DALLAS--(BUSINESS WIRE)--
HollyFrontier Corporation (NYSE:HFC) (“HollyFrontier” or the “Company”)
today reported first quarter net loss attributable to HollyFrontier
stockholders of $(45.5) million or $(0.26) per diluted share for the
quarter ended March 31, 2017, compared to net income of $21.3 million or
$0.12 per diluted share for the quarter ended March 31, 2016.
The first quarter included several special items that reduced net income
by a total of $12.0 million. On a pre-tax basis, these items included a
lower of cost or market inventory valuation charge of $11.8 million,
direct acquisition and integration costs of Petro-Canada Lubricants Inc.
(“PCLI”) totaling $15.6 million, incremental cost of products sold
attributable to our PCLI inventory value step-up of $10.2 million,
HollyFrontier's pro-rata share of Holly Energy Partners' loss on early
extinguishment of debt of $4.5 million, and a gain of $24.5 million on
foreign currency swaps related to the purchase of PCLI.
Excluding these items, net loss for the current quarter was $(33.5)
million versus a loss of $(10.0) million for the same period of 2016.
This decrease was driven by lower product sales due to maintenance at
the El Dorado, Tulsa and Navajo refineries, partially offset by $8.4
million in earnings attributable to our recently acquired PCLI
operations. Production levels averaged approximately 392,000 barrels per
day (“BPD”) and crude oil charges averaged 371,000 BPD for the current
quarter. On a per barrel basis, consolidated refinery gross margin was
$7.74 per produced barrel, a 2% increase compared to $7.59 for the first
quarter of 2016. Total operating expenses for the quarter were $307.1
million compared to $252.6 million for the first quarter of last year
and include $36.0 million in costs attributable to our PCLI operations.
HollyFrontier’s President & CEO, George Damiris, commented, “First
quarter crude rate was negatively impacted by our planned turnaround at
Navajo, planned maintenance at the El Dorado vacuum tower, unplanned
maintenance at the Tulsa CCR reformer, and the crude supply pipeline
outage to our Woods Cross refinery. We are pleased with the results from
the Navajo turnaround and the efficiency and debottleneck projects that
were implemented during the turnaround. During the Tulsa outage, we were
able to accelerate other maintenance and a catalyst upgrade originally
planned for later this year, all of which will allow us to benefit from
higher liquid yields and octane during the summer driving season. We are
also encouraged by the results we have begun to see from our focused
efforts to improve operations and reliability at Cheyenne; crude rate
was over 48,000 barrels per day in March. With no major planned downtime
until November, our refineries are well positioned for strong
operational and financial performance for the remainder of the year.
We closed the PCLI acquisition on February 1st and PCLI continues to
meet or exceed our expectations. Adjusted EBITDA for February and March
was $28.0 million, in line with our annual guidance range. We remain
confident in our $20.0 million per year synergy target and in the
potential for significant margin uplift by increasing Group III base oil
production through feedstock optimization. We are excited about our
growing presence in the lubricants industry and are encouraged by our
progress integrating PCLI into HFC.”
For the first quarter of 2017, net cash used for operations totaled
$39.4 million including $48.0 million of turnaround expenses. During the
period, we declared a dividend of $0.33 per share to shareholders
totaling $59.0 million. At March 31, 2017, our cash and cash equivalents
totaled $129.5 million and our consolidated debt was $2,231.5 million.
Our debt, exclusive of Holly Energy Partners' debt, which is nonrecourse
to HollyFrontier, was $991.0 million at March 31, 2017.
The Company has scheduled a webcast conference call for today, May 3,
2017, at 8:30 AM Eastern Time to discuss first quarter financial
results. This webcast may be accessed at: https://event.webcasts.com/starthere.jsp?ei=1139807.
An audio archive of this webcast will be available using the above noted
link through May 17, 2017.
HollyFrontier Corporation, headquartered in Dallas, Texas, is an
independent petroleum refiner and marketer that produces high-value
light products such as gasoline, diesel fuel, jet fuel and other
specialty products. HollyFrontier operates through its subsidiaries a
135,000 barrels per stream day (“BPSD”) refinery located in El Dorado,
Kansas, two refinery facilities with a combined capacity of 125,000 BPSD
located in Tulsa, Oklahoma, a 100,000 BPSD refinery located in Artesia,
New Mexico, a 52,000 BPSD refinery located in Cheyenne, Wyoming and a
45,000 BPSD refinery in Woods Cross, Utah. HollyFrontier markets its
refined products principally in the Southwest U.S., the Rocky Mountains
extending into the Pacific Northwest and in other neighboring Plains
states. In addition, HollyFrontier, through its subsidiary, owns
Petro-Canada Lubricants Inc., whose Mississauga, Ontario facility
produces 15,600 barrels per day of base oils and other specialized
lubricant products, and also owns a 36% interest (including the 2%
general partner interest) in Holly Energy Partners, L.P.
The following is a “safe harbor” statement under the Private Securities
Litigation Reform Act of 1995: The statements in this press release
relating to matters that are not historical facts are “forward-looking
statements” 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, including those contained in our filings with the
Securities and Exchange Commission. Although we believe that the
expectations reflected in these forward-looking statements are
reasonable, we cannot assure you that our expectations will prove
correct. Therefore, actual outcomes and results could materially differ
from what is expressed, implied or forecast in such 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 the Company’s 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 financing to the Company, the effectiveness of
the Company’s capital investments and marketing strategies, the
Company’s efficiency in carrying out construction projects, the ability
of the Company to acquire refined product operations or pipeline and
terminal operations on acceptable terms and to integrate any recent and
future acquired operations, the possibility of terrorist attacks and the
consequences of any such attacks, general economic conditions and other
financial, operational and legal risks and uncertainties detailed from
time to time in the Company’s Securities and Exchange Commission
filings. The forward-looking statements speak only as of the date made
and, other than as required by law, we undertake no obligation to
publicly update or revise any forward-looking statements, whether as a
result of new information, future events or otherwise.
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RESULTS OF OPERATIONS
|
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|
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|
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|
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Financial Data (all information in this release is unaudited)
|
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|
|
|
|
|
|
|
|
Three Months Ended
March 31,
|
|
Change from 2016
|
|
|
|
2017
|
|
2016
|
|
Change
|
|
Percent
|
|
|
|
(In thousands, except per share data)
|
|
Sales and other revenues
|
|
$
|
3,080,483
|
|
|
$
|
2,018,724
|
|
|
$
|
1,061,759
|
|
|
53
|
%
|
|
Operating costs and expenses:
|
|
|
|
|
|
|
|
|
|
Cost of products sold:
|
|
|
|
|
|
|
|
|
|
Cost of products sold (exclusive of lower of cost or market
inventory valuation adjustment)
|
|
2,641,157
|
|
|
1,625,163
|
|
|
1,015,994
|
|
|
63
|
|
|
Lower of cost or market inventory valuation adjustment
|
|
11,823
|
|
|
(56,121
|
)
|
|
67,944
|
|
|
(121
|
)
|
|
|
|
2,652,980
|
|
|
1,569,042
|
|
|
1,083,938
|
|
|
69
|
|
|
Operating expenses
|
|
307,117
|
|
|
252,583
|
|
|
54,534
|
|
|
22
|
|
|
General and administrative expenses
|
|
57,070
|
|
|
25,621
|
|
|
31,449
|
|
|
123
|
|
|
Depreciation and amortization
|
|
96,040
|
|
|
87,880
|
|
|
8,160
|
|
|
9
|
|
|
Total operating costs and expenses
|
|
3,113,207
|
|
|
1,935,126
|
|
|
1,178,081
|
|
|
61
|
|
|
Income (loss) from operations
|
|
(32,724
|
)
|
|
83,598
|
|
|
(116,322
|
)
|
|
(139
|
)
|
|
Other income (expense):
|
|
|
|
|
|
|
|
|
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Earnings of equity method investments
|
|
1,840
|
|
|
2,765
|
|
|
(925
|
)
|
|
(33
|
)
|
|
Interest income
|
|
819
|
|
|
75
|
|
|
744
|
|
|
992
|
|
|
Interest expense
|
|
(27,158
|
)
|
|
(12,087
|
)
|
|
(15,071
|
)
|
|
125
|
|
|
Loss on early extinguishment of debt
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|
(12,225
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)
|
|
(8,718
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)
|
|
(3,507
|
)
|
|
40
|
|
|
Gain on foreign currency swaps
|
|
24,545
|
|
|
—
|
|
|
24,545
|
|
|
—
|
|
|
Loss on foreign currency transactions
|
|
(9,933
|
)
|
|
—
|
|
|
(9,933
|
)
|
|
—
|
|
|
Other, net
|
|
265
|
|
|
65
|
|
|
200
|
|
|
308
|
|
|
|
|
(21,847
|
)
|
|
(17,900
|
)
|
|
(3,947
|
)
|
|
22
|
|
|
Income (loss) before income taxes
|
|
(54,571
|
)
|
|
65,698
|
|
|
(120,269
|
)
|
|
(183
|
)
|
|
Income tax expense (benefit)
|
|
(16,789
|
)
|
|
22,308
|
|
|
(39,097
|
)
|
|
(175
|
)
|
|
Net income (loss)
|
|
(37,782
|
)
|
|
43,390
|
|
|
(81,172
|
)
|
|
(187
|
)
|
|
Less net income attributable to noncontrolling interest
|
|
7,686
|
|
|
22,137
|
|
|
(14,451
|
)
|
|
(65
|
)
|
|
Net income (loss) attributable to HollyFrontier stockholders
|
|
$
|
(45,468
|
)
|
|
$
|
21,253
|
|
|
$
|
(66,721
|
)
|
|
(314
|
)%
|
|
Earnings (loss) per share attributable to HollyFrontier
stockholders:
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$
|
(0.26
|
)
|
|
$
|
0.12
|
|
|
$
|
(0.38
|
)
|
|
(317
|
)%
|
|
Diluted
|
|
$
|
(0.26
|
)
|
|
$
|
0.12
|
|
|
$
|
(0.38
|
)
|
|
(317
|
)%
|
|
Cash dividends declared per common share
|
|
$
|
0.33
|
|
|
$
|
0.33
|
|
|
$
|
—
|
|
|
—
|
%
|
|
Average number of common shares outstanding:
|
|
|
|
|
|
|
|
|
|
Basic
|
|
176,210
|
|
|
176,737
|
|
|
(527
|
)
|
|
—
|
%
|
|
Diluted
|
|
176,210
|
|
|
176,784
|
|
|
(574
|
)
|
|
—
|
%
|
|
EBITDA
|
|
$
|
72,347
|
|
|
$
|
152,171
|
|
|
$
|
(79,824
|
)
|
|
(52
|
)%
|
|
Adjusted EBITDA
|
|
$
|
85,460
|
|
|
$
|
96,050
|
|
|
$
|
(10,590
|
)
|
|
(11
|
)%
|
|
|
|
|
|
|
|
Balance Sheet Data
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|
|
|
|
|
|
|
|
March 31,
|
|
December 31,
|
|
|
|
2017
|
|
2016
|
|
|
|
(In thousands)
|
|
Cash, cash equivalents and total investments in marketable securities
|
|
$
|
129,512
|
|
|
$
|
1,134,727
|
|
Working capital
|
|
$
|
1,027,183
|
|
|
$
|
1,767,780
|
|
Total assets
|
|
$
|
9,548,254
|
|
|
$
|
9,435,661
|
|
Long-term debt
|
|
$
|
2,231,542
|
|
|
$
|
2,235,137
|
|
Total equity
|
|
$
|
5,229,096
|
|
|
$
|
5,301,985
|
|
|
|
|
|
|
|
|
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Segment Information
Our operations are organized into three reportable segments, Refining,
PCLI and HEP. Our operations that are not included in the Refining, PCLI
and HEP segments are included in Corporate and Other. Intersegment
transactions are eliminated in our consolidated financial statements and
are included in Consolidations and Eliminations. The Refining segment
includes the operations of our 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. Additionally, the Refining segment
includes specialty lubricant products produced at our Tulsa refineries
that are marketed throughout North America and are distributed in
Central and South America. HFC Asphalt operates various asphalt
terminals in Arizona, New Mexico and Oklahoma.
On February 1, 2017, we acquired PCLI, a Canadian-based producer of
lubricant products such as base oils, white oils, specialty products and
finished lubricants. The PCLI segment involves production operations,
located in Mississauga, Ontario, and marketing of its products to both
retail and wholesale outlets through a global sales network with
locations in Canada, the United States, Europe and China.
The HEP segment involves all of the operations of HEP, a consolidated
variable interest entity, which owns and operates logistics assets
consisting of petroleum product and crude oil pipelines, terminals,
tankage, loading rack facilities and refinery process units in the
Mid-Continent, Southwest and Rocky Mountain regions of the United
States. The HEP segment also includes a 75% interest in the UNEV
Pipeline (an HEP consolidated subsidiary), a 50% ownership interest in
each of the Frontier Pipeline, Osage Pipeline and the Cheyenne Pipeline
and a 25% ownership interest in SLC Pipeline. Revenues from the HEP
segment are earned through transactions with unaffiliated parties for
pipeline transportation, rental and terminalling operations as well as
revenues relating to pipeline transportation services provided for our
refining operations. Due to certain basis differences, our reported
amounts for the HEP segment may not agree to amounts reported in HEP's
periodic public filings.
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Refining
|
|
|
PCLI
|
|
|
HEP
|
|
|
Corporate
and Other
|
|
|
Consolidations
and
Eliminations
|
|
|
Consolidated
Total
|
|
|
|
(In thousands)
|
|
Three Months Ended March 31, 2017
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Sales and other revenues
|
|
$
|
2,862,076
|
|
|
|
$
|
201,940
|
|
|
|
$
|
105,634
|
|
|
|
$
|
27
|
|
|
|
$
|
(89,194
|
)
|
|
|
$
|
3,080,483
|
|
|
Operating expenses
|
|
$
|
257,115
|
|
|
|
$
|
36,029
|
|
|
|
$
|
32,489
|
|
|
|
$
|
1,013
|
|
|
|
$
|
(19,529
|
)
|
|
|
$
|
307,117
|
|
|
Depreciation and amortization
|
|
$
|
69,668
|
|
|
|
$
|
5,074
|
|
|
|
$
|
18,373
|
|
|
|
$
|
3,132
|
|
|
|
$
|
(207
|
)
|
|
|
$
|
96,040
|
|
|
Income (loss) from operations
|
|
$
|
(50,255
|
)
|
|
|
$
|
12,394
|
|
|
|
$
|
52,138
|
|
|
|
$
|
(46,435
|
)
|
|
|
$
|
(566
|
)
|
|
|
$
|
(32,724
|
)
|
|
Net income (loss)
|
|
$
|
(50,255
|
)
|
|
|
$
|
8,416
|
|
|
|
$
|
28,283
|
|
|
|
$
|
(24,183
|
)
|
|
|
$
|
(43
|
)
|
|
|
$
|
(37,782
|
)
|
|
Capital expenditures
|
|
$
|
47,674
|
|
|
|
$
|
1,595
|
|
|
|
$
|
8,265
|
|
|
|
$
|
2,223
|
|
|
|
$
|
—
|
|
|
|
$
|
59,757
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended March 31, 2016
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Sales and other revenues
|
|
$
|
1,999,587
|
|
|
|
$
|
—
|
|
|
|
$
|
102,010
|
|
|
|
$
|
110
|
|
|
|
$
|
(82,983
|
)
|
|
|
$
|
2,018,724
|
|
|
Operating expenses
|
|
$
|
228,762
|
|
|
|
$
|
—
|
|
|
|
$
|
26,823
|
|
|
|
$
|
1,255
|
|
|
|
$
|
(4,257
|
)
|
|
|
$
|
252,583
|
|
|
Depreciation and amortization
|
|
$
|
68,878
|
|
|
|
$
|
—
|
|
|
|
$
|
16,029
|
|
|
|
$
|
3,180
|
|
|
|
$
|
(207
|
)
|
|
|
$
|
87,880
|
|
|
Income (loss) from operations
|
|
$
|
55,000
|
|
|
|
$
|
—
|
|
|
|
$
|
56,067
|
|
|
|
$
|
(26,855
|
)
|
|
|
$
|
(614
|
)
|
|
|
$
|
83,598
|
|
|
Net income (loss)
|
|
$
|
55,000
|
|
|
|
$
|
—
|
|
|
|
$
|
48,305
|
|
|
|
$
|
(59,903
|
)
|
|
|
$
|
(12
|
)
|
|
|
$
|
43,390
|
|
|
Capital expenditures
|
|
$
|
104,707
|
|
|
|
$
|
—
|
|
|
|
$
|
42,184
|
|
|
|
$
|
2,682
|
|
|
|
$
|
—
|
|
|
|
$
|
149,573
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
March 31, 2017
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash, cash equivalents and total investments in marketable securities
|
|
$
|
90
|
|
|
|
$
|
56,799
|
|
|
|
$
|
7,007
|
|
|
|
$
|
65,616
|
|
|
|
$
|
—
|
|
|
|
$
|
129,512
|
|
|
Total assets
|
|
$
|
6,514,854
|
|
|
|
$
|
1,158,772
|
|
|
|
$
|
1,906,791
|
|
|
|
$
|
252,549
|
|
|
|
$
|
(284,712
|
)
|
|
|
$
|
9,548,254
|
|
|
Long-term debt
|
|
$
|
—
|
|
|
|
$
|
—
|
|
|
|
$
|
1,240,565
|
|
|
|
$
|
990,977
|
|
|
|
$
|
—
|
|
|
|
$
|
2,231,542
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2016
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash, cash equivalents and total investments in marketable securities
|
|
$
|
49
|
|
|
|
$
|
—
|
|
|
|
$
|
3,657
|
|
|
|
$
|
1,131,021
|
|
|
|
$
|
—
|
|
|
|
$
|
1,134,727
|
|
|
Total assets
|
|
$
|
6,513,806
|
|
|
|
$
|
—
|
|
|
|
$
|
1,920,487
|
|
|
|
$
|
1,306,169
|
|
|
|
$
|
(304,801
|
)
|
|
|
$
|
9,435,661
|
|
|
Long-term debt
|
|
$
|
—
|
|
|
|
$
|
—
|
|
|
|
$
|
1,243,912
|
|
|
|
$
|
991,225
|
|
|
|
$
|
—
|
|
|
|
$
|
2,235,137
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Refining Operating Data
The following tables set forth information, including non-GAAP
performance measures about our 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” below.
|
|
|
Three Months Ended March 31,
|
|
|
|
2017
|
|
2016
|
|
Mid-Continent Region (El Dorado and Tulsa Refineries)
|
|
|
|
|
|
Crude charge (BPD) (1)
|
|
221,890
|
|
|
233,540
|
|
|
Refinery throughput (BPD) (2)
|
|
242,120
|
|
|
252,160
|
|
|
Refinery production (BPD) (3)
|
|
232,580
|
|
|
242,100
|
|
|
Sales of produced refined products (BPD)
|
|
227,700
|
|
|
233,350
|
|
|
Sales of refined products (BPD) (4)
|
|
255,370
|
|
|
262,210
|
|
|
Refinery utilization (5)
|
|
85.3
|
%
|
|
89.8
|
%
|
|
|
|
|
|
|
|
Average per produced barrel (6)
|
|
|
|
|
|
Net sales
|
|
$
|
66.71
|
|
|
$
|
46.69
|
|
|
Cost of products (7)
|
|
60.04
|
|
|
38.85
|
|
|
Refinery gross margin (8)
|
|
6.67
|
|
|
7.84
|
|
|
Refinery operating expenses (9)
|
|
6.12
|
|
|
5.40
|
|
|
Net operating margin (8)
|
|
$
|
0.55
|
|
|
$
|
2.44
|
|
|
|
|
|
|
|
|
Refinery operating expenses per throughput barrel (10)
|
|
$
|
5.76
|
|
|
$
|
5.00
|
|
|
|
|
|
|
|
|
Feedstocks:
|
|
|
|
|
|
Sweet crude oil
|
|
58
|
%
|
|
52
|
%
|
|
Sour crude oil
|
|
19
|
%
|
|
21
|
%
|
|
Heavy sour crude oil
|
|
15
|
%
|
|
20
|
%
|
|
Other feedstocks and blends
|
|
8
|
%
|
|
7
|
%
|
|
Total
|
|
100
|
%
|
|
100
|
%
|
|
|
|
|
|
|
|
Sales of produced refined products:
|
|
|
|
|
|
Gasolines
|
|
50
|
%
|
|
48
|
%
|
|
Diesel fuels
|
|
31
|
%
|
|
34
|
%
|
|
Jet fuels
|
|
9
|
%
|
|
7
|
%
|
|
Fuel oil
|
|
1
|
%
|
|
1
|
%
|
|
Asphalt
|
|
2
|
%
|
|
2
|
%
|
|
Lubricants
|
|
5
|
%
|
|
5
|
%
|
|
LPG and other
|
|
2
|
%
|
|
3
|
%
|
|
Total
|
|
100
|
%
|
|
100
|
%
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended March 31,
|
|
|
|
2017
|
|
2016
|
|
Southwest Region (Navajo Refinery)
|
|
|
|
|
|
Crude charge (BPD) (1)
|
|
74,470
|
|
|
98,130
|
|
|
Refinery throughput (BPD) (2)
|
|
79,490
|
|
|
109,120
|
|
|
Refinery production (BPD) (3)
|
|
78,110
|
|
|
107,510
|
|
|
Sales of produced refined products (BPD)
|
|
76,340
|
|
|
113,370
|
|
|
Sales of refined products (BPD) (4)
|
|
90,700
|
|
|
113,750
|
|
|
Refinery utilization (5)
|
|
74.5
|
%
|
|
98.1
|
%
|
|
|
|
|
|
|
|
Average per produced barrel (6)
|
|
|
|
|
|
Net sales
|
|
$
|
67.16
|
|
|
$
|
45.70
|
|
|
Cost of products (7)
|
|
58.76
|
|
|
38.77
|
|
|
Refinery gross margin (8)
|
|
8.40
|
|
|
6.93
|
|
|
Refinery operating expenses (9)
|
|
6.90
|
|
|
4.24
|
|
|
Net operating margin (8)
|
|
$
|
1.50
|
|
|
$
|
2.69
|
|
|
|
|
|
|
|
|
Refinery operating expenses per throughput barrel (10)
|
|
$
|
6.63
|
|
|
$
|
4.41
|
|
|
|
|
|
|
|
|
Feedstocks:
|
|
|
|
|
|
Sweet crude oil
|
|
18
|
%
|
|
33
|
%
|
|
Sour crude oil
|
|
76
|
%
|
|
57
|
%
|
|
Other feedstocks and blends
|
|
6
|
%
|
|
10
|
%
|
|
Total
|
|
100
|
%
|
|
100
|
%
|
|
|
|
|
|
|
|
Sales of produced refined products:
|
|
|
|
|
|
Gasolines
|
|
53
|
%
|
|
56
|
%
|
|
Diesel fuels
|
|
39
|
%
|
|
38
|
%
|
|
Fuel oil
|
|
4
|
%
|
|
2
|
%
|
|
Asphalt
|
|
1
|
%
|
|
1
|
%
|
|
LPG and other
|
|
3
|
%
|
|
3
|
%
|
|
Total
|
|
100
|
%
|
|
100
|
%
|
|
|
|
|
|
|
|
Rocky Mountain Region (Cheyenne and Woods Cross Refineries)
|
|
|
|
|
|
Crude charge (BPD) (1)
|
|
74,710
|
|
|
59,430
|
|
|
Refinery throughput (BPD) (2)
|
|
83,750
|
|
|
69,230
|
|
|
Refinery production (BPD) (3)
|
|
81,150
|
|
|
66,240
|
|
|
Sales of produced refined products (BPD)
|
|
80,780
|
|
|
66,640
|
|
|
Sales of refined products (BPD) (4)
|
|
81,450
|
|
|
69,970
|
|
|
Refinery utilization (5)
|
|
77.0
|
%
|
|
71.6
|
%
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended March 31,
|
|
|
|
2017
|
|
2016
|
|
Rocky Mountain Region (Cheyenne and Woods Cross Refineries)
|
|
|
|
|
|
Average per produced barrel (6)
|
|
|
|
|
|
Net sales
|
|
$
|
65.83
|
|
|
$
|
46.79
|
|
|
Cost of products (7)
|
|
55.72
|
|
|
39.00
|
|
|
Refinery gross margin (8)
|
|
10.11
|
|
|
7.79
|
|
|
Refinery operating expenses (9)
|
|
10.08
|
|
|
9.68
|
|
|
Net operating margin (8)
|
|
$
|
0.03
|
|
|
$
|
(1.89
|
)
|
|
|
|
|
|
|
|
Refinery operating expenses per throughput barrel (10)
|
|
$
|
9.72
|
|
|
$
|
9.32
|
|
|
|
|
|
|
|
|
Feedstocks:
|
|
|
|
|
|
Sweet crude oil
|
|
38
|
%
|
|
39
|
%
|
|
Heavy sour crude oil
|
|
31
|
%
|
|
32
|
%
|
|
Black wax crude oil
|
|
20
|
%
|
|
15
|
%
|
|
Other feedstocks and blends
|
|
11
|
%
|
|
14
|
%
|
|
Total
|
|
100
|
%
|
|
100
|
%
|
|
|
|
|
|
|
|
Sales of produced refined products:
|
|
|
|
|
|
Gasolines
|
|
58
|
%
|
|
62
|
%
|
|
Diesel fuels
|
|
33
|
%
|
|
32
|
%
|
|
Fuel oil
|
|
2
|
%
|
|
3
|
%
|
|
Asphalt
|
|
5
|
%
|
|
1
|
%
|
|
LPG and other
|
|
2
|
%
|
|
2
|
%
|
|
Total
|
|
100
|
%
|
|
100
|
%
|
|
|
|
|
|
|
|
Consolidated
|
|
|
|
|
|
Crude charge (BPD) (1)
|
|
371,070
|
|
|
391,100
|
|
|
Refinery throughput (BPD) (2)
|
|
405,360
|
|
|
430,510
|
|
|
Refinery production (BPD) (3)
|
|
391,840
|
|
|
415,850
|
|
|
Sales of produced refined products (BPD)
|
|
384,820
|
|
|
413,360
|
|
|
Sales of refined products (BPD) (4)
|
|
427,520
|
|
|
445,930
|
|
|
Refinery utilization (5)
|
|
81.2
|
%
|
|
88.3
|
%
|
|
|
|
|
|
|
|
Average per produced barrel (6)
|
|
|
|
|
|
Net sales
|
|
$
|
66.62
|
|
|
$
|
46.44
|
|
|
Cost of products (7)
|
|
58.88
|
|
|
38.85
|
|
|
Refinery gross margin (8)
|
|
7.74
|
|
|
7.59
|
|
|
Refinery operating expenses (9)
|
|
7.11
|
|
|
5.77
|
|
|
Net operating margin (8)
|
|
$
|
0.63
|
|
|
$
|
1.82
|
|
|
|
|
|
|
|
|
Refinery operating expenses per throughput barrel (10)
|
|
$
|
6.75
|
|
|
$
|
5.54
|
|
|
|
|
|
|
|
|
Feedstocks:
|
|
|
|
|
|
Sweet crude oil
|
|
46
|
%
|
|
45
|
%
|
|
Sour crude oil
|
|
26
|
%
|
|
27
|
%
|
|
Heavy sour crude oil
|
|
15
|
%
|
|
17
|
%
|
|
Black wax crude oil
|
|
4
|
%
|
|
2
|
%
|
|
Other feedstocks and blends
|
|
9
|
%
|
|
9
|
%
|
|
Total
|
|
100
|
%
|
|
100
|
%
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended March 31,
|
|
|
|
2017
|
|
2016
|
|
Consolidated
|
|
|
|
|
|
Sales of produced refined products:
|
|
|
|
|
|
Gasolines
|
|
52
|
%
|
|
53
|
%
|
|
Diesel fuels
|
|
33
|
%
|
|
35
|
%
|
|
Jet fuels
|
|
5
|
%
|
|
4
|
%
|
|
Fuel oil
|
|
2
|
%
|
|
2
|
%
|
|
Asphalt
|
|
3
|
%
|
|
1
|
%
|
|
Lubricants
|
|
3
|
%
|
|
2
|
%
|
|
LPG and other
|
|
2
|
%
|
|
3
|
%
|
|
Total
|
|
100
|
%
|
|
100
|
%
|
|
|
|
|
|
|
|
|
|
|
(1)
|
|
Crude charge represents the barrels per day of crude oil processed
at our refineries.
|
|
|
(2)
|
|
Refinery throughput represents the barrels per day of crude and
other refinery feedstocks input to the crude units and other
conversion units at our refineries.
|
|
|
(3)
|
|
Refinery production represents the barrels per day of refined
products yielded from processing crude and other refinery
feedstocks through the crude units and other conversion units at
our refineries.
|
|
|
(4)
|
|
Includes refined products purchased for resale.
|
|
|
(5)
|
|
Represents crude charge divided by total crude capacity (BPSD).
Effective July 1, 2016, our consolidated crude capacity increased
from 443,000 BPSD to 457,000 BPSD upon completion of our Woods
Cross Refinery expansion project.
|
|
|
(6)
|
|
Represents average per barrel amount for produced refined products
sold, which is a non-GAAP measure. Reconciliations to amounts
reported under GAAP are provided under “Reconciliations to Amounts
Reported Under Generally Accepted Accounting Principles” below.
|
|
|
(7)
|
|
Transportation, terminal and refinery storage costs billed from
HEP are included in cost of products.
|
|
|
(8)
|
|
Excludes lower of cost or market inventory valuation adjustments
of $11.8 million and $56.1 million for the three months ended
March 31, 2017 and 2016, respectively.
|
|
|
(9)
|
|
Represents operating expenses of our refineries, exclusive of
depreciation and amortization.
|
|
|
(10)
|
|
Represents refinery operating expenses, exclusive of depreciation
and amortization, divided by refinery throughput.
|
|
PCLI Operating Data
|
|
|
|
The following table sets forth information about our PCLI
operations for the period from February 1, 2017 (date of
acquisition) through March 31, 2017.
|
|
|
|
Period From
February 1, 2017
Through
March 31, 2017
|
|
PCLI
|
|
|
|
Throughput (BPD) (1)
|
|
22,170
|
|
Production (BPD) (2)
|
|
21,760
|
|
Sales of produced products (BPD)
|
|
24,140
|
|
|
|
|
|
|
(1)
|
|
Throughput represents the barrels per day of feedstocks (principally
vacuum gas oil and hydrocracker bottoms) input into our PCLI
production facilities.
|
|
|
(2)
|
|
Production represents the barrels per day of products yielded from
our PCLI production facilities.
|
|
|
|
|
|
Reconciliations to Amounts Reported Under Generally Accepted
Accounting Principles
Reconciliations of earnings before interest, taxes, depreciation
and amortization (“EBITDA”) and EBITDA excluding lower of cost or market
inventory valuation adjustments and PCLI acquisition and integration
costs, incremental cost of products sold attributable to our PCLI
inventory value step-up and net gain on foreign currency swaps
("Adjusted EBITDA") to amounts reported under generally accepted
accounting principles ("GAAP") in financial statements.
Earnings before interest, taxes, depreciation and amortization, which we
refer to as EBITDA, is calculated as net income (loss) attributable to
HollyFrontier stockholders plus (i) interest expense, net of interest
income, (ii) income tax provision, and (iii) depreciation and
amortization. Adjusted EBITDA is calculated as EBITDA plus or minus (i)
lower of cost or market inventory valuation adjustments (ii) PCLI
acquisition and integration costs (iii) incremental cost of products
sold attributable to our PCLI inventory value step-up and (iv) net gain
on foreign currency swaps.
EBITDA and Adjusted EBITDA are not calculations provided for under
accounting principles generally accepted in the United States; however,
the amounts included in these calculations are derived from amounts
included in our consolidated financial statements. EBITDA and Adjusted
EBITDA should not be considered as alternatives 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 and
Adjusted EBITDA are not necessarily comparable to similarly titled
measures of other companies. These are presented here because they are
widely used financial indicators used by investors and analysts to
measure performance.
EBITDA and Adjusted EBITDA are also used by our management for internal
analysis and as a basis for financial covenants.
Set forth below is our calculation of EBITDA and adjusted EBITDA.
|
|
|
|
Three Months Ended March 31,
|
|
|
|
|
2017
|
|
2016
|
|
|
|
|
(In thousands)
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributable to HollyFrontier stockholders
|
|
$
|
(45,468
|
)
|
|
$
|
21,253
|
|
|
|
Add income tax provision
|
|
(16,789
|
)
|
|
22,308
|
|
|
|
Add interest expense (1)
|
|
39,383
|
|
|
20,805
|
|
|
|
Subtract interest income
|
|
(819
|
)
|
|
(75
|
)
|
|
|
Add depreciation and amortization
|
|
96,040
|
|
|
87,880
|
|
|
|
EBITDA
|
|
$
|
72,347
|
|
|
$
|
152,171
|
|
|
|
Add (subtract) lower of cost or market inventory valuation adjustment
|
|
11,823
|
|
|
(56,121
|
)
|
|
|
Add PCLI acquisition and integration costs
|
|
15,597
|
|
|
—
|
|
|
|
Add Incremental cost of products sold attributable to PCLI inventory
value step-up
|
|
10,238
|
|
|
—
|
|
|
|
Less gain on foreign currency swaps
|
|
(24,545
|
)
|
|
—
|
|
|
|
Adjusted EBITDA
|
|
$
|
85,460
|
|
|
$
|
96,050
|
|
|
|
|
|
|
|
|
|
|
Adjusted EBITDA attributable to our PCLI segment is calculated as
follows:
|
|
|
|
|
|
|
PCLI income from operations (see segment data on page 4)
|
|
$
|
12,394
|
|
|
|
|
|
Add depreciation and amortization (see segment data on page 4)
|
|
5,074
|
|
|
|
|
|
PCLI EBITDA
|
|
$
|
17,468
|
|
|
|
|
|
Add Incremental cost of products sold attributable to PCLI inventory
value step-up
|
|
10,238
|
|
|
|
|
|
Adjusted PCLI EBITDA
|
|
$
|
27,706
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) Includes loss on early extinguishment of debt of $12.2 million
and $8.7 million for the three months ended March 31, 2017 and
2016, respectively.
|
|
|
|
|
|
|
|
|
|
Reconciliations of refinery operating information (non-GAAP
performance measures) to amounts reported under generally accepted
accounting principles in financial statements.
Refinery gross margin and net operating margin are non-GAAP performance
measures that are used by our management and others to compare our
refining performance to that of other companies in our industry. We
believe these margin measures are helpful to investors in evaluating our
refining performance on a relative and absolute basis. Refinery gross
margin per barrel is the difference between average net sales price and
average cost of products per barrel of produced refined products. Net
operating margin per barrel is the difference between refinery gross
margin and refinery operating expenses per barrel of produced refined
products.
These two margins do not include the 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.
Refinery Gross and Net Operating Margins
Below are reconciliations to our consolidated statements of income for
(i) net sales, cost of products sold (exclusive of lower of cost or
market inventory valuation adjustment) and operating expenses, in each
case averaged per produced barrel sold, and (ii) net operating margin
and refinery gross margin. Due to rounding of reported numbers, some
amounts may not calculate exactly.
|
|
|
Reconciliation of produced refined product
sales to total sales and other revenues
|
|
|
|
|
|
|
|
Three Months Ended March 31,
|
|
|
|
2017
|
|
2016
|
|
|
|
(Dollars in thousands, except per barrel amounts)
|
|
Consolidated
|
|
|
|
|
|
Average sales price per produced barrel sold
|
|
$
|
66.62
|
|
|
$
|
46.44
|
|
|
Times sales of produced refined products (BPD)
|
|
384,820
|
|
|
413,360
|
|
|
Times number of days in period
|
|
90
|
|
|
91
|
|
|
Produced refined product sales
|
|
$
|
2,307,304
|
|
|
$
|
1,746,876
|
|
|
|
|
|
|
|
|
Total produced refined product sales
|
|
$
|
2,307,304
|
|
|
$
|
1,746,876
|
|
|
Add refined product sales from purchased products and rounding (1)
|
|
260,940
|
|
|
131,408
|
|
|
Total refined product sales
|
|
2,568,244
|
|
|
1,878,284
|
|
|
Add direct sales of excess crude oil (2)
|
|
258,741
|
|
|
90,918
|
|
|
Add other refining segment revenue (3)
|
|
35,091
|
|
|
30,385
|
|
|
Total refining segment revenue
|
|
2,862,076
|
|
|
1,999,587
|
|
|
Add PCLI segment sales and other revenues
|
|
201,940
|
|
|
—
|
|
|
Add HEP segment sales and other revenues
|
|
105,634
|
|
|
102,010
|
|
|
Add corporate and other revenues
|
|
27
|
|
|
110
|
|
|
Subtract consolidations and eliminations
|
|
(89,194
|
)
|
|
(82,983
|
)
|
|
Sales and other revenues
|
|
$
|
3,080,483
|
|
|
$
|
2,018,724
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reconciliation of average cost of products
per produced barrel sold to cost of products sold (exclusive of
lower of cost or market inventory valuation adjustment)
|
|
|
|
|
|
|
|
Three Months Ended March 31,
|
|
|
|
2017
|
|
2016
|
|
|
|
(Dollars in thousands, except per barrel amounts)
|
|
Consolidated
|
|
|
|
|
|
Average cost of products per produced barrel sold
|
|
$
|
58.88
|
|
|
$
|
38.85
|
|
|
Times sales of produced refined products (BPD)
|
|
384,820
|
|
|
413,360
|
|
|
Times number of days in period
|
|
90
|
|
|
91
|
|
|
Cost of products for produced products sold
|
|
$
|
2,039,238
|
|
|
$
|
1,461,372
|
|
|
|
|
|
|
|
|
Total cost of products for produced products sold
|
|
$
|
2,039,238
|
|
|
$
|
1,461,372
|
|
|
Add refined product costs from purchased products sold and rounding (1)
|
|
260,838
|
|
|
138,374
|
|
|
Total cost of refined products sold
|
|
2,300,076
|
|
|
1,599,746
|
|
|
Add crude oil cost of direct sales of excess crude oil (2)
|
|
259,830
|
|
|
91,588
|
|
|
Add other refining segment cost of products sold (4)
|
|
13,819
|
|
|
11,734
|
|
|
Total refining segment cost of products sold
|
|
2,573,725
|
|
|
1,703,068
|
|
|
Add PCLI segment cost of products sold
|
|
136,304
|
|
|
—
|
|
|
Subtract consolidations and eliminations
|
|
(68,872
|
)
|
|
(77,905
|
)
|
|
Costs of products sold (exclusive of lower of cost or market
inventory valuation adjustment and depreciation and amortization)
|
|
$
|
2,641,157
|
|
|
$
|
1,625,163
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reconciliation of average refinery operating
expenses per produced barrel sold to total operating expenses
|
|
|
|
|
|
|
|
|
|
Three Months Ended March 31,
|
|
|
|
|
2017
|
|
2016
|
|
|
|
|
(Dollars in thousands, except per barrel amounts)
|
|
Consolidated
|
|
|
|
|
|
|
Average refinery operating expenses per produced barrel sold
|
|
|
$
|
7.11
|
|
|
$
|
5.77
|
|
|
Times sales of produced refined products (BPD)
|
|
|
384,820
|
|
|
413,360
|
|
|
Times number of days in period
|
|
|
90
|
|
|
91
|
|
|
Refinery operating expenses for produced products sold
|
|
|
$
|
246,246
|
|
|
$
|
217,043
|
|
|
|
|
|
|
|
|
|
Total refinery operating expenses for produced products sold
|
|
|
$
|
246,246
|
|
|
$
|
217,043
|
|
|
Add other refining segment operating expenses and rounding(5)
|
|
|
10,869
|
|
|
11,719
|
|
|
Total refining segment operating expenses
|
|
|
257,115
|
|
|
228,762
|
|
|
Add PCLI segment operating expenses
|
|
|
36,029
|
|
|
—
|
|
|
Add HEP segment operating expenses
|
|
|
32,489
|
|
|
26,823
|
|
|
Add corporate and other costs
|
|
|
1,013
|
|
|
1,255
|
|
|
Subtract consolidations and eliminations
|
|
|
(19,529
|
)
|
|
(4,257
|
)
|
|
Operating expenses (exclusive of depreciation and amortization)
|
|
|
$
|
307,117
|
|
|
$
|
252,583
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reconciliation of net operating margin per
barrel to refinery gross margin per barrel to total sales and
other revenues
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended March 31,
|
|
|
|
2017
|
|
2016
|
|
|
|
(Dollars in thousands, except per barrel amounts)
|
|
Consolidated
|
|
|
|
|
|
Net operating margin per barrel
|
|
$
|
0.63
|
|
|
$
|
1.82
|
|
|
Add average refinery operating expenses per produced barrel
|
|
7.11
|
|
|
5.77
|
|
|
Refinery gross margin per barrel
|
|
7.74
|
|
|
7.59
|
|
|
Add average cost of products per produced barrel sold
|
|
58.88
|
|
|
38.85
|
|
|
Average sales price per produced barrel sold
|
|
$
|
66.62
|
|
|
$
|
46.44
|
|
|
Times sales of produced refined products (BPD)
|
|
384,820
|
|
|
413,360
|
|
|
Times number of days in period
|
|
90
|
|
|
91
|
|
|
Produced refined product sales
|
|
$
|
2,307,304
|
|
|
$
|
1,746,876
|
|
|
|
|
|
|
|
|
Total produced refined product sales
|
|
$
|
2,307,304
|
|
|
$
|
1,746,876
|
|
|
Add refined product sales from purchased products and rounding (1)
|
|
260,940
|
|
|
131,408
|
|
|
Total refined product sales
|
|
2,568,244
|
|
|
1,878,284
|
|
|
Add direct sales of excess crude oil (2)
|
|
258,741
|
|
|
90,918
|
|
|
Add other refining segment revenue (3)
|
|
35,091
|
|
|
30,385
|
|
|
Total refining segment revenue
|
|
2,862,076
|
|
|
1,999,587
|
|
|
Add PCLI segment sales and other revenues
|
|
201,940
|
|
|
—
|
|
|
Add HEP segment sales and other revenues
|
|
105,634
|
|
|
102,010
|
|
|
Add corporate and other revenues
|
|
27
|
|
|
110
|
|
|
Subtract consolidations and eliminations
|
|
(89,194
|
)
|
|
(82,983
|
)
|
|
Sales and other revenues
|
|
$
|
3,080,483
|
|
|
$
|
2,018,724
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
|
We purchase finished products to facilitate delivery to certain
locations or to meet delivery commitments.
|
|
|
(2)
|
|
We purchase crude oil that at times exceeds the supply needs of
our refineries. Quantities in excess of our needs are sold at
market prices to purchasers of crude oil that are recorded on a
gross basis with the sales price recorded as revenues and the
corresponding acquisition cost as inventory and then upon sale as
cost of products sold. Additionally, at times we enter into
buy/sell exchanges of crude oil with certain parties to facilitate
the delivery of quantities to certain locations that are netted at
cost.
|
|
|
(3)
|
|
Other refining segment revenue includes the incremental revenues
associated with HFC Asphalt, product purchased and sold forward
for profit as market conditions and available storage capacity
allows and miscellaneous revenue.
|
|
|
(4)
|
|
Other refining segment cost of products sold includes the
incremental cost of products for HFC Asphalt, the incremental cost
associated with storing product purchased and sold forward as
market conditions and available storage capacity allows and
miscellaneous costs.
|
|
|
(5)
|
|
Other refining segment operating expenses include the marketing
costs associated with our refining segment and the operating
expenses of HFC Asphalt.
|
View source version on businesswire.com: http://www.businesswire.com/news/home/20170503005522/en/
Source: HollyFrontier Corporation