Alta Mesa Resources, Inc., (NASDAQ:AMR) (“Alta Mesa Resources”, the
“Company” or “Alta Mesa”) today announced 2018 production and capex
guidance estimates for its wholly owned subsidiaries, Alta Mesa
Holdings, LP (“AMHLP”) and Kingfisher Midstream, LLC
(“Kingfisher”). In addition, AMHLP reported its financial results
for the fourth quarter and full year of 2017. A conference call to
discuss these items is scheduled for today at 10 a.m. central time
(888-347-8149). Prior to the call, a supplemental slide deck to be
used on the call will be available in the investor relations
portion of the Company’s website at www.altamesa.net.
- Alta Mesa’s total capital expenditures for 2018 are expected to
range from $725 million to $800 million, including AMHLP STACK
production facilities and Kingfisher midstream facilities
(excluding acquisitions). Capital will be allocated primarily to
AMHLP’s upstream STACK area, $550 million to $580 million, with the
remaining balance being allocated to Kingfisher, $175 million to
$220 million;
- AMHLP’s full-year 2017 STACK production was approximately 20.6
MBOE per day, a 58% increase over 2016 production of approximately
13.1 MBOE per day. Fourth quarter 2017 AMHLP STACK production was
approximately 22.1 MBOE per day, a 47% increase over fourth quarter
2016 production of approximately 15.1 MBOE per day. AMHLP’s
production in the STACK has grown at a five-year compound annual
growth rate of over 80%;
- For 2018, AMHLP forecasts total STACK production to average 33
to 38 MBOE per day, representing an estimated year-over-year growth
of 70% at the midpoint, compared to 2017 STACK
production;
- AMHLP’s year-end 2017 Proved Reserves in the STACK were 176.2
MMBOE, an increase of 46.6 MMBOE, or 36% over year-end
2016;
- AMHLP drilled and completed 134 gross wells in the STACK in
2017, of which 37 gross wells were funded by the joint development
agreement with Bayou City Energy;
- Kingfisher’s 2018 projected Net Income is expected to range
between $81.2 million and $96.2 million and projected EBITDA is
expected to range between $95 million and $110 million (based on
consolidating financial statements), and capital expenditures are
expected to range from $175 million to $215 million. EBITDA is a
non-GAAP measure and is explained in greater detail under “Non-GAAP
Financial Information and Reconciliation.”
Hal Chappelle, Alta Mesa’s Chief Executive
Officer, said, “2017 was a year of significant progress for our
company marked by several important milestones that we believe has
set us up for success in 2018 and beyond. We achieved
year-over-year growth in our production, reserves and EBITDAX; we
have de-risked our acreage with over 250 operated horizontal wells
and a comprehensive scientific and engineering effort to begin
systematic development with multi-well patterns. Creating Alta Mesa
Resources with the upstream assets of Alta Mesa Holdings and
midstream assets of Kingfisher, we believe we have a strong balance
sheet that will allow us to execute on our vision for years to
come.”
AMHLP Upstream STACK Play
Activities
In AMHLP’s STACK play, the company has assembled
a highly contiguous leasehold position of over 130,000 net acres.
In the fourth quarter of 2017, AMHLP completed 36 horizontal wells
in the Osage and Meramec formations. AMHLP had 43 horizontal wells
in progress as of the end of the fourth quarter, 22 of which were
on production subsequent to the end of the quarter. AMHLP currently
has seven rigs operating in the STACK play, with a contracted
eighth rig arriving in April and plans to maintain this level for
the balance of 2018. In total, AMHLP plans to drill between 170 and
180 gross wells during the year. We expect drilling and completion
costs on these wells to average $3.8 million and our type curve has
been approximately 650 MBOE per well. Additionally, we are
intending to deploy approximately $25 million in early 2018 to
expand our fresh water supply system.
Kingfisher Midstream
Activities
The initial Kingfisher 60 MMcf per plant has
been operating at capacity since late 2017 and the 200 MMcf per day
plant expansion is now mechanically complete, with the cryogenic
plant operation set to begin in April. Once the expansion plant is
fully operational, Kingfisher’s operated inlet capacity will be 260
MMcf per day, bringing the total system capacity to 350 MMcf per
day when including the additional 90 MMcf per day of additional
contracted offtake and processing capacity. In late 2017 and early
2018, drilling and completions by third party E&P operators
under contract with Kingfisher slowed considerably. This slowdown
in development by third party groups is reflected in the revised
throughput estimates for 2018. Currently, Kingfisher has more than
300 miles of low-pressure crude and gas gathering lines,
approximately 125 miles of high pressure gas transportation
pipelines and a 50,000 barrel crude storage capacity with six truck
loading LACTS along with three 90,000 gallon bullet tanks for NGL
storage.
James Hackett, Alta Mesa Executive Chairman and
Kingfisher Chief Operating Officer stated, “Despite the delays in
volumes due to changes in third party drilling and completion
schedules on dedicated acreage and a later closing of our merger,
Kingfisher Midstream is well conceived to provide right-sized,
scalable gas gathering and processing and market interface, and is
situated to serve growing production in the STACK. 2017 saw
Kingfisher Midstream establish and grow its service to producers.
Acreage dedications and customer service, combined with
differentiated access to interstate markets, are our fundamental
strengths. We are building a strong management team for Kingfisher
Midstream to both earn business, and to offer the market proven,
experienced leadership for what we expect will be a separate public
company.”
AMHLP Fourth Quarter and Full-Year 2017
Financial and Production Results
During the fourth quarter of 2017, AMHLP sold
its Weeks Island field. Results of operations for Weeks Island
field are reflected as discontinued operations in our consolidated
financial statement for all periods presented. Operating revenues
and expenses for all periods exclude discontinued operations in the
Weeks Island field.
Net loss from continuing operations for the
fourth quarter of 2017 was $40.8 million, compared to a net loss
from continuing operations of $47.3 million for the fourth quarter
of 2016. Net loss from continuing operations for full-year 2017 was
$56.3 million, compared to net loss from continuing operations of
$165.6 million for full-year 2016. Adjusted earnings from
continuing operations before interest, income taxes, depreciation,
depletion and amortization and exploration costs ("Adjusted
EBITDAX") for the fourth quarter of 2017 was $41.0 million,
compared to $33.1 million for the fourth quarter of 2016. Adjusted
EBITDAX from continuing operations for full-year 2017 was $138.7
million compared to $146.3 million for full-year 2016. The change
in adjusted EBITDAX between the annual periods is, in part, a
result of lower average realized commodity prices, offset in part
by increased production and decreased interest expense.
Adjusted EBITDAX is a Non-GAAP financial measure and is described
in the attached table under “Non-GAAP Financial Information and
Reconciliation.”
Total production volumes from continuing
operations in the fourth quarter of 2017 totaled 2.3 MMBOE, or an
average of 24.6 MBOE per day compared to 1.7 MMBOE or 18.6 MBOE per
day in the fourth quarter of 2016. Total production volumes from
continuing operations for full-year 2017 totaled 8.6 MMBOE, or an
average of 23.5 MBOE per day, compared to 6.1 MMBOE or 16.6 MBOE
per day for full-year 2016. The increase in production is primarily
a result of the continued successful development of AMHLP’s STACK
play in Kingfisher County, Oklahoma. Total production in 2017 was
comprised of 49% oil, 35% natural gas and 16% natural gas liquids.
AMHLP production for 2018 is expected to average between 33 and 38
MBOE per day.
Oil, natural gas and natural gas liquids revenue
from continuing operations for the fourth quarter of 2017 totaled
$85.5 million compared to $55.1 million in the fourth quarter of
2016. The change in revenues between the two periods was primarily
due to the increase in oil, natural gas and natural gas liquids
production, offset in part by the decrease in net realized
commodity prices.
Realized prices for oil (including settlements
of derivative contracts) for the fourth quarter of 2017 were $53.02
per barrel, compared to $52.50 per barrel in the fourth quarter of
2016. Realized prices for natural gas liquids (including
settlements of derivative contracts) for the fourth quarter of 2017
were $26.28 per barrel compared to $19.61 per barrel in the fourth
quarter of 2016. Realized prices for natural gas (including
settlements of derivative contracts) in the fourth quarter 2017
were $3.69 per MCF, compared to $2.65 per MCF in the fourth quarter
of 2016. Below is a table of average prices received by AMHLP, with
and without the effect of derivative contract settlements.
Average Prices excluding derivative contract settlements |
|
2017 |
|
2016 |
Oil
(per Bbl) |
$ |
49.44 |
$ |
40.54 |
Natural Gas (per Mcf) |
|
2.63 |
|
2.20 |
Natural Gas Liquids (per Bbl) |
|
24.36 |
|
16.38 |
Combined (per BOE) |
|
33.52 |
|
26.74 |
|
|
|
|
|
Average Prices including derivative contract settlements |
|
2017 |
|
2016 |
Oil
(per Bbl) |
$ |
49.13 |
$ |
68.96 |
Natural Gas (per Mcf) |
|
3.01 |
|
2.69 |
Natural Gas Liquids (per Bbl) |
|
23.31 |
|
16.04 |
Combined realized (per BOE) |
|
34.00 |
|
41.31 |
AMHLP has an active hedging program. Currently,
AMHLP had hedged approximately 45% of its forecasted production of
proved developed producing reserves through 2020 at weighted
average annual floor prices ranging from $50.00 per Bbl to $52.22
per Bbl for oil and from $2.80 MMbtu to $2.90 per MMBtu for natural
gas.
Total production costs from continuing
operations, which includes lease operating expense, marketing and
transportation costs, production and ad valorem taxes and workover
expenses, in the fourth quarter of 2017 were $27.1 million, or
$11.99 per BOE, compared to $18.2 million, or $10.77 per BOE in the
fourth quarter of 2016. For the full year 2017, production costs
were $104.5 million, or $12.19 per BOE, compared to $66.9 million,
or $10.99 per BOE for the full year 2016.
General and administrative costs from continuing
operations in the fourth quarter of 2017 were $20.0 million,
compared to $8.9 million in the fourth quarter of 2016. General and
administrative cost in the fourth quarter of 2017 include
non-recurring SPAC-IPO business combination expenses and non-cash
bonus accruals offset by a decrease in settlement expense recorded
in the third quarter 2017. When adjusted for these non-recurring,
non-cash items, general and administrative costs for the fourth
quarter of 2017 would have been $10.3 million. General and
administrative expenses for full-year 2017 were $55.6 million
compared to $41.8 million for full-year 2016.
Conference Call Information
Alta Mesa invites you to listen to its
conference call which will discuss its financial and operational
results at 10:00 a.m., Central time, on Thursday, March 29, 2018.
If you wish to participate in this conference call, dial
888-347-8149 (toll free in US/Canada) or 412-902-4228 (for
International calls), five to ten minutes before the scheduled
start time. The commentary and answers to questions will include
forward-looking information. A webcast of the call and any related
materials will be available on Alta Mesa Resources website at
www.altamesa.net. Additionally, a replay of the conference call
will be available for one week following the live broadcast by
dialing 844-512-2921 (toll free in US/Canada) or 412-317-6671
(International calls), and referencing Conference ID #10117607.
About Alta Mesa Resources,
Inc.Alta Mesa Resources, Inc. is an independent energy
company focused on the development and acquisition of
unconventional oil and natural gas reserves in the Anadarko Basin
in Oklahoma and provides midstream energy services, including crude
oil and gas gathering, processing and marketing to producers in the
STACK play region through Kingfisher Midstream, LLC.
Safe Harbor Statement and
DisclaimerThe information in this press release includes
“forward-looking statements” within the meaning of Section 27A of
the Securities Act of 1933, as amended, and Section 21E of the
Securities Exchange Act of 1934, as amended. All statements, other
than statements of present or historical fact included in this
press release, regarding Alta Mesa Resources’ strategy, future
operations, financial position, estimated revenues and losses,
projected costs, prospects, plans and objectives of management are
forward-looking statements. When used in this press release, the
words “could”, “should”, “will”, “may”, “believe”, “anticipate”,
“intend”, “estimate”, “expect”, “project,” the negative of such
terms and similar expressions are intended to identify
forward-looking statements, although not all forward-looking
statements contain such identifying words. These forward-looking
statements are based on Alta Mesa Resources’ current expectations
and assumptions about future events and are based on currently
available information as to the outcome and timing of future
events. Alta Mesa Resources’ cautions you that these
forward-looking statements are subject to all of the risks and
uncertainties, most of which are difficult to predict and many of
which are beyond its control, incident to the exploration for and
development and production, gathering and sale of oil, natural gas,
and natural gas liquids. These risks include, but are not limited
to: commodity price volatility, low prices for oil, natural gas
and/or natural gas liquids, global economic conditions, inflation,
increased operating costs, lack of availability of drilling and
production equipment supplies, services and qualified personnel,
processing volumes and pipeline throughput, uncertainties related
to new technologies, geographical concentration of operations of
our subsidiaries Alta Mesa Holdings, LP (“Alta Mesa”) and
Kingfisher Midstream, LLC (“Kingfisher”), environmental risks,
weather risks, security risks, drilling and other operating risks,
regulatory changes, the uncertainty inherent in estimating oil and
natural gas reserves and in projecting future rates of production,
reductions in cash flow, lack of access to capital, Alta Mesa
Resources’ ability to satisfy future cash obligations, restrictions
in existing or future debt agreements of Alta Mesa or Kingfisher,
the timing of development expenditures, managing growth and
integration of acquisitions, failure to realize expected value
creation from property acquisitions, title defects and limited
control over non-operated properties, the Company’s ability to
complete an initial public offering of the Kingfisher midstream
business and the other risks described in the Company’s filings
with the SEC. Reserve engineering is a process of estimating
underground accumulations of oil and natural gas that cannot be
measured in an exact way. The accuracy of any reserve estimate
depends on the quality of available data, the interpretation of
such data and price and cost assumptions made by reservoir
engineers. Specifically, future prices received for production and
costs may vary, perhaps significantly, from the prices and costs
assumed for purposes of these estimates. Sustained lower
prices will cause the twelve-month weighted average price to
decrease over time as the lower prices are reflected in the average
price, which may result in the estimated quantities and present
values of Alta Mesa’s reserves being reduced. In addition, the
results of drilling, testing and production activities may justify
revisions of estimates that were made previously. If significant,
such revisions would change the schedule of any further production
and development drilling. Accordingly, reserve estimates may differ
significantly from the quantities of oil and natural gas that are
ultimately recovered. Should one or more of the risks or
uncertainties described in this press release occur, or should
underlying assumptions prove incorrect, Alta Mesa Resources’ actual
results and plans could differ materially from those expressed in
any forward-looking statements. All forward-looking statements,
expressed or implied, included in this press release are expressly
qualified in their entirety by this cautionary statement. This
cautionary statement should also be considered in connection with
any subsequent written or oral forward-looking statements that Alta
Mesa Resources may issue. Except as otherwise required by
applicable law, Alta Mesa Resources disclaims any duty to update
any forward-looking statements, all of which are expressly
qualified by the statements in this section, to reflect events or
circumstances after the date of this press release.
FOR MORE INFORMATION CONTACT:
Lance L. Weaver (281) 943-5597 lweaver@altamesa.net
|
ALTA MESA HOLDINGS, LP AND
SUBSIDIARIES |
CONSOLIDATED STATEMENTS OF
OPERATIONS |
|
|
Year Ended |
|
December 31, |
|
2017 |
|
2016 |
|
2015 |
|
|
|
|
|
|
|
|
|
|
(in thousands) |
OPERATING REVENUES AND
OTHER |
|
|
|
|
|
|
|
|
Oil |
$ |
206,026 |
|
|
$ |
117,703 |
|
|
$ |
130,015 |
|
Natural
gas |
|
47,583 |
|
|
|
29,510 |
|
|
|
26,445 |
|
Natural
gas liquids |
|
33,804 |
|
|
|
15,663 |
|
|
|
10,864 |
|
Other
revenues |
|
6,040 |
|
|
|
2,563 |
|
|
|
682 |
|
Total
operating revenues |
|
293,453 |
|
|
|
165,439 |
|
|
|
168,006 |
|
Gain
(loss) on sale of assets |
|
(27 |
) |
|
|
3,542 |
|
|
|
67,781 |
|
Gain on
acquisitions of oil and natural gas properties |
|
3,294 |
|
|
|
— |
|
|
|
— |
|
Gain
(loss) on derivative contracts |
|
8,287 |
|
|
|
(40,460 |
) |
|
|
124,141 |
|
Total
operating revenues and other |
|
305,007 |
|
|
|
128,521 |
|
|
|
359,928 |
|
OPERATING EXPENSES |
|
|
|
|
|
|
|
|
Lease and
plant operating expense |
|
60,881 |
|
|
|
46,383 |
|
|
|
53,821 |
|
Marketing
and transportation expense |
|
30,521 |
|
|
|
12,853 |
|
|
|
3,139 |
|
Production and ad valorem taxes |
|
7,228 |
|
|
|
4,168 |
|
|
|
6,307 |
|
Workover
expense |
|
5,873 |
|
|
|
3,540 |
|
|
|
5,200 |
|
Exploration expense |
|
24,606 |
|
|
|
24,768 |
|
|
|
29,445 |
|
Depreciation, depletion, and amortization expense |
|
94,499 |
|
|
|
64,981 |
|
|
|
78,008 |
|
Impairment expense |
|
30,317 |
|
|
|
16,287 |
|
|
|
50,436 |
|
Accretion
expense |
|
1,143 |
|
|
|
1,259 |
|
|
|
1,272 |
|
General
and administrative expense |
|
55,565 |
|
|
|
41,758 |
|
|
|
44,454 |
|
Total
operating expenses |
|
310,633 |
|
|
|
215,997 |
|
|
|
272,082 |
|
INCOME (LOSS) FROM
CONTINUING OPERATIONS |
|
(5,626 |
) |
|
|
(87,476 |
) |
|
|
87,846 |
|
OTHER INCOME
(EXPENSE) |
|
|
|
|
|
|
|
|
Interest
expense |
|
(51,794 |
) |
|
|
(60,884 |
) |
|
|
(62,473 |
) |
Interest
income |
|
1,163 |
|
|
|
894 |
|
|
|
723 |
|
Loss on
extinguishment of debt |
|
— |
|
|
|
(18,151 |
) |
|
|
— |
|
Total
other income (expense) |
|
(50,631 |
) |
|
|
(78,141 |
) |
|
|
(61,750 |
) |
INCOME (LOSS) FROM
CONTINUING OPERATIONS BEFORE STATE INCOME TAXES |
|
(56,257 |
) |
|
|
(165,617 |
) |
|
|
26,096 |
|
Provision
for (benefit from) state income taxes |
|
6 |
|
|
|
(29 |
) |
|
|
562 |
|
INCOME (LOSS) FROM
CONTINUING OPERATIONS |
|
(56,263 |
) |
|
|
(165,588 |
) |
|
|
25,534 |
|
LOSS FROM DISCONTINUED
OPERATIONS, net of state income taxes |
|
(21,398 |
) |
|
|
(2,333 |
) |
|
|
(157,327 |
) |
NET LOSS |
$ |
(77,661 |
) |
|
$ |
(167,921 |
) |
|
$ |
(131,793 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
ALTA MESA HOLDINGS, LP AND
SUBSIDIARIES |
CONSOLIDATED BALANCE SHEETS |
|
|
December 31, |
|
December 31, |
|
2017 |
|
2016 |
|
|
|
|
|
|
|
(in thousands) |
ASSETS |
|
|
|
|
|
CURRENT ASSETS |
|
|
|
|
|
Cash and
cash equivalents |
$ |
3,721 |
|
$ |
7,185 |
Restricted cash |
|
1,269 |
|
|
433 |
Accounts
receivable, net of allowance of $848 and $889, respectively |
|
81,141 |
|
|
34,732 |
Other
receivables |
|
1,542 |
|
|
8,061 |
Receivables due from affiliate |
|
790 |
|
|
8,883 |
Prepaid
expenses and other current assets |
|
2,932 |
|
|
3,986 |
Current
assets — discontinued operations |
|
— |
|
|
2,879 |
Derivative financial instruments |
|
216 |
|
|
83 |
Total
current assets |
|
91,611 |
|
|
66,242 |
PROPERTY AND
EQUIPMENT |
|
|
|
|
|
Oil and
natural gas properties, successful efforts method, net |
|
951,475 |
|
|
632,229 |
Other
property and equipment, net |
|
8,913 |
|
|
9,731 |
Total
property and equipment, net |
|
960,388 |
|
|
641,960 |
OTHER ASSETS |
|
|
|
|
|
Investment in LLC — cost |
|
9,000 |
|
|
9,000 |
Deferred
financing costs, net |
|
1,787 |
|
|
3,029 |
Notes
receivable due from affiliate |
|
12,369 |
|
|
9,987 |
Deposits
and other long-term assets |
|
10,234 |
|
|
2,977 |
Noncurrent assets — discontinued operations |
|
— |
|
|
79,933 |
Derivative financial instruments |
|
8 |
|
|
723 |
Total
other assets |
|
33,398 |
|
|
105,649 |
TOTAL ASSETS |
$ |
1,085,397 |
|
$ |
813,851 |
LIABILITIES AND
PARTNERS' CAPITAL |
|
|
|
|
|
CURRENT
LIABILITIES |
|
|
|
|
|
Accounts
payable and accrued liabilities |
$ |
178,371 |
|
$ |
78,437 |
Accounts
payable — related party |
|
5,476 |
|
|
— |
Advances
from non-operators |
|
5,502 |
|
|
4,058 |
Advances
from related party |
|
23,390 |
|
|
42,528 |
Asset
retirement obligations |
|
7,606 |
|
|
4,900 |
Current
liabilities — discontinued operations |
|
— |
|
|
1,273 |
Derivative financial instruments |
|
19,303 |
|
|
21,207 |
Total
current liabilities |
|
239,648 |
|
|
152,403 |
LONG-TERM
LIABILITIES |
|
|
|
|
|
Asset
retirement obligations, net of current portion |
|
47,449 |
|
|
43,147 |
Long-term
debt, net |
|
607,440 |
|
|
529,905 |
Notes
payable to founder |
|
28,166 |
|
|
26,957 |
Noncurrent liabilities — discontinued operations |
|
— |
|
|
18,325 |
Derivative financial instruments |
|
1,114 |
|
|
4,482 |
Other
long-term liabilities |
|
7,135 |
|
|
6,526 |
Total
long-term liabilities |
|
691,304 |
|
|
629,342 |
TOTAL LIABILITIES |
|
930,952 |
|
|
781,745 |
Commitments and
Contingencies |
|
|
|
|
|
PARTNERS' CAPITAL |
|
154,445 |
|
|
32,106 |
TOTAL LIABILITIES AND
PARTNERS' CAPITAL |
$ |
1,085,397 |
|
$ |
813,851 |
|
|
|
|
|
|
|
ALTA MESA HOLDINGS, LP AND
SUBSIDIARIES |
CONSOLIDATED STATEMENTS OF CASH
FLOWS |
|
|
Year Ended December 31, |
|
2017 |
|
2016 |
|
2015 |
|
|
|
|
|
|
|
|
|
|
(in thousands) |
CASH FLOWS FROM
OPERATING ACTIVITIES: |
|
|
|
|
|
|
|
|
Net loss |
$ |
(77,661 |
) |
|
$ |
(167,921 |
) |
|
$ |
(131,793 |
) |
Adjustments
to reconcile net loss to net cash provided by operating
activities: |
|
|
|
|
|
|
Depreciation, depletion, and amortization expense |
|
111,539 |
|
|
|
92,901 |
|
|
|
143,969 |
|
Impairment expense |
|
30,317 |
|
|
|
16,306 |
|
|
|
176,774 |
|
Accretion
expense |
|
2,095 |
|
|
|
2,174 |
|
|
|
2,076 |
|
Amortization of deferred financing costs |
|
2,732 |
|
|
|
3,905 |
|
|
|
3,392 |
|
Amortization of debt discount |
|
— |
|
|
|
468 |
|
|
|
510 |
|
Dry hole
expense |
|
2,500 |
|
|
|
419 |
|
|
|
22,708 |
|
Expired
leases |
|
9,125 |
|
|
|
11,158 |
|
|
|
6,526 |
|
(Gain)
loss on derivative contracts |
|
(8,287 |
) |
|
|
40,460 |
|
|
|
(124,141 |
) |
Settlements of derivative contracts |
|
4,117 |
|
|
|
88,689 |
|
|
|
106,949 |
|
Premium
paid on derivatives contracts |
|
(520 |
) |
|
|
— |
|
|
|
— |
|
Loss on
extinguishment of debt |
|
— |
|
|
|
18,151 |
|
|
|
— |
|
Interest
converted into debt |
|
1,209 |
|
|
|
1,209 |
|
|
|
1,208 |
|
Interest
on notes receivable due from affiliate |
|
(867 |
) |
|
|
(774 |
) |
|
|
(713 |
) |
(Gain)
loss on sale of assets |
|
22,179 |
|
|
|
(3,542 |
) |
|
|
(67,781 |
) |
Gain on
acquisitions of oil and natural gas properties |
|
(3,294 |
) |
|
|
— |
|
|
|
— |
|
Changes in assets and
liabilities: |
|
|
|
|
|
|
|
|
Accounts
receivable |
|
(43,530 |
) |
|
|
(10,500 |
) |
|
|
16,470 |
|
Other
receivables |
|
6,519 |
|
|
|
10,465 |
|
|
|
(10,288 |
) |
Receivables due from affiliate |
|
218 |
|
|
|
45 |
|
|
|
(1,725 |
) |
Prepaid
expenses and other non-current assets |
|
(6,203 |
) |
|
|
(819 |
) |
|
|
(2,269 |
) |
Advances
from related party |
|
(19,138 |
) |
|
|
42,528 |
|
|
|
— |
|
Settlement of asset retirement obligation |
|
(6,409 |
) |
|
|
(2,125 |
) |
|
|
(1,794 |
) |
Accounts
payable — related party |
|
(2,170 |
) |
|
|
— |
|
|
|
— |
|
Accounts
payable, accrued liabilities, and other liabilities |
|
34,857 |
|
|
|
(11,493 |
) |
|
|
3,900 |
|
NET CASH
PROVIDED BY OPERATING ACTIVITIES |
|
59,328 |
|
|
|
131,704 |
|
|
|
143,978 |
|
CASH FLOWS FROM
INVESTING ACTIVITIES: |
|
|
|
|
|
|
|
|
Capital
expenditures for property and equipment |
|
(313,961 |
) |
|
|
(214,061 |
) |
|
|
(223,604 |
) |
Acquisitions |
|
(55,605 |
) |
|
|
(11,527 |
) |
|
|
(48,202 |
) |
Proceeds
from sale of property |
|
25,205 |
|
|
|
1,290 |
|
|
|
141,404 |
|
Notes
receivable due from affiliate |
|
(1,515 |
) |
|
|
— |
|
|
|
— |
|
NET CASH
USED IN INVESTING ACTIVITIES |
|
(345,876 |
) |
|
|
(224,298 |
) |
|
|
(130,402 |
) |
CASH FLOWS FROM
FINANCING ACTIVITIES: |
|
|
|
|
|
|
|
|
Proceeds
from long-term debt |
|
373,065 |
|
|
|
222,557 |
|
|
|
252,500 |
|
Repayments of long-term debt |
|
(296,622 |
) |
|
|
(333,935 |
) |
|
|
(295,020 |
) |
Repayments of senior secured term loan |
|
— |
|
|
|
(127,708 |
) |
|
|
— |
|
Repurchase of senior notes due 2018 |
|
— |
|
|
|
(459,391 |
) |
|
|
— |
|
Proceeds
from issuance of senior notes due 2024 |
|
— |
|
|
|
500,000 |
|
|
|
— |
|
Additions
to deferred financing costs |
|
(398 |
) |
|
|
(13,747 |
) |
|
|
(4,313 |
) |
Capital
distributions |
|
— |
|
|
|
— |
|
|
|
(3,810 |
) |
Capital
contributions |
|
207,875 |
|
|
|
303,462 |
|
|
|
20,000 |
|
NET CASH
PROVIDED BY (USED IN) FINANCING ACTIVITIES |
|
283,920 |
|
|
|
91,238 |
|
|
|
(30,643 |
) |
NET DECREASE IN CASH,
CASH EQUIVALENTS AND RESTRICTED CASH |
|
(2,628 |
) |
|
|
(1,356 |
) |
|
|
(17,067 |
) |
CASH,
CASH EQUIVALENTS AND RESTRICTED CASH, beginning of period |
|
7,618 |
|
|
|
8,974 |
|
|
|
26,041 |
|
CASH,
CASH EQUIVALENTS, AND RESTRICTED CASH, end of period |
$ |
4,990 |
|
|
$ |
7,618 |
|
|
$ |
8,974 |
|
|
|
|
|
|
|
|
|
|
|
|
|
*Non-GAAP Financial Information and
ReconciliationAMHLP Reconciliation of Net Loss to Adjusted
EBITDAX. Adjusted EBITDAX is a non-GAAP financial measure and as
used herein represents net income (loss) before interest expense,
exploration expense, depletion, depreciation and amortization,
impairment of oil and natural gas properties, accretion of asset
retirement obligations, tax expense, gain (loss) on sale of assets
and the non-cash portion of gain/loss on oil, natural gas and
natural gas liquids derivative contracts. Alta Mesa’s management
believes Adjusted EBITDAX is useful because it allows external
users of our consolidated financial statements, such as industry
analysts, investors, lenders and rating agencies, to more
effectively evaluate our operating performance, compare the results
of our operations from period to period and against our peers
without regard to our financing methods or capital structure and
because it highlights trends in our business that may not otherwise
be apparent when relying solely on GAAP measures. Adjusted EBITDAX
is not a measurement of Alta Mesa’s financial performance under
GAAP, and should not be considered as an alternative to net income
(loss), operating income (loss) or any other performance measure
derived in accordance with GAAP or as an alternative to net cash
provided by operating activities as a measure of Alta Mesa’s
profitability or liquidity. Adjusted EBITDAX has significant
limitations, including that it does not reflect Alta Mesa’s cash
requirements for capital expenditures, contractual commitments,
working capital or debt service. In addition, other companies may
calculate Adjusted EBITDAX differently than Alta Mesa does,
limiting its usefulness as a comparative measure. The following
table sets forth a reconciliation of net income (loss) as
determined in accordance with GAAP to Adjusted EBITDAX for the
periods indicated (unaudited in thousands).
|
Three Months Ended Dec 31, |
|
|
|
2017 |
|
|
|
2016 |
|
|
Net
loss from continuing operations |
$ |
(40,757 |
) |
|
$ |
(47,305 |
) |
|
Adjustments
to net loss: |
|
|
|
|
Benefit for
income taxes |
|
(279 |
) |
|
|
(136 |
) |
|
Interest
expense |
|
12,724 |
|
|
|
8,631 |
|
|
Loss on
extinguishment of debt |
|
- |
|
|
|
18,151 |
|
|
Unrealized
loss - oil & gas hedges |
|
32,080 |
|
|
|
21,340 |
|
|
Exploration
expense |
|
5,011 |
|
|
|
9,414 |
|
|
Depreciation, depletion and amortization |
|
27,081 |
|
|
|
20,479 |
|
|
Impairment
expense |
|
1,112 |
|
|
|
2,048 |
|
|
Accretion
expense |
|
405 |
|
|
|
325 |
|
|
Loss on
sale of assets |
|
3,627 |
|
|
|
180 |
|
|
Adjusted EBITDAX |
$ |
41,004 |
|
|
$ |
33,127 |
|
|
|
Twelve Months Ended Dec 31, |
|
|
|
2017 |
|
|
|
2016 |
|
|
Net
loss from continuing operations |
$ |
(56,263 |
) |
|
$ |
(165,588 |
) |
|
Adjustments
to net loss: |
|
|
|
|
Provision
(benefit) for income taxes |
|
6 |
|
|
|
(29 |
) |
|
Interest
expense |
|
51,794 |
|
|
|
60,884 |
|
|
Loss on
extinguishment of debt |
|
- |
|
|
|
18,151 |
|
|
Unrealized
loss (gain) - oil & gas hedges |
|
(4,690 |
) |
|
|
129,149 |
|
|
Exploration
expense |
|
24,606 |
|
|
|
24,768 |
|
|
Depreciation, depletion and amortization |
|
94,499 |
|
|
|
64,981 |
|
|
Impairment
expense |
|
30,317 |
|
|
|
16,287 |
|
|
Accretion
expense |
|
1,143 |
|
|
|
1,259 |
|
|
(Gain) on
sale of assets |
|
- |
|
|
|
(3,542 |
) |
|
(Gain) on
acquisition of oil and gas properties |
|
(3,294 |
) |
|
|
- |
|
|
Loss on
sale of assets |
|
27 |
|
|
|
- |
|
|
Adjusted EBITDAX |
$ |
138,145 |
|
|
$ |
146,320 |
|
|
Kingfisher Forward Looking Reconciliation of Net
Income to EBITDA. EBITDA is a non-GAAP financial measure and as
used herein represents net income (loss) before interest expense,
tax expense, depreciation and amortization. Kingfisher’s management
believes EBITDA is useful because it allows external users of our
consolidated financial statements, such as industry analysts,
investors, lenders and rating agencies, to more effectively
evaluate our operating performance, compare the results of our
operations from period to period and against our peers without
regard to our financing methods or capital structure and because it
highlights trends in our business that may not otherwise be
apparent when relying solely on GAAP measures. EBITDA is not a
measurement of Kingfisher’s financial performance under GAAP, and
should not be considered as an alternative to net income (loss),
operating income (loss) or any other performance measure derived in
accordance with GAAP or as an alternative to net cash provided by
operating activities as a measure of Kingfisher’s profitability or
liquidity. In addition, other companies may calculate EBITDA
differently than Kingfisher does, limiting its usefulness as a
comparative measure. The following table sets forth a
reconciliation of projected net income (loss) as determined in
accordance with GAAP to EBITDA for the periods indicated (unaudited
in thousands).
Kingfisher EBITDA (Non-GAAP Measure) Outlook |
2018E Low |
2018E High |
Net Income |
$81,200 |
$96,200 |
Interest |
4,000 |
4,000 |
DD&A |
9,800 |
9,800 |
EBITDA |
$95,000 |
$110,000 |
Alta Mesa Resources Annual
Guidance
|
Upstream -
AMHLP |
2018E |
|
|
|
|
Drilling Activity |
|
|
Average rigs |
8 |
|
Gross
well count |
170 - 180 |
|
Net Volumes |
|
|
Oil (BOPD) |
18,000 - 21,000 |
|
Gas (MCFD) |
58,000 - 68,000 |
|
NGL (BPD) |
2,000 |
|
BOEPD |
33,000 - 38,000 |
|
Differentials |
|
|
Oil (% WTI) |
95% |
|
Gas (% NYMEX HH) |
93% |
|
Expenses |
|
|
Total Operating
Expenses |
$135mm - $155mm |
|
CAPEX |
|
|
Non-Acquisition
CAPEX |
$550mm - $580mm |
|
Midstream -
Kingfisher |
2018E |
|
|
|
|
Processing Capacity |
|
|
Cryogenic
processing |
260
MMcf/d |
|
Processing
Agreements |
90
MMcf/d |
|
Inlet Volumes |
|
|
Alta Mesa |
90 -
100 MMcf/d |
|
Third Parties |
50 -
70 MMcf/d |
|
Average Rig count |
|
|
Alta Mesa |
8 |
|
Third Parties |
5 -
15 |
|
Operating Expenses |
|
|
Operating Cost
($/MMbtu) |
$0.20
- $0.25 per MMbtu |
|
G&A |
$5-$6mm |
|
CAPEX |
|
|
Total Capex |
$175 -
$220mm |
|
Plant construction |
$25 -
$45mm |
|
Existing area well
connects and compression |
$70 -
$80mm |
|
Expansion area well
connects and compression |
$70 -
$80mm |
|
Crude
Gathering |
$12 - $15mm |
|
EBITDA |
$95 - $110mm |
Alta Mesa Resources (NASDAQ:AMRWW)
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