%, interest payments semiannually, borrowings due May 2019, effective interest rate of 9.94% for the nine months ended September 30, 2013	'	'
Debt Instrument [Line Items]	'	'
Debt Instrument, Interest Rate, Effective Percentage	9.94%	'
Debt Instrument, Interest Rate, Stated Percentage	9.38%	'
Summary of Long-term debt	'	'
Borrowings under Notes	600	600
Borrowings under 2020 Notes, interest at a fixed rate of 9.625%, interest payments semiannually, borrowings due August 2020, effective interest rate of 10.02% for the nine months ended September 30, 2013	'	'
Summary of Long-term debt	'	'
Borrowings under Notes	275	275
Capital lease obligations, at various interest rates, interest and principal payments quarterly through January 2027 [Member]	'	'
Summary of Long-term debt	'	'
Capital lease obligations, at various interest rates	4.9	5.5
Less unamortized discounts	'	'
Summary of Long-term debt	'	'
Unamortized discount	($15.60)	($17)

LongTerm_Debt_Details_1

Long-Term Debt (Details 1) (USD $)	Sep. 30, 2013
In Millions, unless otherwise specified
Maturities of long-term debt	'
2013	$0.20
2014	0.4
2015	0.3
2016	0.3
2017	0.4
Thereafter	878.3
Long-term debt	$879.90

LongTerm_Debt_Details_Textual

Long-Term Debt (Details Textual) (USD $)	0 Months Ended			9 Months Ended		9 Months Ended			9 Months Ended
In Millions, unless otherwise specified	Sep. 19, 2011	Apr. 21, 2011	Jun. 29, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2013
	9 3/8% Notes	9 3/8% Notes	9 5/8% Notes	Revolving Credit Facility	Revolving Credit Facility	Revolving Credit Facility	Revolving Credit Facility	Revolving Credit Facility	Prime Rate [Member]	London Interbank Offered Rate (LIBOR) [Member]
						Minimum [Member]	Maximum [Member]	Maximum [Member]	Revolving Credit Facility	Revolving Credit Facility
Long-Term Debt (Textual) [Abstract]	'	'	'	'	'	'	'	'	'	'
Senior secured revolving agreement due date	1-May-19	1-May-19	1-Aug-20	24-Jun-16	'	'	'	'	'	'
Senior notes	$200	$400	$275	'	'	'	'	'	'	'
Senior notes sold on	19-Sep-11	21-Apr-11	29-Jun-12	'	'	'	'	'	'	'
Debt instrument percentage of discount price	93.00%	'	98.25%	'	'	'	'	'	'	'
Net proceeds from sales of Notes	180.3	389	262.6	'	'	'	'	'	'	'
Holder of the 2020 Notes will have the right to require that the Company repurchase all or portion in cash purchase price equal to in percentage of the principle, plus any accrued and unpaid interest	101.00%	'	101.00%	'	'	'	'	'	'	'
Margin basis point	'	'	'	'	'	'	'	'	100.00%	225.00%
Debt Instrument, Frequency of Periodic Payment	'semiannually	'	'semiannually	'monthly	'	'	'	'	'	'
Customary letter of credit fee, including a fronting fee per annum on the stated amount of each outstanding letter of credit	'	'	'	0.13%	'	'	'	'	'	'
Line of Credit Facility, Current Borrowing Capacity	'	'	'	617.6	'	'	'	'	'	'
Unutilized commitments fee to the lender under the revolving credit facility	'	'	'	'	'	0.38%	0.50%	'	'	'
Available for additional borrowings based on specified availability limitations	'	'	'	477.1	355.1	'	'	'	'	'
Financial covenant availability under the revolving credit facility falls below the greater	'	'	'	'12.5% of the lesser of (a) the Borrowing Base (as defined in the revolving credit agreement) (without giving effect to the LC Reserve (as defined in the revolving credit agreement)) and (b) the credit agreement commitments then in effect and (ii) $46.4 million, (as increased, upon the effectiveness of the increase in the maximum availability under the revolving credit facility, by the same percentage as the percentage increase in the revolving credit agreement commitments), then the Company will be required to maintain as of the end of each fiscal quarter a Fixed Charge Coverage Ratio (as defined in the revolving credit agreement) of at least 1.0 to 1.0.	'	'	'	'	'	'
Percentage of lesser of the borrowing agreement	'	'	'	12.50%	'	'	'	'	'	'
Senior secured revolving credit facility	'	'	'	'	'	'	850	850	'	'
Letters of Credit Outstanding, Amount	'	'	'	$140.50	$222.40	'	'	'	'	'
Fixed Charge Coverage Ratio	'	'	'	'	'	1	2.8	'	'	'
Current interest rate of senior secured revolving credit facility	'	'	'	'prime plus a basis points margin or LIBOR plus a basis points margin	'	'	'	'	'	'

Derivatives_Details

Derivatives (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Offsetting Assets [Line Items]	'	'
Gross Amounts of Recognized Assets	$67.70	$52
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	-44.8	-48.9
Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets	22.9	3.1
Designated as Hedging Instrument [Member]	'	'
Offsetting Assets [Line Items]	'	'
Gross Amounts of Recognized Assets	61.2	45.1
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	-38.4	-42
Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets	22.8	3.1
Not Designated as Hedging Instrument [Member]	'	'
Offsetting Assets [Line Items]	'	'
Gross Amounts of Recognized Assets	6.5	6.9
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	-6.4	-6.9
Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets	0.1	0
Crude Oil Swaps [Member] | Designated as Hedging Instrument [Member] | Fuel Product [Member]	'	'
Offsetting Assets [Line Items]	'	'
Gross Amounts of Recognized Assets	47.1	24.9
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	-10.5	-14.4
Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets	36.6	10.5
Crude Oil Swaps [Member] | Not Designated as Hedging Instrument [Member] | Fuel Product [Member]	'	'
Offsetting Assets [Line Items]	'	'
Gross Amounts of Recognized Assets	2.2	0.1
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	-0.9	-0.1
Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets	1.3	0
Crude Oil Swaps [Member] | Not Designated as Hedging Instrument [Member] | Specialty Product [Member]	'	'
Offsetting Assets [Line Items]	'	'
Gross Amounts of Recognized Assets	0	1.6
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	0	-1.6
Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets	0	0
Crude Oil Basis Swaps [Member] | Not Designated as Hedging Instrument [Member] | Fuel Product [Member]	'	'
Offsetting Assets [Line Items]	'	'
Gross Amounts of Recognized Assets	0	0.1
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	-3.1	-0.1
Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets	-3.1	0
Gasoline Swaps [Member] | Designated as Hedging Instrument [Member] | Fuel Product [Member]	'	'
Offsetting Assets [Line Items]	'	'
Gross Amounts of Recognized Assets	0	5.2
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	0	-4.9
Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets	0	0.3
Gasoline Swaps [Member] | Not Designated as Hedging Instrument [Member] | Fuel Product [Member]	'	'
Offsetting Assets [Line Items]	'	'
Gross Amounts of Recognized Assets	0.2	0
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	-0.1	0
Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets	0.1	0
Diesel Swaps [Member] | Designated as Hedging Instrument [Member] | Fuel Product [Member]	'	'
Offsetting Assets [Line Items]	'	'
Gross Amounts of Recognized Assets	12.5	7
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	-22.3	-14.9
Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets	-9.8	-7.9
Diesel Swaps [Member] | Not Designated as Hedging Instrument [Member] | Fuel Product [Member]	'	'
Offsetting Assets [Line Items]	'	'
Gross Amounts of Recognized Assets	3.6	5.1
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	-0.7	-5.1
Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets	2.9	0
Jet Fuel Swaps [Member] | Designated as Hedging Instrument [Member] | Fuel Product [Member]	'	'
Offsetting Assets [Line Items]	'	'
Gross Amounts of Recognized Assets	1.6	8
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	-5.6	-7.8
Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets	-4	0.2
Jet Fuel Swaps [Member] | Not Designated as Hedging Instrument [Member] | Fuel Product [Member]	'	'
Offsetting Assets [Line Items]	'	'
Gross Amounts of Recognized Assets	0.4	0
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	-0.2	0
Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets	0.2	0
Natural Gas Swaps [Member] | Not Designated as Hedging Instrument [Member] | Specialty Product [Member]	'	'
Offsetting Assets [Line Items]	'	'
Gross Amounts of Recognized Assets	0.1	0
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	-1.4	0
Net Amounts of Assets Presented in the Condensed Consolidated Balance Sheets	($1.30)	$0

Derivatives_Details_1

Derivatives (Details 1) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Offsetting Liabilities [Line Items]	'	'
Gross Amounts of Recognized Liabilities	($47)	($96.90)
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	44.8	48.9
Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets	-2.2	-48
Designated as Hedging Instrument [Member]	'	'
Offsetting Liabilities [Line Items]	'	'
Gross Amounts of Recognized Liabilities	-37.3	-79.2
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	38.4	42
Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets	1.1	-37.2
Not Designated as Hedging Instrument [Member]	'	'
Offsetting Liabilities [Line Items]	'	'
Gross Amounts of Recognized Liabilities	-9.7	-17.7
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	6.4	6.9
Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets	-3.3	-10.8
Fuel Product [Member] | Crude Oil Swaps [Member] | Designated as Hedging Instrument [Member]	'	'
Offsetting Liabilities [Line Items]	'	'
Gross Amounts of Recognized Liabilities	-8.8	-41.1
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	10.5	14.4
Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets	1.7	-26.7
Fuel Product [Member] | Crude Oil Swaps [Member] | Not Designated as Hedging Instrument [Member]	'	'
Offsetting Liabilities [Line Items]	'	'
Gross Amounts of Recognized Liabilities	-1.1	-10.8
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	0.9	0.1
Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets	-0.2	-10.7
Fuel Product [Member] | Crude Oil Basis Swaps [Member] | Not Designated as Hedging Instrument [Member]	'	'
Offsetting Liabilities [Line Items]	'	'
Gross Amounts of Recognized Liabilities	-5.3	-3.5
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	3.1	0.1
Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets	-2.2	-3.4
Fuel Product [Member] | Gasoline Swaps [Member] | Designated as Hedging Instrument [Member]	'	'
Offsetting Liabilities [Line Items]	'	'
Gross Amounts of Recognized Liabilities	0	-2.8
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	0	4.9
Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets	0	2.1
Fuel Product [Member] | Gasoline Swaps [Member] | Not Designated as Hedging Instrument [Member]	'	'
Offsetting Liabilities [Line Items]	'	'
Gross Amounts of Recognized Liabilities	-0.1	-2.2
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	0.1	0
Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets	0	-2.2
Fuel Product [Member] | Diesel Swaps [Member] | Designated as Hedging Instrument [Member]	'	'
Offsetting Liabilities [Line Items]	'	'
Gross Amounts of Recognized Liabilities	-22.9	-25.2
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	22.3	14.9
Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets	-0.6	-10.3
Fuel Product [Member] | Diesel Swaps [Member] | Not Designated as Hedging Instrument [Member]	'	'
Offsetting Liabilities [Line Items]	'	'
Gross Amounts of Recognized Liabilities	-0.3	-1.2
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	0.7	5.1
Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets	0.4	3.9
Fuel Product [Member] | Jet Fuel Swaps [Member] | Designated as Hedging Instrument [Member]	'	'
Offsetting Liabilities [Line Items]	'	'
Gross Amounts of Recognized Liabilities	-5.6	-10.1
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	5.6	7.8
Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets	0	-2.3
Fuel Product [Member] | Jet Fuel Swaps [Member] | Not Designated as Hedging Instrument [Member]	'	'
Offsetting Liabilities [Line Items]	'	'
Gross Amounts of Recognized Liabilities	0.1	0
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	0.2	0
Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets	0.3	0
Specialty Product [Member] | Crude Oil Swaps [Member] | Not Designated as Hedging Instrument [Member]	'	'
Offsetting Liabilities [Line Items]	'	'
Gross Amounts of Recognized Liabilities	0	0
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	0	1.6
Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets	0	1.6
Specialty Product [Member] | Natural Gas Swaps [Member] | Not Designated as Hedging Instrument [Member]	'	'
Offsetting Liabilities [Line Items]	'	'
Gross Amounts of Recognized Liabilities	-3	0
Gross Amounts Offset in the Condensed Consolidated Balance Sheets	1.4	0
Net Amounts of Liabilities Presented in the Condensed Consolidated Balance Sheets	($1.60)	$0

Derivatives_Details_2

Derivatives (Details 2) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Realized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Discontinuation Cash Flow Hedge Accounting	$1.60	($4.80)	($2.60)	$49.70
Unrealized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Discontinuation Cash Flow Hedge Accounting	$1.30	($35)	$8.70	($6.80)

Derivatives_Details_3

Derivatives (Details 3) (Designated as Hedging Instrument [Member], USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Recognized in Accumulated Other Comprehensive Income (Loss) on Derivatives (Effective Portion)	$14.10	($83.40)	$41.30	($236.30)
Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) into Net Income (Loss) (Effective Portion)	5.6	-41.8	-4.4	-137.8
Amount of Gain (Loss) Recognized in Net Income (Loss) on Derivatives (Ineffective Portion)	9.6	5.3	-15.6	40
Fuel Product [Member] | Crude Oil Swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Recognized in Accumulated Other Comprehensive Income (Loss) on Derivatives (Effective Portion)	59.2	13	32.5	-85.9
Fuel Product [Member] | Gasoline swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Recognized in Accumulated Other Comprehensive Income (Loss) on Derivatives (Effective Portion)	-0.3	8.9	-0.7	-31.3
Fuel Product [Member] | Diesel swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Recognized in Accumulated Other Comprehensive Income (Loss) on Derivatives (Effective Portion)	-33.1	-49.3	8.5	-70.7
Fuel Product [Member] | Jet fuel swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Recognized in Accumulated Other Comprehensive Income (Loss) on Derivatives (Effective Portion)	-11.7	-56	1	-48.4
Fuel Product [Member] | Sales [Member] | Gasoline swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) into Net Income (Loss) (Effective Portion)	-0.1	0	-0.2	-39.2
Fuel Product [Member] | Sales [Member] | Diesel swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) into Net Income (Loss) (Effective Portion)	-4.4	-29.2	-3	-52
Fuel Product [Member] | Sales [Member] | Jet fuel swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) into Net Income (Loss) (Effective Portion)	-0.2	-20.4	1.8	-89
Fuel Product [Member] | Cost of Sales [Member] | Crude Oil Swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) into Net Income (Loss) (Effective Portion)	11.1	8	-2.5	42.6
Fuel Product [Member] | Unrealized Realized [Member] | Crude Oil Swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Recognized in Net Income (Loss) on Derivatives (Ineffective Portion)	11.3	34.1	-16.5	84
Fuel Product [Member] | Unrealized Realized [Member] | Gasoline swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Recognized in Net Income (Loss) on Derivatives (Ineffective Portion)	-0.6	-23.1	-1.2	-38.4
Fuel Product [Member] | Unrealized Realized [Member] | Diesel swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Recognized in Net Income (Loss) on Derivatives (Ineffective Portion)	-0.6	-1.2	-3.9	-3
Fuel Product [Member] | Unrealized Realized [Member] | Jet fuel swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Recognized in Net Income (Loss) on Derivatives (Ineffective Portion)	-0.5	-4.5	6	-2.6
Specialty Product [Member] | Crude Oil Swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Recognized in Accumulated Other Comprehensive Income (Loss) on Derivatives (Effective Portion)	0	0	0	0
Specialty Product [Member] | Cost of Sales [Member] | Crude Oil Swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) into Net Income (Loss) (Effective Portion)	-0.8	-0.2	-0.5	-0.2
Specialty Product [Member] | Unrealized Realized [Member] | Crude Oil Swaps [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Amount of Gain (Loss) Recognized in Net Income (Loss) on Derivatives (Ineffective Portion)	$0	$0	$0	$0

Derivatives_Details_4

Derivatives (Details 4) (Not Designated as Hedging Instrument [Member], USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Realized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$3.50	($5.80)	$12.30	($1.70)
Unrealized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-6.5	-31.7	31.6	-29.1
Fuel Product [Member] | Crude Oil Swaps [Member] | Realized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	2	-8.9	-6.8	-16.2
Fuel Product [Member] | Crude Oil Swaps [Member] | Unrealized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	2.7	40.2	42.5	-40
Fuel Product [Member] | Crude Oil Basis Swaps [Member] | Realized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-0.2	0	7.3	0
Fuel Product [Member] | Crude Oil Basis Swaps [Member] | Unrealized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-7.2	0	-1.9	0
Fuel Product [Member] | Gasoline swaps [Member] | Realized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	0	2.4	2.9	13.8
Fuel Product [Member] | Gasoline swaps [Member] | Unrealized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-0.4	-40.9	-0.4	-1.1
Fuel Product [Member] | Diesel swaps [Member] | Realized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	0.9	2.8	6.4	8
Fuel Product [Member] | Diesel swaps [Member] | Unrealized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-1.1	-34.2	-4.5	6.7
Fuel Product [Member] | Jet fuel swaps [Member] | Realized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	0.7	-0.6	0.7	-1.7
Fuel Product [Member] | Jet fuel swaps [Member] | Unrealized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	0.5	0.5	0.4	0
Specialty Product [Member] | Crude Oil Swaps [Member] | Realized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	0.1	0	1.8	0
Specialty Product [Member] | Crude Oil Swaps [Member] | Unrealized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-0.1	1	-1.6	1.6
Specialty Product [Member] | Natural gas swaps [Member] | Realized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	0	-1.4	0	-4.9
Specialty Product [Member] | Natural gas swaps [Member] | Unrealized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-0.9	1.6	-2.9	2.7
Specialty Product [Member] | Interest rate swaps [Member] | Realized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	0	-0.1	0	-0.7
Specialty Product [Member] | Interest rate swaps [Member] | Unrealized Gain (Loss) [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$0	$0.10	$0	$1

Derivatives_Details_5

Derivatives (Details 5) (USD $)	9 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Derivative [Line Items]	'	'
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$30.20	'
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]	'	'
Derivative [Line Items]	'	'
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred	31.7	-14
2013 | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]	'	'
Derivative [Line Items]	'	'
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred	21.4	'
2014 | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]	'	'
Derivative [Line Items]	'	'
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred	9.9	'
2015 | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]	'	'
Derivative [Line Items]	'	'
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred	-0.8	'
2016 | Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]	'	'
Derivative [Line Items]	'	'
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred	$1.20	'

Derivatives_Details_6

Derivatives (Details 6) (Specialty Product [Member], Not Designated as Hedging Instrument [Member], Natural Gas Swaps Purchases [Member])	Sep. 30, 2013
	MMBTU
Derivative [Line Items]	'
MMBtu	11,550,000
$/MMBtu	4.26
Fourth Quarter 2013 [Member]	'
Derivative [Line Items]	'
MMBtu	1,250,000
$/MMBtu	4.12
Calendar Year 2014 [Member]	'
Derivative [Line Items]	'
MMBtu	3,100,000
$/MMBtu	4.16
Calendar Year 2015 [Member]	'
Derivative [Line Items]	'
MMBtu	3,500,000
$/MMBtu	4.27
Calendar Year 2016 [Member]	'
Derivative [Line Items]	'
MMBtu	2,700,000
$/MMBtu	4.42
Calendar Year 2017 [Member]	'
Derivative [Line Items]	'
MMBtu	1,000,000
$/MMBtu	4.29

Derivatives_Details_7

Derivatives (Details 7) (Fuel Product [Member])	Sep. 30, 2013	Dec. 31, 2012
	bbl	bbl
Cash Flow Hedging [Member] | Crude Oil Swap Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	13,599,500	15,997,500
Average Swap ($/Bbl)	89.49	92.85
Not Designated as Hedging Instrument [Member] | Crude Oil Swaps Sold [Member]	'	'
Derivative [Line Items]	'	'
Barrels	92,000	'
Average Swap ($/Bbl)	102.3	'
Not Designated as Hedging Instrument [Member] | Crude Oil Swap Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	1,416,500	1,821,000
Average Swap ($/Bbl)	93.17	98.72
First Quarter 2013 [Member] | Cash Flow Hedging [Member] | Crude Oil Swap Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	1,665,000
BPD	'	18,500
Average Swap ($/Bbl)	'	101.67
First Quarter 2013 [Member] | Not Designated as Hedging Instrument [Member] | Crude Oil Swap Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	630,000
BPD	'	7,000
Average Swap ($/Bbl)	'	101.34
Second Quarter 2013 [Member] | Cash Flow Hedging [Member] | Crude Oil Swap Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	1,911,000
BPD	'	21,000
Average Swap ($/Bbl)	'	100.22
Second Quarter 2013 [Member] | Not Designated as Hedging Instrument [Member] | Crude Oil Swap Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	455,000
BPD	'	5,000
Average Swap ($/Bbl)	'	98.56
Third Quarter 2013 [Member] | Cash Flow Hedging [Member] | Crude Oil Swap Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	1,426,000
BPD	'	15,500
Average Swap ($/Bbl)	'	95.62
Third Quarter 2013 [Member] | Not Designated as Hedging Instrument [Member] | Crude Oil Swap Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	368,000
BPD	'	4,000
Average Swap ($/Bbl)	'	96.58
Fourth Quarter 2013 [Member] | Cash Flow Hedging [Member] | Crude Oil Swap Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	1,104,000	1,104,000
BPD	12,000	12,000
Average Swap ($/Bbl)	93.41	93.41
Fourth Quarter 2013 [Member] | Not Designated as Hedging Instrument [Member] | Crude Oil Swaps Sold [Member]	'	'
Derivative [Line Items]	'	'
Barrels	92,000	'
Average Swap ($/Bbl)	102.3	'
BPD	1,000	'
Fourth Quarter 2013 [Member] | Not Designated as Hedging Instrument [Member] | Crude Oil Swap Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	368,000	368,000
BPD	4,000	4,000
Average Swap ($/Bbl)	96.58	96.58
Calendar Year 2014 [Member] | Cash Flow Hedging [Member] | Crude Oil Swap Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	6,068,500	5,110,000
BPD	16,626	14,000
Average Swap ($/Bbl)	89.93	89.47
Calendar Year 2014 [Member] | Not Designated as Hedging Instrument [Member] | Crude Oil Swap Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	411,000	'
BPD	1,126	'
Average Swap ($/Bbl)	95.21	'
Calendar Year 2015 [Member] | Cash Flow Hedging [Member] | Crude Oil Swap Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	5,329,000	4,781,500
BPD	14,600	13,100
Average Swap ($/Bbl)	89.08	89.49
Calendar Year 2015 [Member] | Not Designated as Hedging Instrument [Member] | Crude Oil Swap Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	637,500	'
BPD	1,747	'
Average Swap ($/Bbl)	89.89	'
Calendar Year 2016 [Member] | Cash Flow Hedging [Member] | Crude Oil Swap Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	1,098,000	'
BPD	3,000	'
Average Swap ($/Bbl)	85.12	'

Derivatives_Details_8

Derivatives (Details 8) (Fuel Product [Member], Crude Oil Basis Swaps Purchased [Member], USD $)	Sep. 30, 2013	Dec. 31, 2012	Dec. 31, 2012	Dec. 31, 2012	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013
In Millions, unless otherwise specified	Not Designated as Hedging Instrument [Member]	Not Designated as Hedging Instrument [Member]	First Quarter 2013 [Member]	Second Quarter 2013 [Member]	Third Quarter 2013 [Member]	Fourth Quarter 2013 [Member]	Fourth Quarter 2013 [Member]	Fourth Quarter 2013 [Member]	Not Designated as Hedging Instrument [Member]
	bbl	bbl	Not Designated as Hedging Instrument [Member]	Not Designated as Hedging Instrument [Member]	Not Designated as Hedging Instrument [Member]	Not Designated as Hedging Instrument [Member]	Not Designated as Hedging Instrument [Member]	Not Designated as Hedging Instrument [Member]	Realized Gain (Loss) [Member]
			bbl	bbl	bbl	bbl	bbl	bbl
Derivative [Line Items]	'	'	'	'	'	'	'	'	'
Barrels	794,000	912,000	180,000	364,000	184,000	250,000	794,000	184,000	'
BPD	'	'	2,000	4,000	2,000	8,630	8,630	2,000	'
Average Differential to NYMEX WTI ($/Bbl)	-17.92	-25.2	-23.75	-27.38	-23.75	-17.92	-17.92	-23.75	'
Derivative, Gain on Derivative	'	'	'	'	'	'	'	'	$0.10

Derivatives_Details_9

Derivatives (Details 9) (Fuel Product [Member], Diesel Swaps Sold [Member] [Domain])	Sep. 30, 2013	Dec. 31, 2012
	bbl	bbl
Cash Flow Hedging [Member]	'	'
Derivatives related to diesel sales in fuel product segment	'	'
Barrels	11,501,000	10,864,500
Average Swap ($/Bbl)	116.25	117.13
Not Designated as Hedging Instrument [Member]	'	'
Derivatives related to diesel sales in fuel product segment	'	'
Barrels	1,414,500	1,456,000
Average Swap ($/Bbl)	120.87	127.2
First Quarter 2013 [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivatives related to diesel sales in fuel product segment	'	'
Barrels	'	540,000
BPD	'	6,000
Average Swap ($/Bbl)	'	130.57
Second Quarter 2013 [Member] | Cash Flow Hedging [Member]	'	'
Derivatives related to diesel sales in fuel product segment	'	'
Barrels	'	546,000
BPD	'	6,000
Average Swap ($/Bbl)	'	122.74
Second Quarter 2013 [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivatives related to diesel sales in fuel product segment	'	'
Barrels	'	364,000
BPD	'	4,000
Average Swap ($/Bbl)	'	126.82
Third Quarter 2013 [Member] | Cash Flow Hedging [Member]	'	'
Derivatives related to diesel sales in fuel product segment	'	'
Barrels	'	874,000
BPD	'	9,500
Average Swap ($/Bbl)	'	122.23
Third Quarter 2013 [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivatives related to diesel sales in fuel product segment	'	'
Barrels	'	276,000
BPD	'	3,000
Average Swap ($/Bbl)	'	124.17
Fourth Quarter 2013 [Member] | Cash Flow Hedging [Member]	'	'
Derivatives related to diesel sales in fuel product segment	'	'
Barrels	828,000	828,000
BPD	9,000	9,000
Average Swap ($/Bbl)	120.82	120.82
Fourth Quarter 2013 [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivatives related to diesel sales in fuel product segment	'	'
Barrels	276,000	276,000
BPD	3,000	3,000
Average Swap ($/Bbl)	124.17	124.17
Calendar Year 2014 [Member] | Cash Flow Hedging [Member]	'	'
Derivatives related to diesel sales in fuel product segment	'	'
Barrels	4,793,500	3,835,000
BPD	13,133	10,507
Average Swap ($/Bbl)	116.88	116
Calendar Year 2014 [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivatives related to diesel sales in fuel product segment	'	'
Barrels	501,000	'
BPD	1,373	'
Average Swap ($/Bbl)	122.49	'
Calendar Year 2015 [Member] | Cash Flow Hedging [Member]	'	'
Derivatives related to diesel sales in fuel product segment	'	'
Barrels	4,781,500	4,781,500
BPD	13,100	13,100
Average Swap ($/Bbl)	115.81	115.81
Calendar Year 2015 [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivatives related to diesel sales in fuel product segment	'	'
Barrels	637,500	'
BPD	1,747	'
Average Swap ($/Bbl)	118.16	'
Calendar Year 2016 [Member] | Cash Flow Hedging [Member]	'	'
Derivatives related to diesel sales in fuel product segment	'	'
Barrels	1,098,000	'
BPD	3,000	'
Average Swap ($/Bbl)	111.93	'

Derivatives_Details_10

Derivatives (Details 10) (Fuel Product [Member])	Sep. 30, 2013	Dec. 31, 2012
	bbl	bbl
Not Designated as Hedging Instrument [Member] | Jet Fuel Swaps Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	90,000	'
Average Swap ($/Bbl)	116.71	'
Cash flow hedges [Member] | Jet Fuel Swaps Sold [Member]	'	'
Derivative [Line Items]	'	'
Barrels	2,098,500	3,773,000
Average Swap ($/Bbl)	116.31	123.56
First Quarter 2013 [Member] | Cash flow hedges [Member] | Jet Fuel Swaps Sold [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	1,035,000
Average Swap ($/Bbl)	'	127.39
BPD	'	11,500
Second Quarter 2013 [Member] | Cash flow hedges [Member] | Jet Fuel Swaps Sold [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	819,000
Average Swap ($/Bbl)	'	129.2
BPD	'	9,000
Third Quarter 2013 [Member] | Cash flow hedges [Member] | Jet Fuel Swaps Sold [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	368,000
Average Swap ($/Bbl)	'	125.13
BPD	'	4,000
Fourth Quarter 2013 [Member] | Cash flow hedges [Member] | Jet Fuel Swaps Sold [Member]	'	'
Derivative [Line Items]	'	'
Barrels	276,000	276,000
Average Swap ($/Bbl)	122.36	122.36
BPD	3,000	3,000
Calendar Year 2014 [Member] | Not Designated as Hedging Instrument [Member] | Jet Fuel Swaps Purchased [Member]	'	'
Derivative [Line Items]	'	'
Barrels	90,000	'
BPD	247	'
Average Swap ($/Bbl)	116.71	'
Calendar Year 2014 [Member] | Cash flow hedges [Member] | Jet Fuel Swaps Sold [Member]	'	'
Derivative [Line Items]	'	'
Barrels	1,275,000	1,275,000
Average Swap ($/Bbl)	116.64	116.64
BPD	3,493	3,493
Calendar Year 2015 [Member] | Cash flow hedges [Member] | Jet Fuel Swaps Sold [Member]	'	'
Derivative [Line Items]	'	'
Barrels	547,500	'
Average Swap ($/Bbl)	112.51	'
BPD	1,500	'

Derivatives_Details_11

Derivatives (Details 11) (Fuel Product [Member])	Sep. 30, 2013	Dec. 31, 2012
	bbl	bbl
Gasoline Swaps Sold [Member] | Cash Flow Hedging [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	1,360,000
Average Swap ($/Bbl)	'	114.84
Gasoline Swaps Sold [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivative [Line Items]	'	'
Barrels	92,000	365,000
Average Swap ($/Bbl)	105.5	105.5
Gasoline Swaps Purchased [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivative [Line Items]	'	'
Barrels	92,000	'
Average Swap ($/Bbl)	105	'
First Quarter 2013 [Member] | Gasoline Swaps Sold [Member] | Cash Flow Hedging [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	630,000
BPD	'	7,000
Average Swap ($/Bbl)	'	113.59
First Quarter 2013 [Member] | Gasoline Swaps Sold [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	90,000
BPD	'	1,000
Average Swap ($/Bbl)	'	105.5
Second Quarter 2013 [Member] | Gasoline Swaps Sold [Member] | Cash Flow Hedging [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	546,000
BPD	'	6,000
Average Swap ($/Bbl)	'	116.32
Second Quarter 2013 [Member] | Gasoline Swaps Sold [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	91,000
BPD	'	1,000
Average Swap ($/Bbl)	'	105.5
Third Quarter 2013 [Member] | Gasoline Swaps Sold [Member] | Cash Flow Hedging [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	184,000
BPD	'	2,000
Average Swap ($/Bbl)	'	114.73
Third Quarter 2013 [Member] | Gasoline Swaps Sold [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivative [Line Items]	'	'
Barrels	'	92,000
BPD	'	1,000
Average Swap ($/Bbl)	'	105.5
Fourth Quarter 2013 [Member] | Gasoline Swaps Sold [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivative [Line Items]	'	'
Barrels	92,000	92,000
BPD	1,000	1,000
Average Swap ($/Bbl)	105.5	105.5
Fourth Quarter 2013 [Member] | Gasoline Swaps Purchased [Member] | Not Designated as Hedging Instrument [Member]	'	'
Derivative [Line Items]	'	'
Barrels	92,000	'
Average Swap ($/Bbl)	105	'
BPD	1,000	'

Derivatives_Details_Textual

Derivatives (Details Textual) (USD $)	9 Months Ended	12 Months Ended	9 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012	Sep. 30, 2012	Dec. 31, 2012	Dec. 31, 2012
			Realized Gain (Loss) [Member]	Unrealized Gain (Loss) [Member]	Crude Oil Swap Purchased [Member]	First Quarter 2013 [Member]
					Not Designated as Hedging Instrument [Member]	Crude Oil Swap Purchased [Member]
					Specialty Product [Member]	Not Designated as Hedging Instrument [Member]
					Unrealized Gain (Loss) [Member]	Specialty Product [Member]
						bbl
Derivative [Line Items]	'	'	'	'	'	'
Barrels	'	'	'	'	'	200,000
Derivative, Counterparty	'7	'2	'	'	'	'
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	$22.90	$3.10	'	'	'	'
Gain (Loss) on Discontinuation of Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net	'	'	-0.7	-1.7	'	'
Letter Of Credit Issued To Hedging Counterparty	'	25	'	'	'	'
Net Asset Associated with Outstanding Derivative Instruments	5	'	'	'	'	'
Net Liability Associated with Outstanding Derivative Instruments	'	7.5	'	'	'	'
Derivative, Gain on Derivative	'	'	'	'	$1.60	'

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Derivative assets:	'	'
Total derivative assets	$22.90	$3.10
Derivative liabilities:	'	'
Total derivative liabilities	-2.2	-48
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0	0
Pension plan investments	0.2	38.9
Total recurring assets at fair value	0.2	38.9
Derivative liabilities:	'	'
Total derivative liabilities	0	0
RINs Obligation	0	0
Liability Awards	-3	-2.2
Total recurring liabilities at fair value	-3	-2.2
Fair Value, Measurements, Recurring [Member] | Level 2 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0	0
Pension plan investments	44.1	2.7
Total recurring assets at fair value	44.1	2.7
Derivative liabilities:	'	'
Total derivative liabilities	0	0
RINs Obligation	-10.9	-0.8
Liability Awards	0	0
Total recurring liabilities at fair value	-10.9	-0.8
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	22.9	3.1
Pension plan investments	0	0
Total recurring assets at fair value	22.9	3.1
Derivative liabilities:	'	'
Total derivative liabilities	-2.2	-48
RINs Obligation	0	0
Liability Awards	0	0
Total recurring liabilities at fair value	-2.2	-48
Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Derivative assets:	'	'
Total derivative assets	22.9	3.1
Pension plan investments	44.3	41.6
Total recurring assets at fair value	67.2	44.7
Derivative liabilities:	'	'
Total derivative liabilities	-2.2	-48
RINs Obligation	-10.9	-0.8
Liability Awards	-3	-2.2
Total recurring liabilities at fair value	-16.1	-51
Crude Oil Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0	0
Derivative liabilities:	'	'
Total derivative liabilities	0	0
Crude Oil Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0	0
Derivative liabilities:	'	'
Total derivative liabilities	0	0
Crude Oil Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	37.9	10.5
Derivative liabilities:	'	'
Total derivative liabilities	1.5	-35.8
Crude Oil Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Derivative assets:	'	'
Total derivative assets	37.9	10.5
Derivative liabilities:	'	'
Total derivative liabilities	1.5	-35.8
Crude Oil Basis Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0	0
Derivative liabilities:	'	'
Total derivative liabilities	0	0
Crude Oil Basis Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0	0
Derivative liabilities:	'	'
Total derivative liabilities	0	0
Crude Oil Basis Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	-3.1	0
Derivative liabilities:	'	'
Total derivative liabilities	-2.2	-3.4
Crude Oil Basis Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Derivative assets:	'	'
Total derivative assets	-3.1	0
Derivative liabilities:	'	'
Total derivative liabilities	-2.2	-3.4
Gasoline Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0	0
Derivative liabilities:	'	'
Total derivative liabilities	0	0
Gasoline Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0	0
Derivative liabilities:	'	'
Total derivative liabilities	0	0
Gasoline Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0.1	0.3
Derivative liabilities:	'	'
Total derivative liabilities	0	-0.1
Gasoline Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0.1	0.3
Derivative liabilities:	'	'
Total derivative liabilities	0	-0.1
Diesel Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0	0
Derivative liabilities:	'	'
Total derivative liabilities	0	0
Diesel Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0	0
Derivative liabilities:	'	'
Total derivative liabilities	0	0
Diesel Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	-6.9	-7.9
Derivative liabilities:	'	'
Total derivative liabilities	-0.2	-6.4
Diesel Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Derivative assets:	'	'
Total derivative assets	-6.9	-7.9
Derivative liabilities:	'	'
Total derivative liabilities	-0.2	-6.4
Jet Fuel Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0	0
Derivative liabilities:	'	'
Total derivative liabilities	0	0
Jet Fuel Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0	0
Derivative liabilities:	'	'
Total derivative liabilities	0	0
Jet Fuel Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	-3.8	0.2
Derivative liabilities:	'	'
Total derivative liabilities	0.3	-2.3
Jet Fuel Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Derivative assets:	'	'
Total derivative assets	-3.8	0.2
Derivative liabilities:	'	'
Total derivative liabilities	0.3	-2.3
Natural Gas Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0	0
Derivative liabilities:	'	'
Total derivative liabilities	0	0
Natural Gas Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	0	0
Derivative liabilities:	'	'
Total derivative liabilities	0	0
Natural Gas Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]	'	'
Derivative assets:	'	'
Total derivative assets	-1.3	0
Derivative liabilities:	'	'
Total derivative liabilities	-1.6	0
Natural Gas Swaps [Member] | Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Derivative assets:	'	'
Total derivative assets	-1.3	0
Derivative liabilities:	'	'
Total derivative liabilities	($1.60)	$0

Fair_Value_Measurements_Detail1

Fair Value Measurements (Details 1) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Summary of net changes in fair value of the company's level 3 financial assets and liabilities	'	'	'	'
Realized gain on derivative instruments	$4.20	($10.10)	$5.40	$20.50
Change in fair value of cash flow hedges	14.1	-83.4	41.3	-236.3
Level 3 [Member]	'	'	'	'
Summary of net changes in fair value of the company's level 3 financial assets and liabilities	'	'	'	'
Fair value at January 1,	'	'	-44.9	14.9
Realized gain on derivative instruments	'	'	-5.4	-20.5
Unrealized gain (loss) on derivative instruments	'	'	22.9	-11.3
Change in fair value of cash flow hedges	'	'	41.3	-236.3
Settlements	'	'	6.8	157.4
Transfers in (out) of Level 3	'	'	0	0
Fair value at September 30,	20.7	-95.8	20.7	-95.8
Total gain (loss) included in net income attributable to changes in unrealized gain (loss) relating to financial assets and liabilities held as of September 30,	'	'	$22.90	($11.30)

Fair_Value_Measurements_Detail2

Fair Value Measurements (Details 2) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Two Thousand Zero One Nine Notes [Member] | Carrying Value [Member]	'	'
Financial Instrument:	'	'
Notes Payable, Fair Value Disclosure	$588.70	$587.60
Two Thousand Zero One Nine Notes [Member] | Fair Value [Member]	'	'
Financial Instrument:	'	'
Notes Payable, Fair Value Disclosure	663.8	658.8
Two Thousand Zero Two Zero Notes [Member] | Carrying Value [Member]	'	'
Financial Instrument:	'	'
Notes Payable, Fair Value Disclosure	270.7	270.4
Two Thousand Zero Two Zero Notes [Member] | Fair Value [Member]	'	'
Financial Instrument:	'	'
Notes Payable, Fair Value Disclosure	308	301.8
Revolving Credit Facility	'	'
Financial Instrument:	'	'
Revolving credit facility	0	0
Capital Lease Obligations [Member] | Carrying Value [Member]	'	'
Financial Instrument:	'	'
Capital lease and other obligations	4.9	5.5
Capital Lease Obligations [Member] | Fair Value [Member]	'	'
Financial Instrument:	'	'
Capital lease and other obligations	$4.90	$5.50

Fair_Value_Measurements_Detail3

Fair Value Measurements (Details Textual) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Fair Value Disclosures [Abstract]	'	'
Derivative Credit Risk Valuation Adjustment, Derivative Assets	$0.10	$0.10
Fair Value Measurements (Textual) [Abstract]	'	'
Liability was increased as a result of applying the appllicable credit default spread	$0.10	$0.20
Reviews for goodwill impairment annually on	1-Oct-12	'

Partners_Capital_Details

Partners' Capital (Details) (USD $)	0 Months Ended		3 Months Ended		9 Months Ended
In Millions, except Share data, unless otherwise specified	Apr. 02, 2013	Jan. 08, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Partners' capital account, units, sold in public offering	5,250,000	5,750,000	'	'	'	'
Stock price, offering price per share	$37.50	$31.81	'	'	'	'
Proceeds from public offerings of common units, net	$217.30	$175.20	'	'	$392.50	$146.60
Payments for underwriting expense	9.1	7.4	'	'	'	'
General Partner Contribution from Calumet GP, LLC	4.6	3.8	'	'	'	'
General partner interest in partners capital in percentage	2.00%	2.00%	'	'	'	'
Distributions to partners	'	'	52.6	35.9	148.7	94.2
Distributions to partners	'	'	'	'	149	94.2
General partner’s incentive distribution rights	'	'	$3.80	$1.70	$10.90	$3.30
Overallotment Option [Member]	'	'	'	'	'	'
Partners' capital account, units, sold in public offering	787,500	750,000	'	'	'	'

Employee_Benefit_Plans_Details

Employee Benefit Plans (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Pension Benefits [Member]	'	'	'	'
Components of net periodic pension and other post retirement benefits cost	'	'	'	'
Service cost	$0.10	$0.30	$0.30	$0.80
Interest cost	0.6	0.6	1.8	1.8
Expected return on assets	-1.2	-0.5	-2.2	-1.7
Amortization of net loss	0.1	0.1	0.5	0.4
Curtailment gain	0	-0.2	0	-0.2
Net periodic benefit cost (credit)	-0.4	0.3	0.4	1.1
Other Post Retirement Employee Benefits [Member]	'	'	'	'
Components of net periodic pension and other post retirement benefits cost	'	'	'	'
Service cost	0	0	0	0.2
Interest cost	0	0	0	0.2
Expected return on assets	0	0	0	0
Amortization of net loss	0	0	0	0
Curtailment gain	0	-7	0	-7
Net periodic benefit cost (credit)	$0	($7)	$0	($6.60)

Employee_Benefit_Plans_Details1

Employee Benefit Plans (Details 1) (Fair Value, Measurements, Recurring [Member], USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Level 1 [Member]	'	'
Schedule of Pension Plan assets measured at fair value	'	'
Pension assets	$0.20	$38.90
Level 2 [Member]	'	'
Schedule of Pension Plan assets measured at fair value	'	'
Pension assets	44.1	2.7
Cash and cash equivalents [Member] | Level 1 [Member]	'	'
Schedule of Pension Plan assets measured at fair value	'	'
Pension assets	0.2	19.3
Cash and cash equivalents [Member] | Level 2 [Member]	'	'
Schedule of Pension Plan assets measured at fair value	'	'
Pension assets	0	0
Equity [Member] | Level 1 [Member]	'	'
Schedule of Pension Plan assets measured at fair value	'	'
Pension assets	0	5.9
Equity [Member] | Level 2 [Member]	'	'
Schedule of Pension Plan assets measured at fair value	'	'
Pension assets	10	0
Foreign equities [Member] | Level 1 [Member]	'	'
Schedule of Pension Plan assets measured at fair value	'	'
Pension assets	0	2.3
Foreign equities [Member] | Level 2 [Member]	'	'
Schedule of Pension Plan assets measured at fair value	'	'
Pension assets	10	0
BalancedFund [Member] | Level 1 [Member]	'	'
Schedule of Pension Plan assets measured at fair value	'	'
Pension assets	0	3
BalancedFund [Member] | Level 2 [Member]	'	'
Schedule of Pension Plan assets measured at fair value	'	'
Pension assets	0	0
Commingled fund [Member] | Level 1 [Member]	'	'
Schedule of Pension Plan assets measured at fair value	'	'
Pension assets	0	0
Commingled fund [Member] | Level 2 [Member]	'	'
Schedule of Pension Plan assets measured at fair value	'	'
Pension assets	0	2.7
Fixed income [Member] | Level 1 [Member]	'	'
Schedule of Pension Plan assets measured at fair value	'	'
Pension assets	0	8.4
Fixed income [Member] | Level 2 [Member]	'	'
Schedule of Pension Plan assets measured at fair value	'	'
Pension assets	$24.10	$0

Accumulated_Other_Comprehensiv2

Accumulated Other Comprehensive Income (Loss) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]	'	'	'	'
Sales	$1,505.50	$1,179.80	$4,178.30	$3,436.40
Cost of sales	-1,443.40	-1,021.40	-3,880.80	-3,064.90
Net income (loss)	-34.8	42.4	19	160
Derivative gains (losses) reflected in gross profit | Reclassification out of Accumulated Other Comprehensive Income (Loss)	'	'	'	'
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]	'	'	'	'
Sales	-4.7	'	-1.4	'
Cost of sales	10.3	'	-3	'
Net income (loss)	5.6	'	-4.4	'
Amortization of defined benefit pension and postretirement health benefit plans: | Reclassification out of Accumulated Other Comprehensive Income (Loss)	'	'	'	'
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]	'	'	'	'
Amortization of net loss	-0.1	'	-0.5	'
Net income (loss)	($0.10)	'	($0.50)	'

Earnings_Per_Unit_Details

Earnings Per Unit (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Numerator for basic and diluted earnings per limited partner unit	'	'	'	'
Net income (loss)	($34.80)	$42.40	$19	$160
General partner’s interest in net income (loss)	-0.7	0.8	0.4	3.2
General partner’s incentive distribution rights	3.8	1.7	10.9	3.3
Non-vested share based payments	0	-0.2	-0.2	-0.9
Net income (loss) available to limited partners	($37.90)	$39.70	$7.50	$152.60
Denominator	'	'	'	'
Basic weighted average limited partner units outstanding	69,626,650	57,745,806	67,367,326	54,826,636
Participating securities — phantom units	0	79,797	186,383	40,279
Diluted weighted average limited partner units outstanding (1)	69,626,650	57,825,603	67,553,709	54,866,915
Limited partners’ interest basic and diluted net income (loss) per unit	($0.54)	$0.69	$0.11	$2.78

Segments_and_Related_Informati2

Segments and Related Information (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
	segment
Segment Reporting Information [Line Items]	'	'	'	'
Number of Reportable Segments	2	'	'	'
Sales:	'	'	'	'
Total sales	$1,505.50	$1,179.80	$4,178.30	$3,436.40
Depreciation and amortization	34.3	27.7	99.1	74.2
Operating income (loss)	-19	98.8	62.7	212.3
Reconciling Items to Net Income (Loss)	'	'	'	'
Interest expense	-24.2	-24.2	-73.7	-61.2
Gain (loss) on derivative instruments	6.6	-32.2	28.3	9.2
Other	1.9	0.2	2.2	0.3
Income tax expense	-0.1	-0.2	-0.5	-0.6
Net income (loss)	-34.8	42.4	19	160
External Customers [Member]	'	'	'	'
Sales:	'	'	'	'
Total sales	1,505.50	1,179.80	4,178.30	3,436.40
Intersegment Sales [Member]	'	'	'	'
Sales:	'	'	'	'
Total sales	0	0	0	0
Operating Segments [Member] | Specialty Product [Member]	'	'	'	'
Sales:	'	'	'	'
Total sales	591.8	862.3	1,676.10	2,594.30
Depreciation and amortization	20.5	23.1	67.9	60.5
Operating income (loss)	-15.2	36	5.6	114.7
Operating Segments [Member] | Specialty Product [Member] | External Customers [Member]	'	'	'	'
Sales:	'	'	'	'
Total sales	591.8	587.1	1,676.10	1,722
Operating Segments [Member] | Specialty Product [Member] | Intersegment Sales [Member]	'	'	'	'
Sales:	'	'	'	'
Total sales	0	275.2	0	872.3
Operating Segments [Member] | Fuel Product [Member]	'	'	'	'
Sales:	'	'	'	'
Total sales	936.2	607.5	2,573.20	1,751.40
Depreciation and amortization	13.8	4.6	31.2	13.7
Operating income (loss)	-3.8	62.8	57.1	97.6
Operating Segments [Member] | Fuel Product [Member] | External Customers [Member]	'	'	'	'
Sales:	'	'	'	'
Total sales	913.7	592.7	2,502.20	1,714.40
Operating Segments [Member] | Fuel Product [Member] | Intersegment Sales [Member]	'	'	'	'
Sales:	'	'	'	'
Total sales	22.5	14.8	71	37
Operating Segments [Member] | Combined Segments [Member]	'	'	'	'
Sales:	'	'	'	'
Total sales	1,528	1,469.80	4,249.30	4,345.70
Depreciation and amortization	34.3	27.7	99.1	74.2
Operating income (loss)	-19	98.8	62.7	212.3
Operating Segments [Member] | Combined Segments [Member] | External Customers [Member]	'	'	'	'
Sales:	'	'	'	'
Total sales	1,505.50	1,179.80	4,178.30	3,436.40
Operating Segments [Member] | Combined Segments [Member] | Intersegment Sales [Member]	'	'	'	'
Sales:	'	'	'	'
Total sales	22.5	290	71	909.3
Eliminations [Member]	'	'	'	'
Sales:	'	'	'	'
Total sales	-22.5	-290	-71	-909.3
Depreciation and amortization	0	0	0	0
Operating income (loss)	0	0	0	0
Eliminations [Member] | External Customers [Member]	'	'	'	'
Sales:	'	'	'	'
Total sales	0	0	0	0
Eliminations [Member] | Intersegment Sales [Member]	'	'	'	'
Sales:	'	'	'	'
Total sales	($22.50)	($290)	($71)	($909.30)

Segments_and_Related_Informati3

Segments and Related Information (Details 1) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Major product category sales	'	'	'	'
Sales	$1,505.50	$1,179.80	$4,178.30	$3,436.40
Product Concentration Risk [Member]	'	'	'	'
Major product category sales	'	'	'	'
Sales	1,505.50	1,179.80	4,178.30	3,436.40
Sales, percentage	100.00%	100.00%	100.00%	100.00%
Product Concentration Risk [Member] | Specialty Product [Member]	'	'	'	'
Major product category sales	'	'	'	'
Sales	591.8	587.1	1,676.10	1,722
Sales, percentage	39.00%	50.00%	40.00%	49.00%
Product Concentration Risk [Member] | Fuel Product [Member]	'	'	'	'
Major product category sales	'	'	'	'
Sales	913.7	592.7	2,502.20	1,714.40
Sales, percentage	61.00%	50.00%	60.00%	51.00%
Operating Segments [Member] | Specialty Product [Member]	'	'	'	'
Major product category sales	'	'	'	'
Sales	591.8	862.3	1,676.10	2,594.30
Operating Segments [Member] | Fuel Product [Member]	'	'	'	'
Major product category sales	'	'	'	'
Sales	936.2	607.5	2,573.20	1,751.40
Heavy Fuel Oils And Other [Member] | Product Concentration Risk [Member] | Fuel Product [Member]	'	'	'	'
Major product category sales	'	'	'	'
Sales	111.2	34.9	311.9	90
Sales, percentage	8.00%	2.00%	7.00%	3.00%
Jet Fuel [Member] | Product Concentration Risk [Member] | Fuel Product [Member]	'	'	'	'
Major product category sales	'	'	'	'
Sales	41.5	37.1	149.9	125.3
Sales, percentage	3.00%	3.00%	4.00%	4.00%
Diesel [Member] | Product Concentration Risk [Member] | Fuel Product [Member]	'	'	'	'
Major product category sales	'	'	'	'
Sales	347.8	217.8	956.3	657.9
Sales, percentage	23.00%	19.00%	23.00%	20.00%
Gasoline [Member] | Product Concentration Risk [Member] | Fuel Product [Member]	'	'	'	'
Major product category sales	'	'	'	'
Sales	413.2	302.9	1,084.10	841.2
Sales, percentage	27.00%	26.00%	26.00%	24.00%
Asphalt and Other By Products [Member] | Product Concentration Risk [Member] | Specialty Product [Member]	'	'	'	'
Major product category sales	'	'	'	'
Sales	166.4	133.6	350.7	321.9
Sales, percentage	12.00%	11.00%	9.00%	9.00%
Fuels [Member] | Product Concentration Risk [Member] | Specialty Product [Member]	'	'	'	'
Major product category sales	'	'	'	'
Sales	0.3	0.3	1.2	1.7
Sales, percentage	0.00%	1.00%	0.00%	0.00%
Packaged and synthetic specialty products [Member] | Product Concentration Risk [Member] | Specialty Product [Member]	'	'	'	'
Major product category sales	'	'	'	'
Sales	59.9	58.5	185	116.1
Sales, percentage	4.00%	5.00%	4.00%	3.00%
Waxes [Member] | Product Concentration Risk [Member] | Specialty Product [Member]	'	'	'	'
Major product category sales	'	'	'	'
Sales	36.2	37.3	102.4	109.2
Sales, percentage	2.00%	3.00%	2.00%	3.00%
Solvents [Member] | Product Concentration Risk [Member] | Specialty Product [Member]	'	'	'	'
Major product category sales	'	'	'	'
Sales	127.5	120.4	387.2	377.9
Sales, percentage	8.00%	10.00%	9.00%	11.00%
Lubricating Oils [Member] | Product Concentration Risk [Member] | Specialty Product [Member]	'	'	'	'
Major product category sales	'	'	'	'
Sales	$201.50	$237	$649.60	$795.20
Sales, percentage	13.00%	20.00%	16.00%	23.00%

Subsequent_Events_Details

Subsequent Events (Details) (USD $)	9 Months Ended			3 Months Ended		3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Oct. 16, 2013	Sep. 30, 2013	Oct. 16, 2013	Sep. 30, 2013	Sep. 30, 2013
				Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]
						Dividend Declared [Member]	Dividend Paid [Member]
Subsequent Event [Line Items]	'	'	'	'	'	'	'
TexStar pipeline capacity	'	'	'	'	30,000	'	'
TexStar contract period	'	'	15	'	'	'	'
Expected deliveries	'	'	10,000	'	'	'	'
Dividends payable, date declared	'	'	'	'	'	22-Oct-13	'
Dividends payable, amount per share	'	'	'	'	'	$0.69	'
Record date for close of business	'	'	'	'	'	'	4-Nov-13
Dividends payable	'	'	'	'	'	$52.60	'
Dividends payable, date to be paid	'	'	'	'	'	'	14-Nov-13
Quarterly distribution dividends payable amount per share	'	'	'	'	'	'	$2.74
Quarterly distribution dividends payable amount	'	'	'	'	'	'	210.4
Derivative, increase (decrease) to fair value	-3	-0.9	'	-23	'	'	'
Derivative liability, fair value, net	'	'	'	2	'	'	'
Long-term debt, increase (decrease) to fair value	'	'	'	$6	'	'	'