Blueknight Energy Partners, L.P. (“BKEP” or the “Partnership”)
(NASDAQ: BKEP) (NASDAQ: BKEPP) today announced its financial
results for the three and twelve months ended December 31,
2016.
The Partnership reported net income of $2.0 million on total
revenues of $46.0 million for the three months ended December 31,
2016, compared to a net loss of $16.9 million on total revenues of
$43.9 million for the same period in 2015. BKEP recorded a net loss
of $4.8 million on total revenues of $177.4 million for the twelve
months ended December 31, 2016, compared to net income of $6.4
million on total revenues of $180.0 million for the same period in
2015. The Partnership reported operating income of $3.4 million for
the three months ended December 31, 2016, compared to an operating
loss of $16.8 million for the same period in 2015. BKEP reported
operating income of $6.5 million for the twelve months ended
December 31, 2016, compared to operating income of $14.0 million
for the twelve months ended December 31, 2015. Operating income for
the twelve months ended December 31, 2015 included $8.3 million in
income related to the settlement of a 2008 claim and litigation.
Net loss and operating income for the twelve months ended December
31, 2016 were impacted by impairment expense of $25.8 million,
primarily related to the cancellation of the Knight Warrior East
Texas Eaglebine/Woodbine crude oil pipeline project.
BKEP’s adjusted earnings before interest, taxes, depreciation,
amortization, non-cash equity-based compensation, asset impairment
charges, gains related to investments and fees related to the Ergon
transactions (“Adjusted EBITDA”) was $17.1 million for the three
months ended December 31, 2016, as compared to $14.1 million for
the same period in 2015, an increase of 21%. Adjusted EBITDA was
$69.8 million for the twelve months ended December 31, 2016,
compared to $70.1 million for the same period in 2015. Adjusted
EBITDA for the twelve months ended December 31, 2015, included a
$6.0 million gain related to the settlement of litigation. Adjusted
EBITDA, including a reconciliation of such measure to net income,
is explained in the section of this release entitled “Non-GAAP
Financial Measures.”
BKEP’s distributable cash flow was $10.5 million for the three
months ended December 31, 2016, as compared to $9.3 million for the
same period in 2015. Distributable cash flow for the twelve months
ended December 31, 2016 was $46.6 million, as compared to $54.2
million for the same period in 2015. In addition to the $6.0
million gain related to the settlement of litigation as mentioned
above, distributable cash flow for the twelve months ended December
31, 2015 included $2.3 million of cash proceeds received from the
settlement of a 2008 claim. Distributable cash flow for the three
and twelve months ended December 31, 2016 was impacted by fees
related to the Ergon transactions of $0.4 million and $1.8 million,
respectively. Distributable cash flow, including a reconciliation
of such measure to net income, is explained in the section of this
release entitled “Non-GAAP Financial Measures.”
BKEP previously announced a fourth quarter 2016 cash
distribution of $0.1450 per common unit, which is equal to the
previous quarter’s distribution. The Partnership also announced a
$0.17875 distribution per preferred unit. Additional information
regarding the Partnership’s results of operations will be provided
in the Partnership’s Annual Report on Form 10-K for the year ended
December 31, 2016, to be filed with the SEC on March 9, 2017.
Comments from BKEP CEO Mark Hurley:
“We delivered solid 2016 results and were able to make strategic
investments in our asphalt terminalling services business segment
further strengthening our presence as a terminal-centric,
infrastructure-focused company that can provide bulk storage,
transportation and terminalling services throughout the United
States. This capability was enhanced by the Ergon transaction that
was completed in October of 2016, whereby Ergon, a Jackson,
Mississippi based private company, purchased our General Partner
and sold nine asphalt product terminals to us. We own the largest
network of independently-owned asphalt terminals and have a partner
that is a leader in developing and marketing technologies and
products for road construction and preservation in addition to
numerous other logistics, refining and other energy and
infrastructure-related businesses. We are incredibly excited about
this partnership and believe it will lead to other growth projects
in addition to the previously mentioned anticipated asphalt
terminal drop downs in mid-2017 and 2018.
“Our 2016 operating margin, excluding depreciation and
amortization, increased 9% year over year to $83.0 million.
Adjusted EBITDA for the three months ended December 31, 2016 jumped
21% as compared to the same period in 2015, mostly due to the
closing of the Ergon acquisition on October 5, 2016. Adjusted
EBITDA for the year ended December 31, 2016 was in-line with
previous guidance, but essentially flat as compared to 2015.
However, keep in mind that 2015 adjusted EBITDA and distributable
cash flow included $8.3 million in income related to the settlement
of a 2008 claim and litigation.
“Our asphalt products terminalling business continues to perform
exceptionally well as evidenced by our operating margin, excluding
depreciation and amortization, which increased 18% from 2015 to
2016 after recording a 17% increase from 2014 to 2015. In February
2016, we acquired two asphalt terminalling facilities located in
Wilmington, North Carolina and Dumfries, Virginia and entered into
a long-term storage, throughput and handling agreement with Axeon
Marketing LLC. The Axeon transaction was followed by the closing of
the Ergon transaction in October of 2016, which added another nine
terminals to our footprint. Our asphalt terminalling business is
well positioned to take advantage of the increased infrastructure
spending we expect to see in the future.
“Terminalling services, comprised of both our asphalt and crude
oil terminalling segments, accounted for nearly 98% of our fourth
quarter’s total operating margin. These are fee-based,
highly-contracted businesses, and reflect our overall strategy to
invest in businesses with less volatility rather than volume and
price sensitive gathering and transportation businesses. We expect
a similar trend in 2017.
“Our pipeline and trucking and field services businesses
continue to face challenges due to the volatile crude oil market
and service suspension on one of our Oklahoma pipeline systems.
However, with the stabilization of the crude oil markets over the
last few months, we are seeing signs of increasing production in
Oklahoma and increased volumes on our trucks. We are also working
to restore service on our second Oklahoma pipeline and expect to
put that line into condensate service during the second half of
2017. We believe we can be successful in capturing additional
volume on both the condensate and Oklahoma mainline systems as
exploration and production activities rise in the promising STACK
and SCOOP plays.
“We continued our focus on managing costs as operating expenses
decreased by 13% in 2016 when compared to 2015, driven primarily
from the decision to exit the West Texas trucking market in
December 2015. Even though we exited West Texas, which also
decreased revenues, we were able to increase operating margin. In
addition general and administrative expenses decreased 4% year over
year, exclusive of $1.8 million in fees paid on the Ergon
transaction. We expect to continue to aggressively manage these
costs in 2017.
“We also place a priority on maintaining our overall balance
sheet strength and distribution coverage. Leverage at year end
trended slightly upward to 4.2 times as a result of the Ergon
transaction closing in October. We finished 2016 with distribution
coverage of 1.0 times (1.04 times before fees related to the Ergon
transactions). The distribution coverage for 2016 also includes
$1.0 million of distributions attributable to the common and
preferred units issued on October 5, 2016 associated with the
closing of the Ergon transaction. We expect leverage to hold steady
or decrease slightly from the current level as we proceed in
2017.
“On February 12, 2017, we announced that Advantage Pipeline
entered into a definitive agreement whereby Advantage Pipeline will
be acquired by a joint venture formed by affiliates of Plains All
American Pipeline, L.P. and Noble Midstream Partners LP. The
closing of the transaction is expected to occur in the first
quarter of 2017 and is subject to customary closing conditions. We
anticipate net cash proceeds of approximately $27.0 million to
$29.0 million from the sale of Advantage Pipeline.
“We continue to search for growth opportunities and are looking
to expand our terminalling network. We are also diligently working
to complete our Oklahoma condensate project in an effort to better
utilize our Oklahoma crude oil transportation and storage assets.
We will continue to look for or develop additional organic crude
oil opportunities both within and outside Oklahoma. We believe our
business is well positioned for growth and we believe that our new
partnership with Ergon will provide additional access to different
opportunities and we are aggressively exploring those as we move
forward into 2017.”
Results of Operations
The following table summarizes the financial results for the
three and twelve months ended December 31, 2015 and 2016 (in
thousands except per unit data):
Three Monthsended
December 31, Twelve Monthsended December
31, 2015 2016 2015
2016 (unaudited) Service revenue: Third party revenue
$ 32,543 $ 29,505 $ 137,415 $ 126,215 Related party revenue 7,828
11,606 39,103 30,211 Product sales revenue: Third party revenue
3,511 4,910 3,511
20,968 Total revenue 43,882 46,021
180,029 177,394 Costs and
expenses: Operating expense 30,529 30,779 127,974 111,091 Cost of
product sales 3,231 3,341 3,231 14,130 General and administrative
expense 4,589 5,580 18,976 20,029 Asset impairment expense
21,996 2,916 21,996
25,761 Total costs and expenses 60,345
42,616 172,177 171,011 Gain
(loss) on sale of assets (340 ) 23
6,137 108 Operating income (loss)
(16,803 ) 3,428 13,989 6,491
Other income (expense): Equity earnings in unconsolidated
affiliate 594 397 3,932 1,483 Interest expense (net of capitalized
interest of $32, $0, $184 and $41, respectively) (625 )
(1,813 ) (11,202 ) (12,554 ) Income (loss)
before income taxes (16,834 ) 2,012
6,719 (4,580 ) Provision for income taxes (26
) (61 ) (323 ) (260 ) Net income (loss) $
(16,860 ) $ 1,951 $ 6,396 $ (4,840 )
Allocation of net income (loss) for calculation of earnings per
unit: General partner interest in net income (loss) $ (164 ) $ 142
$ 554 $ 433 Preferred interest in net income $ 5,391 $ 8,766 $
21,564 $ 25,824 Net income (loss) available to limited partners $
(22,087 ) $ (6,957 ) $ (15,722 ) $ (31,097 ) Basic and
diluted net loss per common unit $ (0.65 ) $ (0.18 ) $ (0.47 ) $
(0.87 ) Weighted average common units outstanding - basic
and diluted 33,021 37,955 32,945 35,093
The table below summarizes our financial results by segment
operating margin, excluding depreciation and amortization, for the
three and twelve months ended December 31, 2015 and 2016 (dollars
in thousands):
Operating Results
Three MonthsendedDecember
31,
Twelve Monthsended December 31,
Favorable/(Unfavorable) Three Months
Twelve Months (in thousands) 2015
2016 2015 2016 $
% $ % Operating margin, excluding depreciation
and amortization Asphalt services operating margin $ 11,458 $
15,050 $ 48,212 $ 56,769 3,592 31 % 8,557 18 % Crude oil
terminalling and storage operating margin 4,651 4,741 18,842 20,048
90 2 % 1,206 6 % Crude oil pipeline services operating margin 1,885
453 7,694 4,347 (1,432 ) (76 )% (3,347 ) (44 )% Crude oil trucking
and producer field services operating margin (784 )
29 1,304 1,829 813 104 % 525 40 % Total
operating margin, excluding depreciation and amortization $ 17,210
$ 20,273 $ 76,052 $ 82,993 3,063 18 % 6,941 9
%
Non-GAAP Financial Measures
This press release contains the non-GAAP financial measures of
adjusted EBITDA, distributable cash flow and total operating
margin, excluding depreciation and amortization. Adjusted EBITDA is
defined as earnings before interest, income taxes, depreciation,
amortization, non-cash equity-based compensation, asset impairment
charges, gains related to investments and fees related to the Ergon
transactions. Distributable cash flow is defined as adjusted
EBITDA, plus or minus cash proceeds from sale of investments, cash
paid for interest, maintenance capital expenditures, cash paid for
taxes, and cash paid for fees related to the Ergon transactions.
Operating margin, excluding depreciation and amortization, is
defined as revenues from related parties and external customers
less operating expenses, excluding depreciation and amortization.
The use of adjusted EBITDA, distributable cash flow and total
operating margin, excluding depreciation and amortization, should
not be considered as alternatives to GAAP measures such as
operating income, net income or cash flows from operating
activities. Adjusted EBITDA, distributable cash flow and total
operating margin, excluding depreciation and amortization are
presented because the Partnership believes they provide additional
information with respect to its business activities and are used as
supplemental financial measures by management and external users of
the Partnership’s financial statements, such as investors,
commercial banks and others, to assess, among other things, the
Partnership’s operating performance and return on capital as
compared to those of other companies in the midstream energy
sector, without regard to financing or capital structure.
The following table presents a reconciliation of adjusted EBITDA
and distributable cash flow to net income (loss) for the periods
shown (in thousands):
Three Monthsended
December 31, Twelve Monthsended December
31, 2015 2016 2015
2016 Net income (loss) $ (16,860 ) $ 1,951 $ 6,396 $
(4,840 ) Interest expense 625 1,813 11,202 12,554 Gain related to
investments — — (267 ) — Income taxes 26 61 323 260 Depreciation
and amortization 7,087 8,372 27,228 30,820 Non-cash equity-based
compensation, including profits interest expense 823 1,578 2,825
3,417 Asset impairment charge and other 22,404 2,916 22,404 25,761
Fees related to the Ergon transactions — 394
— 1,783 Adjusted EBITDA $ 14,105
$ 17,085 $ 70,111 $ 69,755 Cash
proceeds from sale of investments — — 2,346 — Cash paid for
interest (2,569 ) (3,326 ) (9,915 ) (12,404 ) Cash paid for income
taxes (20 ) (23 ) (412 ) (282 ) Maintenance capital expenditures,
net of reimbursable expenditures (2,199 ) (2,862 ) (7,882 ) (8,724
) Fees related to the Ergon transactions —
(394 ) — (1,783 ) Distributable cash flow $
9,317 $ 10,480 $ 54,248 $ 46,562
Distribution declared (1) $ 10,598 $ 12,250 $ 42,019 $ 46,390
Distribution coverage ratio 0.9 0.9 1.3 1.0 ____________________
(1) Inclusive of preferred and common unit declared cash
distributions. Distributions declared in the three and twelve month
periods ended December 31, 2016 exclude $2.4 million of
distributions paid to Vitol and Charlesbank in conjunction with the
Partnership’s repurchase of 13.3 million Series A Preferred Units
from Vitol and Charlesbank; these distributions were reimbursed to
the Partnership in the form of a capital contribution from Ergon.
The following table presents a reconciliation of total operating
margin, excluding depreciation and amortization, to operating
income (loss) for the periods shown (in thousands):
Operating Results
Three Monthsended December 31, Twelve
Monthsended December 31,
Favorable/(Unfavorable)
(in thousands) 2015 2016
2015 2016 $ %
$ % Total operating margin, excluding
depreciation and amortization $ 17,210
$
20,273
$
76,052
$
82,993 3,063 18 % 6,941 9 % Depreciation and amortization (7,087 )
(8,372 ) (27,228 ) (30,820 ) (1,285 ) (18 )% (3,592 ) (13 )%
General and administrative expense (4,589 ) (5,580 ) (18,976 )
(20,029 ) (991 ) (22 )% (1,053 ) (6 )% Asset impairment expense
(21,996 ) (2,916 ) (21,996 ) (25,761 ) 19,080 87 % (3,765 ) (17 )%
Gain (loss) on sale of assets (340 ) 23
6,137 108 363 107 % (6,029 ) (98 )%
Operating income (loss) $ (16,802 ) $ 3,428 $ 13,989
$ 6,491 20,230 120 % (7,498 ) (54 )%
Investor Conference Call
The Partnership will discuss fourth quarter and full year 2016
results during a conference call on Thursday, March 9, 2017 at 1:30
p.m. CST (2:30 p.m. EST). The conference call will be accessible by
telephone at 1-888-347-8968. International participants will be
able to connect to the conference by calling 1-412-902-4231.
Participants are requested to dial in five to ten minutes prior
to the scheduled start time. An audio replay will be available
through the investors section of the Partnership’s website for 30
days.
Forward-Looking Statements
This release includes forward-looking statements. Statements
included in this release that are not historical facts (including,
without limitation, any statements about future financial and
operating results, guidance, projected or forecasted financial
results, objectives, project timing, expectations and intentions
and other statements that are not historical facts) are
forward-looking statements. Such forward-looking statements are
subject to various risks and uncertainties. These risks and
uncertainties include, among other things, uncertainties relating
to the Partnership’s debt levels and restrictions in its credit
facility, its exposure to the credit risk of our third-party
customers, the Partnership’s future cash flows and operations,
future market conditions, current and future governmental
regulation, future taxation and other factors discussed in the
Partnership’s filings with the Securities and Exchange Commission.
If any of these risks or uncertainties materializes, or should
underlying assumptions prove incorrect, actual results or outcomes
may vary materially from those expected. The Partnership undertakes
no obligation to publicly update or revise any forward-looking
statement, whether as a result of new information, future events or
otherwise.
About Blueknight Energy Partners, L.P.
BKEP owns and operates a diversified portfolio of complementary
midstream energy assets consisting of approximately 9.6 million
barrels of combined asphalt product and residual fuel oil storage
located at 54 terminals in 26 states, 7.4 million barrels of crude
oil storage located in Oklahoma and Texas, approximately 6.6
million barrels of which are located at the Cushing, Oklahoma,
Interchange, approximately 760 miles of crude oil pipeline located
primarily in Oklahoma and Texas and approximately 200 crude oil
transportation and oilfield services vehicles deployed in Kansas,
Oklahoma and Texas. BKEP provides integrated services for companies
engaged in the production, distribution and marketing of crude oil,
asphalt and other petroleum products. BKEP is headquartered in
Oklahoma City, Oklahoma. For more information, visit the
Partnership’s web site at www.bkep.com.
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BKEPInvestor Relations, 918-237-4032investor@bkep.comorMedia
Contact:Brent Gooden, 405-715-3232 or 405-818-1900
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