Edgar Filing: HollyFrontier Corp

HFC 6-30-2013 10Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

_________________________________________________________________

FORM 10-Q

_________________________________________________________________

(Mark One)



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

For the quarterly period ended June 30, 2013



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

For the transition period from __________ to ____________

Commission File Number 1-3876

_________________________________________________________________

HOLLYFRONTIER CORPORATION

(Exact name of registrant as specified in its charter)

_________________________________________________________________



Delaware		75-1056913
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

2828 N. Harwood, Suite 1300 Dallas, Texas		75201
(Address of principal executive offices)		(Zip Code)

(214) 871-3555

(Registrant’s telephone number, including area code)

_________________________________________________________________

(Former name, former address and former fiscal year, if changed since last report)

_________________________________________________________________

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ý No ¨

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



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

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

199,857,034 shares of Common Stock, par value $.01 per share, were outstanding on July 31, 2013.

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HOLLYFRONTIER CORPORATION

INDEX



	Page

Forward-Looking Statements	3

PART I. FINANCIAL INFORMATION

Definitions	4

Item 1. Financial Statements

Consolidated Balance Sheets
June 30, 2013 (Unaudited) and December 31, 2012	6

Consolidated Statements of Income (Unaudited)
Three and Six Months Ended June 30, 2013 and 2012	7

Consolidated Statements of Comprehensive Income (Unaudited)
Three and Six Months Ended June 30, 2013 and 2012	8

Consolidated Statements of Cash Flows (Unaudited)
Six Months Ended June 30, 2013 and 2012	9

Notes to Consolidated Financial Statements (Unaudited)	10

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	36

Item 3. Quantitative and Qualitative Disclosures About Market Risk	51

Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles	51

Item 4. Controls and Procedures	54

PART II. OTHER INFORMATION

Item 1. Legal Proceedings	55

Item 1A. Risk Factors	55

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	56

Item 6. Exhibits	56

Signatures	57

Index to Exhibits	58

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FORWARD-LOOKING STATEMENTS

References herein to HollyFrontier Corporation (“HollyFrontier”) include HollyFrontier and its consolidated subsidiaries. In accordance with the Securities and Exchange Commission’s (“SEC”) “Plain English” guidelines, this Quarterly Report on Form 10-Q has been written in the first person. In this document, the words “we,” “our,” “ours” and “us” refer only to HollyFrontier and its consolidated subsidiaries or to HollyFrontier or an individual subsidiary and not to any other person with certain exceptions. Generally, the words “we,” “our,” “ours” and “us” include Holly Energy Partners, L.P. (“HEP”) and its subsidiaries as consolidated subsidiaries of HollyFrontier, unless when used in disclosures of transactions or obligations between HEP and HollyFrontier or its other subsidiaries. This document contains certain disclosures of agreements that are specific to HEP and its consolidated subsidiaries and do not necessarily represent obligations of HollyFrontier. When used in descriptions of agreements and transactions, “HEP” refers to HEP and its consolidated subsidiaries.

This Quarterly Report on Form 10-Q contains certain “forward-looking statements” within the meaning of the federal securities laws. All statements, other than statements of historical fact included in this Form 10-Q, including, but not limited to, those under “Results of Operations,” “Liquidity and Capital Resources” and “Risk Management” in Part I, Item 2 “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and those in Part II, Item 1 “Legal Proceedings” are forward-looking statements. These statements are based on management’s beliefs and assumptions using currently available information and expectations as of the date hereof, are not guarantees of future performance and involve certain risks and uncertainties. Although we believe that the expectations reflected in these forward-looking statements are reasonable, we cannot assure you that our expectations will prove to be correct. Therefore, actual outcomes and results could materially differ from what is expressed, implied or forecast in these statements. Any differences could be caused by a number of factors including, but not limited to:


•	risks and uncertainties with respect to the actions of actual or potential competitive suppliers of refined petroleum products in our markets;


•	the demand for and supply of crude oil and refined products;


•	the spread between market prices for refined products and market prices for crude oil;


•	the possibility of constraints on the transportation of refined products;


•	the possibility of inefficiencies, curtailments or shutdowns in refinery operations or pipelines;


•	effects of governmental and environmental regulations and policies;


•	the availability and cost of our financing;


•	the effectiveness of our capital investments and marketing strategies;


•	our efficiency in carrying out construction projects;


•	our ability to acquire refined product operations or pipeline and terminal operations on acceptable terms and to integrate any existing or future acquired operations;


•	the possibility of terrorist attacks and the consequences of any such attacks;


•	general economic conditions; and


•	other financial, operational and legal risks and uncertainties detailed from time to time in our SEC filings.

Cautionary statements identifying important factors that could cause actual results to differ materially from our expectations are set forth in this Form 10-Q, including without limitation, the forward-looking statements that are referred to above. This summary discussion should be read in conjunction with the discussion of the known material risk factors and other cautionary statements under the heading “Risk Factors” included in Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2012 and in Item 1A of our Quarterly Report on Form 10-Q for the quarter ended March 31, 2013 and in conjunction with the discussion in this Form 10-Q in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” under the heading “Liquidity and Capital Resources.” All forward-looking statements included in this Form 10-Q and all subsequent written or oral forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these cautionary statements. The forward-looking statements speak only as of the date made and, other than as required by law, we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

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PART I. FINANCIAL INFORMATION

DEFINITIONS

Within this report, the following terms have these specific meanings:

“Alkylation” means the reaction of propylene or butylene (olefins) with isobutane to form an iso-paraffinic gasoline (inverse of cracking).

“Aromatic oil” is long chain oil that is highly aromatic in nature that is used to manufacture tires and in the production of asphalt.

“BPD” means the number of barrels per calendar day of crude oil or petroleum products.

“BPSD” means the number of barrels per stream day (barrels of capacity in a 24 hour period) of crude oil or petroleum products.

“Biodiesel” means a clean alternative fuel produced from renewable biological resources.

“Black wax crude oil” is a low sulfur, low gravity crude oil produced in the Uintah Basin in Eastern Utah that has certain characteristics that require specific facilities to transport, store and refine into transportation fuels.

“Catalytic reforming” means a refinery process which uses a precious metal (such as platinum) based catalyst to convert low octane naphtha to high octane gasoline blendstock and hydrogen. The hydrogen produced from the reforming process is used to desulfurize other refinery oils and is a primary source of hydrogen for the refinery.

“Cracking” means the process of breaking down larger, heavier and more complex hydrocarbon molecules into simpler and lighter molecules.

“Crude distillation” means the process of distilling vapor from liquid crudes, usually by heating, and condensing the vapor slightly above atmospheric pressure turning it back to liquid in order to purify, fractionate or form the desired products.

“Ethanol” means a high octane gasoline blend stock that is used to make various grades of gasoline.

“FCC,” or fluid catalytic cracking, means a refinery process that breaks down large complex hydrocarbon molecules into smaller more useful ones using a circulating bed of catalyst at relatively high temperatures.

“Hydrodesulfurization” means to remove sulfur and nitrogen compounds from oil or gas in the presence of hydrogen and a catalyst at relatively high temperatures.

“Hydrogen plant” means a refinery unit that converts natural gas and steam to high purity hydrogen, which is then used in the hydrodesulfurization, hydrocracking and isomerization processes.

“HF alkylation,” or hydrofluoric alkylation, means a refinery process which combines isobutane and C3/C4 olefins using HF acid as a catalyst to make high octane gasoline blend stock.

“Isomerization” means a refinery process for rearranging the structure of C5/C6 molecules without changing their size or chemical composition and is used to improve the octane of C5/C6 gasoline blendstocks.

“LPG” means liquid petroleum gases.

“Lubricant” or “lube” means a solvent neutral paraffinic product used in passenger and commercial vehicle engine oils, specialty products for metal working or heat transfer and other industrial applications.

“MSAT2” means Control of Hazardous Air Pollutants from Mobile Sources, a rule issued by the U.S. Environmental Protection Agency to reduce hazardous emissions from motor vehicles and motor vehicle fuels.

“MEK” means a lube process that separates waxy oil from non-waxy oils using methyl ethyl ketone as a solvent.

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“MMBTU” means one million British thermal units.

“Natural gasoline” means a low octane gasoline blend stock that is purchased and used to blend with other high octane stocks produced to make various grades of gasoline.

“Paraffinic oil” is a high paraffinic, high gravity oil produced by extracting aromatic oils and waxes from gas oil and is used in producing high-grade lubricating oils.

“Refinery gross margin” means the difference between average net sales price and average product costs per produced barrel of refined products sold. This does not include the associated depreciation and amortization costs.

“Reforming” means the process of converting gasoline type molecules into aromatic, higher octane gasoline blend stocks while producing hydrogen in the process.

“Roofing flux” is produced from the bottom cut of crude oil and is the base oil used to make roofing shingles for the housing industry.

“ROSE,” or “Solvent deasphalter / residuum oil supercritical extraction,” means a refinery unit that uses a light hydrocarbon like propane or butane to extract non-asphaltene heavy oils from asphalt or atmospheric reduced crude. These deasphalted oils are then further converted to gasoline and diesel in the FCC process. The remaining asphaltenes are either sold, blended to fuel oil or blended with other asphalt as a hardener.

“Scanfiner” is a refinery unit that removes sulfur from gasoline to produce low sulfur gasoline blendstock.

“Sour crude oil” means crude oil containing quantities of sulfur greater than 0.4 percent by weight, while “sweet crude oil” means crude oil containing quantities of sulfur equal to or less than 0.4 percent by weight.

“Vacuum distillation” means the process of distilling vapor from liquid crudes, usually by heating, and condensing the vapor below atmospheric pressure turning it back to a liquid in order to purify, fractionate or form the desired products.

“WCS” means Western Canada Select crude oil and is made up of Canadian heavy conventional and bitumen crude oils blended with sweet synthetic and condensate diluents.

“WTI” means West Texas Intermediate and is a grade of crude oil used as a common benchmark in oil pricing. WTI is a sweet crude oil and has a relatively low density.

“WTS” means West Texas Sour, a medium sour crude oil.

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Item 1.	Financial Statements

HOLLYFRONTIER CORPORATION

CONSOLIDATED BALANCE SHEETS

(In thousands, except share data)



	June 30, 2013			December 31, 2012
	(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents (HEP: $8,716 and $5,237, respectively)	$	1,349,420		$	1,757,699
Marketable securities	632,715			630,586
Accounts receivable: Product and transportation (HEP: $36,121 and $38,097, respectively)	701,724			587,728
Crude oil resales	69,081			46,502
	770,805			634,230
Inventories: Crude oil and refined products	1,472,071			1,238,678
Materials, supplies and other (HEP: $1,783 and $1,259, respectively)	78,372			80,954
	1,550,443			1,319,632
Income taxes receivable	62,431			74,957
Prepayments and other (HEP: $2,531 and $2,360, respectively)	82,338			53,161
Total current assets	4,448,152			4,470,265

Properties, plants and equipment, at cost (HEP: $1,168,786 and $1,155,710, respectively)	4,101,398			3,943,114
Less accumulated depreciation (HEP: $(165,829) and $(141,154), respectively)	(843,567		)	(748,414		)
	3,257,831			3,194,700
Marketable securities (long-term)	3,393			5,116
Other assets: Turnaround costs	268,220			151,764
Goodwill (HEP: $288,991 and $288,991, respectively)	2,338,302			2,338,302
Intangibles and other (HEP: $76,203 and $76,300, respectively)	178,036			168,850
	2,784,558			2,658,916
Total assets	$	10,493,934		$	10,328,997

LIABILITIES AND EQUITY
Current liabilities:
Accounts payable (HEP: $13,720 and $12,030, respectively)	$	1,593,370		$	1,314,151
Accrued liabilities (HEP: $24,607 and $23,705, respectively)	135,033			195,077
Deferred income tax liabilities	151,288			145,216
Total current liabilities	1,879,691			1,654,444

Long-term debt (HEP: $799,152 and $864,673, respectively)	990,236			1,336,238
Deferred income taxes (HEP: $5,287 and $4,951, respectively)	579,867			536,670
Other long-term liabilities (HEP: $30,770 and $28,683, respectively)	144,762			158,987

Equity:
HollyFrontier stockholders’ equity:
Preferred stock, $1.00 par value – 5,000,000 shares authorized; none issued	—			—
Common stock $.01 par value – 320,000,000 shares authorized; 255,962,866 shares issued as of June 30, 2013 and December 31, 2012	2,560			2,560
Additional capital	3,982,060			3,911,353
Retained earnings	3,319,550			3,054,769
Accumulated other comprehensive income (loss)	33,206			(8,425		)
Common stock held in treasury, at cost – 55,902,645 and 52,411,370 shares as of June 30, 2013 and December 31, 2012, respectively	(1,071,943		)	(907,303		)
Total HollyFrontier stockholders’ equity	6,265,433			6,052,954
Noncontrolling interest	633,945			589,704
Total equity	6,899,378			6,642,658
Total liabilities and equity	$	10,493,934		$	10,328,997

Parenthetical amounts represent asset and liability balances attributable to Holly Energy Partners, L.P. (“HEP”) as of June 30, 2013 and December 31, 2012. HEP is a consolidated variable interest entity.

See accompanying notes.

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HOLLYFRONTIER CORPORATION

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

(In thousands, except per share data)



	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012

Sales and other revenues	$	5,298,848		$	4,806,681		$	10,006,637		$	9,738,419
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	4,456,808			3,681,764			8,249,343			7,868,681
Operating expenses (exclusive of depreciation and amortization)	277,542			222,726			542,641			464,353
General and administrative expenses (exclusive of depreciation and amortization)	34,000			32,106			63,198			59,634
Depreciation and amortization	70,492			56,948			142,254			113,050
Total operating costs and expenses	4,838,842			3,993,544			8,997,436			8,505,718
Income from operations	460,006			813,137			1,009,201			1,232,701
Other income (expense):
Earnings (loss) of equity method investments	(1,089		)	886			(1,030		)	1,603
Interest income	778			681			2,309			1,141
Interest expense	(19,794		)	(26,942		)	(41,114		)	(60,257		)
Loss on early extinguishment of debt	(22,109		)	—			(22,109		)	—
Gain on sale of marketable equity securities	—			326			—			326
	(42,214		)	(25,049		)	(61,944		)	(57,187		)
Income before income taxes	417,792			788,088			947,257			1,175,514
Income tax provision:
Current	143,439			285,937			350,066			428,807
Deferred	8,604			(219		)	(11,929		)	(2,683		)
	152,043			285,718			338,137			426,124
Net income	265,749			502,370			609,120			749,390
Less net income attributable to noncontrolling interest	8,768			8,871			18,470			14,195
Net income attributable to HollyFrontier stockholders	$	256,981		$	493,499		$	590,650		$	735,195
Earnings per share attributable to HollyFrontier stockholders:
Basic	$	1.27		$	2.40		$	2.91		$	3.55
Diluted	$	1.27		$	2.39		$	2.91		$	3.54
Cash dividends declared per common share	$	0.80		$	0.65		$	1.60		$	1.25
Average number of common shares outstanding:
Basic	201,543			205,727			202,131			207,129
Diluted	201,905			206,481			202,485			207,938

See accompanying notes.

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HOLLYFRONTIER CORPORATION

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

(In thousands)



	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012

Net income	$	265,749		$	502,370		$	609,120		$	749,390
Other comprehensive income (loss):
Securities available-for-sale:
Unrealized gain (loss) on available-for-sale securities	(39		)	(114		)	(26		)	191
Reclassification adjustments to net income on sale or maturity of marketable securities	(6		)	(290		)	(3		)	(407		)
Net unrealized loss on available-for-sale securities	(45		)	(404		)	(29		)	(216		)
Hedging instruments:
Change in fair value of cash flow hedging instruments	27,661			25,242			17,315			(115,455		)
Reclassification adjustments to net income on settlement of cash flow hedging instruments	(6,073		)	4,286			21,631			(11,906		)
Amortization of unrealized loss attributable to discontinued cash flow hedges	270			1,273			1,209			2,547
Net unrealized gain (loss) on hedging instruments	21,858			30,801			40,155			(124,814		)
Settlement of pension plan obligations	28,986			—			28,986			—
Actuarial loss on post-retirement healthcare plan reclassified to net income upon partial plan settlement	—			—			1,726			—
Pension plan curtailment adjustment	—			7,102			—			7,102
Other comprehensive income (loss) before income taxes	50,799			37,499			70,838			(117,928		)
Income tax expense (benefit)	18,986			14,640			26,474			(46,030		)
Other comprehensive income (loss)	31,813			22,859			44,364			(71,898		)
Total comprehensive income	297,562			525,229			653,484			677,492
Less noncontrolling interest in comprehensive income	10,708			8,734			21,202			14,595
Comprehensive income attributable to HollyFrontier stockholders	$	286,854		$	516,495		$	632,282		$	662,897

See accompanying notes.

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HOLLYFRONTIER CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

(In thousands)



	Six Months Ended June 30,
	2013			2012
Cash flows from operating activities:
Net income	$	609,120		$	749,390
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	142,254			113,050
Earnings of equity method investments, net of distributions	2,593			(104		)
Loss on early extinguishment of debt attributable to unamortized discount	7,948			—
Gain on sale of marketable equity securities	—			(326		)
Deferred income taxes	(11,929		)	(2,683		)
Equity-based compensation expense	17,192			17,491
Change in fair value – derivative instruments	(57,192		)	10,289
(Increase) decrease in current assets:
Accounts receivable	(122,875		)	103,674
Inventories	(230,811		)	(195,200		)
Income taxes receivable	12,526			365
Prepayments and other	10,040			17,928
Increase (decrease) in current liabilities:
Accounts payable	216,506			(418,937		)
Income taxes payable	—			121,899
Accrued liabilities	(7,588		)	(34,870		)
Turnaround expenditures	(159,811		)	(46,995		)
Other, net	23,542			(5,468		)
Net cash provided by operating activities	451,515			429,503

Cash flows from investing activities:
Additions to properties, plants and equipment	(153,942		)	(104,401		)
Additions to properties, plants and equipment – HEP	(16,861		)	(23,619		)
Proceeds from sale of property and equipment	5,802			—
Investment in Sabine Biofuels	(2,000		)	(2,000		)
Advances to Sabine Biofuels	(13,700		)	—
Purchases of marketable securities	(399,154		)	(166,429		)
Sales and maturities of marketable securities	398,762			151,996
Net cash used for investing activities	(181,093		)	(144,453		)

Cash flows from financing activities:
Borrowings under credit agreement – HEP	154,500			99,000
Repayments under credit agreement – HEP	(220,500		)	(129,000		)
Net proceeds from issuance of senior notes – HEP	—			294,750
Redemption of senior notes – HFC	(286,812		)	(5,000		)
Redemption premium on early extinguishment of debt	(14,161		)	—
Principal tender on senior notes – HEP	—			(185,000		)
Proceeds from sale of HEP common units	73,444			—
Proceeds from common unit offerings - HEP	73,444			—
Purchase of treasury stock	(159,432		)	(189,771		)
Structured stock repurchase arrangement	—			(100,000		)
Contribution from joint venture partner	—			6,000
Dividends	(264,867		)	(249,958		)
Distributions to noncontrolling interest	(34,604		)	(28,944		)
Excess tax benefit from equity-based compensation	1,037			4,762
Purchase of units for incentive grants – HEP	(2,934		)	(4,533		)
Deferred financing costs	—			(3,229		)
Other	2,184			(833		)
Net cash used for financing activities	(678,701		)	(491,756		)

Cash and cash equivalents:
Decrease for the period	(408,279		)	(206,706		)
Beginning of period	1,757,699			1,578,904
End of period	$	1,349,420		$	1,372,198

Supplemental disclosure of cash flow information:
Cash paid during the period for:
Interest	$	46,566		$	48,928
Income taxes	$	336,099		$	301,854

See accompanying notes.

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HOLLYFRONTIER CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)


NOTE 1:	Description of Business and Presentation of Financial Statements

References herein to HollyFrontier Corporation (“HollyFrontier”) include HollyFrontier and its consolidated subsidiaries. In accordance with the Securities and Exchange Commission’s (“SEC”) “Plain English” guidelines, this Quarterly Report on Form 10-Q has been written in the first person. In these financial statements, the words “we,” “our,” “ours” and “us” refer only to HollyFrontier and its consolidated subsidiaries or to HollyFrontier or an individual subsidiary and not to any other person, with certain exceptions. Generally, the words “we,” “our,” “ours” and “us” include Holly Energy Partners, L.P. (“HEP”) and its subsidiaries as consolidated subsidiaries of HollyFrontier, unless when used in disclosures of transactions or obligations between HEP and HollyFrontier or its other subsidiaries. These financial statements contain certain disclosures of agreements that are specific to HEP and its consolidated subsidiaries and do not necessarily represent obligations of HollyFrontier. When used in descriptions of agreements and transactions, “HEP” refers to HEP and its consolidated subsidiaries.

We are principally an independent petroleum refiner that produces high-value light products such as gasoline, diesel fuel, jet fuel, specialty lubricant products, and specialty and modified asphalt. We own and operate petroleum refineries that serve markets throughout the Mid-Continent, Southwest and Rocky Mountain regions of the United States. As of June 30, 2013, we:

•

owned and operated a petroleum refinery in El Dorado, Kansas (the “El Dorado Refinery”), two refinery facilities located in Tulsa, Oklahoma (collectively, the “Tulsa Refineries”), a refinery in Artesia, New Mexico that is operated in conjunction with crude oil distillation and vacuum distillation and other facilities situated 65 miles away in Lovington, New Mexico (collectively, the “Navajo Refinery”), a refinery located in Cheyenne, Wyoming (the “Cheyenne Refinery”) and a refinery in Woods Cross, Utah (the “Woods Cross Refinery”);


•	owned and operated NK Asphalt Partners (“NK Asphalt”) which operates various asphalt terminals in Arizona and New Mexico;


•	owned Ethanol Management Company (“EMC”), a products terminal and blending facility near Denver, Colorado and a 50% interest in Sabine Biofuels II, LLC (“Sabine Biofuels”), a biodiesel production facility located in Port Arthur, Texas; and

•

owned a 39% interest in HEP, a consolidated variable interest entity (“VIE”), which includes our 2% general partner interest. HEP owns and operates logistic assets consisting of petroleum product and crude oil pipelines and terminal, tankage and loading rack facilities that principally support our refining and marketing operations in the Mid-Continent, Southwest and Rocky Mountain regions of the United States and Alon USA, Inc.'s (“Alon”) refinery in Big Spring, Texas. Additionally, HEP owns a 75% interest in UNEV Pipeline, LLC (“UNEV”), which owns a 12-inch refined products pipeline from Salt Lake City, Utah to Las Vegas, Nevada, together with terminal facilities in the Cedar City, Utah and North Las Vegas areas (the “UNEV Pipeline”), and a 25% interest in SLC Pipeline LLC (the “SLC Pipeline”), a 95-mile intrastate pipeline system that serves refineries in the Salt Lake City area.

We have prepared these consolidated financial statements without audit. In management’s opinion, these consolidated financial statements include all normal recurring adjustments necessary for a fair presentation of our consolidated financial position as of June 30, 2013, the consolidated results of operations and comprehensive income for the three and six months ended June 30, 2013 and 2012 and consolidated cash flows for the six months ended June 30, 2013 and 2012 in accordance with the rules and regulations of the SEC. Although certain notes and other information required by generally accepted accounting principles in the United States (“GAAP”) have been condensed or omitted, we believe that the disclosures in these consolidated financial statements are adequate to make the information presented not misleading. These consolidated financial statements should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2012 that has been filed with the SEC.

Our results of operations for the six months ended June 30, 2013 are not necessarily indicative of the results of operations to be realized for the year ending December 31, 2013.

Balance Sheet Offsetting: We purchase and sell inventories of crude oil with certain same-parties that are net settled in accordance with contractual net settlement provisions. Our policy is to present such balances on a net basis because it more appropriately presents our economic resources (accounts receivable) and claims against us (accounts payable) and the future cash flows associated with such assets and liabilities.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

Accounts Receivable: Our accounts receivable consist of amounts due from customers that are primarily companies in the petroleum industry. Credit is extended based on our evaluation of the customer’s financial condition, and in certain circumstances collateral, such as letters of credit or guarantees, is required. We reserve for doubtful accounts based on our historical loss experience as well as specific accounts identified as high risk, which historically have been minimal. Credit losses are charged to the allowance for doubtful accounts when an account is deemed uncollectible. Our allowance for doubtful accounts was $2.5 million at June 30, 2013 and December 31, 2012.

Inventories: We use the last-in, first-out (“LIFO”) method of valuing inventory. Under the LIFO method, an actual valuation of inventory can only be made at the end of each year based on the inventory levels at that time. Accordingly, interim LIFO calculations are based on management’s estimates of expected year-end inventory levels and are subject to the final year-end LIFO inventory valuation.

Goodwill: Goodwill represents the excess of the cost of an acquired entity over the fair value of the assets acquired and liabilities assumed. Goodwill is not subject to amortization and is tested annually, or more frequently if events or circumstances indicate the possibility of impairment. As of June 30, 2013, there have been no impairments to goodwill.


NOTE 2:	Variable Interest Entities

Holly Energy Partners

HEP, a consolidated VIE, is a publicly held master limited partnership that was formed to acquire, own and operate the petroleum product and crude oil pipeline and terminal, tankage and loading rack facilities that support our refining and marketing operations in the Mid-Continent, Southwest and Rocky Mountain regions of the United States. HEP also owns and operates refined product pipelines and terminals, located primarily in Texas, that serve Alon's refinery in Big Spring, Texas.

As of June 30, 2013, we owned a 39% interest in HEP, including the 2% general partner interest. We are the primary beneficiary of HEP's earnings and cash flows and therefore we consolidate HEP. See Note 16 for supplemental guarantor/non-guarantor financial information, including HEP balances included in these consolidated financial statements. All intercompany transactions with HEP are eliminated in our consolidated financial statements.

HEP has two primary customers (including us) and generates revenues by charging tariffs for transporting petroleum products and crude oil though its pipelines, by charging fees for terminalling refined products and other hydrocarbons, and storing and providing other services at its storage tanks and terminals. Under our long-term transportation agreements with HEP (discussed further below), we accounted for 83% of HEP’s total revenues for the six months ended June 30, 2013. We do not provide financial or equity support through any liquidity arrangements and /or debt guarantees to HEP.

HEP has outstanding debt under a senior secured revolving credit agreement and its senior notes. With the exception of the assets of HEP Logistics Holdings, L.P., one of our wholly-owned subsidiaries and HEP’s general partner, HEP’s creditors have no recourse to our assets. Any recourse to HEP’s general partner would be limited to the extent of HEP Logistics Holdings, L.P.’s assets, which other than its investment in HEP, are not significant. Furthermore, our creditors have no recourse to the assets of HEP and its consolidated subsidiaries. See Note 9 for a description of HEP’s debt obligations.

HEP has risk associated with its operations. If a major customer of HEP were to terminate its contracts or fail to meet desired shipping or throughput levels for an extended period of time, revenue would be reduced and HEP could suffer substantial losses to the extent that a new customer is not found. In the event that HEP incurs a loss, our operating results will reflect HEP’s loss, net of intercompany eliminations, to the extent of our ownership interest in HEP at that point in time.

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(Unaudited) Continued

Transportation Agreements

HEP serves our refineries under long-term pipeline and terminal, tankage and throughput agreements expiring from 2019 through 2026. Under these agreements, we pay HEP fees to transport, store and throughput volumes of refined product and crude oil on HEP's pipeline and terminal, tankage and loading rack facilities that result in minimum annual payments to HEP including UNEV (a consolidated subsidiary of HEP). Under these agreements, the agreed upon tariff rates are subject to annual tariff rate adjustments on July 1 at a rate based upon the percentage change in Producer Price Index (“PPI”) or Federal Energy Regulatory Commission (“FERC”) index. As of July 1, 2013, these agreements result in minimum annualized payments to HEP of $225.5 million.

Since HEP is a consolidated VIE, our transactions with HEP including fees paid under our transportation agreements with HEP are eliminated and have no impact on our consolidated financial statements.

HEP Common Unit Offering

In March 2013, HEP closed on a public offering of 1,875,000 of its common units. Additionally, our wholly-owned subsidiary, HollyFrontier Holdings LLC, as a selling unitholder, closed on a public sale of 1,875,000 HEP common units held by it. HEP used net proceeds of $73.4 million to repay indebtedness incurred under its credit facility and for general partnership purposes. As a result of these transactions and resulting HEP ownership changes, we adjusted additional capital and equity attributable to HEP's noncontrolling interest holders to reallocate HEP's equity among its unitholders.

Sabine Biofuels

We have a 50% ownership interest in Sabine Biofuels, a biofuels production facility that is a VIE. We do not hold a controlling financial interest, nor are we its primary beneficiary. Accordingly, we account for our investment using the equity method of accounting which had a carrying amount of $10.0 million at June 30, 2013 and is classified as a noncurrent asset under “Intangibles and other” in our consolidated balance sheets. Also, we have extended a working capital facility to Sabine Biofuels having an outstanding balance of $17.9 million at June 30, 2013.


NOTE 3:	Financial Instruments

Our financial instruments consist of cash and cash equivalents, investments in marketable securities, accounts receivable, accounts payable, debt and derivative instruments. The carrying amounts of cash and cash equivalents, accounts receivable and accounts payable approximate fair value. HEP's outstanding credit agreement borrowings also approximate fair value as interest rates are reset frequently at current interest rates.

Fair value measurements are derived using inputs (assumptions that market participants would use in pricing an asset or liability, including assumptions about risk). GAAP categorizes inputs used in fair value measurements into three broad levels as follows:


•	(Level 1) Quoted prices in active markets for identical assets or liabilities.


•	(Level 2) Observable inputs other than quoted prices included in Level 1, such as quoted prices for similar assets and liabilities in active markets, similar assets and liabilities in markets that are not active or can be corroborated by observable market data.


•	(Level 3) Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. This includes valuation techniques that involve significant unobservable inputs.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

The carrying amounts and related estimated fair values of our investments in marketable securities, derivative instruments and senior notes at June 30, 2013 and December 31, 2012 were as follows:



					Fair Value by Input Level
Financial Instrument	Carrying Amount		Fair Value		Level 1		Level 2		Level 3
	(In thousands)
June 30, 2013
Assets:
Marketable debt securities	$	636,108	$	636,108	$	—	$	636,108	$	—
Commodity price swaps	51,720		51,720		—		12,683		39,037
HEP interest rate swaps	545		545		—		545		—
Total assets	$	688,373	$	688,373	$	—	$	649,336	$	39,037

Liabilities:
NYMEX futures contracts	$	1,694	$	1,694	$	1,694	$	—	$	—
Commodity price swaps	28,398		28,398		—		26,487		1,911
HollyFrontier senior notes	155,489		161,250		—		161,250		—
HEP senior notes	444,152		452,625		—		452,625		—
Total liabilities	$	629,733	$	643,967	$	1,694	$	640,362	$	1,911



December 31, 2012
Assets:
Marketable debt securities	$	635,702	$	635,702	$	—	$	635,702	$	—
Commodity price swaps	17,383		17,383		—		6,151		11,232
Total assets	$	653,085	$	653,085	$	—	$	641,853	$	11,232

Liabilities:
NYMEX futures contracts	$	5,563	$	5,563	$	5,563	$	—	$	—
Commodity price swaps	83,982		83,982		—		39,092		44,890
HollyFrontier senior notes	435,254		470,990		—		470,990		—
HEP senior notes	443,673		484,125		—		484,125		—
HEP interest rate swaps	3,430		3,430		—		3,430		—
Total liabilities	$	971,902	$	1,048,090	$	5,563	$	997,637	$	44,890

Level 1 Financial Instruments

Our NYMEX futures contracts are exchange traded and are measured and recorded at fair value using quoted market prices, a Level 1 input.

Level 2 Financial Instruments

Investments in marketable debt securities and derivative instruments consisting of commodity price swaps and HEP's interest rate swaps are measured and recorded at fair value using Level 2 inputs. The fair values of the commodity price and interest rate swap contracts are based on the net present value of expected future cash flows related to both variable and fixed rate legs of the respective swap agreements. The measurements are computed using market-based observable inputs, quoted forward commodity prices with respect to our commodity price swaps and the forward London Interbank Offered Rate (“LIBOR”) yield curve with respect to HEP's interest rate swaps. The fair value of the marketable debt securities and senior notes is based on values provided by a third-party, which were derived using market quotes for similar type instruments, a Level 2 input.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

Level 3 Financial Instruments

We have commodity price swap contracts that relate to forecasted sales of diesel and forecasted purchases of WCS and WTS for which quoted forward market prices are not readily available. The forward rate used to value these price swaps is derived using a projected forward rate using quoted market rates for similar products, adjusted for regional pricing and grade differentials, a Level 3 input.

The following table presents the changes in fair value of the Level 3 assets and liabilities (all related to derivative instruments) for the three and six months ended June 30, 2013 and 2012:



	Three Months Ended June 30,						Six Months Ended June 30,
Level 3 Financial Instruments	2013			2012			2013			2012
	(In thousands)
Asset (liability) balance at beginning of period	$	(6,249	)	$	(149,278	)	$	(33,658	)	$	31,616
Change in fair value:
Recognized in other comprehensive income	50,615			248,572			1,413			33,553
Recognized in cost of products sold	3,662			—			47,222			—
Settlement date fair value of contractual maturities:
Recognized in sales and other revenues	(3,868		)	20,167			15,316			54,292
Recognized in cost of products sold	(7,034		)	—			6,833			—
Asset balance at end of period	$	37,126		$	119,461		$	37,126		$	119,461

A hypothetical change of 10% to the estimated future cash flows attributable to our Level 3 derivative instruments would result in an estimated fair value change of approximately $3.7 million.


NOTE 4:	Earnings Per Share

Basic earnings per share is calculated as net income attributable to HollyFrontier stockholders divided by the average number of shares of common stock outstanding. Diluted earnings per share assumes, when dilutive, the issuance of the net incremental shares from variable restricted and variable performance shares. The following is a reconciliation of the denominators of the basic and diluted per share computations for net income attributable to HollyFrontier stockholders:



	Three Months Ended June 30,				Six Months Ended June 30,
	2013		2012		2013		2012
	(In thousands, except per share data)
Net income attributable to HollyFrontier stockholders	$	256,981	$	493,499	$	590,650	$	735,195
Participating securities' share in earnings	917		2,257		2,201		3,116
Net income attributable to common shares	$	256,064	$	491,242	$	588,449	$	732,079
Average number of shares of common stock outstanding	201,543		205,727		202,131		207,129
Effect of dilutive variable restricted shares andperformance share units ⁽¹⁾	362		754		354		809
Average number of shares of common stock outstanding assuming dilution	201,905		206,481		202,485		207,938
Basic earnings per share	$	1.27	$	2.40	$	2.91	$	3.55
Diluted earnings per share	$	1.27	$	2.39	$	2.91	$	3.54

(1) Excludes anti-dilutive restricted and performance share units of:	232		—		248		—

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued


NOTE 5:	Stock-Based Compensation

As of June 30, 2013, we have two principal share-based compensation plans (collectively, the “Long-Term Incentive Compensation Plan”).

The compensation cost charged against income for these plans was $7.9 million and $7.3 million for the three months ended June 30, 2013 and 2012, respectively, and $15.3 million and $15.9 million for the six months ended June 30, 2013 and 2012, respectively. Our accounting policy for the recognition of compensation expense for awards with pro-rata vesting (substantially all of our awards) is to expense the costs ratably over the vesting periods.

Additionally, HEP maintains a share-based compensation plan for Holly Logistic Services, L.L.C. non-employee directors and certain executives and employees. Compensation cost attributable to HEP’s share-based compensation plan was $0.8 million and $0.7 million for the three months ended June 30, 2013 and 2012, respectively, and $1.9 million and $1.6 million for the six months ended June 30, 2013 and 2012, respectively.

Restricted Stock and Restricted Stock Units

Under our Long-Term Incentive Compensation Plan, we grant certain officers and other key employees restricted stock awards with awards generally vesting over a period of three years. Award recipients are generally entitled to all the rights of absolute ownership of the restricted shares from the date of grant (unless a recipient's tax election requires otherwise) including the right to vote the shares and to receive dividends. Upon vesting, restrictions on the restricted shares lapse at which time they convert to common shares. The vesting for certain key executives is contingent upon certain performance targets being realized. In addition, we grant non-employee directors restricted stock unit awards, which typically vest over a period of one year and are payable in stock. The fair value of each restricted stock and restricted stock unit award is measured based on the market price as of the date of grant and is amortized over the respective vesting period.

A summary of restricted stock and restricted stock unit activity and changes during the six months ended June 30, 2013 is presented below:



Restricted Stock and Restricted Stock Units	Grants		Weighted Average Grant Date Fair Value		Aggregate Intrinsic Value ($000)

Outstanding at January 1, 2013 (non-vested)	843,527		$	34.52
Granted	33,181		46.09
Vesting (transfer/conversion to common stock)	(125,600	)	23.53
Forfeited	(11,405	)	36.11
Outstanding at June 30, 2013 (non-vested)	739,703		$	36.88	$	31,645

For the six months ended June 30, 2013, 125,600 restricted stock and restricted stock units vested having a grant date fair value of $3.0 million. As of June 30, 2013, there was $11.8 million of total unrecognized compensation cost related to non-vested restricted stock and restricted stock unit grants. That cost is expected to be recognized over a weighted-average period of 1.1 years.

Performance Share Units

Under our Long-Term Incentive Compensation Plan, we grant certain officers and other key employees performance share units, which are payable in stock upon meeting certain criteria over the service period, and generally vest over a period of three years. Under the terms of our performance share unit grants, awards are subject to either a “financial performance” or “market performance” criteria, or both.

The fair value of performance share unit awards subject to financial performance criteria is computed using the grant date closing stock price of each respective award grant and will apply to the number of units ultimately awarded. The number of shares ultimately issued for each award will be based on our financial performance as compared to peer group companies over the performance period and can range from zero to 200%. As of June 30, 2013, estimated share payouts for outstanding non-vested performance share unit awards ranged from 110% to 170%.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

For the performance share units subject to market performance criteria, performance is calculated as the total shareholder return achieved by HollyFrontier stockholders compared with the average shareholder return achieved by an equally-weighted peer group of independent refining companies over a three-year period. These share unit awards are valued using a Monte Carlo valuation model, which simulates future stock price movements using key inputs including grant date stock prices, expected stock price performance, expected rate of return and volatility. These units are payable in stock based on share price performance relative to the defined peer group and can range from zero to 200% of the initial target award.

A summary of performance share unit activity and changes during the six months ended June 30, 2013 is presented below:



Performance Share Units	Grants

Outstanding at January 1, 2013 (non-vested)	875,574
Granted	528
Vesting and transfer of ownership to recipients	—
Forfeited	(13,719	)
Outstanding at June 30, 2013 (non-vested)	862,383

Based on the weighted-average grant date fair value of $35.40 per share, there was $22.2 million of total unrecognized compensation cost related to non-vested performance share units as of June 30, 2013. That cost is expected to be recognized over a weighted-average period of 1.4 years.


NOTE 6:	Cash and Cash Equivalents and Investments in Marketable Securities

Our investment portfolio at June 30, 2013 consisted of cash, cash equivalents and investments in marketable debt securities.

We invest in highly-rated marketable debt securities that have maturities at the date of purchase of greater than three months. We also invest in other marketable debt securities with the maximum maturity or put date of any individual issue generally not greater than two years from the date of purchase, which are usually held until maturity. All of these instruments are classified as available-for-sale. As a result, they are reported at fair value using quoted market prices. Interest income is recorded as earned. Unrealized gains and losses, net of related income taxes, are reported as a component of accumulated other comprehensive income. Upon sale or maturity, realized gains on our marketable debt securities are recognized as interest income. These gains are computed based on the specific identification of the underlying cost of the securities, net of unrealized gains and losses previously reported in other comprehensive income. Unrealized gains and losses on our available-for-sale securities are due to changes in market prices and are considered temporary.

The following is a summary of our available-for-sale securities:



	Amortized Cost		Gross Unrealized Gain		Gross Unrealized Loss			Fair Value (Net Carrying Amount)
	(In thousands)
June 30, 2013
Certificates of deposit	$	57,756	$	14	$	—		$	57,770
Commercial paper	37,574		16		—			37,590
Corporate debt securities	71,426		6		(47		)	71,385
State and political subdivisions debt securities	469,404		18		(59		)	469,363
Total marketable securities	$	636,160	$	54	$	(106	)	$	636,108

December 31, 2012
Certificates of deposit	$	82,791	$	14	$	(6	)	$	82,799
Commercial paper	45,737		17		—			45,754
Corporate debt securities	49,587		2		(30		)	49,559
State and political subdivisions debt securities	457,615		26		(51		)	457,590
Total marketable securities	$	635,730	$	59	$	(87	)	$	635,702

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

Interest income recognized on our marketable debt securities was $0.6 million and $0.2 million for the three months ended June 30, 2013 and 2012, respectively, and $1.1 million and $0.5 million for the six months ended June 30, 2013 and 2012, respectively.


NOTE 7:	Inventories

Inventory consists of the following components:



	June 30, 2013		December 31, 2012
	(In thousands)
Crude oil	$	544,127	$	502,978
Other raw materials and unfinished products⁽¹⁾	186,121		150,090
Finished products⁽²⁾	741,823		585,610
Process chemicals⁽³⁾	6,848		3,514
Repairs and maintenance supplies and other	71,524		77,440
Total inventory	$	1,550,443	$	1,319,632


(1)	Other raw materials and unfinished products include feedstocks and blendstocks, other than crude.


(2)	Finished products include gasolines, jet fuels, diesels, lubricants, asphalts, LPG’s and residual fuels.


(3)	Process chemicals include additives and other chemicals.


NOTE 8:	Environmental

We expensed $0.6 million and $1.0 million for the three months ended June 30, 2013 and 2012, respectively, and $0.8 million and $15.2 million for the six months ended June 30, 2013 and 2012, respectively, for environmental remediation obligations. The accrued environmental liability reflected in our consolidated balance sheets was $86.3 million and $88.9 million at June 30, 2013 and December 31, 2012, respectively, of which $66.9 million and $72.6 million, respectively, were classified as other long-term liabilities. These accruals include remediation and monitoring costs expected to be incurred over an extended period of time (up to 30 years for certain projects).


NOTE 9:	Debt

HollyFrontier Credit Agreement

We have a $1 billion senior secured credit agreement that matures in July 2016 (the “HollyFrontier Credit Agreement”) and may be used to fund working capital requirements, capital expenditures, acquisitions and general corporate purposes. Obligations under the HollyFrontier Credit Agreement are collateralized by our inventory, accounts receivables and certain deposit accounts and guaranteed by our material, wholly-owned subsidiaries. At June 30, 2013, we were in compliance with all covenants, had no outstanding borrowings and had outstanding letters of credit totaling $28.8 million under the HollyFrontier Credit Agreement.

HEP Credit Agreement

HEP has a $550 million senior secured revolving credit facility that matures in June 2017 (the “HEP Credit Agreement”) and is available to fund capital expenditures, investments, acquisitions, distribution payments and working capital and for general partnership purposes. It is also available to fund letters of credit up to a $50 million sub-limit and to fund distributions to unitholders up to a $60 million sub-limit. At June 30, 2013, HEP was in compliance with all of its covenants, had outstanding borrowings of $355.0 million and no outstanding letters of credit under the HEP Credit Agreement.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

HEP’s obligations under the HEP Credit Agreement are collateralized by substantially all of HEP’s assets (presented parenthetically in our consolidated balance sheets). Indebtedness under the HEP Credit Agreement involves recourse to HEP Logistics Holdings, L.P., its general partner, and is guaranteed by HEP’s wholly-owned subsidiaries. Any recourse to the general partner would be limited to the extent of HEP Logistics Holdings, L.P.’s assets, which other than its investment in HEP, are not significant. HEP’s creditors have no other recourse to our assets. Furthermore, our creditors have no recourse to the assets of HEP and its consolidated subsidiaries.

HollyFrontier Senior Notes

Our 6.875% senior notes ($150 million principal amount maturing November 2018) (the “HollyFrontier Senior Notes”) are unsecured and impose certain restrictive covenants, including limitations on our ability to incur additional debt, incur liens, enter into sale-and-leaseback transactions, pay dividends, enter into mergers, sell assets and enter into certain transactions with affiliates. At any time when the HollyFrontier Senior Notes are rated investment grade by both Moody’s and Standard & Poor’s and no default or event of default exists, we will not be subject to many of the foregoing covenants. Additionally, we have certain redemption rights under the HollyFrontier Senior Notes.

In June 2013, we redeemed our $286.8 million aggregate principal amount of 9.875% senior notes maturing June 2017 at a redemption cost of $301.0 million, at which time we recognized a $22.1 million early extinguishment loss consisting of a $14.2 million debt redemption premium and an unamortized discount of $7.9 million.

HollyFrontier Financing Obligation

We have a financing obligation that relates to a sale and lease-back of certain crude oil tankage that we sold to an affiliate of Plains All American Pipeline, L.P. (“Plains”) in October 2009 for $40.0 million. Monthly lease payments are recorded as a reduction in principal over the 15-year lease term ending in 2024.

HEP Senior Notes

HEP’s senior notes consist of the following:


•	8.25% HEP senior notes ($150 million principal amount maturing March 2018)


•	6.5% HEP senior notes ($300 million principal amount maturing March 2020)

The 8.25% and 6.5% HEP senior notes (collectively, the “HEP Senior Notes”) are unsecured and impose certain restrictive covenants, including limitations on HEP’s ability to incur additional indebtedness, make investments, sell assets, incur certain liens, pay distributions, enter into transactions with affiliates, and enter into mergers. At any time when the HEP Senior Notes are rated investment grade by both Moody’s and Standard & Poor’s and no default or event of default exists, HEP will not be subject to many of the foregoing covenants. Additionally, HEP has certain redemption rights under the HEP Senior Notes.

Indebtedness under the HEP Senior Notes involves recourse to HEP Logistics Holdings, L.P., its general partner, and is guaranteed by HEP’s wholly-owned subsidiaries. However, any recourse to the general partner would be limited to the extent of HEP Logistics Holdings, L.P.’s assets, which other than its investment in HEP, are not significant. HEP’s creditors have no other recourse to our assets. Furthermore, our creditors have no recourse to the assets of HEP and its consolidated subsidiaries.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

The carrying amounts of long-term debt are as follows:



	June 30, 2013			December 31, 2012
	(In thousands)
9.875% Senior Notes
Principal	$	—		$	286,812
Unamortized discount	—			(7,468		)
	—			279,344
6.875% Senior Notes
Principal	150,000			150,000
Unamortized premium	5,489			5,910
	155,489			155,910
Financing Obligation	35,595			36,311

Total HollyFrontier long-term debt	191,084			471,565

HEP Credit Agreement	355,000			421,000

HEP 8.25% Senior Notes
Principal	150,000			150,000
Unamortized discount	(1,449		)	(1,602		)
	148,551			148,398
HEP 6.5% Senior Notes
Principal	300,000			300,000
Unamortized discount	(4,399		)	(4,725		)
	295,601			295,275

Total HEP long-term debt	799,152			864,673

Total long-term debt	$	990,236		$	1,336,238

We capitalized interest attributable to construction projects of $3.0 million and $2.3 million for the three months ended June 30, 2013 and 2012, respectively, and $6.4 million and $3.9 million for the six months ended June 30, 2013 and 2012, respectively.

NOTE 10: Derivative Instruments and Hedging Activities

Commodity Price Risk Management

Our primary market risk is commodity price risk. We are exposed to market risks related to the volatility in crude oil and refined products, as well as volatility in the price of natural gas used in our refining operations. We periodically enter into derivative contracts in the form of commodity price swaps and futures contracts to mitigate price exposure with respect to:


•	our inventory positions;


•	natural gas purchases;


•	costs of crude oil and related grade differentials;


•	prices of refined products; and


•	our refining margins.

Accounting Hedges

We have swap contracts serving as cash flow hedges against price risk on forecasted purchases of natural gas and WTI crude oil and forecasted sales of ultra-low sulfur diesel. These contracts have been designated as accounting hedges and are measured quarterly at fair value with offsetting adjustments (gains/losses) recorded directly to other comprehensive income. These fair value adjustments are later reclassified to earnings as the hedging instruments mature. Also on a quarterly basis, hedge ineffectiveness is measured by comparing the change in fair value of the swap contracts against the expected future cash inflows/outflows on the respective transaction being hedged. Any hedge ineffectiveness is also recognized in earnings.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

The following table presents the pre-tax effect on other comprehensive income (“OCI”) and earnings due to fair value adjustments and maturities of commodity price swaps under hedge accounting:



	Unrealized Gain (Loss) Recognized in OCI			Gain (Loss) Recognized in Earnings Due to Settlements				Gain (Loss) Attributable to Hedge Ineffectiveness Recognized in Earnings
	Unrealized Gain (Loss) Recognized in OCI			Location	Amount			Location	Amount
	(In thousands)
Three Months Ended June 30, 2013
Commodity price swaps
Change in fair value	$	24,764		Sales and other revenues	$	3,868		Sales and other revenues	$	550
Gain reclassified to earnings due to settlements	(6,589		)	Cost of products sold	1,930			Cost of products sold	(1,439		)
Amortization of discontinued hedge reclassified to earnings	270			Operating expenses	521			Operating expenses	106
Total	$	18,445			$	6,319			$	(783	)

Three Months Ended June 30, 2012
Commodity price swaps
Change in fair value	$	27,044		Sales and other revenues	$	(20,167	)	Sales and other revenues	$	2,984
Loss reclassified to earnings due to settlements	3,992			Cost of products sold	16,175			Cost of products sold	(6,317		)
Total	$	31,036			$	(3,992	)		$	(3,333	)

Six Months Ended June 30, 2013
Commodity price swaps
Change in fair value	$	14,360		Sales and other revenues	$	(15,316	)	Sales and other revenues	$	194
Loss reclassified to earnings due to settlements	20,611			Cost of products sold	(4,603		)	Cost of products sold	1,692
Amortization of discontinued hedge reclassified to earnings	360			Operating expenses	(1,052		)	Operating expenses	(259		)
Total	$	35,331			$	(20,971	)		$	1,627

Six Months Ended June 30, 2012
Commodity price swaps
Change in fair value	$	(113,076	)	Sales and other revenues	$	(54,292	)	Sales and other revenues	$	1,655
Gain reclassified to earnings due to settlements	(12,423		)	Cost of products sold	66,715			Cost of products sold	(6,317		)
Total	$	(125,499	)		$	12,423			$	(4,662	)

As of June 30, 2013, we have the following notional contract volumes related to outstanding derivative instruments serving as cash flow hedges against price risk on forecasted purchases of natural gas and crude oil and sales of refined products:



		Notional Contract Volumes by Year of Maturity
Derivative Instrument	Total Outstanding Notional	2013	2014	2015	2016	2017	Unit of Measure

Commodity Price Swaps:
Natural gas - long	43,200,000	4,800,000	9,600,000	9,600,000	9,600,000	9,600,000	MMBTU
WTI crude oil - long	5,701,000	5,336,000	365,000	—	—	—	Barrels
Ultra-low sulfur diesel - short	5,701,000	5,336,000	365,000	—	—	—	Barrels

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

In the first quarter of 2013, we dedesignated certain commodity price swaps (long positions) that previously received hedge accounting treatment. These contracts now serve as economic hedges against price risk on forecasted natural gas purchases totaling 43,200,000 MMBTU's to be purchased ratably through 2017. As of June 30, 2013, we have an unrealized loss of $4.9 million classified as OCI that relates to the application of hedge accounting prior to dedesignation that will be amortized as a charge to operating expenses as the contracts mature.

Economic Hedges

We also have swap contracts that serve as economic hedges (derivatives used for risk management, but not designated as accounting hedges) to fix our purchase price on forecasted natural gas and crude oil and other feedstock purchases, and to lock in the spread between WCS and WTI crude oil and between WTS and WTI crude oil on forecasted purchases of WCS and WTS. Also, we have NYMEX futures contracts to lock in prices on purchases of inventory. These contracts are measured quarterly at fair value with offsetting adjustments (gains/losses) recorded directly to income.

The following table presents the pre-tax effect on income due to maturities and fair value adjustments of our economic hedges:



	Three Months Ended June 30,					Six Months Ended June 30,
Location of Gain (Loss) Recognized in Income	2013			2012		2013			2012
	(In thousands)
Cost of products sold	$	1,839		$	50,863	$	35,431		$	35,869
Operating expenses	(308		)	1,543		(5,301		)	(158		)
Total	$	1,531		$	52,406	$	30,130		$	35,711

As of June 30, 2013, we have the following notional contract volumes related to our outstanding derivative contracts serving as economic hedges:



		Notional Contract Volumes by Year of Maturity
Derivative Instrument	Total Outstanding Notional	2013	2014	2015	2016	2017	Unit of Measure

Commodity price swap (WCS spread) - long	3,588,000	3,588,000	—	—	—	—	Barrels
Commodity price swap (WTS spread) - long	1,472,000	1,472,000	—	—	—	—	Barrels
Commodity price swap (natural gas) - long	43,200,000	4,800,000	9,600,000	9,600,000	9,600,000	9,600,000	MMBTU
Commodity price swap (natural gas) - short	43,200,000	4,800,000	9,600,000	9,600,000	9,600,000	9,600,000	MMBTU
NYMEX futures (WTI) - short	1,896,000	1,681,000	215,000	—	—	—	Barrels

Interest Rate Risk Management

HEP uses interest rate swaps to manage its exposure to interest rate risk.

As of June 30, 2013, HEP had three interest rate swap contracts that hedge its exposure to the cash flow risk caused by the effects of LIBOR changes on $305.0 million in credit agreement advances. The first interest rate swap effectively converts $155.0 million of LIBOR based debt to fixed rate debt having an interest rate of 0.99% plus an applicable margin of 2.50% as of June 30, 2013, which equaled an effective interest rate of 3.49%. This swap matures in February 2016. HEP has two additional interest rate swaps with identical terms which effectively convert $150.0 million of LIBOR based debt to fixed rate debt having an interest rate of 0.74% plus an applicable margin of 2.50% as of June 30, 2013, which equaled an effective interest rate of 3.24%. Both of these swap contracts mature in July 2017. All of these swap contracts have been designated as cash flow hedges. To date, there has been no ineffectiveness on these cash flow hedges.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

The following table presents the pre-tax effect on other comprehensive income and earnings due to fair value adjustments and maturities of HEP's interest rate swaps under cash flow hedge accounting:



	Unrealized Gain (Loss) Recognized in OCI			Loss Recognized in Earnings Due to Settlements
	Unrealized Gain (Loss) Recognized in OCI			Location	Amount
	(In thousands)
Three Months Ended June 30, 2013
Interest rate swaps
Change in fair value	$	2,897
Loss reclassified to earnings due to settlements	516			Interest expense	$	(516	)
Total	$	3,413			$	(516	)

Three Months Ended June 30, 2012
Interest rate swaps
Change in fair value	$	(1,802	)
Loss reclassified to earnings due to settlements	294
Amortization of discontinued hedge reclassified to earnings	1,273			Interest expense	$	(1,567	)
Total	$	(235	)		$	(1,567	)

Six Months Ended June 30, 2013
Interest rate swaps
Change in fair value	$	2,955
Loss reclassified to earnings due to settlements	1,020
Amortization of discontinued hedge reclassified to earnings	849			Interest expense	$	(1,869	)
Total	$	4,824			$	(1,869	)

Six Months Ended June 30, 2012
Interest rate swaps
Change in fair value	$	(2,380	)
Loss reclassified to earnings due to settlements	518
Amortization of discontinued hedge reclassified to earnings	2,547			Interest expense	$	(3,065	)
Total	$	685			$	(3,065	)

The following table presents the fair value and balance sheet locations of our outstanding derivative instruments. These amounts are presented on a gross basis with offsetting balances that reconcile to a net asset or liability position in our consolidated balance sheets. We present on a net basis to reflect the net settlement of these positions in accordance with provisions of our master netting arrangements.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued



	Derivatives in Net Asset Position								Derivatives in Net Liability Position
	Gross Assets		Gross Liabilities Offset in Balance Sheet			Net Assets Recognized in Balance Sheet			Gross Liabilities		Gross Assets Offset in Balance Sheet		Net Liabilities Recognized in Balance Sheet
			(In thousands)
June 30, 2013
Derivatives designated as cash flow hedging instruments:
Commodity price swap contracts	$	35,732	$	(14,358	)	$	21,374		$	—	$	—	$	—
Interest rate swap contracts	2,257		(1,712		)	545			—		—		—
	$	37,989	$	(16,070	)	$	21,919		$	—	$	—	$	—

Derivatives not designated as cash flow hedging instruments:
Commodity price swap contracts	$	15,988	$	(14,040	)	$	1,948		$	—	$	—	$	—
NYMEX futures contracts	—		—			—			1,694		—		1,694
	$	15,988	$	(14,040	)	$	1,948		$	1,694	$	—	$	1,694

Total net balance						$	23,867						$	1,694

Balance sheet classification:	Prepayment and other					$	39,217		Accrued liabilities				$	1,694
	Intangibles and other					2,257
	Other long-term liabilities					(17,607		)
						$	23,867						$	1,694



	Derivatives in Net Asset Position						Derivatives in Net Liability Position
	Gross Assets		Gross Liabilities Offset in Balance Sheet		Net Assets Recognized in Balance Sheet		Gross Liabilities		Gross Assets Offset in Balance Sheet			Net Liabilities Recognized in Balance Sheet
			(In thousands)
December 31, 2012
Derivatives designated as cash flow hedging instruments:
Commodity price swap contracts	$	—	$	—	$	—	$	37,828	$	(17,383	)	$	20,445
Interest rate swap contracts	—		—		—		3,430		—			3,430
	$	—	$	—	$	—	$	41,258	$	(17,383	)	$	23,875

Derivatives not designated as cash flow hedging instruments:
Commodity price swap contracts	$	—	$	—	$	—	$	46,154	$	—		$	46,154
NYMEX futures contracts	—		—		—		5,563		—			5,563
	$	—	$	—	$	—	$	51,717	$	—		$	51,717

Total net balance					$	—						$	75,592

Balance sheet classification:							Accrued liabilities					$	62,388
							Other long-term liabilities					13,204
												$	75,592

At June 30, 2013, we had a pre-tax net unrealized gain of $15.7 million classified in accumulated other comprehensive income that relates to all accounting hedges having contractual maturities through 2017. Assuming commodity prices and interest rates remain unchanged, an unrealized gain of $29.2 million will be effectively transferred from accumulated other comprehensive income into the statement of income as the hedging instruments contractually mature over the next twelve-month period.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued


NOTE 11:	Equity

Changes to equity during the six months ended June 30, 2013 are presented below:



	HollyFrontier Stockholders’ Equity			Noncontrolling Interest			Total Equity
	(In thousands)
Balance at December 31, 2012	$	6,052,954		$	589,704		$	6,642,658
Net income	590,650			18,470			609,120
Dividends	(325,869		)	—			(325,869		)
Distributions to noncontrolling interest holders	—			(34,604		)	(34,604		)
Other comprehensive income, net of tax	41,631			2,733			44,364
Allocated equity on HEP common unit issuances, net of tax	54,011			58,696			112,707
Equity-based compensation	15,312			1,880			17,192
Excess tax benefit attributable to equity-based compensation	1,037			—			1,037
Purchase of treasury stock ⁽¹⁾	(164,293		)	—			(164,293		)
Purchase of HEP units for restricted grants	—			(2,934		)	(2,934		)
Balance at June 30, 2013	$	6,265,433		$	633,945		$	6,899,378


(1)	Includes 32,779 shares withheld under the terms of stock-based compensation agreements to provide funds for the payment of payroll and income taxes due at the vesting of share-based awards.

We have a Board approved repurchase program that authorizes us to repurchase common stock in the open market or through privately negotiated transactions. The timing and amount of stock repurchases will depend on market conditions, corporate, regulatory and other relevant considerations. This program may be discontinued at any time by the Board of Directors. As of June 30, 2013, we had remaining authorization to repurchase up to $356.4 million under this stock repurchase program.


NOTE 12:	Other Comprehensive Income (Loss)

The components and allocated tax effects of other comprehensive income (loss) are as follows:



	Before-Tax			Tax Expense (Benefit)			After-Tax
	(In thousands)
Three Months Ended June 30, 2013
Unrealized loss, net of reclassifications from sale or maturity, on available-for-sale securities	$	(45	)	$	(36	)	$	(9	)
Unrealized gain on hedging activities	21,858			7,747			14,111
Actuarial loss on retirement pension plan reclassified to net income upon partial plan settlement	28,986			11,275			17,711
Other comprehensive income	50,799			18,986			31,813
Less other comprehensive income attributable to noncontrolling interest	1,940			—			1,940
Other comprehensive income attributable to HollyFrontier stockholders	$	48,859		$	18,986		$	29,873

Three Months Ended June 30, 2012
Unrealized loss, net of reclassifications from sale or maturity, on available-for-sale securities	$	(404	)	$	(158	)	$	(246	)
Unrealized gain on hedging activities	30,801			12,035			18,766
Pension plan curtailment	7,102			2,763			4,339
Other comprehensive income	37,499			14,640			22,859
Less other comprehensive loss attributable to noncontrolling interest	(137		)	—			(137		)
Other comprehensive income attributable to HollyFrontier stockholders	$	37,636		$	14,640		$	22,996

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued



	Before-Tax			Tax Expense (Benefit)			After-Tax
	(In thousands)
Six Months Ended June 30, 2013
Unrealized loss, net of reclassifications from sale or maturity, on available-for-sale securities	$	(29	)	$	(28	)	$	(1	)
Unrealized gain on hedging activities	40,155			14,556			25,599
Actuarial loss on retirement pension plan reclassified to net income upon partial plan settlement	28,986			11,275			17,711
Actuarial loss on post-retirement healthcare plan reclassified to net income upon partial plan settlement	1,726			671			1,055
Other comprehensive income	70,838			26,474			44,364
Less other comprehensive income attributable to noncontrolling interest	2,733			—			2,733
Other comprehensive income attributable to HollyFrontier stockholders	$	68,105		$	26,474		$	41,631

Six Months Ended June 30, 2012
Unrealized loss on available-for-sale securities	$	(216	)	$	(84	)	$	(132	)
Unrealized loss on hedging activities	(124,814		)	(48,709		)	(76,105		)
Pension plan curtailment	7,102			2,763			4,339
Other comprehensive loss	(117,928		)	(46,030		)	(71,898		)
Less other comprehensive income attributable to noncontrolling interest	400			—			400
Other comprehensive loss attributable to HollyFrontier stockholders	$	(118,328	)	$	(46,030	)	$	(72,298	)

The following table presents the income statement line item effects for reclassifications out of accumulated other comprehensive income (“AOCI”):



AOCI Component	Gain (Loss) Reclassified From AOCI						Income Statement Line Item
	(In thousands)
	Three Months Ended June 30, 2013			Six Months Ended June 30, 2013

Securities available-for-sale	$	6		$	3		Interest income
	2			1			Income tax expense
	$	4		$	2		Net of tax

Hedging instruments:
Commodity price swaps	$	3,868		$	(15,316	)	Sales and other revenues
	1,930			(4,603		)	Cost of products sold
	521			(1,052		)	Operating expenses
Interest rate swaps	(516		)	(1,869		)	Interest expense
	5,803			(22,840		)
	2,379			(8,444		)	Income tax expense (benefit)
	3,424			(14,396		)	Net of tax
	313			1,133			Noncontrolling interest
	$	3,737		$	(13,263	)	Net of tax and noncontrolling interest

Pension obligation	$	(2,460	)	$	(2,460	)	Cost of products sold
	(23,260		)	(23,260		)	Operating expenses
	(3,266		)	(3,266		)	General and administrative expenses
	(28,986		)	(28,986		)
	(11,275		)	(11,275		)	Income tax benefit
	$	(17,711	)	$	(17,711	)	Net of tax

Retiree medical obligation	$	—		$	(84	)	Cost of products sold
	—			(1,549		)	Operating expenses
	—			(93		)	General and administrative expenses
	—			(1,726		)
	—			(671		)	Income tax benefit
	$	—		$	(1,055	)	Net of tax

Total reclassifications for the period	$	(13,970	)	$	(32,027	)

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued



AOCI Component	Gain (Loss) Reclassified From AOCI						Income Statement Line Item
	(In thousands)
	Three Months Ended June 30, 2012			Six Months Ended June 30, 2012

Securities available-for-sale	$	(36	)	$	81		Interest income
	326			326			Gain on sale of marketable equity securities
	290			407
	113			158			Income tax expense
	$	177		$	249		Net of tax

Hedging instruments
Commodity price swaps	$	(20,167	)	$	(54,292	)	Sales and other revenues
	16,175			66,715			Cost of products sold
Interest rate swaps	(1,567		)	(3,065		)	Interest expense
	(5,559		)	9,358
	(1,807		)	4,335			Income tax expense (benefit)
	(3,752		)	5,023			Net of tax
	913			1,785			Noncontrolling interest
	$	(2,839	)	$	6,808		Net of tax and noncontrolling interest

Total reclassifications for the period	$	(2,662	)	$	7,057

Accumulated other comprehensive income (loss) in the equity section of our consolidated balance sheets includes:



	June 30, 2013			December 31, 2012
	(In thousands)
Pension obligation	$	(6,262	)	$	(23,973	)
Retiree medical obligation	29,660			28,605
Unrealized loss on available-for-sale securities	(8		)	(7		)
Unrealized gain (loss) on hedging activities, net of noncontrolling interest	9,816			(13,050		)
Accumulated other comprehensive income (loss)	$	33,206		$	(8,425	)


NOTE 13:	Retirement Plan

We previously sponsored a non-contributory defined benefit retirement plan that covered certain employees and was fully frozen prior to 2013. In 2012, our Compensation Committee, pursuant to authority delegated to it by the Board of Directors, approved the termination of the HollyFrontier Corporation Pension Plan (the “Plan”). In June 2013, we made contributions of $22.7 million to the Plan.

Our contribution to the Plan in the second quarter of 2013 was sufficient for the Plan to settle its obligations to all participants including the premium paid to the non-participating annuity provider; however, the contract with this annuity provider was not executed as of June 30, 2013. Accordingly, in the second quarter of 2013, we recognized a pre-tax pension settlement charge of $30.9 million, of which $29.0 million was reclassified out of accumulated other comprehensive income, representing the irrevocable portion. We expect to record an additional pre-tax charge of $8.6 million, which includes the remaining pension loss recorded in accumulated other comprehensive income, when the Plan finalizes the contract terms with the annuity provider, which we expect to occur in the third quarter of 2013.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

The net periodic pension expense consisted of the following components:



	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
	(In thousands)
Service cost – benefit earned during the period	$	—		$	509		$	—		$	679
Interest cost on projected benefit obligations	898			1,061			1,797			2,052
Expected return on plan assets	(46		)	(949		)	(92		)	(1,899		)
Amortization of prior service cost	—			50			—			67
Amortization of net loss	693			620			1,386			1,103
Curtailment	—			674			—			899
Settlement	30,893			—			30,893			—
Net periodic pension expense	$	32,438		$	1,965		$	33,984		$	2,901

In 2012, we established a program for plan participants whose benefits pursuant to the defined benefit plan were frozen. The program provides for payments after year-end for three years (beginning with 2012) provided the employee is employed by us on the last day of each year. The payments are based on each employee's years of service and eligible salary. Transition benefit costs associated with transition to the new defined contribution plan were $2.9 million and $3.5 million for the three months ended June 30, 2013 and 2012, respectively, and $5.8 million and $6.9 million, for the six months ended June 30, 2013 and 2012, respectively.

We have a post-retirement healthcare and other benefits plan that is available to certain of our employees who satisfy certain age and service requirements.The net periodic benefit expense of this plan consisted of the following components:



	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
	(In thousands)
Service cost – benefit earned during the period	$	278		$	475		$	556		$	950
Interest cost on projected benefit obligations	159			875			318			1,750
Amortization of prior service credit	(1,474		)	(550		)	(2,948		)	(1,100		)
Amortization of net loss	31			75			62			150
Actuarial loss on post-retirement healthcare plan reclassified to net income upon partial plan settlement	—			—			1,726			—
Net periodic pension expense	$	(1,006	)	$	875		$	(286	)	$	1,750

In the first quarter of 2013, we settled a portion of our post-retirement medical obligation. Upon settlement, we reclassified a $1.7 million pretax loss out of accumulated other comprehensive income that was recognized as a charge to net income.


NOTE 14:	Contingencies

We are a party to various litigation and legal proceedings which we believe, based on advice of counsel, will not either individually or in the aggregate have a materially adverse effect on our financial condition, results of operations or cash flows.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued


NOTE 15:	Segment Information

Our operations are organized into two reportable segments, Refining and HEP. Our operations that are not included in the Refining and HEP segments are included in Corporate and Other. Intersegment transactions are eliminated in our consolidated financial statements and are included in Consolidations and Eliminations.

The Refining segment represents the operations of the El Dorado, Tulsa, Navajo, Cheyenne and Woods Cross Refineries and NK Asphalt (aggregated as a reportable segment). Refining activities involve the purchase and refining of crude oil and wholesale and branded marketing of refined products, such as gasoline, diesel fuel and jet fuel. These petroleum products are primarily marketed in the Mid-Continent, Southwest and Rocky Mountain regions of the United States. Additionally, the Refining segment includes specialty lubricant products produced at our Tulsa Refineries that are marketed throughout North America and are distributed in Central and South America. NK Asphalt operates various asphalt terminals in Arizona and New Mexico.

The HEP segment includes all of the operations of HEP, a consolidated VIE, which owns and operates logistics assets consisting of petroleum product and crude oil pipelines and terminal, tankage and loading rack facilities in the Mid-Continent, Southwest and Rocky Mountain regions of the United States. The HEP segment also includes a 75% interest in UNEV (a consolidated subsidiary of HEP) and a 25% interest in the SLC Pipeline. Revenues from the HEP segment are earned through transactions with unaffiliated parties for pipeline transportation, rental and terminalling operations as well as revenues relating to pipeline transportation services provided for our refining operations. Our revaluation of HEP’s assets and liabilities at March 1, 2008 (date of reconsolidation) resulted in basis adjustments to our consolidated HEP balances. Therefore, our reported amounts for the HEP segment may not agree to amounts reported in HEP’s periodic public filings.

The accounting policies for our segments are the same as those described in the summary of significant accounting policies in our Annual Report on Form 10-K for the year ended December 31, 2012.



	Refining		HEP ⁽¹⁾		Corporate and Other			Consolidations and Eliminations			Consolidated Total
	(In thousands)
Three Months Ended June 30, 2013
Sales and other revenues	$	5,286,881	$	75,121	$	234		$	(63,388	)	$	5,298,848
Depreciation and amortization	$	53,443	$	15,619	$	1,637		$	(207	)	$	70,492
Income (loss) from operations	$	458,777	$	34,392	$	(32,646	)	$	(517	)	$	460,006
Capital expenditures	$	74,866	$	11,848	$	12,125		$	—		$	98,839

Three Months Ended June 30, 2012
Sales and other revenues	$	4,795,647	$	67,103	$	145		$	(56,214	)	$	4,806,681
Depreciation and amortization	$	43,811	$	12,317	$	1,027		$	(207	)	$	56,948
Income (loss) from operations	$	813,044	$	31,929	$	(31,313	)	$	(523	)	$	813,137
Capital expenditures	$	56,262	$	9,365	$	1,006		$	—		$	66,633

Six Months Ended June 30, 2013
Sales and other revenues	$	9,979,307	$	151,605	$	797		$	(125,072	)	$	10,006,637
Depreciation and amortization	$	110,613	$	29,368	$	2,687		$	(414	)	$	142,254
Income (loss) from operations	$	1,000,979	$	67,866	$	(58,618	)	$	(1,026	)	$	1,009,201
Capital expenditures	$	138,498	$	16,861	$	15,444		$	—		$	170,803

Six Months Ended June 30, 2012
Sales and other revenues	$	9,715,384	$	134,680	$	301		$	(111,946	)	$	9,738,419
Depreciation and amortization	$	85,532	$	25,712	$	2,220		$	(414	)	$	113,050
Income (loss) from operations	$	1,227,987	$	64,042	$	(58,288	)	$	(1,040	)	$	1,232,701
Capital expenditures	$	101,796	$	23,619	$	2,605		$	—		$	128,020

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued



	Refining		HEP ⁽¹⁾		Corporate and Other		Consolidations and Eliminations			Consolidated Total
	(in thousands)
June 30, 2013
Cash, cash equivalents and investments in marketable securities	$	7,115	$	8,716	$	1,969,697	$	—		$	1,985,528
Total assets	$	7,279,491	$	1,417,302	$	2,129,611	$	(332,470	)	$	10,493,934
Long-term debt	$	—	$	799,152	$	206,691	$	(15,607	)	$	990,236

December 31, 2012
Cash, cash equivalents and investments in marketable securities	$	2,101	$	5,237	$	2,386,063	$	—		$	2,393,401
Total assets	$	6,702,872	$	1,426,800	$	2,531,967	$	(332,642	)	$	10,328,997
Long-term debt	$	—	$	864,673	$	487,472	$	(15,907	)	$	1,336,238

(1) HEP acquired our 75% interest in UNEV in July 2012. As a result, we have recast our HEP segment information for the three and six months ended June 30, 2012 to include the UNEV Pipeline operations as a consolidated subsidiary of HEP. The UNEV Pipeline operations were previously presented under Corporate and Other.

HEP segment revenues from external customers were $12.1 million and $10.9 million for the three months ended June 30, 2013 and 2012, respectively, and $24.9 million and $22.8 million for the six months ended June 30, 2013 and 2012, respectively.


NOTE 16:	Supplemental Guarantor/Non-Guarantor Financial Information

Our obligations under the HollyFrontier Senior Notes have been jointly and severally guaranteed by the substantial majority of our existing and future restricted subsidiaries (“Guarantor Restricted Subsidiaries”). These guarantees are full and unconditional. HEP, in which we have a 39% ownership interest at June 30, 2013, and its subsidiaries (collectively, “Non-Guarantor Non-Restricted Subsidiaries”), and certain of our other subsidiaries (“Non-Guarantor Restricted Subsidiaries”) have not guaranteed these obligations.

The following condensed consolidating financial information is provided for HollyFrontier Corporation (the “Parent”), the Guarantor Restricted Subsidiaries, the Non-Guarantor Restricted Subsidiaries and the Non-Guarantor Non-Restricted Subsidiaries. The information has been presented as if the Parent accounted for its ownership in the Guarantor Restricted Subsidiaries, and the Guarantor Restricted Subsidiaries accounted for the ownership of the Non-Guarantor Restricted Subsidiaries and Non-Guarantor Non-Restricted Subsidiaries, using the equity method of accounting. The Guarantor Restricted Subsidiaries and the Non-Guarantor Restricted Subsidiaries are collectively the “Restricted Subsidiaries.”

HEP acquired our 75% interest in UNEV in July 2012. As a result, we have recast our HEP segment information for the three and six months ended June 30, 2012 to include the UNEV Pipeline operations as a consolidated subsidiary of HEP. UNEV was previously presented as a Non-Guarantor Restricted Subsidiary.

Table of Contents

HOLLYFRONTIER CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued



Condensed Consolidating Balance Sheet
June 30, 2013	Parent			Guarantor Restricted Subsidiaries		Non- Guarantor Restricted Subsidiaries		Eliminations			HollyFrontier Corp. Before Consolidation of HEP		Non-Guarantor Non-Restricted Subsidiaries (HEP Segment)		Eliminations			Consolidated
	(In thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	1,333,604		$	7,098	$	2	$	—		$	1,340,704	$	8,716	$	—		$	1,349,420
Marketable securities	632,706			9		—		—			632,715		—		—			632,715
Accounts receivable, net	7,188			760,043		11,202		—			778,433		36,121		(43,749		)	770,805
Intercompany accounts receivable (payable)	(1,158,007		)	877,163		280,844		—			—		—		—			—
Inventories	—			1,548,660		—		—			1,548,660		1,783		—			1,550,443
Income taxes receivable	62,431			—		—		—			62,431		—		—			62,431
Prepayments and other	15,169			70,142		—		—			85,311		2,531		(5,504		)	82,338
Total current assets	893,091			3,263,115		292,048		—			4,448,254		49,151		(49,253		)	4,448,152
Properties, plants and equip, net	26,909			2,509,329		—		—			2,536,238		1,002,957		(281,364		)	3,257,831
Marketable securities (long-term)	3,393			—		—		—			3,393		—		—			3,393
Investment in subsidiaries	6,399,298			192,104		—		(6,591,402		)	—		—		—			—
Intangibles and other assets	15,557			2,405,660		25,000		(25,000		)	2,421,217		365,194		(1,853		)	2,784,558
Total assets	$	7,338,248		$	8,370,208	$	317,048	$	(6,616,402	)	$	9,409,102	$	1,417,302	$	(332,470	)	$	10,493,934

LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	76,278		$	1,539,237	$	—	$	—		$	1,615,515	$	13,720	$	(35,865	)	$	1,593,370
Income taxes payable	—			—		—		—			—		—		—			—
Accrued liabilities	50,167			64,369		1,394		—			115,930		24,607		(5,504		)	135,033
Deferred income tax liabilities	151,288			—		—		—			151,288		—		—			151,288
Total current liabilities	277,733			1,603,606		1,394		—			1,882,733		38,327		(41,369		)	1,879,691
Long-term debt	180,488			35,596		—		(25,000		)	191,084		799,152		—			990,236
Liability to HEP	—			251,764		—		—			251,764		—		(251,764		)	—
Deferred income tax liabilities	574,580			—		—		—			574,580		5,287		—			579,867
Other long-term liabilities	37,045			79,944		—		—			116,989		30,770		(2,997		)	144,762
Investment in HEP	—			—		123,550		—			123,550		—		(123,550		)	—
Equity – HollyFrontier	6,268,402			6,399,298		192,104		(6,591,402		)	6,268,402		444,600		(447,569		)	6,265,433
Equity – noncontrolling interest	—			—		—		—			—		99,166		534,779			633,945
Total liabilities and equity	$	7,338,248		$	8,370,208	$	317,048	$	(6,616,402	)	$	9,409,102	$	1,417,302	$	(332,470	)	$	10,493,934

Table of Contents

HOLLYFRONTIER CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued



Condensed Consolidating Balance Sheet
December 31, 2012	Parent			Guarantor Restricted Subsidiaries		Non- Guarantor Restricted Subsidiaries			Eliminations			HollyFrontier Corp. Before Consolidation of HEP		Non-Guarantor Non-Restricted Subsidiaries (HEP Segment)		Eliminations			Consolidated
	(In thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	1,748,808		$	3,652	$	2		$	—		$	1,752,462	$	5,237	$	—		$	1,757,699
Marketable securities	630,579			7		—			—			630,586		—		—			630,586
Accounts receivable, net	4,788			627,262		—			—			632,050		38,097		(35,917		)	634,230
Intercompany accounts receivable (payable)	(546,655		)	285,291		261,364			—			—		—		—			—
Inventories	—			1,318,373		—			—			1,318,373		1,259		—			1,319,632
Income taxes receivable	74,957			—		—			—			74,957		—		—			74,957
Prepayments and other	21,867			34,667		—			—			56,534		2,360		(5,733		)	53,161
Total current assets	1,934,344			2,269,252		261,366			—			4,464,962		46,953		(41,650		)	4,470,265
Properties, plants and equip, net	24,209			2,444,398		—			—			2,468,607		1,014,556		(288,463		)	3,194,700
Marketable securities (long-term)	5,116			—		—			—			5,116		—		—			5,116
Investment in subsidiaries	5,251,396			74,120		—			(5,325,516		)	—		—		—			—
Intangibles and other assets	11,825			2,284,329		25,000			(25,000		)	2,296,154		365,291		(2,529		)	2,658,916
Total assets	$	7,226,890		$	7,072,099	$	286,366		$	(5,350,516	)	$	9,234,839	$	1,426,800	$	(332,642	)	$	10,328,997

LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	1,941		$	1,336,097	$	—		$	—		$	1,338,038	$	12,030	$	(35,917	)	$	1,314,151
Income taxes payable	—			—		—			—			—		—		—			—
Accrued liabilities	71,226			105,298		581			—			177,105		23,705		(5,733		)	195,077
Deferred income tax liabilities	145,225			—		(9		)	—			145,216		—		—			145,216
Total current liabilities	218,392			1,441,395		572			—			1,660,359		35,735		(41,650		)	1,654,444
Long-term debt	460,254			36,311		—			(25,000		)	471,565		864,673		—			1,336,238
Liability to HEP	—			257,777		—			—			257,777		—		(257,777		)	—
Deferred income tax liabilities	530,544			—		1,175			—			531,719		—		4,951			536,670
Other long-term liabilities	48,757			85,220		—			—			133,977		28,683		(3,673		)	158,987
Investment in HEP	—			—		210,499			—			210,499		—		(210,499		)	—
Equity – HollyFrontier	5,968,943			5,251,396		74,120			(5,325,516		)	5,968,943		382,207		(298,196		)	6,052,954
Equity – noncontrolling interest	—			—		—			—			—		115,502		474,202			589,704
Total liabilities and equity	$	7,226,890		$	7,072,099	$	286,366		$	(5,350,516	)	$	9,234,839	$	1,426,800	$	(332,642	)	$	10,328,997

Table of Contents

HOLLYFRONTIER CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued



Condensed Consolidating Statement of Income and Comprehensive Income
Three Months Ended June 30, 2013	Parent			Guarantor Restricted Subsidiaries		Non- Guarantor Restricted Subsidiaries			Eliminations			HollyFrontier Corp. Before Consolidation of HEP			Non-Guarantor Non-Restricted Subsidiaries (HEP Segment)			Eliminations			Consolidated
	(In thousands)
Sales and other revenues	$	100		$	5,286,984	$	31		$	—		$	5,287,115		$	75,121		$	(63,388	)	$	5,298,848
Operating costs and expenses:
Cost of products sold	—			4,518,737		92			282			4,519,111			—			(62,303		)	4,456,808
Operating expenses	—			255,874		19			—			255,893			22,010			(361		)	277,542
General and administrative	30,242			630		28			—			30,900			3,100			—			34,000
Depreciation and amortization	1,400			57,043		—			—			58,443			15,619			(3,570		)	70,492
Total operating costs and expenses	31,642			4,832,284		139			282			4,864,347			40,729			(66,234		)	4,838,842
Income (loss) from operations	(31,542		)	454,700		(108		)	(282		)	422,768			34,392			2,846			460,006
Other income (expense):
Earnings (loss) of equity method investments	469,228			12,592		14,401			(483,655		)	12,566			746			(14,401		)	(1,089		)
Interest income (expense)	(7,456		)	1,936		134			294			(5,092		)	(11,624		)	(2,300		)	(19,016		)
Loss on early extinguishment of debt	(22,109		)	—		—			—			(22,109		)	—			—			(22,109		)
	439,663			14,528		14,535			(483,361		)	(14,635		)	(10,878		)	(16,701		)	(42,214		)
Income before income taxes	408,121			469,228		14,427			(483,643		)	408,133			23,514			(13,855		)	417,792
Income tax provision	151,698			—		—			—			151,698			345			—			152,043
Net income	256,423			469,228		14,427			(483,643		)	256,435			23,169			(13,855		)	265,749
Less net income attributable to noncontrolling interest	—			—		—			—			—			1,130			7,638			8,768
Net income attributable to HollyFrontier stockholders	$	256,423		$	469,228	$	14,427		$	(483,643	)	$	256,435		$	22,039		$	(21,493	)	$	256,981
Comprehensive income attributable to HollyFrontier stockholders	$	286,296		$	489,146	$	15,900		$	(505,034	)	$	286,308		$	23,512		$	(22,966	)	$	286,854



Condensed Consolidating Statement of Income and Comprehensive Income
Three Months Ended June 30, 2012	Parent			Guarantor Restricted Subsidiaries		Non- Guarantor Restricted Subsidiaries		Eliminations			HollyFrontier Corp. Before Consolidation of HEP			Non-Guarantor Non-Restricted Subsidiaries (HEP Segment)			Eliminations			Consolidated
	(In thousands)
Sales and other revenues	$	100		$	4,795,647	$	45	$	—		$	4,795,792		$	67,103		$	(56,214	)	$	4,806,681
Operating costs and expenses:
Cost of products sold	—			3,737,228		—		489			3,737,717			—			(55,953		)	3,681,764
Operating expenses	—			202,222		—		(336		)	201,886			20,371			469			222,726
General and administrative	29,451			138		31		—			29,620			2,486			—			32,106
Depreciation and amortization	876			47,325		—		—			48,201			12,317			(3,570		)	56,948
Total operating costs and expenses	30,327			3,986,913		31		153			4,017,424			35,174			(59,054		)	3,993,544
Income (loss) from operations	(30,227		)	808,734		14		(153		)	778,368			31,929			2,840			813,137
Other income (expense):
Earnings of equity method investments	822,160			11,395		11,114		(833,463		)	11,206			794			(11,114		)	886
Interest income (expense)	(13,424		)	1,705		175		224			(11,320		)	(12,664		)	(2,277		)	(26,261		)
Gain on sale of marketable equity securities	—			326		—		—			326			—			—			326
	808,736			13,426		11,289		(833,239		)	212			(11,870		)	(13,391		)	(25,049		)
Income before income taxes	778,509			822,160		11,303		(833,392		)	778,580			20,059			(10,551		)	788,088
Income tax provision	285,643			—		—		—			285,643			75			—			285,718
Net income	492,866			822,160		11,303		(833,392		)	492,937			19,984			(10,551		)	502,370
Less net income attributable to noncontrolling interest	—			—		—		—			—			(683		)	9,554			8,871
Net income attributable to HollyFrontier stockholders	$	492,866		$	822,160	$	11,303	$	(833,392	)	$	492,937		$	20,667		$	(20,105	)	$	493,499
Comprehensive income attributable to HollyFrontier stockholders	$	515,862		$	852,772	$	11,204	$	(863,905	)	$	515,933		$	20,568		$	(20,006	)	$	516,495

Table of Contents

HOLLYFRONTIER CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued



Condensed Consolidating Statement of Income and Comprehensive Income
Six Months Ended June 30, 2013	Parent			Guarantor Restricted Subsidiaries		Non- Guarantor Restricted Subsidiaries			Eliminations			HollyFrontier Corp. Before Consolidation of HEP			Non-Guarantor Non-Restricted Subsidiaries (HEP Segment)			Eliminations			Consolidated
	(In thousands)
Sales and other revenues	$	631		$	9,979,410	$	63		$	—		$	9,980,104		$	151,605		$	(125,072	)	$	10,006,637
Operating costs and expenses:
Cost of products sold	—			8,371,865		—			415			8,372,280			—			(122,937		)	8,249,343
Operating expenses	—			495,297		—			—			495,297			48,039			(695		)	542,641
General and administrative	54,373			2,405		88			—			56,866			6,332			—			63,198
Depreciation and amortization	2,326			117,663		—			—			119,989			29,368			(7,103		)	142,254
Total operating costs and expenses	56,699			8,987,230		88			415			9,044,432			83,739			(130,735		)	8,997,436
Income (loss) from operations	(56,068		)	992,180		(25		)	(415		)	935,672			67,866			5,663			1,009,201
Other income (expense):
Earnings (loss) of equity method investments	1,020,119			24,206		26,393			(1,046,758		)	23,960			1,403			(26,393		)	(1,030		)
Interest income (expense)	(14,677		)	3,733		271			446			(10,227		)	(24,006		)	(4,572		)	(38,805		)
Loss on early extinguishment of debt	(22,109		)	—		—			—			(22,109		)	—			—			(22,109		)
	983,333			27,939		26,664			(1,046,312		)	(8,376		)	(22,603		)	(30,965		)	(61,944		)
Income before income taxes	927,265			1,020,119		26,639			(1,046,727		)	927,296			45,263			(25,302		)	947,257
Income tax provision	337,737			—		—			—			337,737			400			—			338,137
Net income	589,528			1,020,119		26,639			(1,046,727		)	589,559			44,863			(25,302		)	609,120
Less net income attributable to noncontrolling interest	—			—		—			—			—			4,020			14,450			18,470
Net income attributable to HollyFrontier stockholders	$	589,528		$	1,020,119	$	26,639		$	(1,046,727	)	$	589,559		$	40,843		$	(39,752	)	$	590,650
Comprehensive income attributable to HollyFrontier stockholders	$	631,160		$	1,057,542	$	28,731		$	(1,086,242	)	$	631,191		$	42,935		$	(41,844	)	$	632,282



Condensed Consolidating Statement of Income and Comprehensive Income
Six Months Ended June 30, 2012	Parent			Guarantor Restricted Subsidiaries		Non- Guarantor Restricted Subsidiaries		Eliminations			HollyFrontier Corp. Before Consolidation of HEP			Non-Guarantor Non-Restricted Subsidiaries (HEP Segment)			Eliminations			Consolidated
	(In thousands)
Sales and other revenues	$	199		$	9,715,384	$	102	$	—		$	9,715,685		$	134,680		$	(111,946	)	$	9,738,419
Operating costs and expenses:
Cost of products sold	—			7,978,529		—		980			7,979,509			—			(110,828		)	7,868,681
Operating expenses	—			424,337		—		(721		)	423,616			40,401			336			464,353
General and administrative	54,424			639		46		—			55,109			4,525			—			59,634
Depreciation and amortization	1,979			92,499		—		—			94,478			25,712			(7,140		)	113,050
Total operating costs and expenses	56,403			8,496,004		46		259			8,552,712			70,638			(117,632		)	8,505,718
Income (loss) from operations	(56,204		)	1,219,380		56		(259		)	1,162,973			64,042			5,686			1,232,701
Other income (expense):
Earnings of equity method investments	1,243,221			19,897		19,489		(1,263,140		)	19,467			1,625			(19,489		)	1,603
Interest income (expense)	(27,447		)	3,618		374		728			(22,727		)	(31,834		)	(4,555		)	(59,116		)
Gain on sale of marketable securities	—			326		—		—			326			—			—			326
	1,215,774			23,841		19,863		(1,262,412		)	(2,934		)	(30,209		)	(24,044		)	(57,187		)
Income before income taxes	1,159,570			1,243,221		19,919		(1,262,671		)	1,160,039			33,833			(18,358		)	1,175,514
Income tax provision	425,974			—		—		—			425,974			150			—			426,124
Net income	733,596			1,243,221		19,919		(1,262,671		)	734,065			33,683			(18,358		)	749,390
Less net income attributable to noncontrolling interest	—			—		—		—			—			(1,240		)	15,435			14,195
Net income attributable to HollyFrontier stockholders	$	733,596		$	1,243,221	$	19,919	$	(1,262,671	)	$	734,065		$	34,923		$	(33,793	)	$	735,195
Comprehensive income attributable to HollyFrontier stockholders	$	661,298		$	1,117,681	$	20,204	$	(1,137,416	)	$	661,767		$	35,208		$	(34,078	)	$	662,897

Table of Contents

HOLLYFRONTIER CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued



Condensed Consolidating Statement of Cash Flows
Six Months Ended June 30, 2013	Parent			Guarantor Restricted Subsidiaries			Non- Guarantor Restricted Subsidiaries			HollyFrontier Corp. Before Consolidation of HEP			Non-Guarantor Non-Restricted Subsidiaries (HEP Segment)			Eliminations			Consolidated
	(In thousands)
Cash flows from operating activities	$	241,004		$	162,285		$	1,499		$	404,788		$	81,542		$	(34,815	)	$	451,515

Cash flows from investing activities
Additions to properties, plants and equip	(5,025		)	(148,917		)	—			(153,942		)	—			—			(153,942		)
Additions to properties, plants and equip – HEP	—			—			—			—			(16,861		)	—			(16,861		)
Proceeds from sale of property	—			3,321			—			3,321			2,481			—			5,802
Investment in Sabine Biofuels	—			(2,000		)	—			(2,000		)	—			—			(2,000		)
Advances to Sabine Biofuels	—			(13,700		)	—			(13,700		)	—			—			(13,700		)
Purchases of marketable securities	(399,154		)	—			—			(399,154		)	—			—			(399,154		)
Sales and maturities of marketable securities	398,762			—			—			398,762			—			—			398,762
	(5,417		)	(161,296		)	—			(166,713		)	(14,380		)	—			(181,093		)
Cash flows from financing activities
Net repayments under credit agreement – HEP	—			—			—			—			(66,000		)	—			(66,000		)
Redemption of senior notes - HFC	(286,812		)	—			—			(286,812		)	—			—			(286,812		)
Redemption premium on early extinguishment of debt	(14,161		)	—			—			(14,161		)	—			—			(14,161		)
Proceeds from sale of HEP common units	73,444			—			—			73,444			—			—			73,444
Proceeds from common unit offerings - HEP	—			—			—			—			73,444			—			73,444
Purchase of treasury stock	(159,432		)	—			—			(159,432		)	—			—			(159,432		)
Contribution from general partner	—			—			(1,499		)	(1,499		)	1,499			—			—
Dividends	(264,867		)	—			—			(264,867		)	—			—			(264,867		)
Distributions to noncontrolling interest	—			—			—			—			(69,419		)	34,815			(34,604		)
Excess tax benefit from equity-based compensation	1,037			—			—			1,037			—			—			1,037
Purchase of units for incentive grants - HEP	—			—			—			—			(2,934		)	—			(2,934		)
Other	—			2,457			—			2,457			(273		)	—			2,184
	(650,791		)	2,457			(1,499		)	(649,833		)	(63,683		)	34,815			(678,701		)
Cash and cash equivalents
Increase (decrease) for the period	(415,204		)	3,446			—			(411,758		)	3,479			—			(408,279		)
Beginning of period	1,748,808			3,652			2			1,752,462			5,237			—			1,757,699
End of period	$	1,333,604		$	7,098		$	2		$	1,340,704		$	8,716		$	—		$	1,349,420

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HOLLYFRONTIER CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued



Condensed Consolidating Statement of Cash Flows
Six Months Ended June 30, 2012	Parent			Guarantor Restricted Subsidiaries			Non- Guarantor Restricted Subsidiaries		HollyFrontier Corp. Before Consolidation of HEP			Non-Guarantor Non-Restricted Subsidiaries (HEP Segment)			Eliminations			Consolidated
	(In thousands)
Cash flows from operating activities	$	347,534		$	45,516		$	—	$	393,050		$	67,011		$	(30,558	)	$	429,503

Cash flows from investing activities:
Additions to properties, plants and equip	(1,679		)	(102,722		)	—		(104,401		)	—			—			(104,401		)
Additions to properties, plants and equip – HEP	—			—			—		—			(23,619		)	—			(23,619		)
Investment in Sabine Biofuels	—			(2,000		)	—		(2,000		)	—			—			(2,000		)
Purchases of marketable securities	(166,429		)	—			—		(166,429		)	—			—			(166,429		)
Sales and maturities of marketable securities	151,066			930			—		151,996			—			—			151,996
	(17,042		)	(103,792		)	—		(120,834		)	(23,619		)	—			(144,453		)
Cash flows from financing activities:
Net borrowings under credit agreement – HEP	—			—			—		—			(30,000		)	—			(30,000		)
Repayment of promissory notes	—			72,900			—		72,900			(72,900		)	—			—
Net proceeds from issuance of senior notes - HEP	—			—			—		—			294,750			—			294,750
Principal tender on senior notes - HFC	(5,000		)	—			—		(5,000		)	—			—			(5,000		)
Principal tender on senior notes - HEP	—			—			—		—			(185,000		)	—			(185,000		)
Purchase of treasury stock	(189,771		)	—			—		(189,771		)	—			—			(189,771		)
Structured stock repurchase arrangement	(100,000		)	—			—		(100,000		)	—			—			(100,000		)
Contribution to HEP	—			(9,000		)	—		(9,000		)	9,000			—			—
Contribution from joint venture partner	—			—			—		—			6,000			—			6,000
Dividends	(249,958		)	—			—		(249,958		)	—			—			(249,958		)
Distributions to noncontrolling interest	—			—			—		—			(59,977		)	31,033			(28,944		)
Excess tax benefit from equity-based compensation	4,762			—			—		4,762			—			—			4,762
Purchase of units for restricted grants - HEP	—			—			—		—			(4,533		)	—			(4,533		)
Deferred financing costs	—			(67		)	—		(67		)	(3,162		)	—			(3,229		)
Other	—			(635		)	—		(635		)	277			(475		)	(833		)
	(539,967		)	63,198			—		(476,769		)	(45,545		)	30,558			(491,756		)
Cash and cash equivalents
Increase (decrease) for the period:	(209,475		)	4,922			—		(204,553		)	(2,153		)	—			(206,706		)
Beginning of period	1,575,891			(3,358		)	2		1,572,535			6,369			—			1,578,904
End of period	$	1,366,416		$	1,564		$	2	$	1,367,982		$	4,216		$	—		$	1,372,198

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

This Item 2 contains “forward-looking” statements. See “Forward-Looking Statements” at the beginning of Part I of this Quarterly Report on Form 10-Q. References herein to HollyFrontier Corporation (“HollyFrontier”) include HollyFrontier and its consolidated subsidiaries. In accordance with the Securities and Exchange Commission’s (“SEC”) “Plain English” guidelines, this Quarterly Report on Form 10-Q has been written in the first person. In this document, the words “we,” “our,” “ours” and “us” refer only to HollyFrontier and its consolidated subsidiaries or to HollyFrontier or an individual subsidiary and not to any other person, with certain exceptions. Generally, the words “we,” “our,” “ours” and “us” include Holly Energy Partners, L.P. (“HEP”) and its subsidiaries as consolidated subsidiaries of HollyFrontier, unless when used in disclosures of transactions or obligations between HEP and HollyFrontier or its other subsidiaries. This document contains certain disclosures of agreements that are specific to HEP and its consolidated subsidiaries and do not necessarily represent obligations of HollyFrontier. When used in descriptions of agreements and transactions, “HEP” refers to HEP and its consolidated subsidiaries.

OVERVIEW

We are principally an independent petroleum refiner that produces high-value refined products such as gasoline, diesel fuel, jet fuel, specialty lubricant products, and specialty and modified asphalt. We own and operate refineries having a combined crude oil processing capacity of 443,000 barrels per day that serve markets throughout the Mid-Continent, Southwest and Rocky Mountain regions of the United States. Our refineries are located in El Dorado, Kansas (the “El Dorado Refinery”), Tulsa, Oklahoma (the, “Tulsa Refineries”), which comprise two production facilities, the Tulsa West and East facilities, a petroleum refinery in Artesia, New Mexico, which operates in conjunction with crude, vacuum distillation and other facilities situated 65 miles away in Lovington, New Mexico (collectively, the “Navajo Refinery”), Cheyenne, Wyoming (the, “Cheyenne Refinery”) and Woods Cross, Utah (the “Woods Cross Refinery”).

For the three months ended June 30, 2013, net income attributable to HollyFrontier stockholders was $257.0 million compared to $493.5 million for the three months ended June 30, 2012. For the six months ended June 30, 2013, net income attributable to HollyFrontier stockholders was $590.7 million compared to $735.2 million for the six months ended June 30, 2012.

Overall gross refining margins per produced product sold decreased 26% and 3% over the respective three and six months ended June 30, 2012 due principally to significant contraction in WTI to Brent crude differentials as well as discounts on heavy sour crudes during the second quarter of 2013.

During the current year second quarter, we recognized pension settlement and debt extinguishment charges of $30.9 million and $22.1 million, respectively, and a business interruption insurance recovery of $10.6 million resulting in a net combined after-tax charge of $25.9 million to net income. Also affecting current year net income were the effects of a planned turnaround at our Tulsa Refinery as well as approximately 10 days of unplanned downtime incurred at each of our El Dorado and Cheyenne Refineries as a result of FCC unit issues during the second quarter of 2013. We incurred additional downtime in the first quarter of 2013 due to planned turnaround and maintenance projects at our El Dorado and Navajo Refineries.

OUTLOOK

Our profitability is affected by the spread, or differential, between the market prices for crude oil on the world market (which is based on the price for Brent Sea Crude) and the price for inland U.S. crude oil (which is based on the price for WTI). This differential constantly changes and at times can be volatile. While we have generally experienced wide differentials (with Brent prices in excess of WTI prices) in recent years, which have significantly enhanced our profitability, at the end of the second quarter of 2013, the differential between Brent and WTI narrowed - averaging approximately half of the differential experienced during the first quarter of 2013. Differentials are likely to continue to be volatile in the near term. However, we expect the Brent to WTI differential to reemerge upon completion of additional northern tier pipeline capacity into Cushing, Oklahoma, which we believe will overwhelm Gulf Coast processing capacity with light sweet crude oil flows. Ultimately, we believe pipeline tariffs from Cushing to the Gulf Coast plus marine transportation costs to transport product from the Gulf to alternative markets will set the inland - coastal differential.

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Pursuant to the 2007 Energy Independence and Security Act, the Environmental Protection Agency ("EPA") promulgated the Renewable Fuel Standard 2 (“RFS2”) regulations reflecting the increased volume of renewable fuels mandated to be blended into the nation's fuel supply. The regulations, in part, require refiners to add annually increasing amounts of “renewable fuels” to their petroleum products or purchase credits, known as renewable identification numbers (“RINs”), in lieu of such blending. As of June 2013, we are purchasing RINs in order to meet approximately half of our renewable fuel requirements. Recently, due in part to the nation's fuel supply approaching the “blend wall” (the 10% ethanol limit prescribed by most automobile warranties), the price of RINs has been extremely volatile with the price dramatically increasing in recognition of the decrease in RINs availability. As a result, we expect to continue to experience increasing costs to comply with the renewable fuel mandate. In the wholesale markets we serve, we are seeing price adjustments to indicate that the cost of RINs is being largely paid by the consumer at the pump. However, we continue to use various approaches to mitigate our exposure to the increasing cost of RINs, which include additional renewable fuel blending, shifts in our refined product slate and changes in the way we conduct marketing operations. We cannot predict with certainty whether and to what extent we will be successful in mitigating our exposure to increased RINs costs, and anticipate that increased compliance costs may negatively impact our future results of operations.

A more detailed discussion of our financial and operating results for the three and six months ended June 30, 2013 and 2012 is presented in the following sections.

RESULTS OF OPERATIONS

Financial Data (Unaudited)



	Three Months Ended June 30,						Change from 2012
	2013			2012			Change			Percent
	(In thousands, except per share data)
Sales and other revenues	$	5,298,848		$	4,806,681		$	492,167		10	%
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	4,456,808			3,681,764			775,044			21
Operating expenses (exclusive of depreciation and amortization)	277,542			222,726			54,816			25
General and administrative expenses (exclusive of depreciation and amortization)	34,000			32,106			1,894			6
Depreciation and amortization	70,492			56,948			13,544			24
Total operating costs and expenses	4,838,842			3,993,544			845,298			21
Income from operations	460,006			813,137			(353,131		)	(43	)
Other income (expense):
Earnings (loss) of equity method investments	(1,089		)	886			(1,975		)	(223	)
Interest income	778			681			97			14
Interest expense	(19,794		)	(26,942		)	7,148			(27	)
Loss on early extinguishment of debt	(22,109		)	—			(22,109		)	—
Gain on sale of marketable securities	—			326			(326		)	(100	)
	(42,214		)	(25,049		)	(17,165		)	69
Income before income taxes	417,792			788,088			(370,296		)	(47	)
Income tax provision	152,043			285,718			(133,675		)	(47	)
Net income	265,749			502,370			(236,621		)	(47	)
Less net income attributable to noncontrolling interest	8,768			8,871			(103		)	(1	)
Net income attributable to HollyFrontier stockholders	$	256,981		$	493,499		$	(236,518	)	(48	)%
Earnings per share attributable to HollyFrontier stockholders:
Basic	$	1.27		$	2.40		$	(1.13	)	(47	)%
Diluted	$	1.27		$	2.39		$	(1.12	)	(47	)%
Cash dividends declared per common share	$	0.80		$	0.65		$	0.15		23	%
Average number of common shares outstanding:
Basic	201,543			205,727			(4,184		)	(2	)%
Diluted	201,905			206,481			(4,576		)	(2	)%

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	Six Months Ended June 30,						Change from 2012
	2013			2012			Change			Percent
	(In thousands, except per share data)
Sales and other revenues	$	10,006,637		$	9,738,419		$	268,218		3	%
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	8,249,343			7,868,681			380,662			5
Operating expenses (exclusive of depreciation and amortization)	542,641			464,353			78,288			17
General and administrative expenses (exclusive of depreciation and amortization)	63,198			59,634			3,564			6
Depreciation and amortization	142,254			113,050			29,204			26
Total operating costs and expenses	8,997,436			8,505,718			491,718			6
Income from operations	1,009,201			1,232,701			(223,500		)	(18	)
Other income (expense):
Earnings (loss) of equity method investments	(1,030		)	1,603			(2,633		)	(164	)
Interest income	2,309			1,141			1,168			102
Interest expense	(41,114		)	(60,257		)	19,143			(32	)
Loss on early extinguishment of debt	(22,109		)	—			(22,109		)	—
Gain on sale of marketable securities	—			326			(326		)	(100	)
	(61,944		)	(57,187		)	(4,757		)	8
Income before income taxes	947,257			1,175,514			(228,257		)	(19	)
Income tax provision	338,137			426,124			(87,987		)	(21	)
Net income	609,120			749,390			(140,270		)	(19	)
Less net income attributable to noncontrolling interest	18,470			14,195			4,275			30
Net income attributable to HollyFrontier stockholders	$	590,650		$	735,195		$	(144,545	)	(20	)%
Earnings per share attributable to HollyFrontier stockholders:
Basic	$	2.91		$	3.55		$	(0.64	)	(18	)%
Diluted	$	2.91		$	3.54		$	(0.63	)	(18	)%
Cash dividends declared per common share	$	1.60		$	1.25		$	0.35		28	%
Average number of common shares outstanding:
Basic	202,131			207,129			(4,998		)	(2	)%
Diluted	202,485			207,938			(5,453		)	(3	)%

Balance Sheet Data



	June 30, 2013		December 31, 2012
	(Unaudited)
	(In thousands)
Cash, cash equivalents and investments in marketable securities	$	1,985,528	$	2,393,401
Working capital	$	2,568,461	$	2,815,821
Total assets	$	10,493,934	$	10,328,997
Long-term debt	$	990,236	$	1,336,238
Total equity	$	6,899,378	$	6,642,658

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Other Financial Data (Unaudited)



	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
	(In thousands)
Net cash provided by operating activities	$	202,952		$	175,598		$	451,515		$	429,503
Net cash used for investing activities	$	(76,448	)	$	(75,773	)	$	(181,093	)	$	(144,453	)
Net cash used for financing activities	$	(649,526	)	$	(387,177	)	$	(678,701	)	$	(491,756	)
Capital expenditures	$	98,839		$	66,633		$	170,803		$	128,020
EBITDA ⁽¹⁾	$	520,641		$	862,426		$	1,131,955		$	1,333,485

(1)

Earnings before interest, taxes, depreciation and amortization, which we refer to as “EBITDA”, is calculated as net income plus (i) interest expense, net of interest income, (ii) income tax provision, and (iii) depreciation and amortization. EBITDA is not a calculation provided for under GAAP; however, the amounts included in the EBITDA calculation are derived from amounts included in our consolidated financial statements. EBITDA should not be considered as an alternative to net income or operating income as an indication of our operating performance or as an alternative to operating cash flow as a measure of liquidity. EBITDA is not necessarily comparable to similarly titled measures of other companies. EBITDA is presented here because it is a widely used financial indicator used by investors and analysts to measure performance. EBITDA is also used by our management for internal analysis and as a basis for financial covenants. EBITDA presented above is reconciled to net income under “Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles” following Item 3 of Part I of this Form 10-Q.

Our operations are organized into two reportable segments, Refining and HEP. See Note 15 “Segment Information” in the Notes to Consolidated Financial Statements for additional information on our reportable segments.

Refining Operating Data (Unaudited)

The following tables set forth information, including non-GAAP performance measures, about our refinery operations. The cost of products and refinery gross margin do not include the effect of depreciation and amortization. Reconciliations to amounts reported under GAAP are provided under “Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles” following Item 3 of Part I of this Form 10-Q.



	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Mid-Continent Region (El Dorado and Tulsa Refineries)
Crude charge (BPD) ⁽¹⁾	205,770			243,150			223,030			249,710
Refinery throughput (BPD) ⁽²⁾	226,010			259,250			246,250			266,020
Refinery production (BPD) ⁽³⁾	220,770			251,870			240,380			260,070
Sales of produced refined products (BPD)	213,240			242,560			227,810			250,810
Sales of refined products (BPD) ⁽⁴⁾	261,950			246,130			257,870			255,260
Refinery utilization ⁽⁵⁾	79.1		%	93.5		%	85.8		%	96.0		%

Average per produced barrel ⁽⁶⁾
Net sales	$	118.05		$	118.72		$	117.25		$	119.38
Cost of products ⁽⁷⁾	97.07			94.16			95.39			98.31
Refinery gross margin	20.98			24.56			21.86			21.07
Refinery operating expenses ⁽⁸⁾	6.12			4.63			5.97			4.73
Net operating margin	$	14.86		$	19.93		$	15.89		$	16.34

Refinery operating expenses per throughput barrel ⁽⁹⁾	$	5.77		$	4.33		$	5.52		$	4.46

Feedstocks:
Sweet crude oil	72		%	71		%	72		%	71		%
Sour crude oil	3		%	7		%	4		%	8		%
Heavy sour crude oil	16		%	16		%	15		%	15		%
Other feedstocks and blends	9		%	6		%	9		%	6		%
Total	100		%	100		%	100		%	100		%

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	Three Months Ended June 30,				Six Months Ended June 30,
	2013		2012		2013		2012
Mid-Continent Region (El Dorado and Tulsa Refineries)
Sales of produced refined products:
Gasolines	44	%	46	%	46	%	46	%
Diesel fuels	33	%	28	%	32	%	30	%
Jet fuels	8	%	10	%	8	%	9	%
Fuel oil	1	%	—	%	1	%	—	%
Asphalt	3	%	2	%	3	%	2	%
Lubricants	4	%	5	%	4	%	5	%
LPG and other	7	%	9	%	6	%	8	%
Total	100	%	100	%	100	%	100	%



Southwest Region (Navajo Refinery)
Crude charge (BPD) ⁽¹⁾	104,910			92,960			88,160			87,050
Refinery throughput (BPD) ⁽²⁾	115,230			101,090			97,760			95,740
Refinery production (BPD) ⁽³⁾	114,410			100,960			94,410			94,010
Sales of produced refined products (BPD)	110,830			98,680			91,110			92,970
Sales of refined products (BPD) ⁽⁴⁾	119,740			103,380			104,860			98,250
Refinery utilization ⁽⁵⁾	104.9		%	93.0		%	88.2		%	87.1		%

Average per produced barrel ⁽⁶⁾
Net sales	$	117.03		$	123.25		$	118.95		$	124.50
Cost of products ⁽⁷⁾	100.70			94.98			98.40			100.33
Refinery gross margin	16.33			28.27			20.55			24.17
Refinery operating expenses ⁽⁸⁾	5.10			5.06			6.25			5.81
Net operating margin	$	11.23		$	23.21		$	14.30		$	18.36

Refinery operating expenses per throughput barrel ⁽⁹⁾	$	4.91		$	4.94		$	5.82		$	5.64

Feedstocks:
Sweet crude oil	8		%	4		%	5		%	2		%
Sour crude oil	70		%	80		%	74		%	80		%
Heavy sour crude oil	13		%	8		%	12		%	9		%
Other feedstocks and blends	9		%	8		%	9		%	9		%
Total	100		%	100		%	100		%	100		%

Sales of produced refined products:
Gasolines	50		%	49		%	50		%	51		%
Diesel fuels	40		%	40		%	39		%	38		%
Fuel oil	5		%	6		%	6		%	6		%
Asphalt	2		%	2		%	2		%	2		%
LPG and other	3		%	3		%	3		%	3		%
Total	100		%	100		%	100		%	100		%



Rocky Mountain Region (Cheyenne and Woods Cross Refineries)
Crude charge (BPD) ⁽¹⁾	70,780		75,680		69,850		72,960
Refinery throughput (BPD) ⁽²⁾	77,260		83,860		75,730		81,300
Refinery production (BPD) ⁽³⁾	73,540		82,270		73,200		79,730
Sales of produced refined products (BPD)	73,890		80,230		73,150		78,440
Sales of refined products (BPD) ⁽⁴⁾	75,100		82,360		76,810		80,840
Refinery utilization ⁽⁵⁾	85.3	%	91.2	%	84.2	%	87.9	%

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	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Rocky Mountain Region (Cheyenne and Woods Cross Refineries)
Average per produced barrel ⁽⁶⁾
Net sales	$	116.66		$	120.97		$	112.53		$	115.98
Cost of products ⁽⁷⁾	92.46			85.93			89.55			91.24
Refinery gross margin	24.20			35.04			22.98			24.74
Refinery operating expenses ⁽⁸⁾	7.47			6.05			7.78			6.30
Net operating margin	$	16.73		$	28.99		$	15.20		$	18.44

Refinery operating expenses per throughput barrel ⁽⁹⁾	$	7.14		$	5.79		$	7.51		$	6.08

Feedstocks:
Sweet crude oil	42		%	43		%	43		%	44		%
Sour crude oil	1		%	2		%	1		%	2		%
Heavy sour crude oil	35		%	34		%	34		%	33		%
Black wax crude oil	14		%	11		%	14		%	11		%
Other feedstocks and blends	8		%	10		%	8		%	10		%
Total	100		%	100		%	100		%	100		%

Sales of produced refined products:
Gasolines	51		%	54		%	55		%	55		%
Diesel fuels	35		%	33		%	31		%	32		%
Fuel oil	1		%	1		%	1		%	2		%
Asphalt	5		%	6		%	6		%	5		%
LPG and other	8		%	6		%	7		%	6		%
Total	100		%	100		%	100		%	100		%



Consolidated
Crude charge (BPD) ⁽¹⁾	381,460			411,790			381,040			409,720
Refinery throughput (BPD) ⁽²⁾	418,500			444,200			419,740			443,060
Refinery production (BPD) ⁽³⁾	408,720			435,100			407,990			433,810
Sales of produced refined products (BPD)	397,960			421,470			392,070			422,220
Sales of refined products (BPD) ⁽⁴⁾	456,790			431,870			439,540			434,350
Refinery utilization ⁽⁵⁾	86.1		%	93.0		%	86.0		%	92.5		%

Average per produced barrel ⁽⁶⁾
Net sales	$	117.51		$	120.21		$	116.77		$	119.87
Cost of products ⁽⁷⁾	97.23			92.78			95.00			97.44
Refinery gross margin	20.28			27.43			21.77			22.43
Refinery operating expenses ⁽⁸⁾	6.09			5.00			6.38			5.26
Net operating margin	$	14.19		$	22.43		$	15.39		$	17.17

Refinery operating expenses per throughput barrel ⁽⁹⁾	$	5.79		$	4.75		$	5.95		$	5.01

Feedstocks:
Sweet crude oil	49		%	51		%	51		%	51		%
Sour crude oil	21		%	22		%	20		%	22		%
Heavy sour crude oil	19		%	18		%	17		%	17		%
Black wax crude oil	2		%	2		%	3		%	2		%
Other feedstocks and blends	9		%	7		%	9		%	8		%
Total	100		%	100		%	100		%	100		%

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	Three Months Ended June 30,				Six Months Ended June 30,
	2013		2012		2013		2012
Consolidated
Sales of produced refined products:
Gasolines	47	%	48	%	49	%	49	%
Diesel fuels	35	%	32	%	33	%	32	%
Jet fuels	4	%	6	%	5	%	6	%
Fuel oil	2	%	2	%	2	%	2	%
Asphalt	3	%	3	%	3	%	2	%
Lubricants	3	%	3	%	2	%	3	%
LPG and other	6	%	6	%	6	%	6	%
Total	100	%	100	%	100	%	100	%


(1)	Crude charge represents the barrels per day of crude oil processed at our refineries.


(2)	Refinery throughput represents the barrels per day of crude and other refinery feedstocks input to the crude units and other conversion units at our refineries.


(3)	Refinery production represents the barrels per day of refined products yielded from processing crude and other refinery feedstocks through the crude units and other conversion units at our refineries.


(4)	Includes refined products purchased for resale.


(5)	Represents crude charge divided by total crude capacity (BPSD). Our consolidated crude capacity is 443,000 BPSD.


(6)	Represents average per barrel amount for produced refined products sold, which is a non-GAAP measure. Reconciliations to amounts reported under GAAP are provided under “Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles” following Item 3 of Part I of this Form 10-Q.


(7)	Transportation, terminal and refinery storage costs billed from HEP are included in cost of products.


(8)	Represents operating expenses of our refineries, exclusive of depreciation and amortization and pension settlement charges.


(9)	Represents refinery operating expenses, exclusive of depreciation and amortization and pension settlement costs, divided by refinery throughput.

Results of Operations – Three Months Ended June 30, 2013 Compared to Three Months Ended June 30, 2012

Summary

Net income attributable to HollyFrontier stockholders for the three months ended June 30, 2013 was $257.0 million ($1.27 per basic and diluted share), a $236.5 million decrease compared to $493.5 million ($2.40 per basic and $2.39 per diluted share) for the three months ended June 30, 2012. Net income decreased due principally to a year-over-year decrease in second quarter refining margins, refinery downtime and pension settlement and debt extinguishment charges. Refinery gross margins for the three months ended June 30, 2013 decreased to $20.28 per produced barrel from $27.43 for the three months ended June 30, 2012.

Sales and Other Revenues

Sales and other revenues increased 10% from $4,806.7 million for the three months ended June 30, 2012 to $5,298.8 million for the three months ended June 30, 2013 due to higher refined product sales volumes, partially offset by a year-over-year decrease in second quarter sales prices. The average sales price we received per produced barrel sold was $120.21 for the three months ended June 30, 2012 compared to $117.51 for the three months ended June 30, 2013. Refined product sales volumes for the current period reflect higher volumes of purchased products, comprising 13% of total refined products sales compared to 2% for the three months ended June 30, 2012 due principally to a decrease in refinery production and corresponding sales volumes of produced product as a result of planned turnaround and maintenance projects at our Tulsa Refinery and unplanned outages at our El Dorado and Cheyenne Refineries. Sales and other revenues for the three months ended June 30, 2013 and 2012 include $12.1 million and $10.9 million, respectively, in HEP revenues attributable to pipeline and transportation services provided to unaffiliated parties.

Cost of Products Sold

Cost of products sold increased 21% from $3,681.8 million for the three months ended June 30, 2012 to $4,456.8 million for the three months ended June 30, 2013, due principally to higher crude oil costs and higher sales volumes of purchased products caused, in part, by planned turnaround projects and unplanned refinery outages during the three months ended June 30, 2013. The average price we paid per barrel for crude oil and feedstocks and the transportation costs of moving the finished products to the market place increased 5% from $92.78 for the three months ended June 30, 2012 to $97.23 for the three months ended June 30, 2013.

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Gross Refinery Margins

Gross refinery margin per produced barrel decreased 26% from $27.43 for the three months ended June 30, 2012 to $20.28 for the three months ended June 30, 2013. This was due to the effects of an increase in crude oil and feedstock prices combined with the decrease in average per barrel sales prices for refined products sold for the quarter. Gross refinery margin does not include the effects of depreciation and amortization. See “Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles” following Item 3 of Part 1 of this Form 10-Q for a reconciliation to the income statement of prices of refined products sold and cost of products purchased.

Operating Expenses

Operating expenses, exclusive of depreciation and amortization, increased 25% from $222.7 million for the three months ended June 30, 2012 to $277.5 million for the three months ended June 30, 2013 due principally to $24.8 million in pension settlement costs and higher repair and maintenance and fuel costs during the quarter.

General and Administrative Expenses

General and administrative expenses increased 6% from $32.1 million for the three months ended June 30, 2012 to $34.0 million for the three months ended June 30, 2013 due to $3.5 million in pension settlement costs, partially offset by various year-over-year cost decreases.

Depreciation and Amortization Expenses

Depreciation and amortization increased 24% from $56.9 million for the three months ended June 30, 2012 to $70.5 million for the three months ended June 30, 2013. The increase was due principally to depreciation and amortization attributable to capitalized improvement projects and capitalized refinery turnaround costs.

Interest Expense

Interest expense was $19.8 million for the three months ended June 30, 2013 compared to $26.9 million for the three months ended June 30, 2012. This decrease was due to lower year-over-year debt levels principally as a result of the redemption of our $200 million 8.5% senior notes in September 2012. For the three months ended June 30, 2013 and 2012, interest expense included $11.6 million and $12.7 million, respectively, in interest costs attributable to HEP operations.

Loss on Early Extinguishment of Debt

Income Taxes

For the three months ended June 30, 2013, we recorded income tax expense of $152.0 million compared to $285.7 million for the three months ended June 30, 2012. This decrease is due principally to lower pre-tax earnings during the three months ended June 30, 2013 compared to the same period of 2012. Our effective tax rates, before consideration of earnings attributable to the noncontrolling interest, were 36.4% and 36.3% for the three months ended June 30, 2013 and 2012, respectively.

Results of Operations – Six Months Ended June 30, 2013 Compared to Six Months Ended June 30, 2012

Summary

Net income attributable to HollyFrontier stockholders for the six months ended June 30, 2013 was $590.7 million ($2.91 per basic and diluted share), a $144.5 million decrease compared to $735.2 million ($3.55 per basic and $3.54 per diluted share) for the six months ended June 30, 2012. Net income decreased due principally to refinery downtime, a year-over-year decrease in refining margins and pension settlement and debt extinguishment charges. Refinery gross margins for the six months ended June 30, 2013 decreased slightly to $21.77 per produced barrel from $22.43 for the six months ended June 30, 2012.

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Sales and Other Revenues

Sales and other revenues increased 3% from $9,738.4 million for the six months ended June 30, 2012 to $10,006.6 million for the six months ended June 30, 2013 due to higher refined product sales volumes, partially offset by a decrease in year-over-year sales prices. The average sales price we received per produced barrel sold was $119.87 for the six months ended June 30, 2012 compared to $116.77 for the six months ended June 30, 2013. Refined product sales volumes for the current period reflect higher volumes of purchased products, comprising 11% of total refined products sales compared to 3% for the six months ended June 30, 2012 due to a decrease in refinery production and corresponding sales volumes of produced product as a result of planned turnaround and maintenance projects at our El Dorado, Tulsa and Navajo Refineries and other unplanned refinery outages during the current year-to-date period. Sales and other revenues for the six months ended June 30, 2013 and 2012 include $24.9 million and $22.8 million, respectively, in HEP revenues attributable to pipeline and transportation services provided to unaffiliated parties.

Cost of Products Sold

Cost of products sold increased 5% from $7,868.7 million for the six months ended June 30, 2012 to $8,249.3 million for the six months ended June 30, 2013, due principally to higher refined product sales volumes, partially offset by overall lower crude costs for the current year. The sales volume increase is attributable to higher sales volumes of purchased products caused, in part, by planned turnaround projects and unplanned refinery outages during the six months ended June 30, 2013. The average price we paid per barrel for crude oil and feedstocks and the transportation costs of moving the finished products to the market place decreased 3% from $97.44 for the six months ended June 30, 2012 to $95.00 for the six months ended June 30, 2013.

Gross Refinery Margins

Gross refinery margin per produced barrel decreased 3% from $22.43 for the six months ended June 30, 2012 to $21.77 for the six months ended June 30, 2013. This was due to a larger decrease in average per barrel sales prices for refined products sold when compared to the decrease in crude oil and feedstock prices for the year-to-date period. Gross refinery margin does not include the effects of depreciation and amortization. See “Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles” following Item 3 of Part 1 of this Form 10-Q for a reconciliation to the income statement of prices of refined products sold and cost of products purchased.

Operating Expenses

Operating expenses, exclusive of depreciation and amortization, increased 17% from $464.4 million for the six months ended June 30, 2012 to $542.6 million for the six months ended June 30, 2013 due principally to pension settlement costs and higher repair and maintenance and fuel costs during the current year-to-date period.

General and Administrative Expenses

General and administrative expenses increased 6% from $59.6 million for the six months ended June 30, 2012 to $63.2 million for the six months ended June 30, 2013 due to pension settlement costs, slightly offset by various year-over-year cost decreases.

Depreciation and Amortization Expenses

Depreciation and amortization increased 26% from $113.1 million for the six months ended June 30, 2012 to $142.3 million for the six months ended June 30, 2013. The increase was due principally to depreciation and amortization attributable to capitalized improvement projects and capitalized refinery turnaround costs.

Interest Expense

Interest expense was $41.1 million for the six months ended June 30, 2013 compared to $60.3 million for the six months ended June 30, 2012. This decrease was due to lower year-over-year debt levels principally as a result of the redemption of our $200 million 8.5% senior notes in September 2012. For the six months ended June 30, 2013 and 2012, interest expense included $24.1 million and $31.8 million, respectively, in interest costs attributable to HEP operations.

Loss on Early Extinguishment of Debt

Income Taxes

For the six months ended June 30, 2013, we recorded income tax expense of $338.1 million compared to $426.1 million for the six months ended June 30, 2012. This decrease was due principally to lower pre-tax earnings during the six months ended June 30, 2013 compared to the same period of 2012. Our effective tax rates, before consideration of earnings attributable to the noncontrolling interest, were 35.7% and 36.3% for the six months ended June 30, 2013 and 2012, respectively.

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LIQUIDITY AND CAPITAL RESOURCES

HollyFrontier Credit Agreement

We have a $1 billion senior secured credit agreement that matures in July 2013 (the “HollyFrontier Credit Agreement”) and may be used to fund working capital requirements, capital expenditures, acquisitions and general corporate purposes. Obligations under the HollyFrontier Credit Agreement are collateralized by our inventory, accounts receivables and certain deposit accounts and guaranteed by our material, wholly-owned subsidiaries. At June 30, 2013, we were in compliance with all covenants, had no outstanding borrowings and had outstanding letters of credit totaling $28.8 million under the HollyFrontier Credit Agreement.

HEP Credit Agreement

HollyFrontier Senior Notes

HollyFrontier Financing Obligation

HEP Senior Notes

HEP’s senior notes consist of the following:


•	8.25% HEP senior notes ($150 million principal amount maturing March 2018)


•	6.5% HEP senior notes ($300 million principal amount maturing March 2020)

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HEP Common Unit Issuance

Liquidity

We believe our current cash and cash equivalents, along with future internally generated cash flow and funds available under our credit facilities will provide sufficient resources to fund currently planned capital projects and our liquidity needs for the foreseeable future. In addition, components of our growth strategy include construction of new refinery processing units and the expansion of existing units at our facilities and selective acquisition of complementary assets for our refining operations intended to increase earnings and cash flow.

As of June 30, 2013, our cash, cash equivalents and investments in marketable securities totaled $2.0 billion. We consider all highly-liquid instruments with a maturity of three months or less at the time of purchase to be cash equivalents. Cash equivalents are stated at cost, which approximates market value. These primarily consist of investments in conservative, highly-rated instruments issued by financial institutions, government and corporate entities with strong credit standings and money market funds.

We have a Board approved stock repurchase program that authorizes us to repurchase common stock in the open market or through privately negotiated transactions. The timing and amount of stock repurchases will depend on market conditions, corporate, regulatory and other relevant considerations. This program may be discontinued at any time by the Board of Directors. As of June 30, 2013, we had remaining authorization to repurchase up to $356.4 million under this stock repurchase program.

Cash and cash equivalents decreased $408.3 million for the six months ended June 30, 2013. Net cash used for investing and financing activities of $181.1 million and $678.7 million, respectively, exceeded net cash provided by operating activities of $451.5 million. Working capital decreased by $247.4 million during the six months ended June 30, 2013.

Cash Flows – Operating Activities

Six Months Ended June 30, 2013 Compared to Six Months Ended June 30, 2012

Net cash flows provided by operating activities were $451.5 million for the six months ended June 30, 2013 compared to $429.5 million for the six months ended June 30, 2012, an increase of $22.0 million. Net income for the six months ended June 30, 2013 was $609.1 million, a decrease of $140.3 million compared to $749.4 million for the six months ended June 30, 2012. Non-cash adjustments consisting of depreciation and amortization, loss on early extinguishment of debt attributable to unamortized discount, gain on sale of equity securities, deferred income taxes, equity-based compensation expense and fair value changes to derivative instruments resulted in an increase to operating cash flows of $98.3 million for the six months ended June 30, 2013 compared to $137.8 million for the same period in 2012. Changes in working capital items decreased cash flows by $122.2 million for the six months ended June 30, 2013 compared to $405.1 million for the six months ended June 30, 2012. Additionally, for the six months ended June 30, 2013, turnaround expenditures increased to $159.8 million from $47.0 million for the same period of 2012.

Cash Flows – Investing Activities and Planned Capital Expenditures

Six Months Ended June 30, 2013 Compared to Six Months Ended June 30, 2012

Net cash flows used for investing activities were $181.1 million for the six months ended June 30, 2013 compared to $144.5 million for the six months ended June 30, 2012, an increase of $36.6 million. Cash expenditures for properties, plants and equipment for the first six months of 2013 increased to $170.8 million from $128.0 million for the same period in 2012. These include HEP capital expenditures of $16.9 million and $23.6 million for the six months ended June 30, 2013 and 2012, respectively. In addition, for the six months ended June 30, 2013, we received proceeds of $5.8 million from the sale of property and equipment and advanced Sabine Biofuels $13.7 million. Also for the six months ended June 30, 2013 and 2012, we invested $399.2 million and $166.4 million, respectively, in marketable securities and received proceeds of $398.8 million and $152.0 million, respectively, from the sale or maturity of marketable securities.

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Planned Capital Expenditures

HollyFrontier Corporation

Each year our Board of Directors approves our annual capital budget which includes specific projects that our management is authorized to undertake. Additionally, when conditions warrant or as new opportunities arise, additional projects may be approved. The funds appropriated for a particular capital project may be expended over a period of several years, depending on the time required to complete the project. Therefore, our planned capital expenditures for a given year consist of expenditures appropriated in that year’s capital budget plus expenditures for projects appropriated in prior years which have not yet been completed. Our appropriated capital budget for 2013 is $320.0 million including both sustaining capital and major capital projects. We expect to spend approximately $400.0 million to $450.0 million in cash for capital projects appropriated in 2013 and prior years. This spending is comprised of $130.0 million to $146.0 million at the Woods Cross Refinery, $116.0 million to $130.0 million at the Tulsa Refineries, $56.0 million to $65.0 million at the El Dorado Refinery, $58.0 million to $61.0 million at the Cheyenne Refinery, $28.0 million to $33.0 million at the Navajo Refinery and $12.0 million to $15.0 million for miscellaneous other projects. In addition, we expect to spend up to $200.0 million on refinery turnarounds and tank maintenance during 2013. This reflects an increase to our previous $156.0 million estimate due to turnaround discovery work.

A significant portion of our current capital spending is associated with compliance-oriented capital improvements. This spending is required due to existing consent decrees (for projects including FCC unit flue gas scrubbers and tail gas treatment units), federal fuels regulations (particularly, MSAT2 which mandates a reduction in the benzene content of blended gasoline), refinery waste water treatment improvements and other similar initiatives. Our refinery operations and related emissions are highly regulated at both federal and state levels, and we invest in our facilities as needed to remain in compliance with these standards. Additionally, when faced with new emissions or fuels standards, we seek to execute projects that facilitate compliance and also improve the operating costs and/or yields of associated refining processes.

El Dorado Refinery

Newly appropriated capital projects at the El Dorado Refinery include naphtha fractionation, an additional hydrogen plant and a Low-Nox addition to the FCC unit flue gas scrubber. Continuing project work will include coke drum pressure reduction designed to improve liquid yields and a new tail gas treatment unit to reduce air emissions in compliance with the El Dorado Refinery's existing EPA consent decree.

Tulsa Refineries

New 2013 appropriations for the Tulsa Refineries include a gasoline-blending system and numerous infrastructure upgrades. We will continue spending on the conversion of our propane de-asphalt unit to ROSE technology and on our sulfur recovery project related to the refinery fuel gas system. The sulfur recovery project is expected to be completed in the third quarter of 2013 and, in addition to facilitating compliance with our EPA consent, is anticipated to also allow us to increase use of lower priced sour / heavy crude in Tulsa. Spending on maintenance capital items and general improvements continues at an elevated level at the Tulsa Refineries due to perceived opportunities.

Navajo Refinery

The Navajo Refinery capital spending in 2013 will be principally on previously approved capital appropriations as well as maintenance capital spending. Included among previously approved capital projects is a $25.0 million upgrade to the Navajo Refinery's waste water treatment system.

Cheyenne Refinery

We plan to install a new hydrogen plant at the Cheyenne Refinery and have appropriated this capital project as part of our 2013 budget. The hydrogen plant, along with a previously approved naphtha fractionation project, is anticipated to allow us to reduce benzene content in Cheyenne gasoline production, while at the same time improving the refinery's overall liquid yields and light oils production. Previously appropriated projects still underway at Cheyenne include wastewater treatment plant improvements, a wet gas scrubber for the FCC unit to reduce air emissions, a redundant tail gas unit associated with sulfur recovery processes and additional investment in the waste water treatment plant to reduce selenium concentration in waste water.

Woods Cross Refinery

Newly appropriated capital for the Woods Cross Refinery consists of warehouse and office relocations to accommodate the refinery expansion and modernization program and a new rail loading rack for intermediates and finished products associated with refining waxy crude oil. Engineering is continuing on the previously announced $225.0 million expansion project. Long lead equipment has been ordered and we are finalizing the cost estimate before construction begins. The permit for the refinery expansion project is pending and the second public comment period has ended. We currently expect the project to be mechanically complete in approximately the first to second quarter of 2015.

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Regulatory compliance items or other presently existing or future environmental regulations / consent decrees could cause us to make additional capital investments beyond those described above and incur additional operating costs to meet applicable requirements.

HEP

Each year the Holly Logistic Services, L.L.C. board of directors approves HEP’s annual capital budget, which specifies capital projects that HEP management is authorized to undertake. Additionally, at times when conditions warrant or as new opportunities arise, special projects may be approved. The funds allocated for a particular capital project may be expended over a period of several years, depending on the time required to complete the project. Therefore, HEP’s planned capital expenditures for a given year consist of expenditures approved for capital projects included in its current year capital budget as well as, in certain cases, expenditures approved for capital projects in capital budgets for prior years. The 2013 HEP capital budget is comprised of $10.1 million for maintenance capital expenditures and $2.0 million for expansion capital expenditures.

HEP is proceeding with the expansion of its crude oil transportation system in southeastern New Mexico in response to increased crude oil production in the area. The expansion will provide shippers with additional pipeline takeaway capacity to either common carrier pipeline stations for transportation to major crude oil markets or to our New Mexico refining facilities. To complete the project, HEP will convert an existing refined products pipeline to crude oil service, construct several new pipeline segments, expand an existing pipeline and build new truck unloading stations and crude storage capacity. Excluding the value of the existing pipeline to be converted, total capital expenditures are expected to cost between $35.0 million and $40.0 million. The project is expected to provide increased capacity of up to 100,000 BPD across HEP's system and anticipates it will be in full service no later than May 2014 though some segments may be completed and in service in late 2013.

UNEV is proceeding with a project to add certain enhancements to its product terminal in Las Vegas, Nevada. The project will cost approximately $13.0 million with construction scheduled to be completed during the second quarter of 2014.

HEP is currently evaluating two proposed new pipelines. The first proposed pipeline would be a new 50-mile intrastate crude oil pipeline between Cushing, Oklahoma and our Tulsa refining facilities that would allow for a significant portion of crude oil transported to be heavy Canadian and sour crude oil. The second proposed pipeline would be a new 100-mile interstate petroleum products pipeline between our refinery in Cheyenne, Wyoming and Denver, Colorado. The project also will evaluate the construction of a new petroleum products terminal in North Denver or, alternatively, the routing of the new pipeline to existing third-party product terminals in the Denver area. HEP anticipates that it will be in a position to decide whether to proceed with these projects in the third quarter of 2013.

HEP and we are collaborating to evaluate the construction of a rail facility that will enable crude oil loading and unloading near our Artesia and / or Lovington, New Mexico refining facilities. The rail project, which will be connected to HEP's crude oil pipeline transportation system in southeastern New Mexico, will have an initial capacity of up to 70,000 BPD and will enable access to a variety of crude oil types including WTI, WTS and WCS. The project will provide both additional crude oil takeaway options for producers as crude production in the region continues to grow, and an expanded set of crude oil sourcing options for us. HEP anticipates that project completion would take nine to twelve months once a decision to proceed is made.

Cash Flows – Financing Activities

Six Months Ended June 30, 2013 Compared to Six Months Ended June 30, 2012

Net cash flows used for financing activities were $678.7 million for the six months ended June 30, 2013 compared to $491.8 million for the six months ended June 30, 2012, an increase of $186.9 million. During the six months ended June 30, 2013, we received $73.4 million from the sale of HEP common units, purchased $159.4 million in common stock, paid $264.9 million in dividends, paid $286.8 million in principal and a $14.2 million premium upon the redemption of our 9.875% senior notes and recognized $1.0 million excess tax benefits on our equity-based compensation. Also during this period, HEP received $154.5 million and repaid $220.5 million under the HEP Credit Agreement, paid distributions of $34.6 million to noncontrolling interests, purchased $2.9 million in HEP common units for recipients of its incentive grants and received proceeds of $73.4 million upon its March 2013 common unit offering. During the six months ended June 30, 2012, we purchased $189.8 million in common stock, paid $250.0 million in dividends, provided a $100.0 million up-front payment pursuant to a structured share repurchase arrangement, paid $5.0 million in principal on our 9.875% senior notes and recognized $4.8 million excess tax benefits on our equity-based compensation. Also during this period, HEP received $294.8 million in net proceeds upon the issuance of the HEP 6.5% senior notes, paid $185.0 million in principal on the HEP 6.25% senior notes, received $99.0 million and repaid $129.0 million under the HEP Credit Agreement, paid distributions of $28.9 million to noncontrolling interests, incurred $3.2 million in deferred financing costs and purchased $4.5 million in HEP common units in the open market for recipients of its incentive grants. Additionally, UNEV joint venture partner contributions of $6.0 million were received during the six months ended June 30, 2012.

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Contractual Obligations and Commitments

HollyFrontier Corporation

In June 2013, we redeemed our $286.8 million aggregate principal amount of 9.875% senior notes maturing June 2017. There were no other significant changes to our contractual obligations during the six months ended June 30, 2013.

HEP

During the six months ended June 30, 2013, HEP made net repayments of $66.0 million resulting in $355.0 million of outstanding borrowings under the HEP Credit Agreement at June 30, 2013.

There were no other significant changes to HEP’s long-term contractual obligations during this period.

CRITICAL ACCOUNTING POLICIES

Our discussion and analysis of our financial condition and results of operations are based upon our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The preparation of these financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities as of the date of the financial statements. Actual results may differ from these estimates under different assumptions or conditions.

Our significant accounting policies are described in “Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Critical Accounting Policies” in our Annual Report on Form 10-K for the year ended December 31, 2012. Certain critical accounting policies that materially affect the amounts recorded in our consolidated financial statements include the assessment and consolidation of variable interest entities, the use of the LIFO method of valuing certain inventories, the amortization of deferred costs for regular major maintenance and repairs at our refineries, assessing the possible impairment of certain long-lived assets and goodwill, accounting for derivative instruments and assessing contingent liabilities for probable losses.

We use the LIFO method of valuing inventory. Under the LIFO method, an actual valuation of inventory can only be made at the end of each year based on the inventory levels at that time. Accordingly, interim LIFO calculations are based on management’s estimates of expected year-end inventory levels and are subject to the final year-end LIFO inventory valuation.

Goodwill represents the excess of the cost of an acquired entity over the fair value of the assets acquired and liabilities assumed. Goodwill is not subject to amortization and is tested annually or more frequently if events or circumstances indicate the possibility of impairment. As of June 30, 2013, there have been no impairments to goodwill.

RISK MANAGEMENT

We use certain strategies to reduce some commodity price and operational risks. We do not attempt to eliminate all market risk exposures when we believe that the exposure relating to such risk would not be significant to our future earnings, financial position, capital resources or liquidity or that the cost of eliminating the exposure would outweigh the benefit.

Commodity Price Risk Management


•	our inventory positions;


•	natural gas purchases;


•	costs of crude oil and related grade differentials;


•	prices of refined products; and


•	our refining margins.

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As of June 30, 2013, we have the following notional contract volumes related to all outstanding derivative contracts used to mitigate commodity price risk:



		Notional Contract Volumes by Year of Maturity
Contract Description	Total Outstanding Notional	2013	2014	2015	2016	2017	Unit of Measure

Natural gas price swap - long	86,400,000	9,600,000	19,200,000	19,200,000	19,200,000	19,200,000	MMBTU
Natural gas price swap - short	43,200,000	4,800,000	9,600,000	9,600,000	9,600,000	9,600,000	MMBTU
WTI price swap - long	5,701,000	5,336,000	365,000	—	—	—	Barrels
Ultra-low sulfur diesel price swap - short	5,701,000	5,336,000	365,000	—	—	—	Barrels
WCS price swap - long	3,588,000	3,588,000	—	—	—	—	Barrels
WTS price swap - long	1,472,000	1,472,000	—	—	—	—	Barrels
NYMEX futures (WTI) - short	1,896,000	1,681,000	215,000	—	—	—	Barrels

The following sensitivity analysis provides the hypothetical effects of market price fluctuations to the commodity positions hedged under our derivative contracts:



	Derivative Fair Value Gain (Loss) at June 30,
Change in Underlying Commodity Prices of Hedged Positions	2013			2012
	(In thousands)
10% increase in underlying commodity prices	$	(22,839	)	$	(45,234	)
10% decrease in underlying commodity prices	$	22,839		$	45,234

Interest Rate Risk Management

HEP uses interest rate swaps to manage its exposure to interest rate risk.

As of June 30, 2013, HEP had three interest rate swap contracts that hedge its exposure to the cash flow risk caused by the effects of LIBOR changes on $305.0 million in credit agreement advances. The first interest rate swap effectively converts $155.0 million of LIBOR based debt to fixed rate debt having an interest rate of 0.99% plus an applicable margin of 2.50% as of June 30, 2013, which equaled an effective interest rate of 3.49%. This swap matures in February 2016. HEP has two additional interest rate swaps with identical terms which effectively convert $150.0 million of LIBOR based debt to fixed rate debt having an interest rate of 0.74% plus an applicable margin of 2.50% as of June 30, 2013, which equaled an effective interest rate of 3.24%. Both of these swap contracts mature in July 2017. These swap contracts have been designated as cash flow hedges.

The market risk inherent in our fixed-rate debt and positions is the potential change arising from increases or decreases in interest rates as discussed below.

For the fixed rate HollyFrontier Senior Notes and HEP Senior Notes, changes in interest rates will generally affect fair value of the debt, but not our earnings or cash flows. The outstanding principal, estimated fair value and estimated change in fair value (assuming a hypothetical 10% change in the yield-to-maturity rates) for these debt instruments as of June 30, 2013 is presented below:



	Outstanding Principal		Estimated Fair Value		Estimated Change in Fair Value
	(In thousands)
HollyFrontier Senior Notes	$	150,000	$	161,250	$	3,827
HEP Senior Notes	$	450,000	$	452,625	$	15,060

For the variable rate HEP Credit Agreement, changes in interest rates would affect cash flows, but not the fair value. At June 30, 2013, outstanding borrowings under the HEP Credit Agreement were $355.0 million. By means of its cash flow hedges, HEP has effectively converted the variable rate on $305.0 million of outstanding principal to a weighted average fixed rate of 3.37%.

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At June 30, 2013, our marketable securities included investments in investment grade, highly liquid investments with maturities of three months or less at the time of purchase and hence the interest rate market risk implicit in these cash investments is low. Due to the short-term nature of our cash and cash equivalents, a hypothetical 10% increase in interest rates would not have a material effect on the fair market value of our portfolio. Since we have the ability to liquidate this portfolio, we do not expect our operating results or cash flows to be materially affected by the effect of a sudden change in market interest rates on our investment portfolio.

Our operations are subject to hazards of petroleum processing operations, including fire, explosion and weather-related perils. We maintain various insurance coverages, including business interruption insurance, subject to certain deductibles. We are not fully insured against certain risks because such risks are not fully insurable, coverage is unavailable, or premium costs, in our judgment, do not justify such expenditures.

Financial information is reviewed on the counterparties in order to review and monitor their financial stability and assess their ongoing ability to honor their commitments under the derivative contracts. We have not experienced, nor do we expect to experience, any difficulty in the counterparties honoring their commitments.

We have a risk management oversight committee consisting of members from our senior management. This committee oversees our risk enterprise program, monitors our risk environment and provides direction for activities to mitigate identified risks that may adversely affect the achievement of our goals.


Item 3.	Quantitative and Qualitative Disclosures About Market Risk

See “Risk Management” under “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”

Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles

Reconciliations of earnings before interest, taxes, depreciation and amortization (“EBITDA”) to amounts reported under generally accepted accounting principles in financial statements.

Earnings before interest, taxes, depreciation and amortization, which we refer to as EBITDA, is calculated as net income attributable to HollyFrontier stockholders plus (i) interest expense, net of interest income, (ii) income tax provision, and (iii) depreciation and amortization. EBITDA is not a calculation provided for under GAAP; however, the amounts included in the EBITDA calculation are derived from amounts included in our consolidated financial statements. EBITDA should not be considered as an alternative to net income or operating income as an indication of our operating performance or as an alternative to operating cash flow as a measure of liquidity. EBITDA is not necessarily comparable to similarly titled measures of other companies. EBITDA is presented here because it is a widely used financial indicator used by investors and analysts to measure performance. EBITDA is also used by our management for internal analysis and as a basis for financial covenants.

Set forth below is our calculation of EBITDA.



	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
	(In thousands)
Net income attributable to HollyFrontier stockholders	$	256,981		$	493,499		$	590,650		$	735,195
Add income tax provision	152,043			285,718			338,137			426,124
Add interest expense ⁽¹⁾	41,903			26,942			63,223			60,257
Subtract interest income	(778		)	(681		)	(2,309		)	(1,141		)
Add depreciation and amortization	70,492			56,948			142,254			113,050
EBITDA	$	520,641		$	862,426		$	1,131,955		$	1,333,485

(1) Includes loss on early extinguishment of debt of $22.1 million for the three and six months ended June 30, 2013.

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Reconciliations of refinery operating information (non-GAAP performance measures) to amounts reported under generally accepted accounting principles in financial statements.

Refinery gross margin and net operating margin are non-GAAP performance measures that are used by our management and others to compare our refining performance to that of other companies in our industry. We believe these margin measures are helpful to investors in evaluating our refining performance on a relative and absolute basis.

Refinery gross margin per barrel is the difference between average net sales price and average cost of products per barrel of produced refined products. Net operating margin per barrel is the difference between refinery gross margin and refinery operating expenses per barrel of produced refined products. These two margins do not include the effect of depreciation and amortization. Each of these component performance measures can be reconciled directly to our consolidated statements of income.

Other companies in our industry may not calculate these performance measures in the same manner.

Refinery Gross and Net Operating Margins

Below are reconciliations to our consolidated statements of income for (i) net sales, cost of products and operating expenses, in each case averaged per produced barrel sold, and (ii) net operating margin and refinery gross margin. Due to rounding of reported numbers, some amounts may not calculate exactly.

Reconciliations of refined product sales from produced products sold to total sales and other revenues



	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
	(Dollars in thousands, except per barrel amounts)
Consolidated
Average sales price per produced barrel sold	$	117.51		$	120.21		$	116.77		$	119.87
Times sales of produced refined products sold (BPD)	397,960			421,470			392,070			422,220
Times number of days in period	91			91			181			182
Refined product sales from produced products sold	$	4,255,549		$	4,610,507		$	8,286,545		$	9,211,295

Total refined product sales from produced products sold	$	4,255,549		$	4,610,507		$	8,286,545		$	9,211,295
Add refined product sales from purchased products and rounding ⁽¹⁾	656,271			120,676			1,065,978			276,066
Total refined product sales	4,911,820			4,731,183			9,352,523			9,487,361
Add direct sales of excess crude oil ⁽²⁾	322,524			32,558			558,774			190,840
Add other refining segment revenue ⁽³⁾	52,537			31,906			68,010			37,183
Total refining segment revenue	5,286,881			4,795,647			9,979,307			9,715,384
Add HEP segment sales and other revenues	75,121			67,103			151,605			134,680
Add corporate and other revenues	234			145			797			301
Subtract consolidations and eliminations	(63,388		)	(56,214		)	(125,072		)	(111,946		)
Sales and other revenues	$	5,298,848		$	4,806,681		$	10,006,637		$	9,738,419

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Reconciliation of average cost of products per produced barrel sold to total cost of products sold



	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
	(Dollars in thousands, except per barrel amounts)
Consolidated
Average cost of products per produced barrel sold	$	97.23		$	92.78		$	95.00		$	97.44
Times sales of produced refined products sold (BPD)	397,960			421,470			392,070			422,220
Times number of days in period	91			91			181			182
Cost of products for produced products sold	$	3,521,122		$	3,558,463		$	6,741,644		$	7,487,683

Total cost of products for produced products sold	$	3,521,122		$	3,558,463		$	6,741,644		$	7,487,683
Add refined product costs from purchased products and rounding ⁽¹⁾	645,797			121,872			1,039,837			278,196
Total cost of refined products sold	4,166,919			3,680,335			7,781,481			7,765,879
Add crude oil cost of direct sales of excess crude oil ⁽²⁾	319,653			29,733			545,921			185,543
Add other refining segment cost of products sold ⁽⁴⁾	32,539			27,649			44,878			28,087
Total refining segment cost of products sold	4,519,111			3,737,717			8,372,280			7,979,509
Subtract consolidations and eliminations	(62,303		)	(55,953		)	(122,937		)	(110,828		)
Costs of products sold (exclusive of depreciation and amortization)	$	4,456,808		$	3,681,764		$	8,249,343		$	7,868,681

Reconciliation of average refinery operating expenses per produced barrel sold to total operating expenses



	Three Months Ended June 30,					Six Months Ended June 30,
	2013			2012		2013			2012
	(Dollars in thousands, except per barrel amounts)
Consolidated
Average refinery operating expenses per produced barrel sold	$	6.09		$	5.00	$	6.38		$	5.26
Times sales of produced refined products sold (BPD)	397,960			421,470		392,070			422,220
Times number of days in period	91			91		181			182
Refinery operating expenses for produced products sold	$	220,545		$	191,769	$	452,755		$	404,200

Total refinery operating expenses for produced products sold	$	220,545		$	191,769	$	452,755		$	404,200
Add refining segment pension settlement costs	23,773			—		23,773			—
Add other refining segment operating expenses and rounding ⁽⁵⁾	11,232			9,306		18,907			18,156
Total refining segment operating expenses	255,550			201,075		495,435			422,356
Add HEP segment operating expenses	22,010			20,371		48,039			40,401
Add corporate and other costs	343			811		(138		)	1,260
Subtract consolidations and eliminations	(361		)	469		(695		)	336
Operating expenses (exclusive of depreciation and amortization)	$	277,542		$	222,726	$	542,641		$	464,353

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Reconciliation of net operating margin per barrel to refinery gross margin per barrel to total sales and other revenues



	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
	(Dollars in thousands, except per barrel amounts)
Consolidated
Net operating margin per barrel	$	14.19		$	22.43		$	15.39		$	17.17
Add average refinery operating expenses per produced barrel	6.09			5.00			6.38			5.26
Refinery gross margin per barrel	20.28			27.43			21.77			22.43
Add average cost of products per produced barrel sold	97.23			92.78			95.00			97.44
Average sales price per produced barrel sold	$	117.51		$	120.21		$	116.77		$	119.87
Times sales of produced refined products sold (BPD)	397,960			421,470			392,070			422,220
Times number of days in period	91			91			181			182
Refined product sales from produced products sold	$	4,255,549		$	4,610,507		$	8,286,545		$	9,211,295

Total refined product sales from produced products sold	$	4,255,549		$	4,610,507		$	8,286,545		$	9,211,295
Add refined product sales from purchased products and rounding ⁽¹⁾	656,271			120,676			1,065,978			276,066
Total refined product sales	4,911,820			4,731,183			9,352,523			9,487,361
Add direct sales of excess crude oil ⁽²⁾	322,524			32,558			558,774			190,840
Add other refining segment revenue ⁽³⁾	52,537			31,906			68,010			37,183
Total refining segment revenue	5,286,881			4,795,647			9,979,307			9,715,384
Add HEP segment sales and other revenues	75,121			67,103			151,605			134,680
Add corporate and other revenues	234			145			797			301
Subtract consolidations and eliminations	(63,388		)	(56,214		)	(125,072		)	(111,946		)
Sales and other revenues	$	5,298,848		$	4,806,681		$	10,006,637		$	9,738,419


(1)	We purchase finished products when opportunities arise that provide a profit on the sale of such products, or to meet delivery commitments.

(2)

We purchase crude oil that at times exceeds the supply needs of our refineries. Quantities in excess of our needs are sold at market prices to purchasers of crude oil that are recorded on a gross basis with the sales price recorded as revenues and the corresponding acquisition cost as inventory and then upon sale as cost of products sold. Additionally, at times we enter into buy/sell exchanges of crude oil with certain parties to facilitate the delivery of quantities to certain locations that are netted at carryover cost.


(3)	Other refining segment revenue includes the incremental revenues associated with NK Asphalt and miscellaneous revenue.


(4)	Other refining segment cost of products sold includes the incremental cost of products for NK Asphalt and miscellaneous costs.


(5)	Other refining segment operating expenses include the marketing costs associated with our refining segment and the operating expenses of NK Asphalt.


Item 4.	Controls and Procedures

Evaluation of disclosure controls and procedures. Our principal executive officer and principal financial officer have evaluated, as required by Rule 13a-15(b) under the Securities Exchange Act of 1934 (the “Exchange Act”), our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e)) under the Exchange Act as of the end of the period covered by this Quarterly Report on Form 10-Q. Our disclosure controls and procedures are designed to provide reasonable assurance that the information we are required to disclose in the reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms. Based upon the evaluation, our principal executive officer and principal financial officer have concluded that our disclosure controls and procedures were effective at the reasonable assurance level as of June 30, 2013.

Changes in internal control over financial reporting. There have been no changes in our internal control over financial reporting (as defined in Rule 13a-15(f) under the Exchange Act) that occurred during our last fiscal quarter that have materially affected or are reasonably likely to materially affect our internal control over financial reporting.

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PART II. OTHER INFORMATION


Item 1.	Legal Proceedings

Commitment and Contingency Reserves

We periodically establish reserves for certain legal proceedings. The establishment of a reserve involves an estimation process that includes the advice of legal counsel and subjective judgment of management. While management believes these reserves to be adequate, future changes in the facts and circumstances could result in the actual liability exceeding the estimated ranges of loss and amounts accrued.

While the outcome and impact on us cannot be predicted with certainty, management believes that the resolution of these proceedings through settlement or adverse judgment will not have a material adverse effect on our consolidated financial position or cash flow. Operating results, however, could be significantly impacted in the reporting periods in which such matters are resolved.

Environmental Matters

We are reporting the following proceedings to comply with SEC regulations which require us to disclose proceedings arising under federal, state or local provisions regulating the discharge of materials into the environment or protecting the environment if we reasonably believe that such proceedings may result in monetary sanctions of $100,000 or more. Our respective subsidiaries have or will develop corrective action plans regarding these disclosures that will be implemented in consultation with the respective federal and state agencies. It is not possible to predict the ultimate outcome of these proceedings, although none are currently expected to have a material effect on our consolidated financial position.

Frontier Refining LLC (“FR”), our wholly-owned subsidiary, has undertaken environmental audits at the Cheyenne Refinery regarding compliance with federal and state environmental requirements. By letters dated October 5, 2012, November 7, 2012, and January 10, 2013, and pursuant to EPA's audit policy to the extent applicable, FR submitted reports to the EPA voluntarily disclosing non-compliance with certain emission limitations, reporting requirements, and provisions of a 2009 federal consent decree. By letters dated October 31, 2012, February 6, 2013, June 21, 2013, July 9, 2013 and July 25, 2013, and pursuant to applicable Wyoming audit statutes, FR submitted environmental audit reports to the Wyoming Department of Environmental Quality (“WDEQ”) voluntarily disclosing non-compliance with certain notification, reporting, and other provisions of the refinery's state air permit and other environmental regulatory requirements. Additional self-disclosures and follow-up correspondence are anticipated as the audit activities are completed. No further action has been taken by either agency at this time. The Cheyenne Refinery also has four outstanding Notices of Violations issued in 2010, 2011 and 2013 that are subject to ongoing settlement negotiations with the WDEQ. Additional air, water and waste audits are ongoing or planned for the Cheyenne Refinery for 2013.

Between November 2010 and February 2012, certain of our subsidiaries submitted multiple reports to the EPA to voluntarily disclose non-compliance with fuels regulations at the Cheyenne, El Dorado, Navajo, Tulsa and Woods Cross refineries and at the Cedar City, Utah and Henderson, Colorado terminals. The EPA has requested additional information regarding certain of these reports, and our subsidiaries have complied with all requests received to date.

Other

We are a party to various other litigation and proceedings that we believe, based on advice of counsel, will not either individually or in the aggregate have a materially adverse impact on our financial condition, results of operations or cash flows.


Item 1A.	Risk Factors

There have been no material changes in our risk factors as previously disclosed in Part 1, “Item 1A. Risk Factors” of our Annual Report on Form 10-K for the fiscal year ended December 31, 2012 and in "Item 1A. Risk Factors" of our Quarterly Report on Form 10-Q for the quarter ended March 31, 2013. In addition to the other information set forth in this quarterly report, you should carefully consider the risk factors discussed in our 2012 Form 10-K and March 31, 2013 Form 10-Q, which could materially affect our business, financial condition or future results. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or future results.

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

Under our common stock repurchase programs, repurchases are being made from time to time in the open market or privately negotiated transactions based on market conditions, securities law limitations and other factors. The following table includes repurchases made under these programs during the second quarter of 2013.



Period	Total Number of Shares Purchased	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Maximum Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs
April 2013 ^{(1) (2)}	221,638	$	48.97	—	$	494,399,956
May 2013 ⁽¹⁾	1,173,220	$	49.29	1,093,220	$	440,567,787
June 2013	1,870,852	$	45.00	1,870,852	$	356,373,568
Total for April to June 2013	3,265,710			2,964,072

(1) April and May 2013 include 220,000 shares and 80,000 shares, respectively, not purchased under our approved stock repurchase program, but rather pursuant to separate authority from our Board of Directors. These repurchases were made in the open market.

(2) April 2013 includes 1,638 shares withheld from certain executives and employees under the terms of our share-based compensation unit agreements to provide funds for the payment of payroll and income taxes due at vesting in the case of officers and employees who did not elect to satisfy such taxes by other means.


Item 6.	Exhibits

The Exhibit Index on page 58 of this Quarterly Report on Form 10-Q lists the exhibits that are filed or furnished, as applicable, as part of the Quarterly Report on Form 10-Q.

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SIGNATURES

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




	HOLLYFRONTIER CORPORATION
	(Registrant)

Date: August 8, 2013		/s/ Douglas S. Aron
		Douglas S. Aron
		Executive Vice President and Chief Financial Officer (Principal Financial Officer)

Date: August 8, 2013		/s/ J. W. Gann, Jr.
		J. W. Gann, Jr.
		Vice President, Controller and Chief Accounting Officer (Principal Accounting Officer)

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Exhibit Index



Exhibit Number		Description

3.1		Amended and Restated Certificate of Incorporation of HollyFrontier Corporation (incorporated by reference to Exhibit 3.1 of Registrant's Current Report on Form 8-K filed July 8, 2011, File No. 1-03876).

3.2		Amended and Restated By-Laws of HollyFrontier Corporation (incorporated by reference to Exhibit 3.1 of Registrant's Current Report on Form 8-K filed November 21, 2011, File No. 1-03876).

10.1		Transportation Services Agreement, dated July 16, 2013, by and between HollyFrontier Refining & Marketing LLC and Holly Energy Partners-Operating, L.P. (incorporated by reference to Exhibit 10.1 of Registrant's Current Report on Form 8-K filed July 22, 2013, File No. 1-03876).

10.2		Eighth Amended and Restated Omnibus Agreement, dated July 16, 2013, by and among HollyFrontier Corporation, Holly Energy Partners, L.P. and certain of their respective subsidiaries (incorporated by reference to Exhibit 10.2 of Registrant's Current Report on Form 8-K filed July 22, 2013, File No. 1-03876).

10.3*		Second Amended and Restated Crude Pipeline and Tankage Agreement, dated July 16, 2013, by and among Navajo Refining Company, L.L.C., Holly Refining & Marketing Company - Woods Cross LLC, HollyFrontier Refining & Marketing LLC, Holly Energy Partners-Operating, L.P., HEP Pipeline, LLC and HEP Woods Cross, L.L.C.

10.4*		Refined Products Purchase Agreement, dated December 1, 2009, by and between Holly Refining & Marketing - Tulsa LLC and Sinclair Tulsa Refining Company.

10.5*		First Amendment to Refined Products Purchase Agreement, dated May 17, 2010, by and between Holly Refining & Marketing - Tulsa and Sinclair Tulsa Refining Company.

10.6*		Second Amendment to Refined Products Purchase Agreement, dated December 19, 2011, by and between HollyFrontier Refining & Marketing LLC and Sinclair Oil Corporation.

10.7*		Third Amendment to Refined Products Purchase Agreement, dated June 1, 2012, by and between HollyFrontier Refining & Marketing LLC and Sinclair Oil Corporation.

31.1*		Certification of Chief Executive Officer under Section 302 of the Sarbanes-Oxley Act of 2002.

31.2*		Certification of Chief Financial Officer under Section 302 of the Sarbanes-Oxley Act of 2002.

32.1**		Certification of Chief Executive Officer under Section 906 of the Sarbanes-Oxley Act of 2002.

32.2**		Certification of Chief Financial Officer under Section 906 of the Sarbanes-Oxley Act of 2002.

101+		The following financial information from HollyFrontier Corporation’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2013, formatted in XBRL (Extensible Business Reporting Language): (i) Consolidated Balance Sheets, (ii) Consolidated Statements of Income, (iii) Consolidated Statements of Comprehensive Income, (iv) Consolidated Statements of Cash Flows, and (v) Notes to the Consolidated Financial Statements.

* Filed herewith.

** Furnished herewith.

+ Filed electronically herewith.