UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

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

For the quarterly period ended June 30, 2007.

OR

o		TRANSITION REPORT PURSUANT TO SECTION 13 OR THE SECURITIES EXCHANGE ACT OF 1934

FOR THE TRANSITION PERIOD FROM           TO        

Calumet Specialty Products Partners, L.P.

Delaware		37-1516132
(State or Other Jurisdiction of		(I.R.S. Employer
Incorporation or Organization)		Identification Number)
2780 Waterfront Pkwy E. Drive, Suite 200
Indianapolis, Indiana		46214
(Address of principal executive officers)		(Zip code)

Registrant’s telephone number including area code (317) 328-5660

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

     Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer o      Accelerated filer o      Non-accelerated filer þ

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

     At August 1, 2007, the registrant had 16,366,000 common units and 13,066,000 subordinated units outstanding.

 

 

CALUMET SPECIALTY PRODUCTS PARTNERS, L.P.
FORM 10-Q — JUNE 30, 2007 QUARTERLY REPORT

Table of Contents

		Page
Part I
Item 1. Financial Statements:
Condensed Consolidated Balance Sheets			4
Unaudited Condensed Consolidated Statements of Operations			5
Unaudited Condensed Consolidated Statements of Partners’ Capital			6
Unaudited Condensed Consolidated Statements of Cash Flows			7
Notes to Unaudited Condensed Consolidated Financial Statements			8
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations			19
Item 3. Quantitative and Qualitative Disclosures About Market Risk			32
Item 4T. Controls and Procedures			35
Part II
Item 1. Legal Proceedings			35
Item 1A. Risk Factors			35
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds			36
Item 3. Defaults Upon Senior Securities			36
Item 4. Submission of Matters to a Vote of Security Holders			36
Item 5. Other Information			36
Item 6. Exhibits			36
Certification Pursuant to Section 302
Certification Pursuant to Section 302
Certification Pursuant to Section 1350

FORWARD-LOOKING STATEMENTS

     This Quarterly Report on Form 10-Q includes certain “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. These statements can be identified by the use of forward-looking terminology including “may,” “believe,” “expect,” “anticipate,” “estimate,” “continue,” or other similar words. The statements regarding (i) the Shreveport refinery expansion project’s expected completion date, its estimated cost, the resulting increases in production levels, our ability to amend our credit facilities to permit increased capital expenditures associated with the expansion project and (ii) expected settlements with the Louisiana Department of Environmental Quality (“LDEQ”) or other environmental liabilities, as well as other matters discussed in this Form 10-Q that are not purely historical data, are forward-looking statements. These statements discuss future expectations or state other “forward-looking” information and involve risks and uncertainties. When considering these forward-looking statements, unitholders should keep in mind the risk factors and other cautionary statements included in this quarterly report and in our Annual Report on Form 10-K filed on February 23, 2007. These risk factors and cautionary statements noted throughout this Form 10-Q could cause our actual results to differ materially from those contained in any forward-looking statement. These factors include, but are not limited to:

	•		the overall demand for specialty hydrocarbon products, fuels and other refined products;
	•		our ability to produce specialty products and fuels that meet our customers’ unique and precise specifications;
	•		the results of our hedging activities;
	•		the availability of, and our ability to consummate, acquisition or combination opportunities;
	•		our access to capital to fund expansions or acquisitions and our ability to obtain debt or equity financing on satisfactory terms;
	•		successful integration and future performance of acquired assets or businesses;
	•		environmental liabilities or events that are not covered by an indemnity, insurance or existing reserves;
	•		maintenance of our credit rating and ability to receive open credit from our suppliers;
	•		demand for various grades of crude oil and resulting changes in pricing conditions;
	•		fluctuations in refinery capacity;
	•		the effects of competition;
	•		continued creditworthiness of, and performance by, counterparties;
	•		the impact of crude oil price fluctuations;
	•		the impact of current and future laws, rulings and governmental regulations;
	•		shortages or cost increases of power supplies, natural gas, materials or labor;
	•		weather interference with business operations or project construction;
	•		fluctuations in the debt and equity markets; and
	•		general economic, market or business conditions.

     Other factors described herein, or factors that are unknown or unpredictable, could also have a material adverse effect on future results. Please read Part I Item 3 “Quantitative and Qualitative Disclosures About Market Risk.” Except as required by applicable securities laws, we do not intend to update these forward-looking statements and information.

     References in this Form 10-Q to “Calumet,” “the Company,” “we,” “our,” “us” or like terms refer to Calumet Specialty Products Partners, L.P. and its subsidiaries. References to “Predecessor” in this Form 10-Q refer to Calumet Lubricants Co., Limited Partnership. The results of operations for the six months ended June 30, 2006 for Calumet include the results of operations of the Predecessor for the period of January 1, 2006 through January 31, 2006.

PART I

Item 1. Financial Statements

CALUMET SPECIALTY PRODUCTS PARTNERS, L.P.

		June 30, 2007				December 31, 2006
		(unaudited)				As adjusted, See Note 2
		(In thousands)
ASSETS
Current assets:
Cash		$	22,442			$	80,955
Accounts receivable:
Trade, less allowance for doubtful accounts of $782 and $782, respectively			127,815				97,740
Other			972				1,260
			128,787				99,000
Inventories			102,451				110,985
Prepaid expenses			2,608				1,506
Derivative assets			—				40,802
Deposits and other current assets			21				1,961
Total current assets			256,309				335,209
Property, plant and equipment, net			291,784				191,732
Other noncurrent assets, net			6,169				4,710
Total assets		$	554,262			$	531,651
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities:
Accounts payable		$	109,944			$	78,752
Accrued salaries, wages and benefits			4,301				5,675
Taxes payable			7,911				7,038
Other current liabilities			1,904				2,424
Current portion of long-term debt			1,903				500
Derivative liabilities			52,906				2,995
Total current liabilities			178,869				97,384
Long-term debt, less current portion			50,935				49,000
Total liabilities			229,804				146,384
Commitments and contingencies
Partners’ capital:
Common unitholders (16,366,000 units issued and outstanding)			290,426				274,719
Subordinated unitholders (13,066,000 units issued and outstanding)			54,863				42,347
General partner’s interest			16,038				15,950
Accumulated other comprehensive income (loss)			(36,869	)			52,251
Total partners’ capital			324,458				385,267
Total liabilities and partners’ capital		$	554,262			$	531,651

See accompanying notes to unaudited condensed consolidated financial statements.

CALUMET SPECIALTY PRODUCTS PARTNERS, L.P.

		For the Three Months Ended								For the Six Months Ended
		June 30,								June, 30
		2007				2006				2007				2006
						As adjusted, See								As adjusted, See
						Note 2								Note 2
		(In thousands except per unit data)
Sales		$	421,726			$	429,925			$	772,839			$	827,619
Cost of sales			361,255				371,465				657,333				717,910
Gross profit			60,471				58,460				115,506				109,709
Operating costs and expenses:
Selling, general and administrative			6,435				5,209				11,834				10,138
Transportation			14,048				14,595				27,617				28,502
Taxes other than income taxes			884				903				1,796				1,817
Other			162				168				342				284
Operating income			38,942				37,585				73,917				68,968
Other income (expense):
Interest expense			(1,113	)			(2,157	)			(2,128	)			(6,133	)
Interest income			569				51				1,559				245
Debt extinguishment costs			—				—				—				(2,967	)
Realized loss on derivative instruments			(4,052	)			(12,741	)			(5,788	)			(15,821	)
Unrealized gain (loss) on derivative instruments			3,285				874				(1,492	)			(16,841	)
Other			42				(20	)			(136	)			(15	)
Total other expense			(1,269	)			(13,993	)			(7,985	)			(41,532	)
Net income before income taxes			37,673				23,592				65,932				27,436
Income tax expense			255				52				305				66
Net income		$	37,418			$	23,540			$	65,627			$	27,370
Allocation of net income:
Net income applicable to Predecessor for the period through January 31, 2006			—				—				—				4,408
Net income applicable to Calumet			37,418				23,540				65,627				22,962
Minimum quarterly distribution to common unitholders			(7,365	)			(5,880	)			(14,730	)			(9,765	)
General partner’s incentive distribution rights			(9,353	)			(3,463	)			(14,102	)			(3,463	)
General partner’s interest in net income			(297	)			(264	)			(594	)			(252	)
Common unitholders’ share of income in excess of minimum quarterly distribution			(8,076	)			(4,027	)			(13,592	)			(4,027	)
Limited partners’ interest in net income		$	12,327			$	9,906			$	22,609			$	5,455
Basic and diluted net income per limited partner unit:
Common		$	0.94			$	0.76			$	1.73			$	1.06
Subordinated		$	0.94			$	0.76			$	1.73			$	0.42
Weighted average limited partner common units outstanding — basic			16,366				13,066				16,366				13,007
Weighted average limited partner subordinated units outstanding — basic			13,066				13,066				13,066				13,066
Weighted average limited partner common units outstanding — diluted			16,368				13,066				16,368				13,007
Weighted average limited partner subordinated units outstanding — diluted			13,066				13,066				13,066				13,066
Cash distributions declared per common and subordinated unit		$	0.63			$	0.45			$	1.23			$	0.75

See accompanying notes to unaudited condensed consolidated financial statements.

CALUMET SPECIALTY PRODUCTS PARTNERS, L.P.

		Accumulated Other				Partners’ Capital
		Comprehensive				General				Limited Partners
		Income (Loss)				Partner				Common				Subordinated				Total
		(In thousands)
Balance at December 31, 2006 (As Adjusted, See Note 2)		$	52,251			$	15,950			$	274,719			$	42,347			$	385,267
Comprehensive loss:
Net income							2,114				35,317				28,196				65,627
Cash flow hedge gain reclassified to net income			(5,221	)			—				—				—				(5,221	)
Change in fair value of cash flow hedges			(83,899	)			—				—				—				(83,899	)
Comprehensive loss																			(23,493	)
Amortization of phantom units							—				30				—				30
Distributions to partners							(2,026	)			(19,640	)			(15,680	)			(37,346	)
Balance at June 30, 2007		$	(36,869	)		$	16,038			$	290,426			$	54,863			$	324,458

See accompanying notes to unaudited condensed consolidated financial statements.

CALUMET SPECIALTY PRODUCTS PARTNERS, L.P.

		For the Six Months Ended
		June 30,
		2007				2006
						As adjusted, See
						Note 2
		(In thousands)
Operating activities
Net income		$	65,627			$	27,370
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization			7,454				5,634
Amortization of turnaround costs			1,862				1,514
Debt extinguishment costs			—				2,967
Other non-cash activities			47				252
Changes in assets and liabilities:
Accounts receivable			(29,787	)			(18,713	)
Inventories			8,534				3,855
Prepaid expenses			(1,102	)			7,593
Derivative activity			1,593				18,462
Deposits and other current assets			1,940				6,909
Other noncurrent assets			(4,238	)			2,947
Accounts payable			31,207				42,799
Accrued salaries, wages and benefits			(1,374	)			(5,023	)
Taxes payable			873				1,060
Other current liabilities			(520	)			1,169
Net cash provided by operating activities			82,116				98,795
Investing activities
Additions to property, plant and equipment			(103,109	)			(22,453	)
Proceeds from disposal of property, plant and equipment			49				80
Net cash used in investing activities			(103,060	)			(22,373	)
Financing activities
Repayment of borrowings, net — credit agreements with third parties			(223	)			(208,992	)
Proceeds from initial public offering, net			—				138,743
Contributions from Calumet GP, LLC			—				375
Cash distribution to Calumet Holding, LLC			—				(3,258	)
Distributions to Predecessor partners			—				(6,900	)
Distributions to partners			(37,346	)			(8,000	)
Net cash used in financing activities			(37,569	)			(88,032	)
Net decrease in cash			(58,513	)			(11,610	)
Cash at beginning of period			80,955				12,173
Cash at end of period		$	22,442			$	563
Supplemental disclosure of cash flow information
Interest paid		$	4,087			$	5,958
Income taxes paid		$	100			$	15

See accompanying notes to unaudited condensed consolidated financial statements.

CALUMET SPECIALTY PRODUCTS PARTNERS, L.P.

1. Partnership Organization and Basis of Presentation

     Calumet Specialty Products Partners, L.P. (Calumet, Partnership, or the Company) is a Delaware limited partnership. The general partner is Calumet GP, LLC, a Delaware limited liability company. On January 31, 2006, the Partnership completed the initial public offering of its common units. At that time, substantially all of the assets and liabilities of Calumet Lubricants Co., Limited Partnership and its subsidiaries (Predecessor) were contributed to Calumet. References to the Predecessor in these unaudited condensed consolidated financial statements refer to Calumet Lubricants Co., Limited Partnership and its subsidiaries. On July 5, 2006, the Partnership completed a follow-on public offering of its common units. See Note 7 for further discussion of the units sold and proceeds from these offerings. As of June 30, 2007, the Partnership had 16,366,000 common units, 13,066,000 subordinated units, and 600,653 general partner equivalent units outstanding. The general partner owns 2% of Calumet while the remaining 98% is owned by limited partners. Calumet is engaged in the production and marketing of crude oil-based specialty lubricating oils, solvents, waxes and fuels. Calumet owns refineries located in Princeton, Louisiana, Cotton Valley, Louisiana, and Shreveport, Louisiana, and a terminal located in Burnham, Illinois.

     The unaudited condensed consolidated financial statements of the Company as of June 30, 2007 and for the three and six months ended June 30, 2007 and 2006 included herein have been prepared, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and disclosures normally included in the consolidated financial statements prepared in accordance with accounting principles generally accepted in the United States of America 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 six months ended June 30, 2007 are not necessarily indicative of the results that may be expected for the year ending December 31, 2007. These unaudited condensed consolidated financial statements should be read in conjunction with the Company’s Annual Report on Form 10-K for the year ended December 31, 2006 filed on February 23, 2007.

2. New Accounting Pronouncements

     In July 2006, the Financial Accounting Standards Board (FASB) issued FASB Interpretation No. 48, Accounting for Uncertainty in Income Taxes (the “Interpretation”), an interpretation of FASB Statement No. 109. The Interpretation clarifies the accounting for uncertainty in income taxes by prescribing a recognition threshold and measurement methodology for the financial statement recognition and measurement of a tax position to be taken or expected to be taken in a tax return. The Interpretation is effective for fiscal years beginning after December 15, 2006. The Company adopted the Interpretation on January 1, 2007. The adoption had no effect on the Company’s financial position, results of operations or cash flow. Interest and penalties related to income taxes, if any, would be recorded in income tax expense on the unaudited condensed consolidated statements of operations. The Company had no unrecognized tax benefits as of June 30, 2007 and December 31, 2006. The Company’s income taxes generally remain subject to examination by major tax jurisdictions for a period of three years.

     In September 2006, the FASB issued FASB Staff Position No. AUG AIR-1, Accounting for Planned Major Maintenance Activities (the “Position”), which amends certain provisions in the AICPA Industry Audit Guides, Audits of Airlines, and APB Opinion No. 28, Interim Financial Reporting. The Position prohibits the use of the accrue-in-advance method of accounting for planned major maintenance activities (turnaround costs) and requires the use of the direct expensing method, built-in overhaul method, or deferral method. The Position is effective for fiscal years beginning after December 15, 2006.

     The Company adopted the Position on January 1, 2007 and began using the deferral method to account for turnaround costs. Under this method, actual costs of an overhaul are capitalized as incurred and amortized to cost of sales until the next overhaul date. Prior to the adoption of this standard, the Company accrued for such overhaul costs in advance and recorded the charge to cost of sales. As a result of the adoption of the Position, the Company has adjusted prior periods to account for turnaround costs as capitalized costs, recorded in other noncurrent assets on the consolidated balance sheets, in lieu of accrued turnaround costs. The cumulative effect of the adoption of the Position on prior periods was to increase partners’ capital by $3,318 as of January 1, 2005. The adoption of the Position resulted in a net decrease in cost of sales of $385 and $684, respectively, ($0.01 and $0.02, respectively, per limited partner unit) for the three and six months ended June 30, 2006 from the amount previously reported.

     In September 2006, the FASB issued FASB Statement No. 157, Fair Value Measurements (the “Statement”). The Statement applies to assets and liabilities required or permitted to be measured at fair value under other accounting pronouncements. The

Statement defines fair value, establishes a framework for measuring fair value, and expands disclosure requirements about fair value, but does not provide guidance whether assets and liabilities are required or permitted to be measured at fair value. The Statement is effective for fiscal years beginning after November 15, 2007. The Company does not anticipate that this Statement will have a material effect on its financial position, results of operations, or cash flow.

     In April 2007, the FASB issued FASB Staff Position No. FIN 39-1, Amendment of FASB Interpretation No. 39 (the “Position”), which amends certain aspects of FASB Interpretation Number 39, Offsetting of Amounts Related to Certain Contracts. The Position permits companies to offset fair value amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral against fair value amounts recognized for derivative instruments executed with the same counterparty under a master netting arrangement. The Position is effective for fiscal years beginning after November 15, 2007. The Company does not anticipate that the Position will have a material effect on its financial position, results of operations, or cash flow.

3. Inventory

     The cost of inventories is determined using the last-in, first-out (LIFO) method. Inventories are valued at the lower of cost or market value.

     Inventories consist of the following:

		June 30,				December 31,
		2007				2006
Raw materials		$	31,649			$	26,791
Work in process			23,543				30,130
Finished goods			47,259				54,064
		$	102,451			$	110,985

     The replacement cost of these inventories, based on current market values, would have been $65,468 and $46,711 higher at June 30, 2007 and December 31, 2006, respectively.

4. Shreveport Refinery Expansion

     The Company commenced an expansion project at its Shreveport refinery during the second quarter of 2006. Through June 30, 2007, the Company had incurred capital expenditures of $155,037 (including capitalized interest of $3,856 related to the expansion project, which is recorded to construction-in-progress, a component of property, plant and equipment. Total capital expenditures incurred for this expansion project includes leased components for certain refinery operating units that meet certain capital lease criteria. The Company capitalized a total of $3,537 related to this capital lease, representing the present value of the related lease payments, within property, plant and equipment on the condensed consolidated balance sheet. The Company also recorded a long-term lease obligation related to this capital lease within long-term debt and current portion of long-term debt on the condensed consolidated balance sheet.

     Management has estimated that the Company will incur approximately $45,000 of additional capital expenditures in 2007 related to the expansion project. The expansion project is expected to be completed in the third quarter of 2007 with production ramping up in the fourth quarter of 2007. Management continues to estimate the total cost of the Shreveport refinery expansion project will be approximately $200,000.

5. Derivatives

     The Company utilizes derivative instruments to minimize its price risk and volatility of cash flows associated with the purchase of crude oil and natural gas, the sale of fuel products and interest payments. In accordance with Statement of Financial Accounting Standards (SFAS) No. 133, Accounting for Derivative Instruments and Hedging Activities, which was amended in June 2000 by SFAS No. 138 and in May 2003 by SFAS No. 149 (collectively referred to as “SFAS 133”), the Company recognizes all derivative transactions as either assets or liabilities at fair value on the condensed consolidated balance sheets. To the extent a derivative instrument is designated 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. The Company accounts for certain derivatives hedging purchases of crude oil and natural gas, the sale of gasoline, diesel and jet fuel and the payment of interest as cash flow hedges. The derivatives hedging purchases and sales are recorded to cost of sales and sales in the consolidated statements of operations, respectively, upon recording the related hedged transaction in sales or cost of sales. The

derivatives hedging payments of interest are recorded in interest expense in the condensed consolidated statements of operations. For the three months ended June 30, 2007 and 2006, the Company has recorded a derivative loss of $9,399 and $7,656, respectively, to sales and a derivative loss of $7,637 and a derivative gain of $3,013, respectively, to cost of sales. An interest rate swap loss of $1 and $6, respectively, for the three months ended June 30, 2007 and 2006, was recorded to interest expense. 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 or loss on derivative instruments in the 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 or loss on derivative instruments in the consolidated statements of operations.

     Effective April 1, 2006, the Company restructured and designated certain derivative contracts for its fuel products segment as cash flow hedges of gasoline, diesel, and jet fuel sales and crude oil purchases to the extent they qualified for hedge accounting, and the effective portion of these hedges is recorded in accumulated other comprehensive income (loss) on the condensed consolidated balance sheets until the underlying transaction hedged is recognized in the consolidated statements of operations. Prior to this date, the historical impact of fair value fluctuations in the Company’s gasoline, diesel and crude oil derivative instruments for the fuel products segment had been reflected in the realized/unrealized gain (loss) on derivative instruments line items in the consolidated statements of operations. The Company utilizes third party valuations and published market data to determine the fair value of these derivatives. The decrease in realized and unrealized loss of $11,100 from the three months ended June 30, 2006 to the same period in the current year was primarily due to the unfavorable settlement of certain derivatives not designated as cash flow hedges during the three months ended June 20, 2006 with no such settlements in the current year.

     The Company assesses, both at inception of the hedge and on an on-going basis, whether the derivatives that are used in hedging transactions are highly effective in offsetting changes in cash flows of hedged items. The Company’s estimate of the ineffective portion of the hedges for the six months ended ended June 30, 2007 and 2006 were gains of $3,514 and losses of $3,786, respectively, which were recorded to unrealized loss on derivative instruments in the condensed consolidated statements of operations.

     Comprehensive income (loss) for the Company consists of the changes in fair value of cash flow hedges that have not been reclassified to net income. Comprehensive income for the three and six months ended June 30, 2007 and 2006 was as follows:

		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2007				2006				2007				2006
Net income		$	37,418			$	23,540			$	65,627			$	27,370
Cash flow hedge (gain) loss reclassified to net income			230				(775	)			(5,221	)			(497	)
Change in fair value of cash flow hedges			(22,045	)			(22,081	)			(83,899	)			(22,357	)
Total comprehensive income (loss)		$	15,603			$	684			$	(23,493	)		$	4,516

     The effective portion of the hedges classified in accumulated other comprehensive income (loss) is ($36,869) as of June 30, 2007 and, absent a change in the fair market value of the underlying transactions, will be reclassified to earnings by December 31, 2012 with balances being recognized as follows:

		Accumulated Other
		Comprehensive
Year		Income (Loss)
2007		$	(12,161	)
2008			(17,800	)
2009			(6,802	)
2010			282
2011			(369	)
2012			(19	)
Total		$	(36,869	)

     The Company is exposed to credit risk in the event of nonperformance with our counterparties on these derivative transactions. The Company does not expect nonperformance on any derivative contract.

     The Company utilizes combinations of options to manage crude oil price risk and volatility of cash flows in its specialty products segment. These combinations of options are designated as cash flow hedges of the future purchase of crude oil. The Company’s policy is generally to enter into crude oil derivative contracts for a period no greater than three to six months forward and for 50% to 75% of

anticipated crude oil purchases related to its specialty products production. At June 30, 2007, the Company had the following derivatives related to crude oil purchases used in specialty products production.

										Average				Average				Average				Average
										Lower Put				Upper Put				Lower Call				Upper Call
Crude Oil Put/Call Spread Contracts by Expiration Dates		Barrels				BPD				($/Bbl)				($/Bbl)				($/Bbl)				($/Bbl)
July 2007			248,000				8,000			$	52.52			$	62.52			$	72.52			$	82.52
August 2007			248,000				8,000			$	51.54			$	61.54			$	71.54			$	81.54
September 2007			240,000				8,000			$	54.85			$	64.85			$	74.85			$	84.85
Totals			736,000
Average price										$	52.97			$	62.97			$	72.97			$	82.97

     At December 31, 2006, the Company had the following derivatives related to crude oil purchases for its specialty products production.

										Average				Average				Average				Average
										Lower Put				Upper Put				Lower Call				Upper Call
Crude Oil Put/Call Spread Contracts by Expiration Dates		Barrels				BPD				($/Bbl)				($/Bbl)				($/Bbl)				($/Bbl)
January 2007			248,000				8,000			$	48.66			$	58.66			$	68.66			$	78.66
February 2007			224,000				8,000				49.28				59.28				69.28				79.28
March 2007			248,000				8,000				50.85				60.85				70.85				80.85
Totals			720,000
Average price										$	49.61			$	59.61			$	69.61			$	79.61

     The Company utilizes swap contracts to manage crude oil price risk and volatility of cash flows in its fuel products segment. The Company’s policy is generally to enter into crude oil swap contracts for a period no greater than five years forward and for no more than 75% of crude oil purchases used in fuels production. At June 30, 2007, the Company had the following derivatives related to crude oil purchases in its fuel products segment, all of which are designated as hedges.

Crude Oil Swap Contracts by Expiration Dates		Barrels				BPD				($/Bbl)
Third Quarter 2007			1,773,000				19,272				65.54
Fourth Quarter 2007			1,742,000				18,935				65.51
Calendar Year 2008			8,692,000				23,749				67.20
Calendar Year 2009			8,212,500				22,500				66.26
Calendar Year 2010			7,482,500				20,500				67.27
Calendar Year 2011			1,731,500				4,744				67.64
Totals			29,633,500
Average price										$	66.78

     At December 31, 2006, the Company had the following derivatives related to crude oil purchases in its fuel products segment, all of which are designated as hedges.

Crude Oil Swap Contracts by Expiration Dates		Barrels				BPD				($/Bbl)
First Quarter 2007			1,710,000				19,000			$	65.14
Second Quarter 2007			1,728,000				18,989				64.68
Third Quarter 2007			1,742,000				18,935				65.51
Fourth Quarter 2007			1,742,000				18,935				65.51
Calendar Year 2008			8,143,000				22,249				67.37
Calendar Year 2009			7,482,500				20,500				66.04
Calendar Year 2010			5,840,000				16,000				67.40
Calendar Year 2011			363,500				996				65.99
Totals			28,751,000
Average price										$	66.49

     The Company utilizes swap contracts to manage diesel, gasoline and jet fuel price risk and volatility of cash flows in its fuel products segment. The Company’s policy is generally to enter into diesel and gasoline swap contracts for a period no greater than five years forward and for no more than 75% of forecasted fuels sales.

     At June 30, 2007, the Company had the following derivatives related to diesel and jet fuel sales in its fuel products segment, all of which are designated as hedges except for 58,168 barrels in 2007. The Company recognized a loss of $256 in unrealized (loss) gain on derivative instruments in the consolidated statements of operations during the six months ended June 30, 2007 related to these barrels not designated as cash flow hedges.

Diesel Swap Contracts by Expiration Dates		Barrels				BPD				($/Bbl)
Third Quarter 2007			1,102,000				11,978				81.36
Fourth Quarter 2007			1,102,000				11,978				81.36
Calendar Year 2008			5,307,000				14,500				82.11
Calendar Year 2009			4,745,000				13,000				80.51
Calendar Year 2010			4,745,000				13,000				80.41
Calendar Year 2011			1,458,500				3,996				79.70
Totals			18,459,500
Average price										$	80.98

     At December 31, 2006, the Company had the following derivatives related to diesel and jet fuel sales in its fuel products segment, all of which are designated as hedges except for 169,855 barrels in 2007. As a result of these barrels not being designated as hedges, the Company recognized a gain of $1,314 in unrealized (loss) gain on derivative instruments in the consolidated statements of operations during the year ended December 31, 2006.

Diesel Swap Contracts by Expiration Dates		Barrels				BPD				($/Bbl)
First Quarter 2007			1,080,000				12,000			$	81.10
Second Quarter 2007			1,092,000				12,000				80.74
Third Quarter 2007			1,102,000				11,978				81.36
Fourth Quarter 2007			1,102,000				11,978				81.36
Calendar Year 2008			4,941,000				13,500				82.18
Calendar Year 2009			4,562,500				12,500				80.50
Calendar Year 2010			3,650,000				10,000				80.52
Calendar Year 2011			273,000				748				76.52
Totals			17,802,500
Average price										$	81.07

     At June 30, 2007, the Company had the following derivatives related to gasoline sales in its fuel products segment, all of which are designated as hedges.

Gasoline Swap Contracts by Expiration Dates		Barrels				BPD				($/Bbl)
Third Quarter 2007			671,000				7,293				73.54
Fourth Quarter 2007			640,000				6,957				72.67
Calendar Year 2008			3,385,000				9,249				75.87
Calendar Year 2009			3,467,500				9,500				73.83
Calendar Year 2010			2,737,500				7,500				75.10
Calendar Year 2011			273,000				748				75.30
Totals			11,174,000
Average price										$	74.71

     At December 31, 2006, the Company had the following derivatives related to gasoline sales in its fuel products segment, all of which are designated as hedges.

Gasoline Swap Contracts by Expiration Dates		Barrels				BPD				($/Bbl)
First Quarter 2007			630,000				7,000			$	72.09
Second Quarter 2007			636,000				6,989				71.38
Third Quarter 2007			640,000				6,957				72.67
Fourth Quarter 2007			640,000				6,957				72.67
Calendar Year 2008			3,202,000				8,749				76.17
Calendar Year 2009			2,920,000				8,000				73.45
Calendar Year 2010			2,190,000				6,000				75.27
Calendar Year 2011			90,500				248				70.87
Totals			10,948,500
Average price										$	74.30

     The Company utilizes swap contracts to manage natural gas price risk and volatility of cash flows. These swap contracts are designated as cash flow hedges of the future purchase of natural gas. The Company’s policy is generally to enter into natural gas derivative contracts to hedge approximately 50% or more of its upcoming fall and winter months’ anticipated natural gas requirements. At June 30, 2007, the Company had the following derivatives related to natural gas purchases.

Natural Gas Swap Contracts by Expiration Dates		MMbtu				$/MMbtu
Third Quarter 2007			600,000			$	8.77
Fourth Quarter 2007			900,000				8.77
First Quarter 2008			850,000				8.76
Totals			2,350,000
Average price						$	8.77

     At December 31, 2006, the Company had the following derivatives related to natural gas purchases.

Natural Gas Swap Contracts by Expiration Dates		MMbtu				$/MMbtu
First Quarter 2007			600,000			$	8.87
Third Quarter 2007			100,000				7.99
Fourth Quarter 2007			150,000				7.99
First Quarter 2008			150,000				7.99
Totals			1,000,000
Average price						$	8.52

Interest Rate Swap Contracts

     In 2006, the Company entered into a forward swap contract to manage interest rate risk related to its variable rate senior secured first lien term loan. The Company hedges the interest payments related to 85% of its future term loan indebtedness. This swap contract is designated as a cash flow hedge of the future payment of interest with three-month LIBOR fixed at 5.44% per annum.

6. 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 taxing and regulatory authorities, such as the Louisiana Department of Environmental Quality (“LDEQ”), Environmental Protection Agency (“EPA”), Internal Revenue Service (“IRS”) and Occupational Safety and Health Administration, as the result of audits or reviews of the Company’s business. Management is of the opinion that the ultimate resolution of any known claims, either individually or in the aggregate, will not have a material adverse impact on the Company’s financial position, results of operations or cash flow.

     The Company operates crude oil and specialty hydrocarbon refining and terminal operations, which are subject to stringent and complex federal, state, and local laws and regulations governing the discharge of materials into the environment or otherwise relating to environmental protection. These laws and regulations can impair the Company’s operations that affect the environment in many ways, such as requiring the acquisition of permits to conduct regulated activities; restricting the manner in which the Company can release materials into the environment; requiring remedial activities or capital expenditures to mitigate pollution from former or current operations; and imposing substantial liabilities for pollution resulting from its operations. Certain environmental 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.

     Failure to comply with environmental laws and regulations may result in the triggering of administrative, civil and criminal measures, including the assessment of monetary penalties, the imposition of remedial obligations, and the issuance of injunctions limiting or prohibiting some or all of the Company’s operations. On occasion, the Company receives notices of violation, enforcement and other complaints from regulatory agencies alleging non-compliance with applicable environmental laws and regulations. In particular, the LDEQ has proposed penalties totaling $191 and supplemental projects for the following alleged violations: (i) a May 2001 notification received by the Cotton Valley refinery from the LDEQ regarding several alleged violations of various air emission regulations, as identified in the course of the Company’s Leak Detection and Repair program, and also for failure to submit various reports related to the facility’s air emissions; (ii) a December 2002 notification received by the Company’s Cotton Valley refinery from the LDEQ regarding alleged violations for excess emissions, as identified in the LDEQ’s file review of the Cotton Valley refinery; and (iii) a December 2004 notification received by the Cotton Valley refinery from the LDEQ regarding alleged violations for the construction of a multi-tower pad and associated pump pads without a permit issued by the agency. The Company is currently in settlement negotiations with the LDEQ to resolve these matters, as well as a number of similar matters at the Princeton refinery, for which no penalty has yet been proposed. The Company anticipates that any penalties that may be assessed due to the alleged violations at its Princeton refinery as well as the aforementioned penalties related to the Cotton Valley refinery will be consolidated in a settlement agreement that the Company anticipates executing with the LDEQ in connection with the agency’s “Small Refinery and Single Site Refinery Initiative” described below.

     The Company has recently entered into discussions on a voluntary basis with the LDEQ regarding the Company’s participation in that agency’s “Small Refinery and Single Site Refinery Initiative.” This state initiative is patterned after the EPA’s “National Petroleum Refinery Initiative,” which is a coordinated, integrated compliance and enforcement strategy to address federal Clean Air Act compliance issues at the nation’s largest petroleum refineries. The Company expects that the LDEQ’s primary focus under the state initiative will be on four compliance and enforcement concerns: (i) Prevention of Significant Deterioration/New Source Review; (ii) New Source Performance Standards for fuel gas combustion devices, including flares, heaters and boilers; (iii) Leak Detection and Repair requirements; and (iv) Benzene Waste Operations National Emission Standards for Hazardous Air Pollutants. The Company is only in the beginning stages of discussion with the LDEQ and, consequently, while no significant compliance and enforcement expenditures have been requested as a result of the Company’s discussions, the Company anticipates that it will ultimately be required to make emissions reductions requiring capital investments between an aggregate of $1,000 and $3,000 over a three to five year period at the Company’s three Louisiana refineries.

     Voluntary remediation of subsurface contamination is in process at each 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 its financial condition. However, such costs are often unpredictable and, therefore, there can be no assurance that the future costs will not become material.

     The Company is indemnified by Shell Oil Company, as successor to Pennzoil-Quaker State Company and Atlas Processing Company, for specified environmental liabilities arising from the operations of the Shreveport refinery prior to the Company’s acquisition of the facility. The indemnity is unlimited in amount and duration, but requires the Company to contribute up to $1,000 of the first $5,000 of indemnified costs for certain of the specified environmental liabilities.

     On December 27, 2006, the LDEQ approved the Company’s application for a modification of its air emissions permit for the Shreveport refinery expansion. The Company was required to obtain approval of this modified air emissions permit from the LDEQ prior to commencing construction of the expansion activities. Upon receipt of the permit approval from the LDEQ, the Company commenced construction of the Shreveport refinery expansion project. The approval granted by the LDEQ for the Company’s application for a modified air quality permit was challenged by an individual on her own behalf and on behalf of a neighborhood group and was subsequently voluntarily dismissed on July 11, 2007.

     The Company has agreements with various financial institutions for standby letters of credit which have been issued to domestic vendors. As of June 30, 2007 and December 31, 2006, the Company had outstanding standby letters of credit of $64,446 and $42,775, respectively, under its senior secured revolving credit facility. The Company also had a $50,000 letter of credit outstanding under the senior secured first lien letter of credit facility for its fuel products hedging program, which bears interest at 3.50%.

7. Partners’ Capital

     On January 31, 2006, the Partnership completed the initial public offering of its common units and sold 5,699,900 of those units to the underwriters in the initial public offering at a price to the public of $21.50 per common unit. The Partnership also sold a total of 750,100 common units to certain relatives of the chairman of our general partner at a price of $19.995 per common unit. In addition, on February 8, 2006, the Partnership sold an additional 854,985 common units to the underwriters at a price to the public of $21.50 per common unit pursuant to the underwriters’ over-allotment option. Each of these issuances was made pursuant to the Partnership’s Registration Statement on Form S-1 (File No. 333-128880) declared effective by the Securities and Exchange Commission on January 29, 2006. The proceeds received by the Partnership (net of underwriting discounts and structuring fees and before expenses) from the sale of an aggregate of 7,304,985 units were approximately $144,400. The net proceeds were used to: (i) repay indebtedness and accrued interest under the first lien term loan facility in the amount of approximately $125,700, (ii) repay indebtedness under the secured revolving credit facility in the amount of approximately $13,100 and (iii) pay transaction fees and expenses in the amount of approximately $5,600. Underwriting discounts totaled approximately $11,600 (including certain structuring fees paid to certain of the underwriters of approximately $2,400).

     On July 5, 2006, the Partnership completed a follow-on public offering of its common units in which it sold 3,300,000 common units to the underwriters of the offering at a price to the public of $32.94 per common unit. This issuance was made pursuant to the Partnership’s Registration Statement on Form S-1 (File No. 333-134993) declared effective by the Securities and Exchange Commission on June 28, 2006. The proceeds received by the Partnership (net of underwriting discounts, commissions and expenses but before its general partner’s capital contribution) from this offering was $103,479. The use of proceeds from the offering was to: (i) repay all of its borrowings under its revolving credit facility, which were approximately $9,243 as of June 30, 2006, (ii) fund the future construction and other start-up costs of the planned expansion project at the Shreveport refinery and (iii) to the extent available, for general partnership purposes. Underwriting discounts totaled $4,620. The general partner contributed $2,218 to retain its 2% general partner interest.

     Of the 16,366,000 common units outstanding at June 30, 2007, 10,604,985 are held by the public, with the remaining 5,761,015 held by affiliates. All of the 13,066,000 subordinated units are held by affiliates.

     The Predecessor’s policy was that distributions were limited to the amount necessary to pay each partner’s federal income tax and state income tax on their share of partnership income. However, additional distributions to the partners could be made at the sole discretion of the general partner. In January 2006, the Predecessor made its final distribution of $6,900 to its partners. Subsequent to January 31, 2006, Calumet’s distribution policy is as defined in the Partnership Agreement. During the six months ended June 30, 2007 and 2006, the Company made distributions of $37,346 and $8,000, respectively, to its partners.

     On July 13, 2007, the Company declared a quarterly cash distribution of $0.63 per unit on all outstanding units, or $19,850, for the three months ended June 30, 2007. The distribution will be paid on August 14, 2007 to unitholders of record as of the close of business on August 4, 2007. This quarterly distribution of $0.63 per unit equates to $2.52 per unit on an annualized basis.

8. Segments and Related Information

     Under the provisions of SFAS No. 131, Disclosures about Segments of an Enterprise and Related Information, the Company has two reportable segments: Specialty Products and Fuel Products. The Specialty Products segment produces a variety of lubricating oils, solvents and waxes. These products are sold to customers who purchase these products primarily as raw material components for basic automotive, industrial and consumer goods. The Fuel Products segment produces a variety of fuel and fuel-related products including gasoline, diesel and jet fuel.

     The accounting policies of the segments are the same as those described in the summary of significant accounting policies except that the Company evaluates segment performance based on income from operations. The Company accounts for intersegment sales and transfers at cost plus a specified mark-up. Reportable segment information is as follows:

		Specialty				Fuel				Combined								Consolidated
Three Months Ended June 30, 2007		Products				Products				Segments				Eliminations				Total
Sales:
External customers		$	227,215			$	194,511			$	421,726			$	—			$	421,726
Intersegment sales			155,085				8,266				163,351				(163,351	)			—
Total sales		$	382,300			$	202,777			$	585,077			$	(163,351	)		$	421,726
Depreciation and amortization			4,775				—				4,775				—				4,775
Income from operations			21,019				17,923				38,942				—				38,942
Reconciling items to net income:
Interest expense																			(1,113	)
Interest income																			569
Loss on derivative instruments																			(767	)
Other																			42
Income tax expense																			(255	)
Net income																		$	37,418
Capital expenditures		$	64,912			$	—			$	64,912			$	—			$	64,912

		Specialty				Fuel				Combined								Consolidated
Three Months Ended June 30, 2006		Products				Products				Segments				Eliminations				Total
Sales:
External customers		$	245,331			$	184,594			$	429,925			$	—			$	429,925
Intersegment sales			173,935				11,355				185,290				(185,290	)			—
Total sales		$	419,266			$	195,949			$	615,215			$	(185,290	)		$	429,925
Depreciation and amortization			3,781				—				3,781				—				3,781
Income from operations			22,775				14,810				37,585				—				37,585
Reconciling items to net income :
Interest expense																			(2,157	)
Interest income																			51
Debt extinguishment costs																			—
Loss on derivative instruments																			(11,867	)
Other																			(20	)
Income tax expense																			(52	)
Net income														$	—				23,540
Capital expenditures		$	19,478			$	—			$	19,478			$	—			$	19,478

		Specialty				Fuel				Combined								Consolidated
Six Months Ended June 30, 2007		Products				Products				Segments				Eliminations				Total
Sales:
External customers		$	428,968			$	343,871			$	772,839			$	—			$	772,839
Intersegment sales			279,976				16,071				296,047				(296,047	)			—
Total sales		$	708,944			$	359,942			$	1,068,886			$	(296,047	)		$	772,839
Depreciation and amortization			9,316				—				9,316				—				9,316
Income from operations			43,592				30,325				73,917				—				73,917
Reconciling items to net income:
Interest expense																			(2,128	)
Interest income																			1,559
Loss on derivative instruments																			(7,280	)
Other																			(136	)
Income tax expense																			(305	)
Net income																			65,627
Capital expenditures		$	106,646			$	—			$	106,646			$	—			$	106,646

		Specialty				Fuel				Combined								Consolidated
Six Months Ended June 30, 2006		Products				Products				Segments				Eliminations				Total
Sales:
External customers		$	474,988			$	352,631			$	827,619			$	—			$	827,619
Intersegment sales			340,112				20,906				361,018				(361,018	)			—
Total sales		$	815,100			$	373,537			$	1,188,637			$	(361,018	)		$	827,619
Depreciation and amortization			7,148				—				7,148				—				7,148
Income from operations			42,661				26,307				68,968				—				68,968
Reconciling items to net income:
Interest expense																			(6,133	)
Interest income																			245
Debt extinguishment costs																			(2,967	)
Loss on derivative instruments																			(32,662	)
Other																			(15	)
Income tax expense																			(66	)
Net income																			27,370
Capital expenditures		$	22,453			$	—			$	22,453			$	—			$	22,453

		June 30,				December 31,
		2007				2006
Segment assets:
Specialty Products		$	1,170,370			$	973,854
Fuel Products			828,691				681,677
Combined segments			1,999,061				1,655,531
Eliminations			(1,444,799	)			(1,123,880	)
Total assets		$	554,262			$	531,651

     International sales accounted for less than 10% of consolidated sales for each of the three and six months ended June 30, 2007 and 2006.

     The Company offers products primarily in four general categories consisting of fuels, lubricants, solvents and waxes. Other includes asphalt and other by-products. The following table sets forth the major product category sales

		Three Months Ended June 30,
		2007				2006
Fuels		$	194,242			$	196,104
Lubricants			124,610				136,066
Solvents			52,344				52,031
Waxes			15,278				16,294
Other			35,252				29,430
Total sales		$	421,726			$	429,925

		Six Months Ended June 30,
		2007				2006
Fuels		$	349,169			$	374,707
Lubricants			241,340				268,975
Solvents			101,375				104,391
Waxes			25,634				31,748
Other			55,321				47,798
Total sales		$	772,839			$	827,619

     No customer represented 10% or greater of consolidated sales in each of the three months and six months ended June 30, 2007 and 2006.

9. Subsequent Events

     On July 13, 2007, the Company declared a quarterly cash distribution of $0.63 per unit on all outstanding units, or $19,850, for the three months ended June 30, 2007. The distribution will be paid on August 14, 2007 to unitholders of record as of the close of business on August 4, 2007. This quarterly distribution of $0.63 per unit equates to $2.52 per unit on an annualized basis.

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

Overview

     We are a leading independent producer of high-quality, specialty hydrocarbon products in North America. Our business is organized into two segments: specialty products and fuel products. In our specialty products segment, we process crude oil into a wide variety of customized lubricating oils, solvents and waxes. Our specialty products are sold to domestic and international customers who purchase them primarily as raw material components for basic industrial, consumer and automotive goods. In our fuel products segment, we process crude oil into a variety of fuel and fuel-related products including unleaded gasoline, diesel and jet fuel. In connection with our production of specialty products and fuel products, we also produce asphalt and a limited number of other by-products. The asphalt and other by-products produced in connection with the production of specialty products at the Princeton, Cotton Valley and Shreveport refineries are included in our specialty products segment. The by-products produced in connection with the production of fuel products at the Shreveport refinery are included in our fuel products segment. The fuels produced in connection with the production of specialty products at the Princeton and Cotton Valley refineries are included in our specialty products segment. For the three and six months ended June 30, 2007, approximately 67.1% and 70.5%, respectively of our gross profit was generated from our specialty products segment and approximately 32.9% and 29.5%, respectively of our gross profit was generated from our fuel products segment.

     Our fuel products segment began operations in 2004, as we substantially completed the approximately $39.7 million reconfiguration of the Shreveport refinery to add motor fuels production, including gasoline, diesel and jet fuel, to its existing specialty products production as well as to increase overall feedstock throughput. The project was fully completed in February 2005. The reconfiguration was undertaken to capitalize on strong fuels refining margins, or crack spreads, relative to historical levels, to utilize idled assets, and to enhance the profitability of the Shreveport refinery’s specialty products segment by increasing overall refinery throughput. In 2006, we commenced construction of an expansion project at our Shreveport refinery to increase throughput capacity and feedstock flexibility. Please read “—Liquidity and Capital Resources — Capital Expenditures” below.

     Our sales and net income are principally affected by the price of crude oil, demand for specialty and fuel products, prevailing crack spreads for fuel products, the price of natural gas used as fuel in our operations and our results from derivative instrument activities.

     Our primary raw material is crude oil and our primary outputs are specialty petroleum and fuel products. The prices of crude oil, specialty and fuel products are subject to fluctuations in response to changes in supply, demand, market uncertainties and a variety of additional factors beyond our control. We monitor these risks and enter into financial derivatives designed to mitigate the impact of commodity price fluctuations on our business. The primary purpose of our commodity risk management activities is to economically hedge our cash flow exposure to commodity price risk so that we can meet our cash distribution, debt service and maintenance capital expenditure requirements despite fluctuations in crude oil and fuel products prices. We enter into derivative contracts for future periods in quantities which do not exceed our projected purchases of crude oil and sales of fuel products. Please read Item 3 “Quantitative and Qualitative Disclosures about Market Risk — Commodity Price Risk.” As of June 30, 2007, we have hedged approximately 29 million barrels of fuel products through December 2011 at an average refining margin of $11.83 per barrel and average refining margins range from a low of $11.05 in the first and second quarters of 2011 to a high of $12.86 in the third quarter of 2007. Please refer to Item 3 “Quantitative and Qualitative Disclosures About Market Risk — Commodity Price Risk — Existing Commodity Derivative Instruments” for a detailed listing of our hedge positions.

     Our management uses several financial and operational measurements to analyze our performance. These measurements include the following:

	•		Sales volumes;
	•		Production yields; and

•

Specialty products and fuel products gross profit.

     Sales volumes. We view the volumes of specialty and fuels products sold as an important measure of our ability to effectively utilize our refining assets. Our ability to meet the demands of our customers is driven by the volumes of crude oil and feedstocks that we run at our refineries. Higher volumes improve profitability both through the spreading of fixed costs over greater volumes and the additional gross profit achieved on the incremental volumes.

     Production yields. We seek the optimal product mix for each barrel of crude oil we refine in order to maximize our gross profit and minimize lower margin by-products which we refer to as production yield.

     Specialty products and fuel products gross profit. Specialty products and fuel products gross profit are an important measure of our ability to maximize the profitability of our specialty products and fuel products segments. We define specialty products and fuel products gross profit as sales less the cost of crude oil and other feedstocks and other production-related expenses, the most significant portion of which include labor, plant fuel, utilities, contract services, maintenance and processing materials. We use specialty products and fuel products gross profit as an indicator of our ability to manage our business during periods of crude oil and natural gas price fluctuations, as the prices of our specialty products and fuel products generally do not change immediately with changes in the price of crude oil and natural gas. The increase in selling prices typically lags behind the rising costs of crude oil and other feedstocks for specialty products. Other than plant fuel, production-related expenses generally remain stable across broad ranges of throughput volumes, but can fluctuate depending on maintenance and turnaround activities.

     In addition to the foregoing measures, we also monitor our general and administrative expenditures, substantially all of which are incurred through our general partner, Calumet GP, LLC.

Second Quarter 2007 and Six Months Ended June 30, 2007 Results of Operations

     The following table sets forth information about our combined refinery operations. Refining production volume differs from sales volume due to changes in inventory.

		Three months Ended								Six months Ended
		June 30,								June 30,
		2007				2006				2007				2006
Total sales volume (bpd)(1)			49,736				50,747				46,586				51,425
Total feedstock runs (bpd)(2)			49,488				53,363				47,465				52,869
Refinery production (bpd)(3):
Specialty products:
Lubricating oils			11,495				12,101				10,795				11,899
Solvents			4,994				5,671				5,095				5,012
Waxes			1,337				1,226				1,121				1,186
Fuels			2,022				2,612				2,080				2,561
Asphalt and other by-products			6,723				7,911				5,885				6,742
Total			26,571				29,521				24,976				27,400
Fuel products:
Gasoline			6,660				8,987				7,245				9,491
Diesel			5,433				7,018				5,281				7,369
Jet fuel			7,962				6,581				7,563				6,942
By-products			2,255				604				1,724				452
Total			22,310				23,190				21,813				24,254
Total refinery production			48,881				52,711				46,789				51,654