|
Holly Energy Partners, L.P. Reports Third Quarter Results
Holly Energy Partners, L.P. (“HEP” or the “Partnership”) (NYSE:HEP)
today reported financial results for the third quarter of 2015. For the
quarter, distributable cash flow was $50.3 million, up $4.7 million, or
10% compared to the third quarter of 2014. HEP announced its 44th consecutive
distribution increase on October 22, 2015, raising the quarterly
distribution from $0.545 to $0.555 per unit, which represents an
increase of 6.2% over the distribution for the third quarter of 2014.
Net income attributable to Holly Energy Partners for the third quarter
was $34.5 million ($0.40 per basic and diluted limited partner unit)
compared to $29.7 million ($0.35 per basic and diluted limited partner
unit) for the third quarter of 2014. The increase in earnings is
primarily due to higher pipeline and terminal volumes and annual tariff
increases.
Commenting on the third quarter of 2015, Mike Jennings, Chief Executive
Officer, stated, “We are pleased our financial results for the third
quarter of 2015 allowed us to maintain our record of raising quarterly
distributions. Recent performance and future prospects enabled us to
raise our distribution by a full $0.01 per unit this quarter. HEP’s
steady growth is supported by our fee-based commercial structure with
underlying long-term minimum commitments by our key customers.
"We continue to leverage our logistic capabilities and HollyFrontier
Corporation's refining footprint to create unique third party
acquisition opportunities like our acquisition of a 50% interest in the
Frontier Pipeline during the third quarter of 2015. In addition, we
completed our acquisition of dropdown assets including the naphtha
fractionation and hydrogen generation units at HollyFrontier's El Dorado
refinery as of November 1, 2015. This acquisition, which is supported by
a long-term contract with HollyFrontier, is 100% fee-based with no
commodity risk or exposure, like all of HEP's past acquisitions from
HollyFrontier.
"I am optimistic about HEP’s growth outlook given our talented
employees, high quality assets in traditionally favorable geographic
locations, and ongoing support from our general partner, HollyFrontier."
Third Quarter 2015 Revenue Highlights
Revenues for the quarter were $88.4 million, an increase of $6.3 million
compared to the third quarter of 2014 due to the effect of higher
pipeline volumes and annual tariff increases. Overall pipeline volumes
were up 22% compared to the three months ended September 30, 2014,
largely due to increased volumes from the New Mexico gathering system
expansion.
-
Revenues from our refined product pipelines were $31.0 million,
an increase of $2.3 million compared to the third quarter of 2014
mainly due to increased revenue from UNEV pipeline of $1.9 million in
addition to increased volumes and annual tariff increases. Shipments
averaged 197.8 mbpd compared to 188.0 mbpd for the third quarter of
2014.
-
Revenues from our intermediate pipelines were $7.5 million, an
increase of $0.5 million, on shipments averaging 148.8 mbpd compared
to 139.5 mbpd for the third quarter of 2014. Revenues increased mainly
due to an increase in volumes and annual tariff increases.
-
Revenues from our crude pipelines were $17.4 million, an
increase of $2.8 million, on shipments averaging 297.8 mbpd compared
to 199.6 mbpd for the third quarter of 2014. Revenues increased mainly
due to a $1.6 million increase in revenue from the New Mexico
gathering system expansion. The increase in volumes is due to
increased crude production in the Artesia Basin as well as the
reversal of the Roadrunner pipeline, which made it possible for HFC to
purchase and HEP to transport crude volumes in excess of HFC refining
capacity.
-
Revenues from terminal, tankage and loading rack fees were
$32.5 million, an increase of $0.7 million compared to the third
quarter of 2014. Refined products terminalled in our facilities
averaged 370.9 mbpd compared to 325.9 mbpd for the third quarter of
2014. Revenues increased due to our first quarter 2015 acquisition of
an existing crude tank farm adjacent to HFC's El Dorado refinery as
well as increased volumes and annual tariff increases.
Revenues for the three months ended September 30, 2015, include the
recognition of $0.6 million of prior shortfalls billed to shippers in
2014 as they did not meet their minimum volume commitments within the
contractual make-up period. As of September 30, 2015, shortfall deferred
revenue in our consolidated balance sheet was $7.8 million. Such
deferred revenue will be recognized in earnings either as (a) payment
for shipments in excess of guaranteed levels, if and to the extent the
pipeline system has the necessary capacity for shipments in excess of
guaranteed levels, or (b) when shipping rights expire unused over the
contractual make-up period.
Nine Months Ended September 30, 2015 Revenue Highlights
Revenues for the nine months ended September 30, 2015, were $261.6
million, an increase of $17.5 million compared to the nine months ended
September 30, 2014. This is due principally to the effect of annual
tariff increases and increased pipeline shipments largely due to
increased volumes from the New Mexico gathering system expansion.
-
Revenues from our refined product pipelines were $96.8 million,
an increase of $7.2 million primarily due to increased volumes and
annual tariff increases. Shipments averaged 193.5 mbpd compared to
180.2 mbpd for the nine months ended September 30, 2014, largely due
to lower volumes in the second quarter of 2014 resulting from major
maintenance performed at Alon's Big Spring refinery as well as higher
spot volumes on our UNEV pipeline.
-
Revenues from our intermediate pipelines were $21.5 million, a
decrease of $0.1 million, on shipments averaging 143.4 mbpd compared
to 140.5 mbpd for the nine months ended September 30, 2014. The
decrease in revenue was due to the effects of a $0.7 million decrease
in deferred revenue realized offset by higher volumes and annual
tariff increases.
-
Revenues from our crude pipelines were $49.5 million, an
increase of $9.3 million, on shipments averaging 292.2 mbpd compared
to 185.1 mbpd for the nine months ended September 30, 2014. Revenues
increased due to the annual tariff increases and increased volume in
addition to $5.8 million in increased revenue from the New Mexico
gathering system expansion.
-
Revenues from terminal, tankage and loading rack fees were
$93.9 million, an increase of $1.1 million compared to the nine months
ended September 30, 2014. This increase is due to annual fee increases
and increased terminal volumes. Refined products terminalled in our
facilities averaged 359.3 mbpd compared to 330.6 mbpd for the nine
months ended September 30, 2014, largely due to lower volumes in the
second quarter of 2014 resulting from major maintenance performed at
Alon's Big Spring refinery.
Revenues for the nine months ended September 30, 2015, include the
recognition of $8.6 million of prior shortfalls billed to shippers in
2014, as they did not meet their minimum volume commitments within the
contractual make-up period.
Operating Costs and Expenses Highlights
Operating costs and expenses were $44.1 million and $133.1 million for
the three and the nine months ended September 30, 2015, respectively,
representing an increase of $0.9 million from the three months ended
September 30, 2014, and an increase of $5.4 million from the nine months
ended September 30, 2014. The increase for the nine months ended
September 30, 2015, is primarily due to higher maintenance project
expenses of $6.8 million and an increase in environmental remediation
provisions, net of recovery from third parties, of $1.7 million offset
by lower employee costs of $3.5 million as a result of the secondment of
employees in El Dorado and Cheyenne.
Interest expense was $9.5 million and $27.3 million for the three and
the nine months ended September 30, 2015, respectively, representing an
increase of $0.9 million and a decrease of $0.1 million over the same
periods of 2014. The increase for the three months ended September 30,
2015, is due to an increase in borrowings under our credit agreement.
The decrease for the nine months ended September 30, 2015, is
principally due to the early extinguishment of our 8.25% Senior Notes in
March 2014.
We have scheduled a webcast conference call today at 4:00 PM Eastern
Time to discuss financial results. This webcast may be accessed at: https://event.webcasts.com/starthere.jsp?ei=1079834.
An audio archive of this webcast will be available using the above noted
link through November 18, 2015.
About Holly Energy Partners, L.P.
Holly Energy Partners, L.P., headquartered in Dallas, Texas, provides
petroleum product and crude oil transportation, terminalling, storage
and throughput services to the petroleum industry, including
HollyFrontier Corporation subsidiaries. The Partnership owns and
operates petroleum product and crude gathering pipelines, tankage and
terminals in Texas, New Mexico, Arizona, Washington, Idaho, Oklahoma,
Utah, Wyoming and Kansas. In addition, the Partnership owns a 75%
interest in UNEV Pipeline, LLC, the owner of a Holly Energy operated
refined products pipeline running from Salt Lake City, Utah to Las
Vegas, Nevada, and related product terminals; a 50% interest in Frontier
Pipeline Company, the owner of a 289-mile crude oil pipeline running
from Casper, Wyoming to Frontier Station, Utah; and a 25% interest in
SLC Pipeline LLC, the owner of a 95-mile intrastate pipeline system
serving refineries in the Salt Lake City, Utah area.
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, a 125,000 bpsd refinery in Tulsa, Oklahoma, a 100,000 bpsd
refinery located in Artesia, New Mexico, a 52,000 bpsd refinery located
in Cheyenne, Wyoming, and a 31,000 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. A subsidiary of HollyFrontier also owns
a 39% interest (including the general partner interest) in Holly Energy
Partners, L.P.
The statements in this press release relating to matters that are not
historical facts are “forward-looking statements” within the meaning of
the federal securities laws. 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 our beliefs and assumptions
and those of our general partner using currently available information
and expectations as of the date hereof, are not guarantees of future
performance and involve certain risks and uncertainties. Although we and
our general partner believe that such expectations reflected in such
forward-looking statements are reasonable, neither we nor our general
partner can give assurance that our expectations will prove to be
correct. 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. Our
forward-looking statements are subject to a variety of risks,
uncertainties and assumptions. If one or more of these risks or
uncertainties materialize, or if underlying assumptions prove incorrect,
our actual results may vary materially from those anticipated,
estimated, projected or expected. Certain factors could cause actual
results to differ materially from results anticipated in the
forward-looking-statements. These factors include, but are not limited
to:
-
risks and uncertainties with respect to the actual quantities of
petroleum products and crude oil shipped on our pipelines and/or
terminalled, stored and throughput in our terminals;
-
the economic viability of HollyFrontier Corporation, Alon USA, Inc.
and our other customers;
-
the demand for refined petroleum products in markets we serve;
-
our ability to purchase and integrate future acquired operations;
-
our ability to complete previously announced or contemplated
acquisitions;
-
the availability and cost of additional debt and equity financing;
-
the possibility of reductions in production or shutdowns at refineries
utilizing our pipeline and terminal facilities;
-
the effects of current and future government regulations and policies;
-
our operational efficiency in carrying out routine operations and
capital construction projects;
-
the possibility of terrorist attacks and the consequences of any such
attacks;
-
general economic conditions; and
-
other financial, operations and legal risks and uncertainties detailed
from time to time in our 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.
RESULTS OF OPERATIONS (Unaudited)
Income, Distributable Cash Flow and Volumes
The following tables present income, distributable cash flow and volume
information for the three and the nine months ended September 30, 2015
and 2014.
|
|
|
|
Three Months Ended
September 30,
|
|
|
Change from
|
|
|
|
|
2015
|
|
|
2014
|
|
|
2014
|
|
|
|
|
(In thousands, except per unit data)
|
|
Revenues
|
|
|
|
|
|
|
|
|
|
|
Pipelines:
|
|
|
|
|
|
|
|
|
|
|
Affiliates – refined product pipelines
|
|
|
$
|
19,945
|
|
|
|
$
|
17,811
|
|
|
|
$
|
2,134
|
|
|
Affiliates – intermediate pipelines
|
|
|
|
7,488
|
|
|
|
|
7,038
|
|
|
|
|
450
|
|
|
Affiliates – crude pipelines
|
|
|
|
17,393
|
|
|
|
|
14,557
|
|
|
|
|
2,836
|
|
|
|
|
|
|
44,826
|
|
|
|
|
39,406
|
|
|
|
|
5,420
|
|
|
Third parties – refined product pipelines
|
|
|
|
11,095
|
|
|
|
|
10,939
|
|
|
|
|
156
|
|
|
|
|
|
|
55,921
|
|
|
|
|
50,345
|
|
|
|
|
5,576
|
|
|
Terminals, tanks and loading racks:
|
|
|
|
|
|
|
|
|
|
|
Affiliates
|
|
|
|
28,890
|
|
|
|
|
28,044
|
|
|
|
|
846
|
|
|
Third parties
|
|
|
|
3,578
|
|
|
|
|
3,741
|
|
|
|
|
(163
|
)
|
|
|
|
|
|
32,468
|
|
|
|
|
31,785
|
|
|
|
|
683
|
|
|
Total revenues
|
|
|
|
88,389
|
|
|
|
|
82,130
|
|
|
|
|
6,259
|
|
|
Operating costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
Operations
|
|
|
|
24,095
|
|
|
|
|
25,456
|
|
|
|
|
(1,361
|
)
|
|
Depreciation and amortization
|
|
|
|
16,326
|
|
|
|
|
15,483
|
|
|
|
|
843
|
|
|
General and administrative
|
|
|
|
3,673
|
|
|
|
|
2,266
|
|
|
|
|
1,407
|
|
|
|
|
|
|
44,094
|
|
|
|
|
43,205
|
|
|
|
|
889
|
|
|
Operating income
|
|
|
|
44,295
|
|
|
|
|
38,925
|
|
|
|
|
5,370
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Equity in earnings of equity method investments
|
|
|
|
1,269
|
|
|
|
|
880
|
|
|
|
|
389
|
|
|
Interest expense, including amortization
|
|
|
|
(9,486
|
)
|
|
|
|
(8,585
|
)
|
|
|
|
(901
|
)
|
|
Interest income
|
|
|
|
381
|
|
|
|
|
—
|
|
|
|
|
381
|
|
|
Other income
|
|
|
|
176
|
|
|
|
|
11
|
|
|
|
|
165
|
|
|
|
|
|
|
(7,660
|
)
|
|
|
|
(7,694
|
)
|
|
|
|
34
|
|
|
Income before income taxes
|
|
|
|
36,635
|
|
|
|
|
31,231
|
|
|
|
|
5,404
|
|
|
State income tax expense
|
|
|
|
(69
|
)
|
|
|
|
(42
|
)
|
|
|
|
(27
|
)
|
|
Net income
|
|
|
|
36,566
|
|
|
|
|
31,189
|
|
|
|
|
5,377
|
|
|
Allocation of net income attributable to noncontrolling interests
|
|
|
|
(2,081
|
)
|
|
|
|
(1,509
|
)
|
|
|
|
(572
|
)
|
|
Net income attributable to Holly Energy Partners
|
|
|
|
34,485
|
|
|
|
|
29,680
|
|
|
|
|
4,805
|
|
|
General partner interest in net income, including incentive
distributions(1)
|
|
|
|
(10,830
|
)
|
|
|
|
(8,940
|
)
|
|
|
|
(1,890
|
)
|
|
Limited partners’ interest in net income
|
|
|
$
|
23,655
|
|
|
|
$
|
20,740
|
|
|
|
$
|
2,915
|
|
|
Limited partners’ earnings per unit – basic and diluted:(1)
|
|
|
$
|
0.40
|
|
|
|
$
|
0.35
|
|
|
|
$
|
0.05
|
|
|
Weighted average limited partners’ units outstanding
|
|
|
|
58,657
|
|
|
|
|
58,657
|
|
|
|
|
—
|
|
|
EBITDA(2)
|
|
|
$
|
59,985
|
|
|
|
$
|
53,790
|
|
|
|
$
|
6,195
|
|
|
Distributable cash flow(3)
|
|
|
$
|
50,306
|
|
|
|
$
|
45,581
|
|
|
|
$
|
4,725
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Volumes (bpd)
|
|
|
|
|
|
|
|
|
|
|
Pipelines:
|
|
|
|
|
|
|
|
|
|
|
Affiliates – refined product pipelines
|
|
|
|
127,151
|
|
|
|
|
116,727
|
|
|
|
|
10,424
|
|
|
Affiliates – intermediate pipelines
|
|
|
|
148,753
|
|
|
|
|
139,502
|
|
|
|
|
9,251
|
|
|
Affiliates – crude pipelines
|
|
|
|
297,810
|
|
|
|
|
199,627
|
|
|
|
|
98,183
|
|
|
|
|
|
|
573,714
|
|
|
|
|
455,856
|
|
|
|
|
117,858
|
|
|
Third parties – refined product pipelines
|
|
|
|
70,675
|
|
|
|
|
71,271
|
|
|
|
|
(596
|
)
|
|
|
|
|
|
644,389
|
|
|
|
|
527,127
|
|
|
|
|
117,262
|
|
|
Terminals and loading racks:
|
|
|
|
|
|
|
|
|
|
|
Affiliates
|
|
|
|
293,074
|
|
|
|
|
255,556
|
|
|
|
|
37,518
|
|
|
Third parties
|
|
|
|
77,869
|
|
|
|
|
70,364
|
|
|
|
|
7,505
|
|
|
|
|
|
|
370,943
|
|
|
|
|
325,920
|
|
|
|
|
45,023
|
|
|
Total for pipelines and terminal assets (bpd)
|
|
|
|
1,015,332
|
|
|
|
|
853,047
|
|
|
|
|
162,285
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended
September 30,
|
|
|
Change from
|
|
|
|
|
2015
|
|
|
2014
|
|
|
2014
|
|
|
|
|
(In thousands, except per unit data)
|
|
Revenues
|
|
|
|
|
|
|
|
|
|
|
Pipelines:
|
|
|
|
|
|
|
|
|
|
|
Affiliates—refined product pipelines
|
|
|
$
|
60,731
|
|
|
|
$
|
59,520
|
|
|
|
$
|
1,211
|
|
|
Affiliates—intermediate pipelines
|
|
|
|
21,522
|
|
|
|
|
21,632
|
|
|
|
|
(110
|
)
|
|
Affiliates—crude pipelines
|
|
|
|
49,483
|
|
|
|
|
40,207
|
|
|
|
|
9,276
|
|
|
|
|
|
|
131,736
|
|
|
|
|
121,359
|
|
|
|
|
10,377
|
|
|
Third parties—refined product pipelines
|
|
|
|
36,031
|
|
|
|
|
30,037
|
|
|
|
|
5,994
|
|
|
|
|
|
|
167,767
|
|
|
|
|
151,396
|
|
|
|
|
16,371
|
|
|
Terminals, tanks and loading racks:
|
|
|
|
|
|
|
|
|
|
|
Affiliates
|
|
|
|
82,532
|
|
|
|
|
82,403
|
|
|
|
|
129
|
|
|
Third parties
|
|
|
|
11,325
|
|
|
|
|
10,333
|
|
|
|
|
992
|
|
|
|
|
|
|
93,857
|
|
|
|
|
92,736
|
|
|
|
|
1,121
|
|
|
Total revenues
|
|
|
|
261,624
|
|
|
|
|
244,132
|
|
|
|
|
17,492
|
|
|
Operating costs and expenses
|
|
|
|
|
|
|
|
|
|
|
Operations
|
|
|
|
77,350
|
|
|
|
|
72,835
|
|
|
|
|
4,515
|
|
|
Depreciation and amortization
|
|
|
|
46,083
|
|
|
|
|
46,953
|
|
|
|
|
(870
|
)
|
|
General and administrative
|
|
|
|
9,659
|
|
|
|
|
7,933
|
|
|
|
|
1,726
|
|
|
|
|
|
|
133,092
|
|
|
|
|
127,721
|
|
|
|
|
5,371
|
|
|
Operating income
|
|
|
|
128,532
|
|
|
|
|
116,411
|
|
|
|
|
12,121
|
|
|
Equity in earnings of equity method investments
|
|
|
|
2,634
|
|
|
|
|
2,150
|
|
|
|
|
484
|
|
|
Interest expense, including amortization
|
|
|
|
(27,310
|
)
|
|
|
|
(27,368
|
)
|
|
|
|
58
|
|
|
Interest income
|
|
|
|
384
|
|
|
|
|
3
|
|
|
|
|
381
|
|
|
Loss on early extinguishment of debt
|
|
|
|
—
|
|
|
|
|
(7,677
|
)
|
|
|
|
7,677
|
|
|
Other
|
|
|
|
406
|
|
|
|
|
45
|
|
|
|
|
361
|
|
|
|
|
|
|
(23,886
|
)
|
|
|
|
(32,847
|
)
|
|
|
|
8,961
|
|
|
Income before income taxes
|
|
|
|
104,646
|
|
|
|
|
83,564
|
|
|
|
|
21,082
|
|
|
State income tax expense
|
|
|
|
(106
|
)
|
|
|
|
(145
|
)
|
|
|
|
39
|
|
|
Net income
|
|
|
|
104,540
|
|
|
|
|
83,419
|
|
|
|
|
21,121
|
|
|
Allocation of net income attributable to noncontrolling interests
|
|
|
|
(7,851
|
)
|
|
|
|
(6,562
|
)
|
|
|
|
(1,289
|
)
|
|
Net income attributable to Holly Energy Partners
|
|
|
|
96,689
|
|
|
|
|
76,857
|
|
|
|
|
19,832
|
|
|
General partner interest in net income, including incentive
distributions (1)
|
|
|
|
(30,835
|
)
|
|
|
|
(25,334
|
)
|
|
|
|
(5,501
|
)
|
|
Limited partners’ interest in net income
|
|
|
$
|
65,854
|
|
|
|
$
|
51,523
|
|
|
|
$
|
14,331
|
|
|
Limited partners’ earnings per unit—basic and diluted (1)
|
|
|
$
|
1.11
|
|
|
|
$
|
0.87
|
|
|
|
$
|
0.24
|
|
|
Weighted average limited partners’ units outstanding
|
|
|
|
58,657
|
|
|
|
|
58,657
|
|
|
|
|
—
|
|
|
EBITDA (2)
|
|
|
$
|
169,804
|
|
|
|
$
|
158,997
|
|
|
|
$
|
10,807
|
|
|
Distributable cash flow (3)
|
|
|
$
|
143,495
|
|
|
|
$
|
130,883
|
|
|
|
$
|
12,612
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Volumes (bpd)
|
|
|
|
|
|
|
|
|
|
|
Pipelines:
|
|
|
|
|
|
|
|
|
|
|
Affiliates—refined product pipelines
|
|
|
|
121,564
|
|
|
|
|
119,718
|
|
|
|
|
1,846
|
|
|
Affiliates—intermediate pipelines
|
|
|
|
143,361
|
|
|
|
|
140,505
|
|
|
|
|
2,856
|
|
|
Affiliates—crude pipelines
|
|
|
|
292,158
|
|
|
|
|
185,131
|
|
|
|
|
107,027
|
|
|
|
|
|
|
557,083
|
|
|
|
|
445,354
|
|
|
|
|
111,729
|
|
|
Third parties—refined product pipelines
|
|
|
|
71,915
|
|
|
|
|
60,492
|
|
|
|
|
11,423
|
|
|
|
|
|
|
628,998
|
|
|
|
|
505,846
|
|
|
|
|
123,152
|
|
|
Terminals and loading racks:
|
|
|
|
|
|
|
|
|
|
|
Affiliates
|
|
|
|
282,299
|
|
|
|
|
262,458
|
|
|
|
|
19,841
|
|
|
Third parties
|
|
|
|
77,011
|
|
|
|
|
68,185
|
|
|
|
|
8,826
|
|
|
|
|
|
|
359,310
|
|
|
|
|
330,643
|
|
|
|
|
28,667
|
|
|
Total for pipelines and terminal assets (bpd)
|
|
|
|
988,308
|
|
|
|
|
836,489
|
|
|
|
|
151,819
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30,
|
|
|
December 31,
|
|
|
|
|
2015
|
|
|
2014
|
|
|
|
|
(In thousands)
|
|
Balance Sheet Data
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
|
$
|
10,856
|
|
|
$
|
2,830
|
|
Working capital
|
|
|
$
|
13,857
|
|
|
$
|
3,140
|
|
Total assets
|
|
|
$
|
1,466,029
|
|
|
$
|
1,401,555
|
|
Long-term debt
|
|
|
$
|
951,067
|
|
|
$
|
867,579
|
|
Partners' equity(4)
|
|
|
$
|
293,797
|
|
|
$
|
320,362
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
|
Net income attributable to Holly Energy Partners is allocated
between limited partners and the general partner interest in
accordance with the provisions of the partnership agreement. Net
income allocated to the general partner includes incentive
distributions declared subsequent to quarter end. General partner
incentive distributions were $10.3 million and $8.5 million for the
three months ended September 30, 2015 and 2014, respectively, and
$29.5 million and $24.3 million for the nine months ended September
30, 2015 and 2014, respectively.
|
|
|
|
(2)
|
|
Earnings before interest, taxes, depreciation and amortization
(“EBITDA”) is calculated as net income attributable to Holly Energy
Partners plus (i) interest expense and loss on early extinguishment
of debt, net of interest income, (ii) state income tax and (iii)
depreciation and amortization. EBITDA is not a calculation based
upon 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 attributable to Holly Energy Partners 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 also is used by our management for internal
analysis and as a basis for compliance with financial covenants.
|
|
|
|
|
|
Set forth below is our calculation of EBITDA.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
September 30,
|
|
|
|
Nine Months Ended
September 30,
|
|
|
|
|
2015
|
|
|
2014
|
|
|
|
2015
|
|
|
2014
|
|
|
|
|
(In thousands)
|
|
Net income attributable to Holly Energy Partners
|
|
|
$
|
34,485
|
|
|
|
$
|
29,680
|
|
|
|
$
|
96,689
|
|
|
|
$
|
76,857
|
|
|
Add (subtract):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
|
8,992
|
|
|
|
|
8,148
|
|
|
|
|
25,885
|
|
|
|
|
25,984
|
|
|
Interest Income
|
|
|
|
(381
|
)
|
|
|
|
—
|
|
|
|
|
(384
|
)
|
|
|
|
(3
|
)
|
|
Amortization of discount and deferred debt charges
|
|
|
|
494
|
|
|
|
|
437
|
|
|
|
|
1,425
|
|
|
|
|
1,384
|
|
|
Loss on early extinguishment of debt
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
|
7,677
|
|
|
State income tax expense
|
|
|
|
69
|
|
|
|
|
42
|
|
|
|
|
106
|
|
|
|
|
145
|
|
|
Depreciation and amortization
|
|
|
|
16,326
|
|
|
|
|
15,483
|
|
|
|
|
46,083
|
|
|
|
|
46,953
|
|
|
EBITDA
|
|
|
$
|
59,985
|
|
|
|
$
|
53,790
|
|
|
|
$
|
169,804
|
|
|
|
$
|
158,997
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(3)
|
|
Distributable cash flow is not a calculation based upon GAAP.
However, the amounts included in the calculation are derived from
amounts presented in our consolidated financial statements, with the
general exception of maintenance capital expenditures. Distributable
cash flow should not be considered in isolation or as an alternative
to net income attributable to Holly Energy Partners or operating
income, as an indication of our operating performance, or as an
alternative to operating cash flow as a measure of liquidity.
Distributable cash flow is not necessarily comparable to similarly
titled measures of other companies. Distributable cash flow is
presented here because it is a widely accepted financial indicator
used by investors to compare partnership performance. It is also
used by management for internal analysis and our performance units.
We believe that this measure provides investors an enhanced
perspective of the operating performance of our assets and the cash
our business is generating.
|
|
|
|
|
|
Set forth below is our calculation of distributable cash flow.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
September 30,
|
|
|
|
Nine Months Ended
September 30,
|
|
|
|
|
2015
|
|
|
2014
|
|
|
|
2015
|
|
|
2014
|
|
|
|
|
(In thousands)
|
|
Net income attributable to Holly Energy Partners
|
|
|
$
|
34,485
|
|
|
|
$
|
29,680
|
|
|
|
|
$
|
96,689
|
|
|
|
$
|
76,857
|
|
|
Add (subtract):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation and amortization
|
|
|
|
16,326
|
|
|
|
|
15,483
|
|
|
|
|
|
46,083
|
|
|
|
|
46,953
|
|
|
Amortization of discount and deferred debt charges
|
|
|
|
494
|
|
|
|
|
437
|
|
|
|
|
|
1,425
|
|
|
|
|
1,384
|
|
|
Loss on early extinguishment of debt
|
|
|
|
—
|
|
|
|
|
—
|
|
|
|
|
|
—
|
|
|
|
|
7,677
|
|
|
Increase (decrease) in deferred revenue attributable to shortfall
billings
|
|
|
|
1,152
|
|
|
|
|
1,090
|
|
|
|
|
|
(1,043
|
)
|
|
|
|
(49
|
)
|
|
Maintenance capital expenditures*
|
|
|
|
(2,121
|
)
|
|
|
|
(653
|
)
|
|
|
|
|
(5,640
|
)
|
|
|
|
(2,344
|
)
|
|
Increase (decrease) in environmental liability
|
|
|
|
(526
|
)
|
|
|
|
(657
|
)
|
|
|
|
|
2,944
|
|
|
|
|
(296
|
)
|
|
Increase (decrease) in reimbursable deferred revenue
|
|
|
|
(321
|
)
|
|
|
|
(676
|
)
|
|
|
|
|
671
|
|
|
|
|
(1,887
|
)
|
|
Other non-cash adjustments
|
|
|
|
817
|
|
|
|
|
877
|
|
|
|
|
|
2,366
|
|
|
|
|
2,588
|
|
|
Distributable cash flow
|
|
|
$
|
50,306
|
|
|
|
$
|
45,581
|
|
|
|
|
$
|
143,495
|
|
|
|
$
|
130,883
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
Maintenance capital expenditures are capital expenditures made to
replace partially or fully depreciated assets in order to maintain
the existing operating capacity of our assets and to extend their
useful lives. Maintenance capital expenditures include expenditures
required to maintain equipment reliability, tankage and pipeline
integrity, and safety and to address environmental regulations.
|
|
|
|
(4)
|
|
As a master limited partnership, we distribute our available cash,
which historically has exceeded our net income attributable to Holly
Energy Partners because depreciation and amortization expense
represents a non-cash charge against income. The result is a decline
in partners’ equity since our regular quarterly distributions have
exceeded our quarterly net income attributable to Holly Energy
Partners. Additionally, if the assets contributed and acquired from
HollyFrontier while we were a consolidated variable interest entity
of HollyFrontier had been acquired from third parties, our
acquisition cost in excess of HollyFrontier’s basis in the
transferred assets of $305.3 million would have been recorded as
increases to our properties and equipment and intangible assets at
the time of acquisition instead of decreases to partners’ equity.
|
View source version on businesswire.com: http://www.businesswire.com/news/home/20151104005445/en/ Copyright Business Wire 2015
Source: Business Wire
(November 4, 2015 - 6:30 AM EST)
News by QuoteMedia
www.quotemedia.com
|
