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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
_________________________________________________________________
FORM 10-Q
_________________________________________________________________
(Mark One)
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2019
OR
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)
Securities registered pursuant to 12(b) of the Securities Exchange Act of 1934:
Title of each class
Trading Symbol(s)
Name of each exchange on which registered
Common Stock $0.01 par value
HFC
New York Stock Exchange
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      No  
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted 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 such files).    Yes      No  
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer
Accelerated filer
Non-accelerated filer
Smaller reporting company
Emerging growth company
 
 
 
 
 
 
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes      No  
161,389,721 shares of Common Stock, par value $.01 per share, were outstanding on October 25, 2019.


Table of Content

HOLLYFRONTIER CORPORATION
INDEX
 
 
Page
 
 
 
 
 
 
PART I. FINANCIAL INFORMATION
 
 
 
 
 
 
 
September 30, 2019 (Unaudited) and December 31, 2018
 
 
 
Three and Nine Months Ended September 30, 2019 and 2018
 
 
 
Three and Nine Months Ended September 30, 2019 and 2018
 
 
 
Nine Months Ended September 30, 2019 and 2018
 
 
 
Three and Nine Months Ended September 30, 2019 and 2018
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Index to Exhibits
 
 
Signatures


Table of Content

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. Forward-looking statements use words such as “anticipate,” “project,” “expect,” “plan,” “goal,” “forecast,” “intend,” “should,” “would,” “could,” “believe,” “may,” and similar expressions and statements regarding our plans and objectives for future operations. 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. All statements concerning our expectations for future results of operations are based on forecasts for our existing operations and do not include the potential impact of any future acquisitions. 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 or lubricant product operations or pipeline and terminal operations on acceptable terms and to integrate any existing or future acquired operations;
the possibility of terrorist or cyber 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, 2018 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.

3

Table of Content

DEFINITIONS

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

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.

Base oil” is a lubricant grade oil initially produced from refining crude oil or through chemical synthesis that is used in producing lubricant products such as lubricating greases, motor oil and metal processing fluids.

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.

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

Crude oil 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.

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.

LPG” means liquid petroleum gases.

Lubricant” or “lube” means a solvent neutral paraffinic product used in commercial heavy duty engine oils, passenger car oils and specialty products for industrial applications such as heat transfer, metalworking, rubber and other general process oil.

MMBTU” means one million British thermal units.

Rack back” represents the portion of our Lubricants and Specialty Products business operations that entails the processing of feedstocks into base oils.

Rack forward” represents the portion of our Lubricants and Specialty Products business operations that entails the processing of base oils into finished lubricants and the packaging, distribution and sale to customers.

Refinery gross margin” means the difference between average net sales price and average cost per barrel sold. This does not include the associated depreciation and amortization costs.

“RINs” means renewable identification numbers and refers to serial numbers assigned to credits generated from renewable fuel production under the Environmental Protection Agency’s Renewable Fuel Standard (“RFS”) regulations, which require blending renewable fuels into the nation’s fuel supply. In lieu of blending, refiners may purchase these transferable credits in order to comply with the regulations.

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.

“White oil” is an extremely pure, highly-refined petroleum product that has a wide variety of applications ranging from pharmaceutical to cosmetic products.

“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.



4

Table of Content

PART I. FINANCIAL INFORMATION

Item 1.
Financial Statements
HOLLYFRONTIER CORPORATION
CONSOLIDATED BALANCE SHEETS
(In thousands, except share data)
 
 
September 30,
2019
 
December 31, 2018
 
 
(Unaudited)
 
 
ASSETS
 
 
 
 
Current assets:
 
 
 
 
Cash and cash equivalents (HEP: $7,469 and $3,045, respectively)
 
$
981,856

 
$
1,154,752

 
 
 
 
 
Accounts receivable: Product and transportation (HEP: $16,182 and $12,332, respectively)
 
811,355

 
635,623

Crude oil resales
 
28,476

 
36,078

 
 
839,831

 
671,701

Inventories: Crude oil and refined products
 
1,429,911

 
1,166,404

Materials, supplies and other (HEP: $883 and $858, respectively)
 
207,148

 
187,975

 
 
1,637,059

 
1,354,379

Income taxes receivable
 
23,591

 
34,040

Prepayments and other (HEP: $3,896 and $3,452, respectively)
 
50,429

 
81,507

Total current assets
 
3,532,766

 
3,296,379

 
 
 
 
 
Properties, plants and equipment, at cost (HEP: $2,042,185 and $2,058,388, respectively)
 
7,134,025

 
6,780,980

Less accumulated depreciation (HEP: $(535,215) and $(489,217), respectively)
 
(2,336,637
)
 
(2,098,446
)
 
 
4,797,388

 
4,682,534

Operating lease right-of-use assets (HEP: $3,454)
 
453,377

 

 
 
 
 
 
Other assets: Turnaround costs
 
405,043

 
339,861

Goodwill (HEP: $312,873 and $314,229, respectively)
 
2,370,406

 
2,246,435

Intangibles and other (HEP: $166,743 and $176,291, respectively)
 
632,348

 
429,392

 
 
3,407,797

 
3,015,688

Total assets
 
$
12,191,328

 
$
10,994,601

 
 
 
 
 
LIABILITIES AND EQUITY
 
 
 
 
Current liabilities:
 
 
 
 
Accounts payable (HEP: $12,809 and $16,723, respectively)
 
$
1,229,767

 
$
872,627

Income taxes payable
 
18,782

 
17,636

Operating lease liabilities (HEP: $5,384)
 
99,622

 

Accrued liabilities (HEP: $28,669 and $27,240, respectively)
 
357,175

 
277,892

Total current liabilities
 
1,705,346

 
1,168,155

 
 
 
 
 
Long-term debt (HEP: $1,431,869 and $1,418,900, respectively)
 
2,425,234

 
2,411,540

Noncurrent operating lease liabilities (HEP: $71,022)
 
355,410

 

Deferred income taxes (HEP: $423 and $488, respectively)
 
916,520

 
722,576

Other long-term liabilities (HEP: $60,482 and $63,534, respectively)
 
247,455

 
233,271

 
 
 
 
 
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; 256,036,760 and 256,036,788 shares issued as of September 30, 2019 and December 31, 2018, respectively
 
2,560

 
2,560

Additional capital
 
4,224,770

 
4,196,125

Retained earnings
 
4,740,677

 
4,196,902

Accumulated other comprehensive income
 
17,217

 
13,623

Common stock held in treasury, at cost – 94,174,173 and 83,915,297 shares as of September 30, 2019 and December 31, 2018, respectively
 
(2,965,016
)
 
(2,490,639
)
Total HollyFrontier stockholders’ equity
 
6,020,208

 
5,918,571

Noncontrolling interest
 
521,155

 
540,488

Total equity
 
6,541,363

 
6,459,059

Total liabilities and equity
 
$
12,191,328

 
$
10,994,601

Parenthetical amounts represent asset and liability balances attributable to Holly Energy Partners, L.P. (“HEP”) as of September 30, 2019 and December 31, 2018. HEP is a variable interest entity.

See accompanying notes.

5

Table of Content

HOLLYFRONTIER CORPORATION
CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
(In thousands, except per share data)

 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
 
2019
 
2018
 
2019
 
2018
 
 
 
 
 
 
 
 
 
Sales and other revenues
 
$
4,424,828

 
$
4,770,799

 
$
13,104,690

 
$
13,370,462

Operating costs and expenses:
 
 
 
 
 
 
 
 
Cost of products sold (exclusive of depreciation and amortization):
 
 
 
 
 
 
 
 
Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment)
 
3,403,767

 
3,752,234

 
10,307,856

 
10,695,275

Lower of cost or market inventory valuation adjustment
 
34,062

 
17,837

 
(150,483
)
 
(192,927
)
 
 
3,437,829

 
3,770,071

 
10,157,373

 
10,502,348

Operating expenses (exclusive of depreciation and amortization)
 
345,578

 
317,196

 
1,010,422

 
933,699

Selling, general and administrative expenses (exclusive of depreciation and amortization)
 
87,626

 
71,130

 
260,977

 
204,469

Depreciation and amortization
 
127,016

 
108,885

 
375,345

 
323,605

Goodwill impairment
 

 

 
152,712

 

Total operating costs and expenses
 
3,998,049

 
4,267,282

 
11,956,829

 
11,964,121

Income from operations
 
426,779

 
503,517

 
1,147,861

 
1,406,341

Other income (expense):
 
 
 
 
 
 
 
 
Earnings of equity method investments
 
1,334

 
1,114

 
5,217

 
4,127

Interest income
 
6,164

 
5,136

 
17,127

 
10,660

Interest expense
 
(36,027
)
 
(32,399
)
 
(106,938
)
 
(97,446
)
Gain on foreign currency transactions
 
395

 
281

 
4,873

 
5,516

Other, net
 
2,356

 
741

 
3,005

 
3,451

 
 
(25,778
)
 
(25,127
)
 
(76,716
)
 
(73,692
)
Income before income taxes
 
401,001

 
478,390

 
1,071,145

 
1,332,649

Income tax expense:
 
 
 
 
 
 
 
 
Current
 
58,255

 
70,595

 
176,903

 
216,529

Deferred
 
44,766

 
45,663

 
102,959

 
102,213

 
 
103,021

 
116,258

 
279,862

 
318,742

Net income
 
297,980

 
362,132

 
791,283

 
1,013,907

Less net income attributable to noncontrolling interest
 
36,167

 
19,666

 
79,500

 
57,843

Net income attributable to HollyFrontier stockholders
 
$
261,813

 
$
342,466

 
$
711,783

 
$
956,064

Earnings per share attributable to HollyFrontier stockholders:
 
 
 
 
 
 
 
 
Basic
 
$
1.60

 
$
1.95

 
$
4.23

 
$
5.42

Diluted
 
$
1.58

 
$
1.93

 
$
4.20

 
$
5.37

Average number of common shares outstanding:
 
 
 
 
 
 
 
 
Basic
 
163,676

 
175,097

 
167,935

 
175,865

Diluted
 
165,011

 
176,927

 
169,125

 
177,557


See accompanying notes.

6

Table of Content

HOLLYFRONTIER CORPORATION
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
(In thousands)
 
 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
 
2019
 
2018
 
2019
 
2018
 
 
 
 
 
 
 
 
 
Net income
 
$
297,980

 
$
362,132

 
$
791,283

 
$
1,013,907

Other comprehensive income (loss):
 
 
 
 
 
 
 
 
Foreign currency translation adjustment
 
(9,311
)
 
8,325

 
4,212

 
(15,118
)
Hedging instruments:
 
 
 
 
 
 
 
 
Change in fair value of cash flow hedging instruments
 
(1,989
)
 
4,161

 
12,909

 
(4,242
)
Reclassification adjustments to net income on settlement of cash flow hedging instruments
 
(5,573
)
 
1,631

 
(12,537
)
 
6,038

Net unrealized gain (loss) on hedging instruments
 
(7,562
)
 
5,792

 
372

 
1,796

Other comprehensive income (loss) before income taxes
 
(16,873
)
 
14,117

 
4,584

 
(13,322
)
Income tax expense (benefit)
 
(3,888
)
 
3,234

 
990

 
(2,677
)
Other comprehensive income (loss)
 
(12,985
)
 
10,883

 
3,594

 
(10,645
)
Total comprehensive income
 
284,995

 
373,015

 
794,877

 
1,003,262

Less noncontrolling interest in comprehensive income
 
36,167

 
19,666

 
79,500

 
57,843

Comprehensive income attributable to HollyFrontier stockholders
 
$
248,828

 
$
353,349

 
$
715,377

 
$
945,419


See accompanying notes.


7

Table of Content

HOLLYFRONTIER CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
(In thousands)
 
 
Nine Months Ended September 30,
 
 
2019
 
2018
Cash flows from operating activities:
 
 
 
 
Net income
 
$
791,283

 
$
1,013,907

Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
 
Depreciation and amortization
 
375,345

 
323,605

Goodwill impairment
 
152,712

 

Lower of cost or market inventory valuation adjustment
 
(150,483
)
 
(192,927
)
Earnings of equity method investments, inclusive of distributions
 
280

 
463

(Gain) loss on sale of assets
 
202

 
(52
)
Deferred income taxes
 
102,959

 
102,213

Equity-based compensation expense
 
30,635

 
26,096

Change in fair value – derivative instruments
 
19,880

 
(3,007
)
(Increase) decrease in current assets:
 
 
 
 
Accounts receivable
 
(116,793
)
 
(136,764
)
Inventories
 
(47,409
)
 
(33,856
)
Income taxes receivable
 
13,704

 
27,792

Prepayments and other
 
17,710

 
(14,089
)
Increase (decrease) in current liabilities:
 
 
 
 
Accounts payable
 
321,537

 
(37,160
)
Income taxes payable
 
808

 
76,277

Accrued liabilities
 
54,779

 
84,328

Turnaround expenditures
 
(152,431
)
 
(114,593
)
Other, net
 
(3,314
)
 
7,664

Net cash provided by operating activities
 
1,411,404

 
1,129,897

 
 
 
 
 
Cash flows from investing activities:
 
 
 
 
Additions to properties, plants and equipment
 
(171,229
)
 
(167,967
)
Additions to properties, plants and equipment – HEP
 
(23,828
)
 
(41,111
)
Purchase of Sonneborn, net of cash acquired
 
(662,665
)
 

Purchase of Red Giant Oil, net of cash acquired
 

 
(54,088
)
Other, net
 
958

 
3,999

Net cash used for investing activities
 
(856,764
)
 
(259,167
)
 
 
 
 
 
Cash flows from financing activities:
 
 
 
 
Borrowings under credit agreements
 
269,500

 
256,000

Repayments under credit agreements
 
(257,000
)
 
(347,000
)
Proceeds from issuance of common units - HEP
 

 
114,887

Purchase of treasury stock
 
(471,976
)
 
(177,710
)
Dividends
 
(168,008
)
 
(175,921
)
Distributions to noncontrolling interest
 
(100,095
)
 
(93,128
)
Payments on finance leases
 
(1,158
)
 

Other, net
 
(600
)
 
(544
)
Net cash used for financing activities
 
(729,337
)
 
(423,416
)
 
 
 
 
 
Effect of exchange rate on cash flow
 
1,801

 
(2,394
)
 
 
 
 
 
Cash and cash equivalents:
 
 
 
 
Increase (decrease) for the period
 
(172,896
)
 
444,920

Beginning of period
 
1,154,752

 
630,757

End of period
 
$
981,856

 
$
1,075,677

 
 
 
 
 
Supplemental disclosure of cash flow information:
 
 
 
 
Cash paid during the period for:
 
 
 
 
Interest
 
$
(93,929
)
 
$
(89,553
)
Income taxes, net
 
$
(163,232
)
 
$
(112,520
)

See accompanying notes.

8


HOLLYFRONTIER CORPORATION
CONSOLIDATED STATEMENTS OF EQUITY
(Unaudited)
(In thousands)

 
HollyFrontier Stockholders' Equity
 
 
 
 
 
Common Stock
 
 Additional Capital
 
Retained Earnings
 
Accumulated Other Comprehensive Income
 
Treasury stock
 
Non-controlling Interest
 
Total
Equity
 
 
Balance at December 31, 2018
$
2,560

 
$
4,196,125

 
$
4,196,902

 
$
13,623

 
$
(2,490,639
)
 
$
540,488

 
$
6,459,059

Net income

 

 
253,055

 

 

 
23,431

 
276,486

Dividends ($0.33 declared per common share)

 

 
(56,849
)
 

 

 

 
(56,849
)
Distributions to noncontrolling interest holders

 

 

 

 

 
(33,673
)
 
(33,673
)
Other comprehensive income, net of tax

 

 

 
13,775

 

 

 
13,775

Issuance of common stock under incentive compensation plans, net of tax

 
3

 

 

 
(3
)
 

 

Equity-based compensation

 
8,713

 

 

 

 
661

 
9,374

Purchase of treasury stock

 

 

 

 
(73,225
)
 

 
(73,225
)
Purchase of HEP units for restricted grants

 

 

 

 

 
(373
)
 
(373
)
Balance at March 31, 2019
$
2,560

 
$
4,204,841

 
$
4,393,108

 
$
27,398

 
$
(2,563,867
)
 
$
530,534

 
$
6,594,574

Net income

 

 
196,915

 

 

 
19,902

 
216,817

Dividends ($0.33 declared per common share)

 

 
(56,659
)
 

 

 

 
(56,659
)
Distributions to noncontrolling interest holders

 

 

 

 

 
(33,030
)
 
(33,030
)
Other comprehensive income, net of tax

 

 

 
2,804

 

 

 
2,804

Equity attributable to HEP common unit issuances, net of tax

 

 

 

 

 
(140
)
 
(140
)
Issuance of common stock under incentive compensation plans, net of tax

 
(138
)
 

 

 
138

 

 

Equity-based compensation

 
11,602

 

 

 

 
586

 
12,188

Purchase of treasury stock

 

 

 

 
(205,555
)
 

 
(205,555
)
Balance at June 30, 2019
$
2,560

 
$
4,216,305

 
$
4,533,364

 
$
30,202

 
$
(2,769,284
)
 
$
517,852

 
$
6,530,999

Net income

 

 
261,813

 

 

 
36,167

 
297,980

Dividends ($0.33 declared per common share)

 

 
(54,500
)
 

 

 

 
(54,500
)
Distributions to noncontrolling interest holders

 

 

 

 

 
(33,392
)
 
(33,392
)
Other comprehensive loss, net of tax

 

 

 
(12,985
)
 

 

 
(12,985
)
Issuance of common stock under incentive compensation plans, net of tax

 
(80
)
 

 

 
80

 

 

Equity-based compensation

 
8,545

 

 

 

 
528

 
9,073

Purchase of treasury stock

 

 

 

 
(195,812
)
 

 
(195,812
)
Balance at September 30, 2019
$
2,560

 
$
4,224,770

 
$
4,740,677

 
$
17,217

 
$
(2,965,016
)
 
$
521,155

 
$
6,541,363




9


 
HollyFrontier Stockholders' Equity
 
 
 
 
 
Common Stock
 
 Additional Capital
 
Retained Earnings
 
Accumulated Other Comprehensive Income
 
Treasury stock
 
Non-controlling Interest
 
Total
Equity
 
 
Balance at December 31, 2017
$
2,560

 
$
4,132,696

 
$
3,346,615

 
$
29,869

 
$
(2,140,911
)
 
$
526,111

 
$
5,896,940

Net income

 

 
268,091

 

 

 
20,771

 
288,862

Dividends ($0.33 declared per common share)

 

 
(58,856
)
 

 

 

 
(58,856
)
Distributions to noncontrolling interest holders

 

 

 

 

 
(29,237
)
 
(29,237
)
Other comprehensive loss, net of tax

 

 

 
(13,580
)
 

 

 
(13,580
)
Equity attributable to HEP common unit issuances, net of tax

 
41,980

 

 

 

 
58,031

 
100,011

Issuance of common stock under incentive compensation plans, net of tax

 
1,057

 

 

 
(1,057
)
 

 

Equity-based compensation

 
7,961

 

 

 

 
836

 
8,797

Purchase of treasury stock

 

 

 

 
(27,520
)
 

 
(27,520
)
Purchase of HEP units for restricted grants

 

 

 

 

 
(58
)
 
(58
)
Adoption of accounting standards

 

 
(11,019
)
 
3,572

 

 

 
(7,447
)
Other

 
1

 
(1
)
 

 

 

 

Balance at March 31, 2018
$
2,560

 
$
4,183,695

 
$
3,544,830

 
$
19,861

 
$
(2,169,488
)
 
$
576,454

 
$
6,157,912

Net income

 

 
345,507

 

 

 
17,406

 
362,913

Dividends ($0.33 declared per common share)

 

 
(58,644
)
 

 

 

 
(58,644
)
Distributions to noncontrolling interest holders

 

 

 

 

 
(31,522
)
 
(31,522
)
Other comprehensive loss, net of tax

 

 

 
(7,948
)
 

 

 
(7,948
)
Equity attributable to HEP common unit issuances, net of tax

 
221

 

 

 

 
232

 
453

Issuance of common stock under incentive compensation plans, net of tax

 
335

 

 

 
(335
)
 

 

Equity-based compensation

 
7,797

 

 

 

 
712

 
8,509

Purchase of treasury stock

 

 

 

 
(28,030
)
 

 
(28,030
)
Other

 
(3
)
 
3

 

 

 

 

Balance at June 30, 2018
$
2,560

 
$
4,192,045

 
$
3,831,696

 
$
11,913

 
$
(2,197,853
)
 
$
563,282

 
$
6,403,643

Net income

 

 
342,466

 

 

 
19,666

 
362,132

Dividends ($0.33 declared per common share)

 

 
(58,421
)
 

 

 

 
(58,421
)
Distributions to noncontrolling interest holders

 

 

 

 

 
(32,369
)
 
(32,369
)
Other comprehensive income, net of tax

 

 

 
10,883

 

 

 
10,883

Equity attributable to HEP common unit issuances, net of tax

 

 

 

 

 
(61
)
 
(61
)
Issuance of common stock under incentive compensation plans, net of tax

 
(188
)
 

 

 
188

 

 

Equity-based compensation

 
8,082

 

 

 

 
708

 
8,790

Purchase of treasury stock

 

 

 

 
(131,082
)
 

 
(131,082
)
Adoption of accounting standards

 

 
(3,110
)
 
3,110

 

 

 

Other

 
(1
)
 
(2
)
 

 

 

 
(3
)
Balance at September 30, 2018
$
2,560

 
$
4,199,938

 
$
4,112,629

 
$
25,906

 
$
(2,328,747
)
 
$
551,226

 
$
6,563,512


See accompanying notes.


10

Table of Content

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 an independent petroleum refiner and marketer that produces high-value light products such as gasoline, diesel fuel, jet fuel and other specialty products. We own and operate petroleum refineries that serve markets throughout the Mid-Continent, Southwest and Rocky Mountain regions of the United States. In addition, we produce base oils and other specialized lubricants in the United States, Canada and the Netherlands, with retail and wholesale marketing of our products through a global sales network with locations in Canada, the United States, Europe, China and Latin America. As of September 30, 2019, 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 Petro-Canada Lubricants Inc. (“PCLI”) located in Mississauga, Ontario, which produces base oils and other specialized lubricant products;
owned and operated Sonneborn with manufacturing facilities in Petrolia, Pennsylvania and the Netherlands;
owned and operated Red Giant Oil Company LLC (“Red Giant Oil”), which supplies locomotive engine oil with storage and distribution facilities in Iowa, Kansas, Utah and Wyoming, along with a blending and packaging facility in Texas;
owned and operated HollyFrontier Asphalt Company LLC (“HFC Asphalt”), which operates various asphalt terminals in Arizona, New Mexico and Oklahoma; and
owned a 57% limited partner interest and a non-economic general partner interest in HEP, a variable interest entity (“VIE”). HEP owns and operates logistic assets consisting of petroleum product and crude oil pipelines, terminals, tankage, loading rack facilities and refinery processing units that principally support our refining and marketing operations in the Mid-Continent, Southwest and Rocky Mountain regions of the United States.

On November 12, 2018, we entered into an equity purchase agreement to acquire 100% of the issued and outstanding capital stock of Sonneborn US Holdings Inc. and 100% of the membership rights in Sonneborn Coöperatief U.A. (collectively, “Sonneborn”). The acquisition closed on February 1, 2019.

On July 10, 2018, we entered into a definitive agreement to acquire Red Giant Oil, a privately-owned lubricants company. The acquisition closed on August 1, 2018.

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 September 30, 2019, the consolidated results of operations, comprehensive income and statements of equity for the three and nine months ended September 30, 2019 and 2018 and consolidated cash flows for the nine months ended September 30, 2019 and 2018 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, 2018 that has been filed with the SEC.


11


Our results of operations for the nine months ended September 30, 2019 are not necessarily indicative of the results of operations to be realized for the year ending December 31, 2019.

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 $4.4 million at September 30, 2019 and $3.6 million at December 31, 2018.

Inventories: Inventories related to our refining operations are stated at the lower of cost, using the last-in, first-out (“LIFO”) method for crude oil and unfinished and finished refined products, or market. In periods of rapidly declining prices, LIFO inventories may have to be written down to market value due to the higher costs assigned to LIFO layers in prior periods. In addition, the use of the LIFO inventory method may result in increases or decreases to cost of sales in years that inventory volumes decline as the result of charging cost of sales with LIFO inventory costs generated in prior periods. An actual valuation of inventory under the LIFO method is 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.

Inventories of our Petro-Canada Lubricants and Sonneborn businesses are stated at the lower of cost, using the first-in, first-out (“FIFO”) method, or net realizable value.

Inventories consisting of process chemicals, materials and maintenance supplies and renewable identification numbers (“RINs”) are stated at the lower of weighted-average cost or net realizable value.

Leases: At inception, we determine if an arrangement is or contains a lease. Right-of-use (“ROU”) assets represent our right to use an underlying asset for the lease term and lease liabilities represent our payment obligation under the leasing arrangement. ROU assets and lease liabilities are recognized at the commencement date based on the present value of lease payments over the lease term. We use our estimated incremental borrowing rate (“IBR”) to determine the present value of lease payments as most of our leases do not contain an implicit rate. Our IBR represents the interest rate which we would pay to borrow, on a collateralized basis, an amount equal to the lease payments over a similar term in a similar economic environment. We use the implicit rate when readily determinable.

Operating leases are recorded in operating lease right-of-use assets and current and noncurrent operating lease liabilities on our consolidated balance sheet. Finance leases are included in properties, plants and equipment and accrued liabilities and other long-term liabilities on our consolidated balance sheet.

Our lease term includes an option to extend the lease when it is reasonably certain that we will exercise that option. Leases with a term of 12 months or less are not recorded on our balance sheet and lease expense is accounted for on a straight-line basis. For certain equipment leases, we apply a portfolio approach for the operating lease ROU assets and liabilities. Also, as a lessee, we separate non-lease components that are identifiable and exclude them from the determination of net present value of lease payment obligations. In addition, HEP, as a lessor, does not separate the non-lease (service) component in contracts in which the lease component is the dominant component. HEP treats these combined components as an operating lease.


12


Goodwill and Long-lived Assets: As of September 30, 2019, our goodwill balance was $2.4 billion, with goodwill assigned to our Refining, Lubricants and Specialty Products and HEP segments of $1,733.5 million, $324.1 million and $312.9 million, respectively. During the nine months ended September 30, 2019, we recognized $279.2 million in goodwill as a result of our Sonneborn acquisition, all of which has been assigned to our Lubricants and Specialty Products segment. See Note 17 for additional information on our segments. The carrying amount of our goodwill may fluctuate from period to period due to the effects of foreign currency translation adjustments on goodwill assigned to our Lubricants and Specialty Products segment. 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 an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying amount. Our goodwill impairment testing first entails either a quantitative assessment or an optional qualitative assessment to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If we determine that based on the qualitative factors that it is more likely than not that the fair value of the reporting unit is greater than its carrying amount, a quantitative test is performed in which we estimate the fair value of the related reporting unit. If the carrying amount of a reporting unit exceeds its fair value, the goodwill of that reporting unit is impaired, and we measure goodwill impairment as the excess of the carrying amount of reporting unit over the related fair value.

Our long-lived assets principally consist of our refining assets that are organized as refining asset groups and the assets of our Lubricants and Specialty Products asset groups. The refinery asset groups also constitute our individual refinery reporting units that are used for testing and measuring goodwill impairments. Our long-lived assets are evaluated for impairment by identifying whether indicators of impairment exist and if so, assessing whether the long-lived assets are recoverable from estimated future undiscounted cash flows. The actual amount of impairment loss measured, if any, is equal to the amount by which the asset group’s carrying value exceeds its fair value.

Goodwill impairment
During the second quarter of 2019, we performed interim goodwill impairment testing of the PCLI reporting unit included in our Lubricants and Specialty Products segment. We elected to perform this interim assessment due to the recent reorganization of our reporting unit structure within the Lubricants and Specialty Products segment, combined with the identification of events and circumstances which were indicators of potential goodwill impairment at PCLI, including recent declines in gross margins to lower than historic levels. These recent lower gross margins are in the base oil market which is largely attributed to the increase in global supply of base oils with a current outlook for continued near-term softness.

Our interim goodwill impairment testing was performed as of May 31, 2019. The estimated fair values of our goodwill reporting units within our Lubricants and Specialty Products segment were derived using a combination of both income and market approaches. The income approach reflects expected future cash flows based on estimated future production volumes, selling prices, gross margins, operating costs and capital expenditures. Our market approach includes both the guideline public company and guideline transaction methods. Both methods utilize pricing multiples derived from historical market transactions of other like-kind assets. These fair value measurements involve significant unobservable inputs (Level 3 inputs). See Note 6 for further discussion of Level 3 inputs.

As a result of our impairment testing, we determined that the carrying value of the PCLI reporting unit’s goodwill within our Lubricants and Specialty Products segment was fully impaired and a goodwill impairment charge of $152.7 million was recorded. Our testing did not identify any other impairments.

We performed our annual goodwill impairment testing as of July 1, 2019 and determined there was no additional impairment of goodwill attributable to our reporting units.

Revenue Recognition: Revenue on refined product and excess crude oil sales are recognized when delivered (via pipeline, in-tank or rack) and the customer obtains control of such inventory, which is typically when title passes and the customer is billed. All revenues are reported inclusive of shipping and handling costs billed and exclusive of any taxes billed to customers. Shipping and handling costs incurred are reported as cost of products sold. Additionally, our lubricants and specialty products business has sales agreements with marketers and distributors that provide certain rights of return or provisions for the repurchase of products previously sold to them. Under these agreements, revenues and cost of revenues are deferred until the products have been sold to end customers. Our lubricants and specialty products business also has agreements that create an obligation to deliver products at a future date for which consideration has already been received and recorded as deferred revenue. This revenue is recognized when the products are delivered to the customer.


13


HEP recognizes revenues as products are shipped through its pipelines and terminals and as other services are rendered. Additionally, HEP has certain throughput agreements that specify minimum volume requirements, whereby HEP bills a customer for a minimum level of shipments in the event a customer ships below their contractual requirements. If there are no future performance obligations, HEP recognizes these deficiency payments as revenue. In certain of these throughput agreements, a customer may later utilize such shortfall billings as credit towards future volume shipments in excess of its minimum levels within its respective contractual shortfall make-up period. Such amounts represent an obligation to perform future services, which may be initially deferred and later recognized as revenue based on estimated future shipping levels, including the likelihood of a customer’s ability to utilize such amounts prior to the end of the contractual shortfall make-up period. HEP recognizes the service portion of these deficiency payments as revenue when HEP does not expect it will be required to satisfy these performance obligations in the future based on the pattern of rights exercised by the customer. Payment terms under our contracts with customers are consistent with industry norms and are typically payable within 30 days of the date of invoice.

Foreign Currency Translation: Assets and liabilities recorded in foreign currencies are translated into U.S. dollars using exchange rates in effect as of the balance sheet date. Revenue and expense accounts are translated using the weighted-average exchange rates during the period presented. Foreign currency translation adjustments are recorded as a component of accumulated other comprehensive income.

In connection with our PCLI acquisition on February 1, 2017, we issued intercompany notes to initially fund certain of our foreign businesses. Remeasurement adjustments resulting from the conversion of such intercompany financing amounts to functional currencies are recorded as gains and losses as a component of other income (expense) in the income statement. Such adjustments are not recorded to the Lubricants and Specialty Products segment operations, but to Corporate and Other. See Note 17 for additional information on our segments.

Income Taxes: Provisions for income taxes include deferred taxes resulting from temporary differences in income for financial and tax purposes, using the liability method of accounting for income taxes. The liability method requires the effect of tax rate changes on deferred income taxes to be reflected in the period in which the rate change was enacted. The liability method also requires that deferred tax assets be reduced by a valuation allowance unless it is more likely than not that the assets will be realized.

Potential interest and penalties related to income tax matters are recognized in income tax expense. We believe we have appropriate support for the income tax positions taken and to be taken on our income tax returns and that our accruals for tax liabilities are adequate for all open years based on an assessment of many factors, including past experience and interpretations of tax law applied to the facts of each matter.

Inventory Repurchase Obligations: We periodically enter into same-party sell / buy transactions, whereby we sell certain refined product inventory and subsequently repurchase the inventory in order to facilitate delivery to certain locations. Such sell / buy transactions are accounted for as inventory repurchase obligations under which proceeds received under the initial sell is recognized as an inventory repurchase obligation that is subsequently reversed when the inventory is repurchased. For the nine months ended September 30, 2019 and 2018, we received proceeds of $13.2 million and $38.4 million, respectively, and repaid $12.5 million and $39.3 million, respectively, under these sell / buy transactions.

Accounting Pronouncements - Recently Adopted

Goodwill Impairment Testing
In January 2017, Accounting Standard Update (“ASU”) 2017-04, “Simplifying the Test for Goodwill Impairment,” was issued amending the testing for goodwill impairment by eliminating Step 2 from the goodwill impairment test. Step 2 measures a goodwill impairment loss by comparing the implied fair value of a reporting unit’s goodwill with the carrying amount of that goodwill. We adopted this standard effective in the second quarter of 2019, and the adoption of this standard resulted in no change to the amount of goodwill impairment recorded in the second quarter of 2019.


14


Leases
In February 2016, ASU 2016-02, “Leases,” was issued requiring leases to be measured and recognized as a lease liability, with a corresponding ROU asset on the balance sheet. We adopted this standard effective January 1, 2019 using the optional transition method, whereby comparative prior period financial information will not be restated and will continue to be reported under the lease accounting standard in effect during those periods. We also elected practical expedients provided by the new standard, including the package of practical expedients, whereby we did not reassess lease classification or initial indirect lease cost under the new standard. In addition, we elected to exclude short-term leases, which at inception have a lease term of 12 months or less, from the amounts recognized on our balance sheet. In addition, HEP elected an expedient whereby a lessor does not have to separate non-lease (service) components from lease components under certain contracts. Under this expedient, HEP treated the combined components of its leases with third parties (i.e., the contracts that are not eliminated upon consolidation of HEP by HFC) as an operating lease in which the dominant component was a lease in accordance with ASC 842. Upon adoption of this standard, we recognized $433.4 million of lease liabilities and corresponding ROU assets on our consolidated balance sheet. Adoption of this standard did not have a material impact on our results of operations or cash flows. In addition, upon our acquisition of Sonneborn on February 1, 2019, we recognized $15.6 million of lease liabilities and corresponding ROU assets.

Accounting Pronouncements - Not Yet Adopted

Credit Losses Measurement
In June 2016, ASU 2016-13, “Measurement of Credit Losses on Financial Instruments,” was issued requiring measurement of all expected credit losses for certain types of financial instruments, including trade receivables, held at the reporting date based on historical experience, current conditions and reasonable and supportable forecasts. This standard is effective January 1, 2020, and our preliminary review of historic and expected credit losses indicates the amount of expected credit losses upon adoption would not be materially different from the current allowance for doubtful accounts balance.


NOTE 2:
Acquisitions

On November 12, 2018, we entered into an equity purchase agreement to acquire 100% of the capital stock of Sonneborn. The acquisition closed on February 1, 2019. Sonneborn is a producer of specialty hydrocarbon chemicals such as white oils, petrolatums and waxes with manufacturing facilities in the United States and Europe.

Aggregate consideration totaled $701.6 million and consisted of $662.7 million in cash paid at acquisition, net of cash acquired. Working capital settlement pursuant to the purchase agreement has been finalized.

This transaction is accounted for as a business combination using the acquisition method of accounting, with the purchase price allocated to the fair value of the acquired Sonneborn assets and liabilities as of the February 1 acquisition date, with the excess purchase price recorded as goodwill assigned to our Lubricants and Specialty Products segment.

The following summarizes our preliminary value estimates of the Sonneborn assets and liabilities acquired on February 1, 2019:
 
(In millions)
Cash and cash equivalents
$
38.9

Accounts receivable and other current assets
58.6

Inventories
81.0

Properties, plants and equipment
168.2

Goodwill
279.2

Intangibles and other noncurrent assets
231.5

Accounts payable and accrued liabilities
(47.0
)
Deferred income tax liabilities
(84.5
)
Other long-term liabilities
(24.3
)
 
$
701.6




15


The preliminary purchase price allocation resulted in the recognition of $279.2 million in goodwill, which relates to the established workforce and global market presence of the acquired business as well as the expected synergies to be gained upon combining with our existing operations to form an expanded lubricants and specialty products business.

Intangibles include customer relationships, trademarks, patents and technical know-how totaling $214.6 million that are being amortized on a straight-line basis over a 12-year period.

These values, including deferred taxes, are preliminary and, therefore, may change once we complete our valuations.

Our consolidated financial and operating results reflect the Sonneborn operations beginning February 1, 2019. Our results of operations for the three months ended September 30, 2019 included revenues and income before income taxes of $88.1 million and $6.6 million, respectively, and revenue and income before income taxes of $253.5 million and $5.0 million, respectively, for the period from February 1, 2019 through September 30, 2019 related to these operations.

As of September 30, 2019, we have incurred $20.1 million in incremental direct integration and regulatory costs that principally relate to legal, advisory, regulatory and other professional fees and are presented as selling, general and administrative expenses.

The following unaudited pro forma information for the nine months ended September 30, 2019 and the three and nine months ended September 30, 2018 presents the revenues and operating income for our Lubricants and Specialty Products segment assuming the acquisition of Sonneborn had occurred as of January 1, 2018. The proforma effects on consolidated HFC revenue and operating income are not material.
 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
 
2018
 
2019
 
2018
 
 
(In thousands)
Sales and other revenues
 
$
571,685

 
$
1,608,648

 
$
1,679,554

Operating income (1)
 
$
39,496

 
$
(127,972
)
 
$
110,424



(1) For the nine months ended September 30, 2019, includes goodwill impairment of $152.7 million from the PCLI reporting unit of our Lubricants and Specialty Products segment. See Note 1 for additional information on this goodwill impairment.


NOTE 3:
Leases

We have operating and finance leases for land, buildings, pipelines, storage tanks, transportation and other equipment for our operations. Our leases have remaining terms of one to 60 years, some of which include options to extend the leases for up to 10 years. Certain of our leases for pipeline assets include provisions for variable payments which are based on a measure of throughput and also contain a provision for the lessor to adjust the rate per barrel periodically over the life of the lease. These variable costs are not included in the initial measurement of ROU assets and lease liabilities.


16


The following table presents the amounts and balance sheet locations of our operating and financing leases recorded on our consolidated balance sheet.
 
 
September 30, 2019
 
 
(In thousands)
Operating leases:
 
 
Operating lease right-of-use assets
 
$
453,377

 
 
 
Operating lease liabilities
 
99,622

Noncurrent operating lease liabilities
 
355,410

Total operating lease liabilities
 
$
455,032

 
 
 
Finance leases:
 
 
Properties, plants and equipment, at cost
 
$
12,830

Accumulated amortization
 
(6,375
)
Properties, plants and equipment, net
 
$
6,455

 
 
 
Accrued liabilities
 
$
1,663

Other long-term liabilities
 
4,929

Total finance lease liabilities
 
$
6,592


Supplemental balance sheet information related to our leases was as follows:
 
 
September 30, 2019
 
 
 
Weighted average remaining lease term (in years)
 
 
Operating leases
 
7.6

Finance leases
 
8.2

 
 
 
Weighted average discount rate
 
 
Operating leases
 
4.2
%
Finance leases
 
5.3
%


The components of lease expense were as follows:
 
 
Three Months Ended
September 30, 2019
 
Nine Months Ended
September 30, 2019
 
 
(In thousands)
Operating lease expense
 
$
28,263

 
$
83,646

Finance lease expense:
 
 
 
 
Amortization of right-of-use assets
 
375

 
1,150

Interest on lease liabilities
 
84

 
255

Variable lease cost
 
1,862

 
3,251

Total lease expense
 
$
30,584

 
$
88,302


Supplemental cash flow information related to leases was as follows:
 
 
Nine Months Ended
September 30, 2019
 
 
(In thousands)
Cash paid for amounts included in the measurement of lease liabilities:
 
 
Operating cash flows from operating leases
 
$
88,500

Operating cash flows from finance leases
 
$
255

Financing cash flows from finance leases
 
$
1,158

 
 
 
Right-of-use assets obtained in exchange for lease obligations:
 
 
Operating leases
 
$
80,211



17




As of September 30, 2019, minimum future lease payments of our operating and finance lease obligations were as follows:
 
 
Operating
 
Finance
 
 
(In thousands)
Remainder of 2019
 
$
29,036

 
$
500

2020
 
107,362

 
1,945

2021
 
89,194

 
1,123

2022
 
75,923

 
859

2023
 
70,194

 
895

2024 and thereafter
 
172,200

 
2,772

Future minimum lease payments
 
543,909

 
8,094

Less: imputed interest
 
88,877

 
1,502

Total lease obligations
 
455,032

 
6,592

Less: current obligations
 
99,622

 
1,663

Long-term lease obligations
 
$
355,410

 
$
4,929



As of September 30, 2019, we have entered into certain leases that have not yet commenced. Such leases include a 15-year lease for plant equipment, with estimated future lease payments of $6.8 million, expected to commence in the second quarter of 2020, and a 5-year lease for office equipment, with estimated future lease payments of $0.4 million, expected to commence in the fourth quarter of 2019.

Our consolidated income statement reflects lease revenue recognized by HEP for contracts with third parties in which HEP is the lessor. Lease income recognized was as follows:

 
 
Three Months Ended
September 30, 2019
 
Nine Months Ended
September 30, 2019
 
 
(In thousands)
Operating lease revenues
 
$
8,374

 
$
24,840



Annual minimum undiscounted lease payments in which HEP is a lessor to third-party contracts as of September 30, 2019 were as follows:

 
(In thousands)
Remainder of 2019
$
8,010

2020
17,542

2021
12,794

2022
11,376

2023
11,248

Thereafter
14,060

Total
$
75,030





18


NOTE 4:
Holly Energy Partners

HEP is a publicly held master limited partnership that owns and operates logistic assets consisting of petroleum product and crude oil pipelines, terminals, tankage, loading rack facilities and refinery processing units that principally support our refining and marketing operations in the Mid-Continent, Southwest and Rocky Mountain regions of the United States and Delek’s refinery in Big Spring, Texas. Additionally, as of September 30, 2019, HEP owned a 75% interest in UNEV Pipeline, LLC (“UNEV”), the owner of a pipeline running from Woods Cross, Utah to Las Vegas, Nevada (the “UNEV Pipeline”) and associated product terminals, and had a 50% ownership interest in each of Osage Pipe Line Company, LLC, the owner of a pipeline running from Cushing, Oklahoma to El Dorado, Kansas (the “Osage Pipeline”) and Cheyenne Pipeline, LLC, the owner of a pipeline running from Fort Laramie, Wyoming to Cheyenne, Wyoming (the “Cheyenne Pipeline”).

As of September 30, 2019, we owned a 57% limited partner interest and a non-economic general partner interest in HEP. As the general partner of HEP, we have the sole ability to direct the activities that most significantly impact HEP’s financial performance, and therefore as HEP's primary beneficiary, we consolidate HEP.

HEP has two primary customers (including us) and generates revenues by charging tariffs for transporting petroleum products and crude oil through its pipelines, by charging fees for terminalling refined products and other hydrocarbons, and by 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 78% of HEP’s total revenues for the nine months ended September 30, 2019. 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. HEP’s creditors have no recourse to our assets. Furthermore, our creditors have no recourse to the assets of HEP and its consolidated subsidiaries. See Note 11 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.

HEP Private Placement Agreements
On January 25, 2018, HEP entered into a common unit purchase agreement in which certain purchasers agreed to purchase in a private placement 3,700,000 HEP common units, representing limited partner interests, at a price of $29.73 per common unit. The private placement closed on February 6, 2018, at which time HEP received proceeds of $110.0 million, which were used to repay indebtedness under the HEP Credit Agreement.

HEP Common Unit Continuous Offering Program
In May 2016, HEP established a continuous offering program under which HEP may issue and sell common units from time to time, representing limited partner interests, up to an aggregate gross sales amount of $200 million. During the nine months ended September 30, 2019, HEP did not issue any common units under this program. As of September 30, 2019, HEP has issued 2,413,153 common units under this program, providing $82.3 million in gross proceeds.

HEP intends to use the net proceeds for general partnership purposes, which may include funding working capital, repayment of debt, acquisitions and capital expenditures. Amounts repaid under HEP’s credit facility may be reborrowed from time to time.

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.

Cushing Connect Joint Venture
On October 2, 2019, HEP Cushing (“HEP Cushing”), a wholly-owned subsidiary of HEP, and Plains Marketing, L.P. (“PMLP”), a wholly-owned subsidiary of Plains All American Pipeline, L.P. (“Plains”), formed a 50/50 joint venture, Cushing Connect Pipeline & Terminal LLC (the “Joint Venture”), for (i) the development and construction of a new 160,000 barrel per day common carrier crude oil pipeline (the “Pipeline”) that will connect the Cushing, Oklahoma crude oil hub to our Tulsa Refineries and (ii) the ownership and operation of 1.5 million barrels of crude oil storage in Cushing, Oklahoma (the “JV Terminal”). The JV Terminal is expected to be in service during the second quarter of 2020, and the Pipeline is expected to be in service during the first quarter of 2021. Long-term commercial agreements have been entered into to support the Joint Venture assets.

19



The Joint Venture will contract with an affiliate of HEP to manage the construction and operation of the Pipeline and with an affiliate of Plains to manage the operation of the JV Terminal. The total Joint Venture investment will be shared proportionately among the partners, and HEP estimates its share of the cost of the JV Terminal contributed by Plains and Pipeline construction costs are approximately $65.0 million.

Transportation Agreements
HEP serves our refineries under long-term pipeline, terminal and tankage throughput agreements and refinery processing tolling agreements expiring from 2021 through 2036. Under these agreements, we pay HEP fees to transport, store and process throughput volumes of refined products, crude oil and feedstocks on HEP’s pipeline, terminals, tankage, loading rack facilities and refinery processing units 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 or Federal Energy Regulatory Commission index. As of September 30, 2019, these agreements result in minimum annualized payments to HEP of $349.0 million.

Our transactions with HEP and fees paid under our transportation agreements with HEP and UNEV are eliminated and have no impact on our consolidated financial statements.


NOTE 5:
Revenues

Substantially all revenue-generating activities relate to sales of refined product and excess crude oil inventories sold at market prices (variable consideration) under contracts with customers. Additionally, we have revenues attributable to HEP logistics services provided under petroleum product and crude oil pipeline transportation, processing, storage and terminalling agreements with third parties.

Disaggregated revenues were as follows:    
 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
 
2019
 
2018
 
2019
 
2018
 
 
(In thousands)
Revenues by type
 
 
 
 
 
 
 
 
Refined product revenues
 
 
 
 
 
 
 
 
Transportation fuels (1)
 
$
3,354,927

 
$
3,598,815

 
$
9,796,334

 
$
10,193,218

Specialty lubricant products (2)
 
461,669

 
422,760

 
1,413,194

 
1,237,002

Asphalt, fuel oil and other products (3)
 
299,305

 
288,013

 
767,023

 
741,139

Total refined product revenues
 
4,115,901

 
4,309,588

 
11,976,551

 
12,171,359

Excess crude oil revenues (4)
 
264,675

 
422,122

 
997,988

 
1,074,928

Transportation and logistic services
 
29,868

 
25,596

 
89,388

 
77,799

Other revenues (5)
 
14,384

 
13,493

 
40,763

 
46,376

Total sales and other revenues
 
$
4,424,828

 
$
4,770,799

 
$
13,104,690

 
$
13,370,462


20


 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
 
2019
 
2018
 
2019
 
2018
 
 
(In thousands)
Refined product revenues by market
 
 
 
 
 
 
 
 
United States
 
 
 
 
 
 
 
 
Mid-Continent
 
$
2,191,014

 
$
2,337,689

 
$
6,283,488

 
$
6,458,935

Southwest
 
913,326

 
1,016,771

 
2,772,281

 
2,865,324

Rocky Mountains
 
611,003

 
627,542

 
1,739,401

 
1,869,414

Northeast
 
151,919

 
85,344

 
427,926

 
261,380

Canada
 
184,784

 
190,727

 
536,911

 
563,088

Europe, Asia and Latin America
 
63,855

 
51,515

 
216,544

 
153,218

Total refined product revenues
 
$
4,115,901

 
$
4,309,588

 
$
11,976,551

 
$
12,171,359


(1)
Transportation fuels consist of gasoline, diesel and jet fuel.
(2)
Specialty lubricant products consist of base oil, waxes, finished lubricants and other specialty fluids.
(3)
Asphalt, fuel oil and other products revenue include revenues attributable to our Refining and Lubricants and Specialty Products segments of $231.4 million and $67.9 million, respectively, for the three months ended September 30, 2019, $612.0 million and $155.0 million, respectively, for the nine months ended September 30, 2019, $234.9 million and $53.1 million, respectively, for the three months ended September 30, 2018, and $589.7 million and $151.4 million, respectively, for the nine months ended September 30, 2018.
(4)
Excess crude oil revenues represent sales of purchased crude oil inventory that at times exceeds the supply needs of our refineries.
(5)
Other revenues are principally attributable to our Refining segment.

Our consolidated balance sheet reflects contract liabilities related to unearned revenues attributable to future service obligations under HEP’s third-party transportation agreements and production agreements from the acquisition of Sonneborn on February 1, 2019. The following table presents changes to our contract liabilities during the nine months ended September 30, 2019.

 
 
January 1, 2019
 
Sonneborn Acquisition
 
Increase
 
Recognized as Revenue
 
September 30, 2019
 
 
(In thousands)
Accrued liabilities
 
$
132

 
6,463

 
$
19,255

 
$
(21,135
)
 
$
4,715



As of September 30, 2019, we have long-term contracts with customers that specify minimum volumes of gasoline, diesel, lubricants and specialty products to be sold ratably at market prices through 2021. Such volumes are typically nominated in the month preceding delivery and delivered ratably throughout the following month. Future prices are subject to market fluctuations and therefore, we have elected the exemption to exclude variable consideration under these contracts under Accounting Standards Codification 606-10-50-14A. Aggregate minimum volumes expected to be sold (future performance obligations) under our long-term product sales contracts with customers are as follows:

 
 
Remainder of 2019
 
2020
 
2021
 
Thereafter
 
Total
 
 
(In thousands)
Refined product sales volumes (barrels)
 
5,610

 
7,964

 
1,847

 

 
15,421



21


Additionally, HEP has long-term contracts with third-party customers that specify minimum volumes of product to be transported through its pipelines and terminals that result in fixed-minimum annual revenues through 2022. Annual minimum revenues attributable to HEP’s third-party contracts as of September 30, 2019 are presented below:

 
 
Remainder of 2019
 
2020
 
2021
 
Thereafter
 
Total
 
 
(In thousands)
HEP contractual minimum revenues
 
$
10,695

 
$
28,238

 
$
22,822

 
$
38,575

 
$
100,330




NOTE 6:
Fair Value Measurements

Our financial instruments measured at fair value on a recurring basis consist of derivative instruments and RINs credit obligations.

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.

The carrying amounts of derivative instruments and RINs credit obligations at September 30, 2019 and December 31, 2018 were as follows:
 
 
 
 
Fair Value by Input Level
 
 
Carrying Amount
 
Level 1
 
Level 2
 
Level 3
 
 
(In thousands)
September 30, 2019
 
 
 
 
 
 
 
 
Assets:
 
 
 
 
 
 
 
 
NYMEX futures contracts
 
$
2,976

 
$
2,976

 
$

 
$

Foreign currency forward contracts
 
2,511

 

 
2,511

 

Commodity price swaps
 
18,007

 

 
18,007

 

Commodity forward contracts
 
1,453

 

 
1,453

 

Total assets
 
$
24,947

 
$
2,976

 
$
21,971

 
$

 
 
 
 
 
 
 
 
 
Liabilities:
 
 
 
 
 
 
 
 
Foreign currency forward contracts
 
$
17

 
$

 
$
17

 
$

Commodity price swaps
 
1,094

 

 
1,094

 

Commodity forward contracts
 
1,367

 

 
1,367

 

Total liabilities
 
$
2,478

 
$

 
$
2,478

 
$


22


 
 
 
 
Fair Value by Input Level
Financial Instrument
 
Carrying Amount
 
Level 1
 
Level 2
 
Level 3
 
(In thousands)
December 31, 2018
 
 
 
 
 
 
 
 
Assets:
 
 
 
 
 
 
 
 
NYMEX futures contracts
 
$
2,473

 
$
2,473

 
$

 
$

Foreign currency forward contracts
 
25,956

 

 
25,956

 

Commodity price swaps
 
10,817

 

 
10,817

 

Commodity forward contracts
 
1,034

 

 
1,034

 
$

Total assets
 
$
40,280

 
$
2,473

 
$
37,807

 
$

 
 
 
 
 
 
 
 
 
Liabilities:
 
 
 
 
 
 
 
 
Commodity price swaps
 
$
956

 
$

 
$
956

 
$

Commodity forward contracts
 
1,137

 

 
1,137

 

RINs credit obligations (1)
 
4,084

 

 
4,084

 

Total liabilities
 
$
6,177

 
$

 
$
6,177

 
$



(1)
Represent obligations for RINs credits for which we did not have sufficient quantities at December 31, 2018 to satisfy our Environmental Protection Agency (“EPA”) regulatory blending requirements.

Level 1 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 Instruments
Derivative instruments consisting of foreign currency forward contracts, commodity price swaps and forward sales and purchase contracts are measured and recorded at fair value using Level 2 inputs. The fair value of the commodity price swap contracts is 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 input and quoted forward commodity prices with respect to our commodity price swaps. RINs credit obligations are valued based on current market RINs prices. The fair value of foreign currency forward contracts are based on values provided by a third party, which were derived using market quotes for similar type instruments, a Level 2 input.



23


NOTE 7:
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 restricted shares and performance share units. 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
September 30,
 
Nine Months Ended
September 30,
 
 
2019
 
2018
 
2019
 
2018
 
 
(In thousands, except per share data)
Net income attributable to HollyFrontier stockholders
 
$
261,813

 
$
342,466

 
$
711,783

 
$
956,064

Participating securities’ (restricted stock) share in earnings
 
385

 
1,171

 
1,033

 
3,321

Net income attributable to common shares
 
$
261,428

 
$
341,295

 
$
710,750

 
$
952,743

Average number of shares of common stock outstanding
 
163,676

 
175,097

 
167,935

 
175,865

Effect of dilutive variable restricted shares and performance share units (1)
 
1,335

 
1,830

 
1,190

 
1,692

Average number of shares of common stock outstanding assuming dilution
 
165,011

 
176,927

 
169,125

 
177,557

Basic earnings per share
 
$
1.60

 
$
1.95

 
$
4.23

 
$
5.42

Diluted earnings per share
 
$
1.58

 
$
1.93

 
$
4.20

 
$
5.37

(1) Excludes anti-dilutive restricted and performance share units of:
 
109

 

 
120

 
2




NOTE 8:
Stock-Based Compensation

We have a principal share-based compensation plan (the “Long-Term Incentive Compensation Plan”). The compensation cost charged against income for the plan was $9.2 million and $8.1 million for the three months ended September 30, 2019 and 2018, respectively, and $30.0 million and $23.8 million for the nine months ended September 30, 2019 and 2018, respectively. Our accounting policy for the recognition of compensation expense for awards with pro-rata vesting 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.’s non-employee directors and certain executives and employees. Compensation cost attributable to HEP’s share-based compensation plan was $0.5 million and $0.7 million for the three months ended September 30, 2019 and 2018, respectively, and $1.8 million and $2.3 million for the nine months ended September 30, 2019 and 2018, respectively.

Restricted Stock and Restricted Stock Units
Under our Long-Term Incentive Compensation Plan, we grant certain officers and other key employees restricted stock unit awards with awards generally vesting over a period of three years. We previously granted restricted stock to certain officers and key employees with awards vesting over a period of three years. Certain restricted stock unit award recipients have the right to receive dividends, however, restricted stock units do not have any other rights of absolute ownership. Restricted stock award recipients are generally entitled to all the rights of absolute ownership of the restricted shares from the date of grant including the right to vote the shares and to receive dividends. Upon vesting, restrictions on the restricted stock and restricted stock units lapse at which time they convert to common shares or cash. 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 grant date market price of our common shares and is amortized over the respective vesting period. We account for forfeitures on an estimated basis.


24


A summary of restricted stock and restricted stock unit activity during the nine months ended September 30, 2019 is presented below:
Restricted Stock and Restricted Stock Units
 
Grants
 
Weighted Average Grant Date Fair Value
 
Aggregate Intrinsic Value ($000)
 
 
 
 
 
 
 
Outstanding at January 1, 2019 (non-vested)
 
1,196,914

 
$
46.81

 
 
Granted
 
45,006

 
52.97

 
 
Vesting (transfer/conversion to common stock)
 
(17,374
)
 
49.32

 
 
Forfeited
 
(38,600
)
 
47.97

 
 
Outstanding at September 30, 2019 (non-vested)
 
1,185,946

 
46.97

 
$
63,614


For the nine months ended September 30, 2019, restricted stock and restricted stock units vested having a grant date fair value of $0.9 million. As of September 30, 2019, there was $14.4 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 1.0 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 or cash 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 “financial performance” and “market performance” criteria. Financial performance is based on our financial performance compared to a peer group of independent refining companies, while market performance is based on the relative standing of total shareholder return achieved by HollyFrontier compared to peer group companies. The number of shares ultimately issued under these awards can range from zero to 200% of target award amounts.

A summary of performance share unit activity during the nine months ended September 30, 2019 is presented below:
Performance Share Units
 
Grants
 
 
 
Outstanding at January 1, 2019 (non-vested)
 
662,431

Granted
 
6,086

Forfeited
 
(4,516
)
Outstanding at September 30, 2019 (non-vested)
 
664,001



As of September 30, 2019, there was $7.9 million of total unrecognized compensation cost related to non-vested performance share units having a grant date fair value of $47.24 per unit. That cost is expected to be recognized over a weighted-average period of 0.9 years.



25


NOTE 9:
Inventories

Inventories consist of the following components:
 
 
September 30,
2019
 
December 31, 2018
 
 
(In thousands)
Crude oil
 
$
472,932

 
$
503,705

Other raw materials and unfinished products(1)
 
306,504

 
360,124

Finished products(2)
 
860,130

 
662,713

Lower of cost or market reserve
 
(209,655
)
 
(360,138
)
Process chemicals(3)
 
29,040

 
31,413

Repair and maintenance supplies and other (4)
 
178,108

 
156,562

Total inventory
 
$
1,637,059

 
$
1,354,379


(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.
(4)
Includes RINs.

Our inventories that are valued at the lower of LIFO cost or market reflect a valuation reserve of $209.7 million and $360.1 million at September 30, 2019 and December 31, 2018, respectively. The December 31, 2018 market reserve of $360.1 million was reversed due to the sale of inventory quantities that gave rise to the 2018 reserve. A new market reserve of $209.7 million was established as of September 30, 2019 based on market conditions and prices at that time. The effect of the change in lower of cost or market reserve was an increase to cost of products sold totaling $34.1 million and $17.8 million for the three months ended September 30, 2019 and 2018, respectively, and a decrease to cost of products sold totaling $150.5 million and $192.9 million for the nine months ended September 30, 2019 and 2018, respectively.

At September 30, 2019, the LIFO value of inventory, net of the lower of cost or market reserve, was equal to current costs.

During the three months ended September 30, 2019, the EPA granted the Cheyenne Refinery and the Woods Cross Refinery each a one-year small refinery exemption from the Renewable Fuel Standard (“RFS”) program requirements for the 2018 calendar year end. As a result, the Cheyenne Refinery’s and the Woods Cross Refinery’s gasoline and diesel production are not subject to the Renewable Volume Obligation (“RVO”) for 2018. In the third quarter of 2019, we increased our inventory of RINs and reduced our cost of products sold by $36.6 million representing the net cost of the RINs charge to cost of products sold in 2018, less the loss incurred for selling 2018 vintage RINs in excess of those which we can use subject to the 20% carryover limit.

During the three months ended June 30, 2018, the EPA granted the Woods Cross Refinery a one-year small refinery exemption from the RFS program requirements for the 2017 calendar year end. As a result, the Woods Cross Refinery’s gasoline and diesel production are not subject to the RVO for 2017. In the second quarter of 2018, we increased our inventory of RINs and reduced our cost of products sold by $25.3 million, representing the net cost of the Woods Cross Refinery’s RINs charge to cost of products sold in 2017, less the loss incurred for selling 2017 vintage RINs in excess of those which we can use subject to the 20% carryover limit.

During the three months ended March 31, 2018, the EPA granted the Cheyenne Refinery a one-year small refinery exemption from the RFS program requirements for the 2015 and 2017 calendar years end. As a result, the Cheyenne Refinery’s gasoline and diesel production are not subject to the RVO for those years. At the date we received the 2017 Cheyenne Refinery exemption, we had not yet retired RINs to satisfy the 2017 RVO, which we intended to satisfy, in part, with 2016 vintage RINs subject to the 20% carryover limit. In the first quarter of 2018, we increased our inventory of RINs and reduced our cost of products sold by $37.9 million, representing the net cost of the Cheyenne Refinery’s RINs charged to cost of products sold in 2017, less the loss incurred from selling 2016 vintage RINs prior to their expiration in 2018.


26


In the first quarter of 2018, the EPA provided us 2018 vintage RINs to replace the RINs previously submitted to meet the Cheyenne Refinery’s 2015 RVO. In the first quarter of 2018, we increased our inventory of RINs and reduced our cost of products sold by $33.8 million representing the fair value of the 2018 replacement RINs obtained from the Cheyenne Refinery’s exemption of its 2015 RVO.

Various subsidiaries of HollyFrontier have intervened in three lawsuits brought by renewable fuel interest groups against the EPA in federal appellate courts alleging violations of the RFS under the Clean Air Act and challenging the EPA’s handling of small refinery exemptions. We believe the EPA correctly applied applicable law to the matters at issue and will vigorously defend the EPA’s position on small refinery exemptions. It is too early to assess whether the cases are expected to have any impact on us.


NOTE 10:
Environmental

Environmental costs are charged to operating expenses if they relate to an existing condition caused by past operations and do not contribute to current or future revenue generation. We have ongoing investigations of environmental matters at various locations and routinely assess our recorded environmental obligations, if any, with respect to such matters. Liabilities are recorded when site restoration and environmental remediation, cleanup and other obligations are either known or considered probable and can be reasonably estimated. Such estimates are undiscounted and require judgment with respect to costs, time frame and extent of required remedial and cleanup activities and are subject to periodic adjustments based on currently available information. Recoveries of environmental costs through insurance, indemnification arrangements or other sources are included in other assets to the extent such recoveries are considered probable.

We incurred expense of $1.8 million and $3.3 million for the three months ended September 30, 2019 and 2018, respectively, and $5.5 million and $4.9 million for the nine months ended September 30, 2019 and 2018, respectively, for environmental remediation obligations. The accrued environmental liability reflected in our consolidated balance sheets was $109.9 million and $110.2 million at September 30, 2019 and December 31, 2018, respectively, of which $92.4 million and $93.8 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). Estimated liabilities could increase in the future when the results of ongoing investigations become known, are considered probable and can be reasonably estimated.


NOTE 11:
Debt

HollyFrontier Credit Agreement
We have a $1.35 billion senior unsecured revolving credit facility maturing in February 2022 (the “HollyFrontier Credit Agreement”). The HollyFrontier Credit Agreement may be used for revolving credit loans and letters of credit from time to time and is available to fund general corporate purposes. At September 30, 2019, we were in compliance with all covenants, had no outstanding borrowings and had outstanding letters of credit totaling $4.9 million under the HollyFrontier Credit Agreement.

HEP Credit Agreement
HEP has a $1.4 billion senior secured revolving credit facility maturing in July 2022 (the “HEP Credit Agreement”) and is available to fund capital expenditures, investments, acquisitions, distribution payments, working capital and for general partnership purposes. It is also available to fund letters of credit up to a $50 million sub-limit and has a $300 million accordion. During the nine months ended September 30, 2019, HEP received advances totaling $269.5 million and repaid $257.0 million under the HEP Credit Agreement. At September 30, 2019, HEP was in compliance with all of its covenants, had outstanding borrowings of $935.5 million and no outstanding letters of credit under the HEP Credit Agreement.

HEP’s obligations under the HEP Credit Agreement are collateralized by substantially all of HEP’s assets and are guaranteed by HEP’s material 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 recourse to our other assets. Furthermore, our creditors have no recourse to the assets of HEP and its consolidated subsidiaries.

HollyFrontier Senior Notes
Our 5.875% senior notes ($1 billion aggregate principal amount maturing April 2026) (the “HollyFrontier Senior Notes”) are unsecured and unsubordinated obligations of ours and rank equally with all our other existing and future unsecured and unsubordinated indebtedness.

27



HollyFrontier Financing Arrangements
In December 2018, certain of our wholly-owned subsidiaries entered into financing arrangements whereby such subsidiaries sold a portion of their precious metals catalyst to a financial institution and then leased back the precious metals catalyst in exchange for total cash received of $32.5 million. The volume of the precious metals catalyst and the lease rate are fixed over the one-year term of each lease, and the lease payments are recorded as interest expense. At maturity, we must repurchase the precious metals catalyst at its then fair market value. These financing arrangements are recorded at a Level 2 fair value totaling $36.5 million at September 30, 2019 and are included in “Accrued liabilities” in our consolidated balance sheets. See Note 6 for additional information on Level 2 inputs.

HEP Senior Notes
HEP’s 6.0% senior notes ($500 million aggregate principal amount maturing August 2024) (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 is guaranteed by HEP’s wholly-owned subsidiaries. HEP’s creditors have no recourse to our assets. Furthermore, our creditors have no recourse to the assets of HEP and its consolidated subsidiaries.

The carrying amounts of long-term debt are as follows:
 
 
September 30,
2019
 
December 31,
2018
 
 
(In thousands)
HollyFrontier 5.875% Senior Notes
 
 
 
 
Principal
 
$
1,000,000

 
$
1,000,000

Unamortized discount and debt issuance costs
 
(6,635
)
 
(7,360
)
 
 
993,365

 
992,640

 
 
 
 
 
HEP Credit Agreement
 
935,500

 
923,000

 
 
 
 
 
HEP 6% Senior Notes
 
 
 
 
Principal
 
500,000

 
500,000

Unamortized discount and debt issuance costs
 
(3,631
)
 
(4,100
)
 
 
496,369

 
495,900

 
 
 
 
 
Total HEP long-term debt
 
1,431,869

 
1,418,900

 
 
 
 
 
Total long-term debt
 
$
2,425,234

 
$
2,411,540


The fair values of the senior notes are as follows:
 
 
September 30,
2019
 
December 31,
2018
 
 
(In thousands)
 
 
 
 
 
HollyFrontier senior notes
 
$
1,121,460

 
$
1,019,160

 
 
 
 
 
HEP senior notes
 
$
523,220

 
$
488,310



These fair values are based on a Level 2 input. See Note 6 for additional information on Level 2 inputs.


28


We capitalized interest attributable to construction projects of $0.7 million and $1.3 million for the three months ended September 30, 2019 and 2018, respectively, and $1.8 million and $3.3 million for the nine months ended September 30, 2019 and 2018, respectively.


NOTE 12: 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, forward purchase and sales and futures contracts to mitigate price exposure with respect to our inventory positions, natural gas purchases, sales prices of refined products and crude oil costs.

Foreign Currency Risk Management
We are exposed to market risk related to the volatility in foreign currency exchange rates. We periodically enter into derivative contracts in the form of foreign exchange forward and foreign exchange swap contracts to mitigate the exposure associated with fluctuations on intercompany notes with our foreign subsidiaries that are not denominated in the U.S. dollar.

Accounting Hedges
We have swap contracts serving as cash flow hedges against price risk on forecasted purchases of natural gas and to lock in basis spread differentials on forecasted purchases of crude oil. We also periodically have forward sales contracts that lock in the prices of future sales of crude oil and refined product. These contracts have been designated as accounting hedges and are measured 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.

The following table presents the pre-tax effect on other comprehensive income (“OCI”) and earnings due to fair value adjustments and maturities of derivatives designated as hedging instruments under hedge accounting:
 
 
Net Unrealized Gain (Loss) Recognized in OCI
 
Gain (Loss) Reclassified into Earnings
Derivatives Designated as Cash Flow Hedging Instruments
 
Three Months Ended
September 30,
 
Income Statement Location
 
Three Months Ended
September 30,
 
2019
 
2018
 
 
2019
 
2018
 
 
(In thousands)
Commodity contracts
 
$
(7,562
)
 
$
5,792

 
Sales and other revenues
 
$

 
$
(1,422
)
 
 
 
 
 
 
Cost of products sold
 
6,027

 

 
 
 
 
 
 
Operating expenses
 
(454
)
 
(209
)
Total
 
$
(7,562
)
 
$
5,792

 
 
 
$
5,573

 
$
(1,631
)


 
 
Net Unrealized Gain (Loss) Recognized in OCI
 
Gain (Loss) Reclassified into Earnings
Derivatives Designated as Cash Flow Hedging Instruments
 
Nine Months Ended
September 30,
 
Income Statement Location
 
Nine Months Ended
September 30,
 
2019
 
2018
 
 
2019
 
2018
 
 
(In thousands)
Commodity contracts
 
$
372

 
$
1,796

 
Sales and other revenues
 
$
(1,799
)
 
$
(5,093
)
 
 
 
 
 
 
Cost of products sold
 
15,323

 

 
 
 
 
 
 
Operating expenses
 
(987
)
 
(945
)
Total
 
$
372

 
$
1,796

 
 
 
$
12,537

 
$
(6,038
)



29


Economic Hedges
We have commodity contracts including contracts to lock in basis spread differentials on forecasted purchases of crude oil, swap contracts to lock in the crack spread of WTI and gasoline, NYMEX futures contracts to lock in prices on forecasted purchases and sales of inventory and forward purchase and sell contracts that serve as economic hedges (derivatives used for risk management, but not designated as accounting hedges). We also have forward currency contracts to fix the rate of foreign currency. In addition, our catalyst financing arrangements discussed in Note 11 could require repayment under certain conditions based on the futures price of platinum, which is an embedded derivative. These contracts are measured 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:
 
 
Gain (Loss) Recognized in Earnings
Derivatives Not Designated as Hedging Instruments
 
Income Statement Location
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2019
 
2018
 
2019
 
2018
 
 
 
 
(In thousands)
Commodity contracts
 
Cost of products sold
 
$
8,640

 
$
(8,252
)
 
$
1,561

 
$
(20,580
)
 
 
Interest expense
 
(1,720
)
 

 
(2,995
)
 

Foreign currency contracts
 
Gain on foreign currency transactions
 
5,713

 
(7,052
)
 
(8,983
)
 
18,504

 
 
Total
 
$
12,633

 
$
(15,304
)
 
$
(10,417
)
 
$
(2,076
)


As of September 30, 2019, we have the following notional contract volumes related to outstanding derivative instruments:
 
 
 
 
Notional Contract Volumes by Year of Maturity
 
 
 
 
Total Outstanding Notional
 
2019
 
2020
 
2021
 
Unit of Measure
Derivatives Designated as Hedging Instruments
 
 
 
 
 
 
 
 
 
 
Natural gas price swaps - long
 
4,050,000

 
450,000

 
1,800,000

 
1,800,000

 
MMBTU
Crude oil price swaps (basis spread) - long
 
5,954,000

 
1,196,000

 
4,758,000

 

 
Barrels
Forward crude oil contracts - short
 
423,739

 
423,739

 

 

 
Barrels
 
 
 
 
 
 
 
 
 
 
 
Derivatives Not Designated as Hedging Instruments
 
 
 
 
 
 
 
 
 
 
NYMEX futures (WTI) - short
 
1,825,000

 
1,713,000

 
112,000

 

 
Barrels
Crude oil price swaps (basis spread) - long
 
1,464,000

 

 
1,464,000

 

 
Barrels
WTI and gasoline crack spread swaps - short
 
200,000

 
200,000

 

 

 
Barrels
Forward gasoline and diesel contracts - long
 
538,500

 
538,500

 

 

 
Barrels
Forward crude oil contracts - long
 
140,849

 
140,849

 

 

 
Barrels
Physical contracts - long
 
350,000

 
350,000

 

 

 
Barrels
Physical contracts - short
 
350,000

 
350,000

 

 

 
Barrels
Foreign currency forward contracts
 
434,443,896

 
114,213,501

 
320,230,395

 

 
U.S. dollar
Forward commodity contracts (platinum)
 
41,147

 
41,147

 

 

 
Troy ounces


30


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.
 
 
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)
 
 
September 30, 2019
 
 
 
 
 
 
 
 
 
 
 
 
Derivatives designated as cash flow hedging instruments:
 
 
Commodity price swap contracts
 
$
13,182

 
$
(1,576
)
 
$
11,606

 
$
1,614

 
$
(500
)
 
$
1,114

Commodity forward contracts
 

 

 

 
258

 

 
258

 
 
$
13,182

 
$
(1,576
)
 
$
11,606

 
$
1,872

 
$
(500
)
 
$
1,372

 
 
 
 
 
 
 
 
 
 
 
 
 
Derivatives not designated as cash flow hedging instruments:
 
 
Foreign currency forward contracts
 
$
2,511

 
$

 
$
2,511

 
$
17

 
$

 
$
17

NYMEX futures contracts
 
2,976

 

 
2,976

 

 

 

Commodity price swap contracts
 
6,401

 

 
6,401

 

 
(20
)
 
(20
)
Commodity forward contracts
 
1,453

 

 
1,453

 
1,109

 

 
1,109

 
 
$
13,341

 
$

 
$
13,341

 
$
1,126

 
$
(20
)
 
$
1,106

 
 
 
 
 
 
 
 
 
 
 
 
 
Total net balance
 
 
 
 
 
$
24,947

 
 
 
 
 
$
2,478

 
 
 
 
 
 
 
 
 
 
 
 
 
Balance sheet classification:
 
Prepayment and other
 
$
23,295

 
Accrued liabilities
 
$
1,922

 
 
Intangibles and other
 
1,652

 
Other long-term liabilities
 
556

 
 
 
 
$
24,947

 
 
 
 
 
$
2,478

December 31, 2018
 
 
Derivatives designated as cash flow hedging instruments:
 
 
Commodity price swap contracts
 
$
11,790

 
$
(973
)
 
$
10,817

 
$
1,755

 
$
(799
)
 
$
956

 
 
$
11,790

 
$
(973
)
 
$
10,817

 
$
1,755

 
$
(799
)
 
$
956

 
 
 
 
 
 
 
 
 
 
 
 
 
Derivatives not designated as cash flow hedging instruments:
 
 
Foreign currency forward contracts
 
$
25,956

 
$

 
$
25,956

 
$

 
$

 
$

NYMEX futures contracts
 
2,473

 

 
2,473

 

 

 

Commodity forward contracts
 
1,034

 

 
1,034

 
1,137

 

 
1,137

 
 
$
29,463

 
$

 
$
29,463

 
$
1,137

 
$

 
$
1,137

 
 
 
 
 
 
 
 
 
 
 
 
 
Total net balance
 
 
 
 
 
$
40,280

 
 
 
 
 
$
2,093

 
 
 
 
 
 
 
 
 
 
 
 
 
Balance sheet classification:
 
Prepayment and other
 
$
37,982

 
Accrued liabilities
 
$
1,137

 
 
Intangibles and other
 
2,298

 
Other long-term liabilities
 
956

 
 
 
 
$
40,280

 
 
 
 
 
$
2,093


At September 30, 2019, we had a pre-tax net unrealized gain of $10.2 million classified in accumulated other comprehensive income that relates to all accounting hedges having contractual maturities through 2021. Assuming commodity prices remain unchanged, an unrealized gain of $10.3 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.



31


NOTE 13:
Equity

In September 2018, our Board of Directors approved a $1 billion share repurchase program, which replaced all existing share repurchase programs, authorizing 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 and corporate, regulatory and other relevant considerations. This program may be discontinued at any time by the Board of Directors. As of September 30, 2019, we had remaining authorization to repurchase up to $313.2 million under this stock repurchase program. In addition, we are authorized by our Board of Directors to repurchase shares in an amount sufficient to offset shares issued under our compensation programs.

During the nine months ended September 30, 2019 and 2018, we withheld 5,359 and 12,593, respectively, shares of our common stock 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.


NOTE 14:
Other Comprehensive Income

The components and allocated tax effects of other comprehensive income are as follows:
 
 
Before-Tax
 
Tax Expense
(Benefit)
 
After-Tax
 
 
(In thousands)
Three Months Ended September 30, 2019
 
 
 
 
 
 
Net change in foreign currency translation adjustment
 
$
(9,311
)
 
$
(1,959
)
 
$
(7,352
)
Net unrealized loss on hedging instruments
 
(7,562
)
 
(1,929
)
 
(5,633
)
Other comprehensive loss attributable to HollyFrontier stockholders
 
$
(16,873
)
 
$
(3,888
)
 
$
(12,985
)
 
 
 
 
 
 
 
Three Months Ended September 30, 2018
 
 
 
 
 
 
Net change in foreign currency translation adjustment
 
$
8,325

 
$
1,756

 
$
6,569

Net unrealized gain on hedging instruments
 
5,792

 
1,478

 
4,314

Other comprehensive income attributable to HollyFrontier stockholders
 
$
14,117

 
$
3,234

 
$
10,883

 
 
 
 
 
 
 
Nine Months Ended September 30, 2019
 
 
 
 
 
 
Net change in foreign currency translation adjustment
 
$
4,212

 
$
896

 
$
3,316

Net unrealized gain on hedging instruments
 
372

 
94

 
278

Other comprehensive income attributable to HollyFrontier stockholders
 
$
4,584

 
$
990

 
$
3,594

 
 
 
 
 
 
 
Nine Months Ended September 30, 2018
 
 
 
 
 
 
Net change in foreign currency translation adjustment
 
$
(15,118
)
 
$
(3,130
)
 
$
(11,988
)
Net unrealized gain on hedging instruments
 
1,796

 
453

 
1,343

Other comprehensive loss attributable to HollyFrontier stockholders
 
$
(13,322
)
 
$
(2,677
)
 
$
(10,645
)

32



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
September 30,
 
 
 
 
2019
 
2018
 
 
 
 
 
 
 
 
 
Hedging instruments:
 
 
 
 
 
 
Commodity price swaps
 
$

 
$
(1,422
)
 
Sales and other revenues
 
 
6,027

 

 
Cost of products sold
 
 
(454
)
 
(209
)
 
Operating expenses
 
 
5,573

 
(1,631
)
 
 
 
 
1,421

 
(416
)
 
Income tax expense (benefit)
Total reclassifications for the period
 
$
4,152

 
$
(1,215
)
 
Net of tax
 
 
 
 
 
 
 
 
 
Nine Months Ended
September 30,
 
 
 
 
2019
 
2018
 
 
 
 
 
 
 
 
 
Hedging instruments:
 
 
 
 
 
 
Commodity price swaps
 
$
(1,799
)
 
$
(5,093
)
 
Sales and other revenues
 
 
15,323

 

 
Cost of products sold
 
 
(987
)
 
(945
)
 
Operating expenses
 
 
12,537

 
(6,038
)
 
 
 
 
3,197

 
(1,540
)
 
Income tax expense (benefit)
Total reclassifications for the period
 
$
9,340

 
$
(4,498
)
 
Net of tax


Accumulated other comprehensive income in the equity section of our consolidated balance sheets includes:
 
 
September 30,
2019
 
December 31,
2018
 
 
(In thousands)
Foreign currency translation adjustment
 
$
(9,360
)
 
$
(12,676
)
Unrealized loss on pension obligation
 
(1,404
)
 
(1,404
)
Unrealized gain on post-retirement benefit obligations
 
20,358

 
20,358

Unrealized gain on hedging instruments
 
7,623

 
7,345

Accumulated other comprehensive income
 
$
17,217

 
$
13,623




NOTE 15:
Post-retirement Plans

Our net periodic pension expense consisted of the following components:
 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
 
2019
 
2018
 
2019
 
2018
 
 
(In thousands)
Service cost - benefit earned during the period
 
$
1,209

 
$
1,093

 
$
3,605

 
$
3,337

Interest cost on projected benefit obligations
 
450

 
556

 
1,325

 
1,698

Expected return on plan assets
 
(822
)
 
(856
)
 
(2,441
)
 
(2,615
)
Amortization of loss
 
15

 

 
45

 

Net periodic pension expense
 
$
852

 
$
793

 
$
2,534

 
$
2,420



The expected long-term annual rates of return on plan assets are 5.00% and 2.20% for the PCLI and Sonneborn plans, respectively. These rates were used in measuring 2019 net periodic benefit costs.


33


The net periodic benefit credit of our post-retirement healthcare and other benefits plans consisted of the following components
 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
 
2019
 
2018
 
2019
 
2018
 
 
(In thousands)
Service cost – benefit earned during the period
 
$
387

 
$
411

 
$
1,161

 
$
1,238

Interest cost on projected benefit obligations
 
267

 
234

 
801

 
705

Amortization of prior service credit
 
(870
)
 
(870
)
 
(2,611
)
 
(2,611
)
Amortization of gain
 
(22
)
 

 
(66
)
 

Net periodic post-retirement credit
 
$
(238
)
 
$
(225
)
 
$
(715
)
 
$
(668
)

The components, other than service cost, of our net periodic pension expense and net periodic post-retirement credit are recorded in Other, net in our consolidated statements of income.

Sonneborn has various post-retirement benefit plans for employees in the United States and in the Netherlands.
The plans for Sonneborn employees in the Netherlands include a defined benefit pension plan which was frozen and all plan participants became inactive in 2016. The plan assets are in the form of a third-party insurance contract that is valued based on the assets held by the insurer and insures a value which approximates the accrued benefits related to the plan’s accumulated benefit obligation. A new multiemployer pension plan was established in 2016, which is accounted for as a defined contribution plan. Also, in 2016, a new plan was established to provide future indexation benefits to participants who had accrued benefits under the expiring arrangements. Such benefits are funded by Sonneborn Refined Products B.V.
The plans for Sonneborn employees in the United States include a post-retirement medical plan and a multiemployer plan for union employees. These plans are accounted for as defined contribution plans.


NOTE 16:
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 material adverse effect on our financial condition, results of operations or cash flows.

In March 2006, a subsidiary of ours sold the assets of Montana Refining Company under an Asset Purchase Agreement (“APA”). Calumet Montana Refining LLC, the current owner of the assets, submitted requests for reimbursement of approximately $20.0 million pursuant to contractual indemnity provisions under the APA for various costs incurred. Calumet also asserted claims related to environmental matters. We rejected all of the currently pending claims for payment, and selected issues were arbitrated in July 2018. In September 2018, the arbitration panel ruled on the selected issues and held that the APA places a number of important limitations on claims advanced by Calumet. In a ruling dated August 16, 2019, as amended on October 3, 2019, the arbitration panel determined that, with regard to all claims asserted by Calumet, we do not owe any amounts to Calumet. Accordingly, during the third quarter of 2019, estimated costs previously accrued for this matter were reversed into income.

We filed a business interruption claim with our insurance carriers related to a fire at our Woods Cross Refinery that occurred in the first quarter 2018. As of September 30, 2019, we have collected interim payments totaling $56.0 million, but have not reached a final agreement regarding the amounts owed to us pursuant to our business interruption coverage. We have accounted for this claim as a gain contingency and accordingly, we have deferred revenue recognition for the interim payments received until such time that uncertainties regarding the amounts owed to us have been resolved.


NOTE 17:
Segment Information

Our operations are organized into three reportable segments, Refining, Lubricants and Specialty Products and HEP. Our operations that are not included in the Refining, Lubricants and Specialty Products and HEP segments are included in Corporate and Other. Intersegment transactions are eliminated in our consolidated financial statements and are included in Eliminations. Corporate and
Other and Eliminations are aggregated and presented under Corporate, Other and Eliminations column.

34



The Refining segment represents the operations of the El Dorado, Tulsa, Navajo, Cheyenne and Woods Cross Refineries and HFC 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. HFC Asphalt operates various asphalt terminals in Arizona, New Mexico and Oklahoma.

The Lubricants and Specialty Products segment involves PCLI’s production operations, located in Mississauga, Ontario, that includes lubricant products such as base oils, white oils, specialty products and finished lubricants, and the operations of our Petro- Canada Lubricants business that includes the marketing of products to both retail and wholesale outlets through a global sales network with locations in Canada, the United States, Europe and China. Additionally, the Lubricants and Specialty Products segment includes specialty lubricant products produced at our Tulsa Refineries that are marketed throughout North America and are distributed in Central and South America. Also, effective with our acquisition that closed August 1, 2018, the Lubricants and Specialty Products segment includes Red Giant Oil, one of the largest suppliers of locomotive engine oil in North America, and effective with our acquisition that closed February 1, 2019, includes Sonneborn, a producer of specialty hydrocarbon chemicals such as white oils, petrolatums and waxes with manufacturing facilities in the United States and Europe.

The HEP segment includes all of the operations of HEP, which owns and operates logistics and refinery assets consisting of petroleum product and crude oil pipelines, terminals, tankage, loading rack facilities and processing units in the Mid-Continent, Southwest and Rocky Mountain regions of the United States. As of September 30, 2019, the HEP segment also includes a 75% ownership interest in UNEV (a consolidated subsidiary of HEP) and 50% ownership interests in each of the Osage Pipeline and the Cheyenne 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. Due to certain basis differences, 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, 2018.

35


 
 
Refining
 
Lubricants and Specialty Products
 
HEP
 
Corporate, Other
and Eliminations
 
Consolidated
Total
 
 
(In thousands)
Three Months Ended September 30, 2019
 
 
 
 
 
 
 
 
Sales and other revenues:
 
 
 
 
 
 
 
 
 
 
Revenues from external customers
 
$
3,865,399

 
$
529,561

 
$
29,868

 
$

 
$
4,424,828

Intersegment revenues
 
81,571

 
8,157

 
106,027

 
(195,755
)
 

 
 
$
3,946,970

 
$
537,718

 
$
135,895

 
$
(195,755
)
 
$
4,424,828

Cost of products sold (exclusive of lower of cost or market inventory)
 
$
3,177,167

 
$
397,926

 
$

 
$
(171,326
)
 
$
3,403,767

Lower of cost or market inventory valuation adjustment
 
$
34,062

 
$

 
$

 
$

 
$
34,062

Operating expenses
 
$
276,869

 
$
57,974

 
$
44,924

 
$
(34,189
)
 
$
345,578

Selling, general and administrative expenses
 
$
31,707

 
$
43,875

 
$
2,714

 
$
9,330

 
$
87,626

Depreciation and amortization
 
$
76,765

 
$
22,700

 
$
24,121

 
$
3,430

 
$
127,016

Income (loss) from operations
 
$
350,400

 
$
15,243

 
$
64,136

 
$
(3,000
)
 
$
426,779

Earnings of equity method investments
 
$

 
$

 
$
1,334

 
$

 
$
1,334

Capital expenditures
 
$
53,506

 
$
8,697

 
$
6,076

 
$
6,310

 
$
74,589

 
 
 
 
 
 
 
 
 
 
 
Three Months Ended September 30, 2018
 
 
 
 
 
 
 
 
Sales and other revenues:
 
 
 
 
 
 
 
 
 
 
Revenues from external customers
 
$
4,270,835

 
$
474,260

 
$
25,596

 
$
108

 
$
4,770,799

Intersegment revenues
 
101,334

 
1,626

 
100,188

 
(203,148
)
 

 
 
$
4,372,169

 
$
475,886

 
$
125,784

 
$
(203,040
)
 
$
4,770,799

Cost of products sold (exclusive of lower of cost or market inventory)
 
$
3,572,593

 
$
359,742

 
$

 
$
(180,101
)
 
$
3,752,234

Lower of cost or market inventory valuation adjustment
 
$
17,837

 
$

 
$

 
$

 
$
17,837

Operating expenses
 
$
262,010

 
$
40,288

 
$
35,995

 
$
(21,097
)
 
$
317,196

Selling, general and administrative expenses
 
$
30,394

 
$
33,514

 
$
2,498

 
$
4,724

 
$
71,130

Depreciation and amortization
 
$
70,793

 
$
11,139

 
$
24,367

 
$
2,586

 
$
108,885

Income (loss) from operations
 
$
418,542

 
$
31,203

 
$
62,924

 
$
(9,152
)
 
$
503,517

Earnings of equity method investments
 
$

 
$

 
$
1,114

 
$

 
$
1,114

Capital expenditures
 
$
47,088

 
$
8,094

 
$
9,541

 
$
5,214

 
$
69,937



36


 
 
Refining
 
Lubricants and Specialty Products
 
HEP
 
Corporate, Other
and Eliminations
 
Consolidated
Total
 
 
(In thousands)
Nine Months Ended September 30, 2019
 
 
 
 
 
 
 
 
Sales and other revenues:
 
 
 
 
 
 
 
 
 
 
Revenues from external customers
 
$
11,446,841

 
$
1,568,241

 
$
89,388

 
$
220

 
$
13,104,690

Intersegment revenues
 
244,799

 
8,157

 
311,755

 
(564,711
)
 

 
 
$
11,691,640

 
$
1,576,398

 
$
401,143

 
$
(564,491
)
 
$
13,104,690

Cost of products sold (exclusive of lower of cost or market inventory)
 
$
9,598,539

 
$
1,202,296

 
$

 
$
(492,979
)
 
$
10,307,856

Lower of cost or market inventory valuation adjustment
 
$
(150,483
)
 
$

 
$

 
$

 
$
(150,483
)
Operating expenses
 
$
794,081

 
$
170,655

 
$
123,045

 
$
(77,359
)
 
$
1,010,422

Selling, general and administrative expenses
 
$
88,322

 
$
125,681

 
$
7,322

 
$
39,652

 
$
260,977

Depreciation and amortization
 
$
227,405

 
$
65,891

 
$
72,192

 
$
9,857

 
$
375,345

Goodwill impairment
 
$

 
$
152,712

 
$

 
$

 
$
152,712

Income (loss) from operations
 
$
1,133,776

 
$
(140,837
)
 
$
198,584

 
$
(43,662
)
 
$
1,147,861

Earnings of equity method investments
 
$

 
$

 
$
5,217

 
$

 
$
5,217

Capital expenditures
 
$
129,167

 
$
25,887

 
$
23,828

 
$
16,175

 
$
195,057

 
 
 
 
 
 
 
 
 
 
 
Nine Months Ended September 30, 2018
 
 
 
 
 
 
 
 
Sales and other revenues:
 
 
 
 
 
 
 
 
 
 
Revenues from external customers
 
$
11,915,797

 
$
1,376,531

 
$
77,799

 
$
335

 
$
13,370,462

Intersegment revenues
 
284,538

 
11,884

 
295,629

 
(592,051
)
 

 
 
$
12,200,335

 
$
1,388,415

 
$
373,428

 
$
(591,716
)
 
$
13,370,462

Cost of products sold (exclusive of lower of cost or market inventory)
 
$
10,179,509

 
$
1,040,414

 
$

 
$
(524,648
)
 
$
10,695,275

Lower of cost or market inventory valuation adjustment
 
$
(192,927
)
 
$

 
$

 
$

 
$
(192,927
)
Operating expenses
 
$
764,415

 
$
125,101

 
$
106,731

 
$
(62,548
)
 
$
933,699

Selling, general and administrative expenses
 
$
82,966

 
$
99,425

 
$
8,293

 
$
13,785

 
$
204,469

Depreciation and amortization
 
$
210,957

 
$
30,023

 
$
74,117

 
$
8,508

 
$
323,605

Income (loss) from operations
 
$
1,155,415

 
$
93,452

 
$
184,287

 
$
(26,813
)
 
$
1,406,341

Earnings of equity method investments
 
$

 
$

 
$
4,127

 
$

 
$
4,127

Capital expenditures
 
$
132,050

 
$
23,138

 
$
41,111

 
$
12,779

 
$
209,078



 
 
Refining
 
Lubricants and Specialty Products
 
HEP
 
Corporate, Other
and Eliminations
 
Consolidated
Total
 
 
(In thousands)
September 30, 2019
 
 
 
 
 
 
 
 
 
 
Cash and cash equivalents
 
$
21,443

 
$
170,116

 
$
7,469

 
$
782,828

 
$
981,856

Total assets
 
$
7,321,741

 
$
2,139,092

 
$
2,089,110

 
$
641,385

 
$
12,191,328

Long-term debt
 
$

 
$

 
$
1,431,869

 
$
993,365

 
$
2,425,234

 
 
 
 
 
 
 
 
 
 
 
December 31, 2018
 
 
 
 
 
 
 
 
 
 
Cash and cash equivalents
 
$
7,236

 
$
80,931

 
$
3,045

 
$
1,063,540

 
$
1,154,752

Total assets
 
$
6,465,155

 
$
1,506,209

 
$
2,142,027

 
$
881,210

 
$
10,994,601

Long-term debt
 
$

 
$

 
$
1,418,900

 
$
992,640

 
$
2,411,540





37

Table of Content


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 an independent petroleum refiner and marketer that produces high-value light products such as gasoline, diesel fuel, jet fuel and other specialty products. We own and operate refineries 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, 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”). We market our refined products principally in the Southwest United States, the Rocky Mountains extending into the Pacific Northwest and in other neighboring Plains states. In addition, we produce base oils and other specialized lubricants in the United States, Canada and the Netherlands, and export products to more than 80 countries. We also own a 57% limited partner interest and a non-economic general partner interest in HEP, a master limited partnership that provides petroleum product and crude oil transportation, terminalling, storage and throughput services to the petroleum industry, including HollyFrontier Corporation subsidiaries.

On November 12, 2018, we entered into an equity purchase agreement to acquire 100% of the issued and outstanding capital stock of Sonneborn US Holdings Inc. and 100% of the membership rights in Sonneborn Coöperatief U.A. (collectively, “Sonneborn”). The acquisition closed on February 1, 2019. Cash consideration paid was $662.7 million. Sonneborn is a producer of specialty hydrocarbon chemicals such as white oils, petrolatums and waxes with manufacturing facilities in the United States and Europe.

On July 10, 2018, we entered into a definitive agreement to acquire Red Giant Oil Company LLC (“Red Giant Oil”), a privately-owned lubricants company. The acquisition closed on August 1, 2018. Cash consideration paid was $54.2 million. Red Giant Oil is one of the largest suppliers of locomotive engine oil in North America and is headquartered in Council Bluffs, Iowa with storage and distribution facilities in Iowa, Kansas, Utah and Wyoming, along with a blending and packaging facility in Texas.

For the three months ended September 30, 2019, net income attributable to HollyFrontier stockholders was $261.8 million compared to $342.5 million for the three months ended September 30, 2018. For the nine months ended September 30, 2019, net income attributable to HollyFrontier stockholders was $711.8 million compared to $956.1 million for the nine months ended September 30, 2018. Overall gross refining margins per produced barrel sold for the three months ended September 30, 2019 decreased 11% over the same period of 2018 due to a decrease in the average per barrel sold sales price during the current year quarter, partially offset by decreased crude oil and feedstock prices. Included in our financial results for the third quarter was an inventory reserve adjustment that decreased pre-tax earnings by $34.1 million.

Pursuant to the 2007 Energy Independence and Security Act, the Environmental Protection Agency (“EPA”) promulgated the Renewable Fuel Standard (“RFS”) regulations, which increased the 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. Compliance with RFS significantly increases our cost of products sold, with RINs costs totaling $8.4 million for the three months ended September 30, 2019, which is net of the $36.6 million cost reduction resulting from small refinery RINs waivers granted by the EPA in 2019 as described in Note 9 “Inventories” in the Notes to Consolidated Financial Statements.


38

Table of Content

OUTLOOK

For the fourth quarter of 2019, we expect crack spreads to experience typical seasonal weakness as demand for refined products softens. Operationally, we are currently undergoing turnarounds at our El Dorado and Cheyenne refineries, and we expect to run between 380,000 to 390,000 barrels per day of crude oil.

In our Lubricants and Specialty Products segment, we expect the Rack Forward business to perform well based on steady demand for finished products. We expect this to be offset somewhat by oversupply in the base oil markets which will depress Rack Back earnings in the fourth quarter.

At HEP, we anticipate typical seasonal strengthening in the fourth quarter around the UNEV pipeline to drive higher sequential earnings. For 2019 and through 2020, HEP expects to hold the quarterly distribution constant at $0.6725 per unit, or $2.69 on an annualized basis, while maintaining a distribution coverage ratio of 1.0x. HEP’s 2020 distribution guidance reflects growth from contractual tariff escalators and the recently announced Cushing Connect joint venture, offset by lower revenues from Delek and elevated maintenance capital expenditures due to one-time events.

A more detailed discussion of our financial and operating results for the three and nine months ended September 30, 2019 and 2018 is presented in the following sections.


39

Table of Content

RESULTS OF OPERATIONS

Financial Data
 
 
Three Months Ended
September 30,
 
Change from 2018
 
 
2019
 
2018
 
Change
 
Percent
 
 
(In thousands, except per share data)
Sales and other revenues
 
$
4,424,828

 
$
4,770,799

 
$
(345,971
)
 
(7
)%
Operating costs and expenses:
 
 
 
 
 
 
 
 
Cost of products sold (exclusive of depreciation and amortization):
 
 
 
 
 
 
 
 
Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment)
 
3,403,767

 
3,752,234

 
(348,467
)
 
(9
)
Lower of cost or market inventory valuation adjustment
 
34,062

 
17,837

 
16,225

 
91

 
 
3,437,829

 
3,770,071

 
(332,242
)
 
(9
)
Operating expenses (exclusive of depreciation and amortization)
 
345,578

 
317,196

 
28,382

 
9

Selling, general and administrative expenses (exclusive of depreciation and amortization)
 
87,626

 
71,130

 
16,496

 
23

Depreciation and amortization
 
127,016

 
108,885

 
18,131

 
17

Total operating costs and expenses
 
3,998,049

 
4,267,282

 
(269,233
)
 
(6
)
Income from operations
 
426,779

 
503,517

 
(76,738
)
 
(15
)
Other income (expense):
 
 
 
 
 
 
 
 
Earnings of equity method investments
 
1,334

 
1,114

 
220

 
20

Interest income
 
6,164

 
5,136

 
1,028

 
20

Interest expense
 
(36,027
)
 
(32,399
)
 
(3,628
)
 
11

Gain on foreign currency transactions
 
395

 
281

 
114

 
41

Other, net
 
2,356

 
741

 
1,615

 
218

 
 
(25,778
)
 
(25,127
)
 
(651
)
 
3

Income before income taxes
 
401,001

 
478,390

 
(77,389
)
 
(16
)
Income tax expense
 
103,021

 
116,258

 
(13,237
)
 
(11
)
Net income
 
297,980

 
362,132

 
(64,152
)
 
(18
)
Less net income attributable to noncontrolling interest
 
36,167

 
19,666

 
16,501

 
84

Net income attributable to HollyFrontier stockholders
 
$
261,813

 
$
342,466

 
$
(80,653
)
 
(24
)%
Earnings per share attributable to HollyFrontier stockholders:
 
 
 
 
 
 
 
 
Basic
 
$
1.60

 
$
1.95

 
$
(0.35
)
 
(18
)%
Diluted
 
$
1.58

 
$
1.93

 
$
(0.35
)
 
(18
)%
Cash dividends declared per common share
 
$
0.33

 
$
0.33

 
$

 
 %
Average number of common shares outstanding:
 
 
 
 
 
 
 
 
Basic
 
163,676

 
175,097

 
(11,421
)
 
(7
)%
Diluted
 
165,011

 
176,927

 
(11,916
)
 
(7
)%


40

Table of Content

 
 
Nine Months Ended
September 30,
 
Change from 2018
 
 
2019
 
2018
 
Change
 
Percent
 
 
(In thousands, except per share data)
Sales and other revenues
 
$
13,104,690

 
$
13,370,462

 
$
(265,772
)
 
(2
)%
Operating costs and expenses:
 
 
 
 
 
 
 
 
Cost of products sold (exclusive of depreciation and amortization):
 
 
 
 
 
 
 
 
Cost of products sold (exclusive of lower of cost or market inventory valuation adjustment)
 
10,307,856

 
10,695,275

 
(387,419
)
 
(4
)
Lower of cost or market inventory valuation adjustment
 
(150,483
)
 
(192,927
)
 
42,444

 
(22
)
 
 
10,157,373

 
10,502,348

 
(344,975
)
 
(3
)
Operating expenses (exclusive of depreciation and amortization)
 
1,010,422

 
933,699

 
76,723

 
8

Selling, general and administrative expenses (exclusive of depreciation and amortization)
 
260,977

 
204,469

 
56,508

 
28

Depreciation and amortization
 
375,345

 
323,605

 
51,740

 
16

Goodwill impairment
 
152,712

 

 
152,712

 

Total operating costs and expenses
 
11,956,829

 
11,964,121

 
(7,292
)
 

Income from operations
 
1,147,861

 
1,406,341

 
(258,480
)
 
(18
)
Other income (expense):
 
 
 
 
 
 
 
 
Earnings of equity method investments
 
5,217

 
4,127

 
1,090

 
26

Interest income
 
17,127

 
10,660

 
6,467

 
61

Interest expense
 
(106,938
)
 
(97,446
)
 
(9,492
)
 
10

Gain on foreign currency transactions
 
4,873

 
5,516

 
(643
)
 
(12
)
Other, net
 
3,005

 
3,451

 
(446
)
 
(13
)
 
 
(76,716
)
 
(73,692
)
 
(3,024
)
 
4

Income before income taxes
 
1,071,145

 
1,332,649

 
(261,504
)
 
(20
)
Income tax expense
 
279,862

 
318,742

 
(38,880
)
 
(12
)
Net income
 
791,283

 
1,013,907

 
(222,624
)
 
(22
)
Less net income attributable to noncontrolling interest
 
79,500

 
57,843

 
21,657

 
37

Net income attributable to HollyFrontier stockholders
 
$
711,783

 
$
956,064

 
$
(244,281
)
 
(26
)%
Earnings per share attributable to HollyFrontier stockholders:
 
 
 
 
 
 
 
 
Basic
 
$
4.23

 
$
5.42

 
$
(1.19
)
 
(22
)%
Diluted
 
$
4.20

 
$
5.37

 
$
(1.17
)
 
(22
)%
Cash dividends declared per common share
 
$
0.99

 
$
0.99

 
$

 
 %
Average number of common shares outstanding:
 
 
 
 
 
 
 
 
Basic
 
167,935

 
175,865

 
(7,930
)
 
(5
)%
Diluted
 
169,125

 
177,557

 
(8,432
)
 
(5
)%

Balance Sheet Data
 
 
September 30, 2019
 
December 31, 2018
 
 
(Unaudited)
 
 
 
 
(In thousands)
Cash and cash equivalents
 
$
981,856

 
$
1,154,752

Working capital
 
$
1,827,420

 
$
2,128,224

Total assets
 
$
12,191,328

 
$
10,994,601

Long-term debt
 
$
2,425,234

 
$
2,411,540

Total equity
 
$
6,541,363

 
$
6,459,059



41

Table of Content

Other Financial Data 
 
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
 
2019
 
2018
 
2019
 
2018
 
 
(In thousands)
Net cash provided by operating activities
 
$
441,854

 
$
401,752

 
$
1,411,404

 
$
1,129,897

Net cash used for investing activities
 
$
(74,455
)
 
$
(113,089
)
 
$
(856,764
)
 
$
(259,167
)
Net cash used for financing activities
 
$
(299,473
)
 
$
(193,701
)
 
$
(729,337
)
 
$
(423,416
)
Capital expenditures
 
$
74,588

 
$
69,937

 
$
195,057

 
$
209,078

EBITDA (1)
 
$
521,713

 
$
594,872

 
$
1,456,801

 
$
1,685,197


(1)
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. 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.

Segment Operating Data

Our operations are organized into three reportable segments, Refining, Lubricants and Specialty Products and HEP. See Note 17 “Segment Information” in the Notes to Consolidated Financial Statements for additional information on our reportable segments.

Refining Segment Operating Data

Our refinery operations include the El Dorado, Tulsa, Navajo, Cheyenne and Woods Cross Refineries. The following tables set forth information, including non-GAAP performance measures, about our consolidated refinery operations. The cost of products and refinery gross and net operating margins do not include the non-cash effects of lower of cost or market inventory valuation adjustments and 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 September 30,
 
Nine Months Ended September 30,
 
 
2019
 
2018
 
2019
 
2018
Mid-Continent Region (El Dorado and Tulsa Refineries)
 
 
 
 
 
 
 
 
Crude charge (BPD) (1)
 
294,380

 
262,550

 
257,590

 
260,150

Refinery throughput (BPD) (2)
 
307,720

 
276,560

 
272,440

 
274,330

Sales of produced refined products (BPD) (3)
 
290,930

 
255,840

 
260,780

 
259,890

Refinery utilization (4)
 
113.2
%
 
101.0
%
 
99.1
%
 
100.1
%
 
 
 
 
 
 
 
 
 
Average per produced barrel (5)
 
 
 
 
 
 
 
 
Refinery gross margin
 
$
14.61

 
$
16.43

 
$
14.55

 
$
12.99

Refinery operating expenses (6)
 
5.05

 
5.48

 
5.48

 
5.18

Net operating margin
 
$
9.56

 
$
10.95

 
$
9.07

 
$
7.81

 
 
 
 
 
 
 
 
 
Refinery operating expenses per throughput barrel (7)
 
$
4.77

 
$
5.07

 
$
5.25

 
$
4.90

 
 
 
 
 
 
 
 
 
Feedstocks:
 
 
 
 
 
 
 
 
Sweet crude oil
 
59
%
 
59
%
 
56
%
 
54
%
Sour crude oil
 
21
%
 
21
%
 
23
%
 
24
%
Heavy sour crude oil
 
16
%
 
15
%
 
16
%
 
17
%
Other feedstocks and blends
 
4
%
 
5
%
 
5
%
 
5
%
Total
 
100
%
 
100
%
 
100
%
 
100
%

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Table of Content

 
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
 
2019
 
2018
 
2019
 
2018
Mid-Continent Region (El Dorado and Tulsa Refineries)
 
 
 
 
 
 
 
 
Sales of produced refined products:
 
 
 
 
 
 
 
 
Gasolines
 
49
%
 
49
%
 
51
%
 
51
%
Diesel fuels
 
34
%
 
34
%
 
32
%
 
33
%
Jet fuels
 
6
%
 
6
%
 
7
%
 
6
%
Fuel oil
 
1
%
 
1
%
 
1
%
 
1
%
Asphalt
 
4
%
 
4
%
 
3
%
 
3
%
Base oils
 
4
%
 
4
%
 
4
%
 
4
%
LPG and other
 
2
%
 
2
%
 
2
%
 
2
%
Total
 
100
%
 
100
%
 
100
%
 
100
%
Southwest Region (Navajo Refinery)
 
 
 
 
 
 
 
 
Crude charge (BPD) (1)
 
106,860

 
109,560

 
107,330

 
109,200

Refinery throughput (BPD) (2)
 
117,250

 
117,880

 
117,660

 
118,300

Sales of produced refined products (BPD) (3)
 
116,890

 
122,210

 
120,760

 
120,900

Refinery utilization (4)
 
106.9
%
 
109.6
%
 
107.3
%
 
109.2
%
 
 
 
 
 
 
 
 
 
Average per produced barrel (5)
 
 
 
 
 
 
 
 
Refinery gross margin
 
$
18.61

 
$
22.60

 
$
19.35

 
$
17.84

Refinery operating expenses (6)
 
5.25

 
4.53

 
4.90

 
4.63

Net operating margin
 
$
13.36

 
$
18.07

 
$
14.45

 
$
13.21

 
 
 
 
 
 
 
 
 
Refinery operating expenses per throughput barrel (7)
 
$
5.23

 
$
4.69

 
$
5.03

 
$
4.73

 
 
 
 
 
 
 
 
 
Feedstocks:
 
 
 
 
 
 
 
 
Sweet crude oil
 
22
%
 
28
%
 
21
%
 
31
%
Sour crude oil
 
69
%
 
65
%
 
70
%
 
61
%
Other feedstocks and blends
 
9
%
 
7
%
 
9
%
 
8
%
Total
 
100
%
 
100
%
 
100
%
 
100
%
 
 
 
 
 
 
 
 
 
Sales of produced refined products:
 
 
 
 
 
 
 
 
Gasolines
 
50
%
 
49
%
 
51
%
 
50
%
Diesel fuels
 
40
%
 
41
%
 
39
%
 
40
%
Fuel oil
 
3
%
 
3
%
 
3
%
 
3
%
Asphalt
 
5
%
 
5
%
 
5
%
 
4
%
LPG and other
 
2
%
 
2
%
 
2
%
 
3
%
Total
 
100
%
 
100
%
 
100
%
 
100
%
Rocky Mountain Region (Cheyenne and Woods Cross Refineries)
 
 
 
 
 
 
 
 
Crude charge (BPD) (1)
 
74,790

 
69,880

 
78,530

 
71,000

Refinery throughput (BPD) (2)
 
81,830

 
76,120

 
85,300

 
78,410

Sales of produced refined products (BPD) (3)
 
77,680

 
69,720

 
77,890

 
74,850

Refinery utilization (4)
 
77.1
%
 
72.0
%
 
81.0
%
 
73.2
%
 
 
 
 
 
 
 
 
 
Average per produced barrel (6)
 
 
 
 
 
 
 
 
Refinery gross margin (8)
 
$
24.97

 
$
24.75

 
$
19.73

 
$
24.95

Refinery operating expenses (9)
 
11.95

 
12.80

 
11.39

 
11.97

Net operating margin (8)
 
$
13.02

 
$
11.95

 
$
8.34

 
$
12.98

 
 
 
 
 
 
 
 
 
Refinery operating expenses per throughput barrel (10)
 
$
11.34

 
$
11.72

 
$
10.40

 
$
11.42


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Table of Content

 
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
 
2019
 
2018
 
2019
 
2018
Rocky Mountain Region (Cheyenne and Woods Cross Refineries)
 
 
 
 
 
 
 
 
Feedstocks:
 
 
 
 
 
 
 
 
Sweet crude oil
 
38
%
 
24
%
 
36
%
 
25
%
Heavy sour crude oil
 
30
%
 
44
%
 
33
%
 
44
%
Black wax crude oil
 
23
%
 
24
%
 
23
%
 
22
%
Other feedstocks and blends
 
9
%
 
8
%
 
8
%
 
9
%
Total
 
100
%
 
100
%
 
100
%
 
100
%
 
 
 
 
 
 
 
 
 
Sales of produced refined products:
 
 
 
 
 
 
 
 
Gasolines
 
54
%
 
54
%
 
53
%
 
56
%
Diesel fuels
 
32
%
 
34
%
 
34
%
 
33
%
Fuel oil
 
4
%
 
2
%
 
4
%
 
3
%
Asphalt
 
5
%
 
7
%
 
5
%
 
5
%
LPG and other
 
5
%
 
3
%
 
4
%
 
3
%
Total
 
100
%
 
100
%
 
100
%
 
100
%
Consolidated
 
 
 
 
 
 
 
 
Crude charge (BPD) (1)
 
476,030

 
441,990

 
443,450

 
440,350

Refinery throughput (BPD) (2)
 
506,800

 
470,560

 
475,400

 
471,040

Sales of produced refined products (BPD) (3)
 
485,500

 
447,770

 
459,440

 
455,640

Refinery utilization (4)
 
104.2
%
 
96.7
%
 
97.0
%
 
96.4
%
 
 
 
 
 
 
 
 
 
Average per produced barrel (5)
 
 
 
 
 
 
 
 
Refinery gross margin
 
$
17.23

 
$
19.41

 
$
16.69

 
$
16.25

Refinery operating expenses (6)
 
6.20

 
6.36

 
6.33

 
6.15

Net operating margin
 
$
11.03

 
$
13.05

 
$
10.36

 
$
10.10

 
 
 
 
 
 
 
 
 
Refinery operating expenses per throughput barrel (7)
 
$
5.94

 
$
6.05

 
$
6.12

 
$
5.94

 
 
 
 
 
 
 
 
 
Feedstocks:
 
 
 
 
 
 
 
 
Sweet crude oil
 
47
%
 
45
%
 
44
%
 
43
%
Sour crude oil
 
29
%
 
29
%
 
30
%
 
30
%
Heavy sour crude oil
 
14
%
 
16
%
 
15
%
 
17
%
Black wax crude oil
 
4
%
 
4
%
 
4
%
 
4
%
Other feedstocks and blends
 
6
%
 
6
%
 
7
%
 
6
%
Total
 
100
%
 
100
%
 
100
%
 
100
%
Sales of produced refined products:
 
 
 
 
 
 
 
 
Gasolines
 
50
%
 
50
%
 
51
%
 
52
%
Diesel fuels
 
35
%
 
36
%
 
35
%
 
35
%
Jet fuels
 
4
%
 
3
%
 
4
%
 
3
%
Fuel oil
 
2
%
 
2
%
 
2
%
 
2
%
Asphalt
 
4
%
 
5
%
 
4
%
 
4
%
Base oils
 
2
%
 
2
%
 
2
%
 
2
%
LPG and other
 
3
%
 
2
%
 
2
%
 
2
%
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)
Represents barrels sold of refined products produced at our refineries (including HFC Asphalt) and does not include volumes
of refined products purchased for resale or volumes of excess crude oil sold.
(4)
Represents crude charge divided by total crude capacity (BPSD). Our consolidated crude capacity is 457,000 BPSD.
(5)
Represents average amount per produced barrel 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.

44

Table of Content

(6)
Represents total refining segment operating expenses, exclusive of depreciation and amortization, divided by sales volumes
of refined products produced at our refineries.
(7)
Represents total refining segment operating expenses, exclusive of depreciation and amortization, divided by refinery throughput.

Lubricants and Specialty Products Operating Data

The following table sets forth information about our lubricants and specialty products operations.
 
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
 
2019
 
2018
 
2019
 
2018
Lubricants and Specialty Products
 
 
 
 
 
 
 
 
Throughput (BPD)
 
23,190

 
21,410

 
19,920

 
20,530

Sales of produced refined products (BPD)
 
36,160

 
31,970

 
34,740

 
21,340

 
 
 
 
 
 
 
 
 
Sales of produced refined products:
 
 
 
 
 
 
 
 
Finished products
 
50
%
 
49
%
 
50
%
 
48
%
Base oils
 
24
%
 
28
%
 
27
%
 
31
%
Other
 
26
%
 
23
%
 
23
%
 
21
%
Total
 
100
%
 
100
%
 
100
%
 
100
%

Supplemental financial data attributable to our Lubricants and Specialty Products segment is presented below.
 
 
Rack Back (1)
 
Rack Forward (2)
 
Eliminations (3)
 
Total Lubricants and Specialty Products
 
 
(In thousands)
Three months ended September 30, 2019
 
 
 
 
 
 
 
 
Sales and other revenues
 
$
196,355

 
$
477,261

 
$
(135,898
)
 
$
537,718

Cost of products sold
 
$
175,976

 
$
357,848

 
$
(135,898
)
 
$
397,926

Operating expenses
 
$
27,825

 
$
30,149

 
$

 
$
57,974

Selling, general and administrative expenses
 
$
5,862

 
$
38,013

 
$

 
$
43,875

Depreciation and amortization
 
$
11,390

 
$
11,310

 
$

 
$
22,700

Income (loss) from operations
 
$
(24,698
)
 
$
39,941

 
$

 
$
15,243

 
 
 
 
 
 
 
 
 
Three months ended September 30, 2018
 
 
 
 
 
 
 
 
Sales and other revenues
 
$
197,226

 
$
424,386

 
$
(145,726
)
 
$
475,886

Cost of products sold
 
$
177,748

 
$
327,720

 
$
(145,726
)
 
$
359,742

Operating expenses
 
$
26,748

 
$
13,540

 
$

 
$
40,288

Selling, general and administrative expenses
 
$
7,439

 
$
26,075

 
$

 
$
33,514

Depreciation and amortization
 
$
6,345

 
$
4,794

 
$

 
$
11,139

Income (loss) from operations
 
$
(21,054
)
 
$
52,257

 
$

 
$
31,203


45

Table of Content

 
 
Rack Back (1)
 
Rack Forward (2)
 
Eliminations (3)
 
Total Lubricants and Specialty Products
 
 
(In thousands)
Nine months ended September 30, 2019
 
 
 
 
 
 
 
 
Sales and other revenues
 
$
486,035

 
$
1,428,786

 
$
(338,423
)
 
$
1,576,398

Cost of products sold
 
$
453,519

 
$
1,087,200

 
$
(338,423
)
 
$
1,202,296

Operating expenses
 
$
87,970

 
$
82,685

 
$

 
$
170,655

Selling, general and administrative expenses
 
$
25,707

 
$
99,974

 
$

 
$
125,681

Depreciation and amortization
 
$
32,991

 
$
32,900

 
$

 
$
65,891

Goodwill impairment (4)
 
$
152,712

 
$

 
$

 
$
152,712

Income (loss) from operations
 
$
(266,864
)
 
$
126,027

 
$

 
$
(140,837
)
 
 
 
 
 
 
 
 
 
Nine months ended September 30, 2018
 
 
 
 
 
 
 
 
Sales and other revenues
 
$
546,300

 
$
1,248,886

 
$
(406,771
)
 
$
1,388,415

Cost of products sold
 
$
482,842

 
$
964,343

 
$
(406,771
)
 
$
1,040,414

Operating expenses
 
$
82,729

 
$
42,372

 
$

 
$
125,101

Selling, general and administrative expenses
 
$
22,146

 
$
77,279

 
$

 
$
99,425

Depreciation and amortization
 
$
17,986

 
$
12,037

 
$

 
$
30,023

Income (loss) from operations
 
$
(59,403
)
 
$
152,855

 
$

 
$
93,452


(1) Rack back consists of our PCLI base oil production activities, by-product sales to third parties and intra-segment base oil sales to rack forward.
(2) Rack forward activities include the purchase of base oils from rack back and the blending, packaging, marketing and distribution and sales of finished lubricants and specialty products to third parties.
(3) Intra-segment sales of rack back produced base oils to rack forward are eliminated under the “Eliminations” column.
(4) During the three months ended June 30, 2019, a goodwill impairment charge of $152.7 million was recorded in the PCLI reporting unit within the Lubricants and Specialty Products segment. We have separately allocated this charge for purposes of management’s discussion and analysis presentation of Rack Back and Rack Forward results entirely to Rack Back.


Results of Operations – Three Months Ended September 30, 2019 Compared to Three Months Ended September 30, 2018

Summary
Net income attributable to HollyFrontier stockholders for the three months ended September 30, 2019 was $261.8 million ($1.60 per basic and $1.58 per diluted share), a $80.7 million decrease compared to net income of $342.5 million ($1.95 per basic and $1.93 per diluted share) for the three months ended September 30, 2018. Net income decreased due principally to lower gross refining margins offset by higher refining segment sales volumes. For the three months ended September 30, 2019, lower of cost or market inventory reserve adjustments decreased pre-tax earnings by $34.1 million compared to a decrease of $17.8 million for the three months ended September 30, 2018. Refinery gross margins for the three months ended September 30, 2019 decreased to $17.23 per barrel sold from $19.41 for the three months ended September 30, 2018. During the three months ended September 30, 2019, our Cheyenne Refinery and Woods Cross Refinery were each granted a one-year small refinery exemption from the EPA for the 2018 calendar year, at which time we recorded a total $36.6 million reduction to cost of products sold.

Sales and Other Revenues
Sales and other revenues decreased 7% from $4,770.8 million for the three months ended September 30, 2018 to $4,424.8 million for the three months ended September 30, 2019 due to a year-over-year decrease in third quarter sales prices offset by higher refined product sales volumes. Sales and other revenues for the three months ended September 30, 2019 and 2018 included $29.9 million and $25.6 million, respectively, in HEP revenues attributable to pipeline and transportation services provided to unaffiliated parties. Additionally, sales and other revenues included $529.6 million and $474.3 million in unaffiliated revenues related to our Lubricants and Specialty Products segment for the three months ended September 30, 2019 and 2018, respectively. Sonneborn contributed $88.1 million in sales and other revenues for the three months ended September 30, 2019.


46

Table of Content

Cost of Products Sold
Total cost of products sold decreased 9% from $3,770.1 million for the three months ended September 30, 2018 to $3,437.8 million for the three months ended September 30, 2019, due principally to lower crude oil costs, partially offset by higher refined product sales volumes. Additionally during the third quarter of 2019, we recognized a lower of cost or market inventory valuation charge of $34.1 million compared to $17.8 million for the same period of 2018, resulting in a new $209.7 million inventory reserve at September 30, 2019. The reserve at September 30, 2019 is based on market conditions and prices at that time. Current period cost of products sold includes $48.4 million in costs attributable to our Sonneborn operations. During the third quarter of 2019, we recorded a $36.6 million RINs cost reduction as a result of our Cheyenne Refinery and Woods Cross Refinery small refinery exemptions.

Gross Refinery Margins
Gross refinery margin per barrel sold decreased 11% from $19.41 for the three months ended September 30, 2018 to $17.23 for the three months ended September 30, 2019. This was due to the effects of a decrease in the average per barrel sold sales price during the current year quarter, partially offset by decreased crude oil and feedstock prices. Gross refinery margin does not include the non-cash effects of lower of cost or market inventory valuation adjustments or depreciation and amortization. See “Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles” following Item 3 of Part I of this Form 10-Q for a reconciliation to the income statement of sale prices of products sold and cost of products purchased.

Operating Expenses
Operating expenses, exclusive of depreciation and amortization, increased 9% from $317.2 million for the three months ended September 30, 2018 to $345.6 million for the three months ended September 30, 2019 due principally to higher repair and maintenance costs. Current period operating expenses include $15.2 million in costs attributable to our Sonneborn operations.

Selling, General and Administrative Expenses
Selling, general and administrative expenses increased 23% from $71.1 million for the three months ended September 30, 2018 to $87.6 million for the three months ended September 30, 2019 due principally to higher legal and professional fees and salary costs. Current period selling, general and administrative expenses include $7.9 million in costs attributable to our Sonneborn operations. Additionally, direct integration and regulatory costs of our recently acquired Sonneborn operations were $3.9 million for the three months ended September 30, 2019.

Depreciation and Amortization Expenses
Depreciation and amortization increased 17% from $108.9 million for the three months ended September 30, 2018 to $127.0 million for the three months ended September 30, 2019. This increase was due principally to depreciation and amortization attributable to capitalized improvement projects and capitalized refinery turnaround costs. Current period depreciation and amortization expenses include $9.1 million in costs attributable to our Sonneborn operations.

Interest Income
Interest income for the three months ended September 30, 2019 was $6.2 million compared to $5.1 million for the three months ended September 30, 2018. This increase was due to higher average cash balances on hand during the current year quarter.

Interest Expense
Interest expense was $36.0 million for the three months ended September 30, 2019 compared to $32.4 million for the three months ended September 30, 2018. This increase was due to interest attributable to higher HEP debt levels during the current year quarter relative to the same period of 2018. For the three months ended September 30, 2019 and 2018, interest expense included $18.8 million and $18.0 million, respectively, in interest costs attributable to HEP operations.

Gain on Foreign Currency Transactions
Remeasurement adjustments resulting from the conversion of the intercompany financing structure on our PCLI acquisition from local currencies to the U.S. dollar resulted in gains of $0.4 million and $0.3 million for the three months ended September 30, 2019 and 2018, respectively. For the three months ended September 30, 2019 and 2018, gain on foreign currency translation included a gain of $5.7 million and a loss of $7.1 million, respectively, on foreign exchange forward contracts (utilized as an economic hedge).

Income Taxes
For the three months ended September 30, 2019, we recorded income tax expense of $103.0 million compared to $116.3 million for the three months ended September 30, 2018. Our effective tax rates, before consideration of earnings attributable to the noncontrolling interest, were 25.7% and 24.3% for the three months ended September 30, 2019 and 2018, respectively.



47

Table of Content

Results of Operations – Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Summary
Net income attributable to HollyFrontier stockholders for the nine months ended September 30, 2019 was $711.8 million ($4.23 per basic and $4.20 per diluted share), a $244.3 million decrease compared to net income attributable to HollyFrontier stockholders of $956.1 million ($5.42 per basic and $5.37 per diluted share) for the nine months ended September 30, 2018. Net income decreased due principally to a goodwill impairment charge of $152.7 million, offset by an increase in gross refining margins and refining segment sales volumes. For the nine months ended September 30, 2019, lower of cost or market inventory reserve adjustments increased pre-tax earnings by $150.5 million compared to $192.9 million for the nine months ended September 30, 2018. Refinery gross margins for the nine months ended September 30, 2019 increased to $16.69 per produced barrel from $16.25 for the nine months ended September 30, 2018. During the nine months ended September 30, 2019, our Cheyenne Refinery and Woods Cross Refinery were each granted a one-year small refinery exemption from the EPA for the 2018 calendar year, at which time we recorded a total $36.6 million reduction to cost of products sold. During the nine months ended September 30, 2018, our Cheyenne Refinery was granted a one-year small refinery exemption from the EPA for the 2015 and 2017 calendar years and our Woods Cross Refinery was granted a one-year small refinery exemption for 2017. As a result of these exemptions, we recorded reductions totaling $97.0 million to our cost of products sold in 2018.

Sales and Other Revenues
Sales and other revenues decreased 2% from $13,370.5 million for the nine months ended September 30, 2018 to $13,104.7 million for the nine months ended September 30, 2019 due to a year-over-year decrease in sales prices, partially offset by higher refined product volumes. Sales and other revenues for the nine months ended September 30, 2019 and 2018 include $89.4 million and $77.8 million, respectively, in HEP revenues attributable to pipeline and transportation services provided to unaffiliated parties. Additionally, sales and other revenues included $1,568.2 million and $1,376.5 million in unaffiliated revenues related to our Lubricants and Specialty Products segment for the nine months ended September 30, 2019 and 2018, respectively. Sonneborn contributed $253.5 million in sales and other revenues for the nine months ended September 30, 2019.

Cost of Products Sold
Total cost of products sold decreased from $10,502.3 million for the nine months ended September 30, 2018 to $10,157.4 million for the nine months ended September 30, 2019, due principally to lower crude oil costs. Additionally, during the nine months ended September 30, 2019, we recognized a $150.5 million lower of cost or market inventory valuation benefit compared to $192.9 million for the same period of last year, resulting in a new $209.7 million inventory reserve at September 30, 2019. The reserve at September 30, 2019 is based on market conditions and prices at that time. Cost of products sold includes $163.7 million in costs attributable to our Sonneborn operations for the nine months ended September 30, 2019. During the nine months ended September 30, 2019, we recorded a $36.6 million RINs cost reduction as a result of our Cheyenne Refinery and Woods Cross Refinery small refinery exemptions. During the nine months ended September 30, 2018, we recorded a $97.0 million RINs cost reduction as a result of our Cheyenne Refinery and Woods Cross Refinery small refinery exemptions.

Gross Refinery Margins
Gross refinery margin per barrel sold increased 3% from $16.25 for the nine months ended September 30, 2018 to $16.69 for the nine months ended September 30, 2019. This was primarily due to the effects of decreased crude oil and feedstock prices during the current year-to-date period. Gross refinery margin does not include the non-cash effects of lower of cost or market inventory valuation adjustments or depreciation and amortization. See “Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles” following Item 3 of Part I of this Form 10-Q for a reconciliation to the income statement of sales prices of products sold and cost of products purchased.

Operating Expenses
Operating expenses, exclusive of depreciation and amortization, increased 8% from $933.7 million for the nine months ended September 30, 2018 to $1,010.4 million for the nine months ended September 30, 2019 due principally to higher repair and maintenance costs related to a February 2019 fire in an FCC unit at our El Dorado Refinery. Prior year period operating expenses included higher repair and maintenance costs as a result of the Woods Cross Refinery fire and resulting damage in March 2018. Current year operating expenses include $38.6 million in costs attributable to our Sonneborn operations.


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Selling, General and Administrative Expenses
Selling, general and administrative expenses increased 28% from $204.5 million for the nine months ended September 30, 2018 to $261.0 million for the nine months ended September 30, 2019 due principally to higher legal and professional fees and salary costs. Current year selling, general and administrative expenses include $21.0 million in costs attributable to our Sonneborn operations. Additionally, direct integration and regulatory costs of our recently acquired Sonneborn operations were $20.1 million for the nine months ended September 30, 2019. We incurred $3.6 million in integration costs of our PCLI business during the nine months ended September 30, 2018.

Depreciation and Amortization Expenses
Depreciation and amortization increased 16% from $323.6 million for the nine months ended September 30, 2018 to $375.3 million for the nine months ended September 30, 2019. This increase was due principally to depreciation and amortization attributable to capitalized improvement projects and capitalized refinery turnaround costs. Current year depreciation and amortization expenses include $24.4 million in costs attributable to our Sonneborn operations.

Goodwill Impairment
During the nine months ended September 30, 2019, we recorded goodwill impairment charges of $152.7 million that relate to PCLI. See Note 1 “Description of Business and Presentation of Financial Statements” in the Notes to Consolidated Financial Statements for additional information on the PCLI impairment.

Interest Income
Interest income for the nine months ended September 30, 2019 was $17.1 million compared to $10.7 million for the nine months ended September 30, 2018. This increase was due to higher average cash balances during the current year-to-date period.

Interest Expense
Interest expense was $106.9 million for the nine months ended September 30, 2019 compared to $97.4 million for the nine months ended September 30, 2018. This increase was due to interest attributable to higher HEP debt levels during the current year relative to the same period of 2018. For the nine months ended September 30, 2019 and 2018, interest expense included $57.1 million and $53.2 million, respectively, in interest costs attributable to HEP operations.

Gain on Foreign Currency Transactions
Remeasurement adjustments resulting from the conversion of the intercompany financing structure on our PCLI acquisition from local currencies to the U.S. dollar resulted in a $4.9 million gain for the nine months ended September 30, 2019, and a $5.5 million gain for the nine months ended September 30, 2018. For the nine months ended September 30, 2019 and 2018, gain on foreign currency translation included a loss of $9.0 million and a gain of $18.5 million, respectively, on foreign exchange forward contracts (utilized as an economic hedge).

Income Taxes
For the nine months ended September 30, 2019, we recorded income tax expense of $279.9 million compared to $318.7 million for the nine months ended September 30, 2018. Our effective tax rates, before consideration of earnings attributable to the noncontrolling interest, were 26.1% and 23.9% for the nine months ended September 30, 2019 and 2018, respectively. Our current year effective tax rate reflects the effects of the $152.7 million goodwill impairment charge that is not deductible for income tax purposes.


LIQUIDITY AND CAPITAL RESOURCES

HollyFrontier Credit Agreement
We have a $1.35 billion senior unsecured revolving credit facility maturing in February 2022 (the “HollyFrontier Credit Agreement”). The HollyFrontier Credit Agreement may be used for revolving credit loans and letters of credit from time to time and is available to fund general corporate purposes. At September 30, 2019, we were in compliance with all covenants, had no outstanding borrowings and had outstanding letters of credit totaling $4.9 million under the HollyFrontier Credit Agreement.

HollyFrontier Financing Arrangements
In December 2018, certain of our wholly-owned subsidiaries entered into financing arrangements whereby such subsidiaries sold a portion of their precious metals catalyst to a financial institution and then leased back the precious metals catalyst in exchange for total cash received of $32.5 million. The volume of the precious metals catalyst and the lease rate are fixed over the one-year term of each lease, and the lease payments are recorded as interest expense. At maturity, we must repurchase the precious metals catalyst at its then fair market value.


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HEP Credit Agreement
HEP has a $1.4 billion senior secured revolving credit facility maturing in July 2022 (the “HEP Credit Agreement”) and is available to fund capital expenditures, investments, acquisitions, distribution payments, working capital and for general partnership purposes. It is also available to fund letters of credit up to a $50 million sub-limit and has a $300 million accordion. During the nine months ended September 30, 2019, HEP received advances totaling $269.5 million and repaid $257.0 million under the HEP Credit Agreement. At September 30, 2019, HEP was in compliance with all of its covenants, had outstanding borrowings of $935.5 million and no outstanding letters of credit under the HEP Credit Agreement.

See Note 11 “Debt” in the Notes to Consolidated Financial Statements for additional information on our debt instruments.

HEP Common Unit Continuous Offering Program
In May 2016, HEP established a continuous offering program under which HEP may issue and sell common units from time to time, representing limited partner interests, up to an aggregate gross sales amount of $200 million. During the nine months ended September 30, 2019, HEP did not issue any common units under this program. As of September 30, 2019, HEP has issued 2,413,153 units under this program, providing $82.3 million in gross proceeds.

HEP intends to use the net proceeds for general partnership purposes, which may include funding working capital, repayment of debt, acquisitions and capital expenditures. Amounts repaid under HEP’s credit facility may be reborrowed from time to time.

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 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. We also expect to use cash for repurchases of our common stock under our share repurchase program, support of our master limited partnership and the payment of cash dividends.

As of September 30, 2019, our cash and cash equivalents totaled $981.9 million. 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.

In September 2018, our Board of Directors approved a $1 billion share repurchase program, which replaced all existing share repurchase programs, authorizing 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 and corporate, regulatory and other relevant considerations. This program may be discontinued at any time by the Board of Directors. As of September 30, 2019, we had remaining authorization to repurchase up to $313.2 million under this stock repurchase program. In addition, we are authorized by our Board of Directors to repurchase shares in an amount sufficient to offset shares issued under our compensation programs.

Cash and cash equivalents decreased $172.9 million for the nine months ended September 30, 2019. Net cash used for investing and financing activities of $856.8 million, and $729.3 million, respectively, exceeded net cash provided by operating activities of $1,411.4 million.
 
Cash Flows – Operating Activities

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018
Net cash flows provided by operating activities were $1,411.4 million for the nine months ended September 30, 2019 compared to $1,129.9 million for the nine months ended September 30, 2018, an increase of $281.5 million. Net income for the nine months ended September 30, 2019 was $791.3 million, a decrease of $222.6 million compared to $1,013.9 million for the nine months ended September 30, 2018. Non-cash adjustments to net income consisting of depreciation and amortization, goodwill impairment, lower of cost or market inventory valuation adjustment, earnings of equity method investments, inclusive of distributions, gain / loss on sale of assets, deferred income taxes, equity-based compensation expense and fair value changes to derivative instruments totaled $531.5 million for the nine months ended September 30, 2019 compared to $256.4 million for the same period in 2018. Adjusted for non-cash items, changes in working capital increased operating cash flows by $244.3 million and decreased operating cash flows by $33.5 million, for the nine months ended September 30, 2019 and 2018, respectively. Additionally, for the nine months ended September 30, 2019, turnaround expenditures increased to $152.4 million from $114.6 million from the same period of 2018.


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Cash Flows – Investing Activities and Planned Capital Expenditures

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018
Net cash flows used for investing activities were $856.8 million for the nine months ended September 30, 2019 compared to $259.2 million for the nine months ended September 30, 2018, an increase of $597.6 million. Current year investing activities reflect a net cash outflow of $662.7 million upon the acquisition of Sonneborn, and prior year investing activities reflect a net cash outflow of $54.1 million upon the acquisition of Red Giant Oil. Cash expenditures for properties, plants and equipment for the first nine months of 2019 decreased to $195.1 million from $209.1 million for the same period in 2018. These include HEP capital expenditures of $23.8 million and $41.1 million for the nine months ended September 30, 2019 and 2018, respectively.

Planned Capital Expenditures

HollyFrontier Corporation
Each year our Board of Directors approves our annual capital budget, which includes specific projects that 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. During 2019, we expect to spend approximately $600.0 million to $640.0 million in cash for capital projects and refinery turnarounds appropriated in 2019 and prior years. Refinery turnaround spending is amortized over the useful life of the turnaround. Our expected capital and turnaround cash spending for 2019 is as follows:

        
 
Expected Cash Spending Range
 
(In millions)
Type:
 
 
 
Capital
$
300.0

-
$
320.0

Turnarounds
300.0

-
320.0

Total
$
600.0

-
$
640.0


The refining industry is capital intensive and requires on-going investments to sustain our refining operations. This includes replacement of, or rebuilding, refinery units and components that extend the useful life. We also invest in projects that improve operational reliability and profitability via enhancements that improve refinery processing capabilities as well as production yield and flexibility. Our capital expenditures also include projects related to environmental, health and safety compliance and include initiatives as a result of federal and state mandates.

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.

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 in excess of a year, 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 2019 HEP capital budget is comprised of $7.0 million to $8.0 million for maintenance capital expenditures and $35.0 million expansion capital expenditures. HEP expects the majority of the expansion capital budget to be invested in refined product pipeline expansions, crude system enhancements, new storage tanks and enhanced blending capabilities at its racks. In addition, HEP may spend funds periodically to perform capital upgrades or additions to its assets where a customer reimburses HEP for such costs. The upgrades or additions would generally benefit the customer over the remaining live of the related service agreements.


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Cash Flows – Financing Activities

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018
Net cash flows used for financing activities were $729.3 million for the nine months ended September 30, 2019 compared to $423.4 million for the nine months ended September 30, 2018, an increase of $305.9 million. During the nine months ended September 30, 2019, we purchased $472.0 million of treasury stock and paid $168.0 million in dividends. Also during this period, HEP received $269.5 million and repaid $257.0 million under the HEP Credit Agreement and paid distributions of $100.1 million to noncontrolling interests. During the nine months ended September 30, 2018, we purchased $177.7 million of treasury stock and paid $175.9 million in dividends. Also during this period, HEP received $256.0 million and repaid $347.0 million under the HEP Credit Agreement, received $114.9 million in proceeds from the issuance of its common units and paid distributions of $93.1 million to noncontrolling interests.

Contractual Obligations and Commitments

HollyFrontier Corporation

There were no significant changes to our long-term contractual obligations during the nine months ended September 30, 2019.

HEP

During the nine months ended September 30, 2019, HEP had net borrowings of $12.5 million resulting in $935.5 million of outstanding borrowings under the HEP Credit Agreement at September 30, 2019. 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, 2018. Certain critical accounting policies that materially affect the amounts recorded in our consolidated financial statements include the use of the last-in, first-out (“LIFO”) method of valuing certain inventories, assessing the possible impairment of certain long-lived assets and goodwill, and assessing contingent liabilities for probable losses.

Inventory Valuation: Inventories related to our refining operations are stated at the lower of cost, using the LIFO method for crude oil and unfinished and finished refined products, or market. In periods of rapidly declining prices, LIFO inventories may have to be written down to market value due to the higher costs assigned to LIFO layers in prior periods. In addition, the use of the LIFO inventory method may result in increases or decreases to cost of sales in years that inventory volumes decline as the result of charging cost of sales with LIFO inventory costs generated in prior periods. An actual valuation of inventory under the LIFO method is 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.

At September 30, 2019, our lower of cost or market inventory valuation reserve was $209.7 million. This amount, or a portion thereof, is subject to reversal as a reduction to cost of products sold in subsequent periods as inventories giving rise to the reserve are sold, and a new reserve is established.

Inventories consisting of process chemicals, materials and maintenance supplies and RINs are stated at the lower of weighted-average cost or net realizable value. Inventories of our Petro-Canada Lubricants and Sonneborn businesses are stated at the lower of cost, using the FIFO method, or net realizable value.


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Goodwill and Long-lived Assets: As of September 30, 2019, our goodwill balance was $2.4 billion, with goodwill assigned to our Refining, Lubricants and Specialty Products and HEP segments of $1,733.5 million, $324.1 million and $312.9 million, respectively. 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 an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying amount. Our goodwill impairment testing first entails either a quantitative assessment or an optional qualitative assessment to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If we determine that based on the qualitative factors that it is more likely than not that the fair value of the reporting unit is greater than its carrying amount, a quantitative test is performed in which we estimate the fair value of the related reporting unit. If the carrying amount of a reporting unit exceeds its fair value, the goodwill of that reporting unit is impaired, and we measure goodwill impairment as the excess of the carrying amount of reporting unit over the related fair value.

Our long-lived assets principally consist of our refining assets that are organized as refining asset groups and the assets of our Lubricants and Specialty Products business. The refinery asset groups also constitute our individual refinery reporting units that are used for testing and measuring goodwill impairments. Our long-lived assets are evaluated for impairment by identifying whether indicators of impairment exist and if so, assessing whether the long-lived assets are recoverable from estimated future undiscounted cash flows. The actual amount of impairment loss measured, if any, is equal to the amount by which the asset group’s carrying value exceeds its fair value.

Goodwill impairment
During the second quarter of 2019, we performed interim goodwill impairment testing of the PCLI reporting unit included in our Lubricants and Specialty Products segment. We elected to perform this interim assessment due to the recent reorganization of our reporting unit structure within the Lubricants and Specialty Products segment, combined with the identification of events and circumstances which were indicators of potential goodwill impairment at PCLI, including recent declines in gross margins to lower than historic levels. These recent lower gross margins are in the base oil market which is largely attributed to the increase in global supply of base oils with a current outlook for continued near-term softness.

Our interim goodwill impairment testing was performed as of May 31, 2019. The estimated fair values of our goodwill reporting units within our Lubricants and Specialty Products segment were derived using a combination of both income and market approaches. The income approach reflects expected future cash flows based on estimated future production volumes, selling prices, gross margins, operating costs and capital expenditures. Our market approach includes both the guideline public company and guideline transaction methods. Both methods utilize pricing multiples derived from historical market transactions of other like-kind assets.

As a result of our impairment testing, we determined that the carrying value of the PCLI reporting unit’s goodwill within our Lubricants and Specialty Products segment was fully impaired and a goodwill impairment charge of $152.7 million was recorded. Our testing did not identify any other impairments.

We performed our annual goodwill impairment testing as of July 1, 2019 and determined there was no additional impairment of goodwill attributable to our reporting units.

Contingencies
We are subject to proceedings, lawsuits and other claims related to environmental, labor, product and other matters. We are required to assess the likelihood of any adverse judgments or outcomes to these matters as well as potential ranges of probable losses. A determination of the amount of reserves required, if any, for these contingencies is made after careful analysis of each individual issue. The required reserves may change in the future due to new developments in each matter or changes in approach such as a change in settlement strategy in dealing with these matters.


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.


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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, forward purchase and sales and futures contracts to mitigate price exposure with respect to our inventory positions, natural gas purchases, sales prices of refined products and crude oil costs.

Foreign Currency Risk Management
We are exposed to market risk related to the volatility in foreign currency exchange rates. We periodically enter into derivative contracts in the form of foreign exchange forward and foreign exchange swap contracts to mitigate the exposure associated with fluctuations on intercompany notes with our foreign subsidiaries that are not denominated in the U.S. dollar.

As of September 30, 2019, we have the following notional contract volumes related to all outstanding derivative instruments used to mitigate commodity price and foreign currency risk:
 
 
 
 
Notional Contract Volumes by Year of Maturity
 
 
Derivative Instrument
 
Total Outstanding Notional
 
2019
 
2020
 
2021
 
Unit of Measure
 
 
 
 
 
 
 
 
 
 
 
Natural gas price swaps - long
 
4,050,000

 
450,000

 
1,800,000

 
1,800,000

 
MMBTU
Crude oil price swaps (basis spread) - long
 
7,418,000

 
1,196,000

 
6,222,000

 

 
Barrels
WTI and gasoline crack spread swaps - short
 
200,000

 
200,000

 

 

 
Barrels
NYMEX futures (WTI) - short
 
1,825,000

 
1,713,000

 
112,000

 

 
Barrels
Forward gasoline and diesel contracts - long
 
538,500

 
538,500

 

 

 
Barrels
Forward crude oil contracts -short
 
423,739

 
423,739

 

 

 
Barrels
Forward crude oil contracts - long
 
140,849

 
140,849

 

 

 
Barrels
Physical contracts - long
 
350,000

 
350,000

 

 

 
Barrels
Physical contracts - short
 
350,000

 
350,000

 

 

 
Barrels
Foreign currency forward contracts
 
434,443,896

 
114,213,501

 
320,230,395

 

 
U.S. dollar
Forward commodity contracts (platinum) (1)
 
41,147

 
41,147

 

 

 
Troy ounces

(1) Represents an embedded derivative within our catalyst financing arrangements, which may be refinanced or require repayment under certain conditions. See Note 11 “Debt” in the Notes to Consolidated Financial Statements for additional information on these financing arrangements.

The following sensitivity analysis provides the hypothetical effects of market price fluctuations to the commodity positions hedged under our derivative contracts:
 
 
Estimated Change in Fair Value at June 30,
Commodity-based Derivative Contracts
 
2019
 
2018
 
 
(In thousands)
Hypothetical 10% change in underlying commodity prices
 
$
8,432

 
$
14,837


Interest Rate Risk Management
The market risk inherent in our fixed-rate debt 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 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 this debt as of September 30, 2019 is presented below:
 
 
Outstanding
Principal
 
Estimated
Fair Value
 
Estimated
Change in
Fair Value
 
 
(In thousands)
HollyFrontier Senior Notes
 
$
1,000,000

 
$
1,121,460

 
$
23,042

HEP Senior Notes
 
$
500,000

 
$
523,220

 
$
10,800



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For the variable rate HEP Credit Agreement, changes in interest rates would affect cash flows, but not the fair value. At September 30, 2019, outstanding borrowings under the HEP Credit Agreement were $935.5 million. A hypothetical 10% change in interest rates applicable to the HEP Credit Agreement would not materially affect cash flows.

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.

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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 September 30,
 
Nine Months Ended September 30,
 
 
2019
 
2018
 
2019
 
2018
 
 
(In thousands)
Net income attributable to HollyFrontier stockholders
 
$
261,813

 
$
342,466

 
$
711,783

 
$
956,064

Add income tax expense
 
103,021

 
116,258

 
279,862

 
318,742

Add interest expense
 
36,027

 
32,399

 
106,938

 
97,446

Subtract interest income
 
(6,164
)
 
(5,136
)
 
(17,127
)
 
(10,660
)
Add depreciation and amortization
 
127,016

 
108,885

 
375,345

 
323,605

EBITDA
 
$
521,713

 
$
594,872

 
$
1,456,801

 
$
1,685,197


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 produced barrel sold is total refining segment revenues less total refining segment cost of products sold, exclusive of lower of cost or market inventory valuation adjustments, divided by sales volumes of produced refined products sold. Net operating margin per barrel sold is the difference between refinery gross margin and refinery operating expenses per produced barrel sold. These two margins do not include the non-cash effects of lower of cost or market inventory valuation adjustments or 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.

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


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Reconciliation of average refining segment net operating margin per produced barrel sold to refinery gross margin to total sales
and other revenues

 
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
 
2019
 
2018
 
2019
 
2018
 
 
(Dollars in thousands, except per barrel amounts)
Consolidated
 
 
 
 
 
 
 
 
Net operating margin per produced barrel sold
 
$
11.03

 
$
13.05

 
$
10.36

 
$
10.10

Add average refinery operating expenses per produced barrel sold
 
6.20

 
6.36

 
6.33

 
6.15

Refinery gross margin per produced barrel sold
 
17.23

 
19.41


16.69

 
16.25

Times produced barrels sold (BPD)
 
485,500

 
447,770

 
459,440

 
455,640

Times number of days in period
 
92

 
92

 
273

 
273

Refining segment gross margin
 
769,595

 
799,592


2,093,379

 
2,021,333

Add (subtract) rounding
 
208

 
(16
)
 
(278
)
 
(507
)
Total refining segment gross margin
 
769,803

 
799,576


2,093,101

 
2,020,826

Add refining segment cost of products sold
 
3,177,167

 
3,572,593

 
9,598,539

 
10,179,509

Refining segment sales and other revenues
 
3,946,970

 
4,372,169

 
11,691,640

 
12,200,335

Add lubricants and specialty products segment sales and other revenues
 
537,718

 
475,886

 
1,576,398

 
1,388,415

Add HEP segment sales and other revenues
 
135,895

 
125,784

 
401,143

 
373,428

Subtract corporate, other and eliminations
 
(195,755
)
 
(203,040
)
 
(564,491
)
 
(591,716
)
Sales and other revenues
 
$
4,424,828

 
$
4,770,799

 
$
13,104,690

 
$
13,370,462



Reconciliation of average refining segment operating expenses per produced barrel sold to total operating expenses

 
 
Three Months Ended September 30,
 
Nine Months Ended September 30,
 
 
2019
 
2018
 
2019
 
2018
 
 
(Dollars in thousands, except per barrel amounts)
Consolidated
 
 
 
 
 
 
 
 
Average refinery operating expenses per produced barrel sold
 
$
6.20

 
$
6.36

 
$
6.33

 
$
6.15

Times produced barrels sold (BPD)
 
485,500

 
447,770

 
459,440

 
455,640

Times number of days in period
 
92

 
92

 
273

 
273

Refinery operating expenses
 
276,929

 
261,999

 
793,954

 
764,997

Add (subtract) rounding
 
(60
)
 
11

 
127

 
(582
)
Total refining segment operating expenses
 
276,869

 
262,010

 
794,081

 
764,415

Add lubricants and specialty products segment operating expenses
 
57,974

 
40,288

 
170,655

 
125,101

Add HEP segment operating expenses
 
44,924

 
35,995

 
123,045

 
106,731

Subtract corporate, other and eliminations
 
(34,189
)
 
(21,097
)
 
(77,359
)
 
(62,548
)
Operating expenses (exclusive of depreciation and amortization)
 
$
345,578

 
$
317,196

 
$
1,010,422

 
$
933,699




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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 September 30, 2019.

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

In the ordinary course of business, we may become party to legal, regulatory or administrative proceedings or governmental investigations, including environmental and other matters. Damages or penalties may be sought from us in some matters and certain matters may require years to resolve. While the outcome and impact of these proceedings and investigations on us cannot be predicted with certainty, based on advice of counsel and information currently available to us, management believes that the resolution of these proceedings and investigations through settlement or adverse judgment will not either individually or in the aggregate have a material adverse effect on our financial condition, results of operations or cash flows.

The environmental proceedings are reported to comply with SEC regulations which require us to disclose proceedings arising under 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.

Environmental Matters

Cheyenne
HollyFrontier Cheyenne Refining LLC (“HFCR”) has been in discussions with the Wyoming Department of Environmental Quality (“WDEQ”) relating to Notices of Violations issued in late 2016 and 2018 for possible violations of air quality standards related to operation of certain refinery units at the Cheyenne Refinery. On July 18, 2019, HFCR and WDEQ entered into a consent decree pursuant to which HFCR agreed to pay penalties related to alleged violations of air quality limits that occurred during the second quarter of 2016 through the second quarter of 2017. HFCR and WDEQ are in discussions to resolve alleged violations of air quality limits that occurred during the third quarter of 2017 through calendar year 2018.

On August 19, 2019 and October 30, 2019, HFCR received letters from the EPA providing a preliminary estimate of stipulated penalties related to the alleged violations that occurred during the third quarter of 2017 through the second quarter of 2019 pursuant to HFCR’s federal consent decree. HFCR responded to the EPA preliminary estimate of stipulated penalties related to the alleged violations that occurred during the third quarter of 2017 through calendar year 2018 in a letter dated September 18, 2019 and is in dialogue with the EPA and the WDEQ to discuss an appropriate resolution of all alleged violations.

Separately, on October 23, 2019, HFCR received a Notice of Violation from the WDEQ for possible violations of air quality standards during the first and second quarters of 2019, which are not addressed by the federal consent decree. No penalty demand has yet been made by the WDEQ relating to such possible violations.  HFCR and WDEQ are working towards settlement of these alleged violations.

It is too soon to predict the outcome of the negotiations and the ultimate penalty amount.

El Dorado
HollyFrontier El Dorado Refining LLC (“HFEDR”) is engaged in discussions with, and has responded to document requests from, the EPA and the U.S. Department of Justice (“DOJ”) regarding potential Clean Air Act civil violations relating to flaring devices and other equipment at the refinery. Topics of the discussions include (a) three information requests for activities beginning in January 2009, (b) Risk Management Program compliance issues relating to a November 2014 inspection and subsequent events, (c) a Notice of Violation issued by the EPA in August 2017 and (d) possible late reporting under the Emergency Planning and Community Right-to-Know Act for the release of sulfur dioxide and visible emissions from October 2018. HFEDR is currently in a dialogue with the EPA about a possible settlement of potential and alleged civil violations for the foregoing items. We are currently unable to estimate the final amount of civil penalties that might be included in any settlement. HFEDR will continue to work with the EPA and DOJ to resolve these civil matters. Some of the foregoing civil investigations resulted from fires that occurred at the El Dorado Refinery in September 2017, October 2018 and March 2019. An employee fatality occurred during the September 2017 event.

The Occupational Safety and Health Administration (“OSHA”) completed an investigation of the March 2019 event and issued one citation to HFEDR on August 29, 2019. HFEDR is currently in dialogue with OSHA about possible settlement. HFEDR previously settled the OSHA claims related to an investigation of the September 2017 event. In April 2019, HFEDR became aware that the EPA also initiated a criminal investigation into one or more of the foregoing events. HFEDR has received a grand jury subpoena requesting certain documents be provided to the EPA with respect to the September 2017 event. We are cooperating with this investigation.


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Tulsa
HollyFrontier Tulsa Refining LLC (“HFTR”) operates under two Consent Decrees with the EPA and the Oklahoma Department of Environmental Quality (“ODEQ”) for the East and West refineries. On December 13, 2017, during a meeting between the parties, ODEQ proposed stipulated penalties related to violations of the two Consent Decrees. The violations concern Clean Air Act regulated fuel gas and flare operations. On July 1, 2019, ODEQ issued a demand letter for stipulated penalties under the East Refinery Consent Decree as proposed in the 2017 meeting. In August 2019, HFTR paid the penalties set forth in the demand letter to ODEQ and the EPA satisfying the requirements of the East Refinery Consent Decree. On September 16, 2019, ODEQ issued a demand letter for stipulated penalties under the West Refinery Consent Decree. HFTR is working with ODEQ to resolve this matter. Additionally, on April 3, 2019, during a meeting between the parties, the EPA notified HFTR of potential monitoring violations of the Consent Decrees. HFTR is working with the ODEQ and the EPA to document a settlement agreement for the additional actions.

Woods Cross
HollyFrontier Woods Cross Refining LLC (“HFWCR”) received an early settlement agreement from the Utah Department of Environmental Quality’s Division of Air Quality (“DAQ”) for alleged violations associated with operation of HFWCR’s diesel-fired emergency engines. HFWCR has reached an agreement in principle with the Utah Attorney General’s office to settle this matter. The agreement is subject to review and approval by the Utah Air Quality Board.

Federal Trade Commission

On July 23, 2019, the Federal Trade Commission (“FTC”) issued a Civil Investigative Demand and a related Subpoena Duce Tecum requesting we provide specified information relating to the Sonneborn acquisition that closed on February 1, 2019. We are in the process of responding to the FTC request. Based on the limited information that we have at this time, we are unable to predict the outcome of this request. On December 14, 2018, we received early termination of the applicable waiting period under the Hart-Scott-Rodino Antitrust Improvements Act from the FTC and Department of Justice with respect to the Sonneborn acquisition. On January 17, 2019, we received early termination of the applicable waiting period under the German antitrust laws with respect to the Sonneborn acquisition. Early termination is granted to transactions that the antitrust agencies determine raise no substantive competition concerns.

Renewable Fuel Standard

Various subsidiaries of HollyFrontier have intervened in three lawsuits brought by renewable fuel interest groups against the EPA in federal courts alleging violations of the Renewable Fuel Standard under the Clean Air Act and challenging the EPA’s handling of small refinery exemptions. We believe the EPA correctly applied applicable law to the matters at issue and will vigorously defend the EPA’s position on small refinery exemptions.

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, 2018. You should carefully consider the risk factors discussed in our 2018 Form 10-K, 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

(c) Common Stock Repurchases Made in the Quarter

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 third quarter of 2019.

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
July 2019
 
1,258,100

 
$
47.94

 
1,258,100

 
$
448,563,068

August 2019
 
1,449,882

 
$
46.50

 
1,449,882

 
$
381,139,885

September 2019
 
1,328,000

 
$
51.15

 
1,328,000

 
$
313,216,174

Total for July to September 2019
 
4,035,982

 
 
 
4,035,982

 
 


Item 6.
Exhibits

The Exhibit Index on page 63 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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Exhibit Index

Exhibit Number
  
Description
 
 
 
3.1
 
 
 
 
3.2
 
 
 
 
10.1
 
Fifth Amended and Restated Master Throughput Agreement, dated as of July 1, 2019, by and between HollyFrontier Refining and Marketing LLC and Holly Energy Partners - Operating, L.P. (incorporated by reference to Exhibit 10.1 of Registrant’s Form 8-K Current Report filed July 2, 2019, File No. 1-03876).
 
 
 
10.2
 
Sixth Amended and Restated Master Throughput Agreement, dated as of October 2, 2019, by and between HollyFrontier Refining & Marketing LLC and Holly Energy Partners -Operating, L.P. (incorporated by reference to Exhibit 10.1 of Registrant’s Form 8-K Current Report filed October 3, 2019, File No. 1-03876).
 
 
 
10.3
 
Twentieth Amended and Restated Omnibus Agreement, dated as of October 2, 2019, by and between HollyFrontier Corporation, Holly Energy Partners, L.P. and certain of their respective subsidiaries (incorporated by reference to Exhibit 10.2 of Registrant’s Form 8-K Current Report filed October 3, 2019, File No. 1-03876).
 
 
 
31.1*
 
 
 
 
31.2*
 
 
 
 
32.1**
 
 
 
 
32.2**
 
 
 
 
101
 
The following financial information from HollyFrontier Corporation’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2019, formatted as inline XBRL (Inline 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. The instance document does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document.

 
 
 
104
 
Cover page Interactive Data File (formatted as inline XBRL and contained in exhibit 101).

* Filed herewith.
** Furnished herewith.
+ Filed electronically herewith.


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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: October 31, 2019
 
 
/s/ Richard L. Voliva III
 
 
 
Richard L.Voliva III
 
 
 
Executive Vice President and
Chief Financial Officer
(Principal Financial Officer)
 
 
 
 
Date: October 31, 2019
 
 
/s/ J. W. Gann, Jr.
 
 
 
J. W. Gann, Jr.
 
 
 
Vice President, Controller and
Chief Accounting Officer
(Principal Accounting Officer)

63