HighPoint Resources Reports Second Quarter 2018 Financial and Operating Results
DENVER, Aug. 8, 2018 /PRNewswire/ -- HighPoint Resources Corporation (the "Company" or "HighPoint") (NYSE: HPR) today reported second quarter of 2018 financial and operating results, highlighted by oil volumes above the mid-point of guidance and early positive results from Hereford development activity.
For the second quarter of 2018, the Company reported a net loss of $46.9 million, or $0.22 per diluted share. Adjusted net income for the second quarter of 2018 was a net loss of $3.2 million, or $0.02 per diluted share. EBITDAX for the second quarter of 2018 was $63.1 million. Adjusted net income (loss) and EBITDAX are non-GAAP (Generally Accepted Accounting Principles) measures. Please reference the reconciliations to GAAP financial statements at the end of this release.
Chief Executive Officer and President Scot Woodall commented, "Our second quarter results demonstrate our continued operating excellence as we reported total equivalent production sales volumes within our guidance range, including oil volumes that were above the mid-point of guidance. During the second quarter, we generated EBITDAX of $63.1 million, an increase of 35% over the first quarter of 2018 and 72% over the second quarter last year. We are well positioned for continued growth with a dominant acreage position, a low cost structure, and ample liquidity of $381 million at the end of the second quarter. Combined with disciplined capital allocation across an extensive and attractive inventory of XRL drilling locations we remain well positioned for value creation.
"Operationally, our development program is on track as Hereford activity began as planned in April. Drilling of the first DSU was recently completed and we initiated production from nine DUCs. Three of the DUCs were placed on flowback in May and we are seeing positive early production data as the wells are performing consistent with our base type-curve assumptions. The early results highlight the significant resource potential of the Hereford asset. The pace of development at Hereford will increase during the second half of the year as we are currently operating two drilling rigs. NE Wattenberg also continues to see very consistent results and produced an average of 23,900 Boe/d in the second quarter of 2018, representing a 65% increase over the second quarter of 2017.
"Midstream constraints in NE Wattenberg resulted in curtailed natural gas and liquids production during the second quarter. While we had anticipated these issues, the impact was greater than forecast due to a period of unseasonably warm weather in June and July, which resulted in an increase in processing facility outages. We are adjusting our 2018 natural gas and NGL guidance to account for these temporary issues, but expect that full-year oil volumes will be relatively unchanged from previous expectations.
"I am pleased with HighPoint's ability to create long-term shareholder value through development of our extensive and favorable asset base targeting the oil-weighted and rural core of the DJ Basin. We remain positioned to deliver significant growth in production, cash flow and EBITDAX and reiterate our 2019 outlook."
OPERATING AND FINANCIAL RESULTS
The following table summarizes certain operating and financial results for the second quarter of 2018 and 2017 and for the first quarter of 2018:
Three Months Ended Three Months Ended
June 30, March 31,
2018 2017 Change 2018 Change
---- ---- ------ ---- ------
Combined
production sales
volumes (MBoe) 2,409 1,526 58% 1,914 26%
Net cash provided
by (used in)
operating
activities ($
millions) $14.6 $0.1 *nm $54.3 (73)%
Discretionary cash
flow ($ millions)
(1) $51.3 $21.6 138% $34.9 47%
Combined realized
prices with
hedging (per Boe) $39.29 $37.42 5% $37.86 4%
Net income (loss)
($ millions) $(46.9) $(18.4) (155)% $(24.9) (88)%
Per share, basic $(0.22) $(0.25) 12% $(0.20) (10)%
Per share, diluted $(0.22) $(0.25) 12% $(0.20) (10)%
Adjusted net
income (loss) ($
millions) (1) $(3.2) $(12.9) 75% $(5.9) 46%
Per share, basic $(0.02) $(0.17) 88% $(0.05) (60)%
Per share, diluted $(0.02) $(0.17) 88% $(0.05) (60)%
Weighted average
shares
outstanding,
basic (in
thousands) 209,393 74,794 180% 123,596 69%
Weighted average
shares
outstanding,
diluted (in
thousands) 209,393 74,794 180% 123,596 69%
EBITDAX ($
millions) (1) $63.1 $36.7 72% $46.7 35%
* Not meaningful
(1) Discretionary cash flow, adjusted
net income (loss) and EBITDAX are
non-GAAP measures. Please
reference the reconciliations to
GAAP financial statements at the
end of this release.
The Company reported oil, natural gas and natural gas liquids ("NGL") production of 2.41 MMBoe for the second quarter of 2018, which was an increase of 58% over the second quarter of 2017. Oil volumes totaled 1.51 MMBbls, which was an increase of 67% over the second quarter of 2017. Production sales volumes from NE Wattenberg totaled 2.2 MMBoe and Hereford volumes totaled 0.2 MMBoe. Second quarter natural gas and NGL production was impacted by midstream constraints in NE Wattenberg, including high line pressures, unplanned processing facility outages due to unseasonably warm weather and lower product recoveries associated with interim processing facilities.
Production sales volumes were comprised of approximately 63% oil, 21% natural gas and 16% NGLs.
For the second quarter of 2018, WTI oil prices averaged $67.88 per barrel, NWPL natural gas prices averaged $1.95 per MMBtu and NYMEX natural gas prices averaged $2.80 per MMBtu. Commodity price realizations to benchmark pricing were oil less $2.76 per barrel versus WTI and natural gas less $0.66 per Mcf compared to NWPL. The NGL price averaged approximately 31% of the WTI price per barrel.
For the second quarter of 2018, the Company had derivative commodity swaps in place for 11,637 barrels of oil per day tied to WTI pricing at $52.98 per barrel, 5,000 MMBtu of natural gas per day tied to NWPL regional pricing at $2.68 per MMBtu and no hedges in place for NGLs.
Three Months Ended Three Months Ended
June 30, March 31,
2018 2017 Change 2018 Change
---- ---- ------ ---- ------
Average Realized
Prices before
Hedging:
----------------
Oil (per Bbl) $65.07 $45.83 42% $60.45 8%
Natural gas (per
Mcf) 1.29 2.43 (47)% 1.95 (34)%
NGLs (per Bbl) 20.84 16.20 29% 20.31 3%
Combined (per
Boe) 45.71 33.38 37% 42.24 8%
Average Realized
Prices with
Hedging:
----------------
Oil (per Bbl) $54.59 $52.39 4% $53.00 3%
Natural gas (per
Mcf) 1.40 2.56 (45)% 1.98 (29)%
NGLs (per Bbl) 20.84 16.20 29% 20.31 3%
Combined (per
Boe) 39.29 37.42 5% 37.86 4%
LOE averaged $3.15 per Boe in the second quarter of 2018 compared to $3.61 per Boe in the second quarter of 2017. The year-over-year reduction in LOE is a result of improved operating efficiencies on the legacy NE Wattenberg asset and disposition of higher LOE wells in Utah.
Production tax expense averaged $4.02 per Boe in the second quarter of 2018 compared to $2.25 per Boe in the second quarter of 2017. Production tax expense averaged approximately 9% of revenues in the second quarter of 2018 compared to 7% of revenues in the second quarter of 2017. The increase was due to a higher estimated effective tax rate for Colorado severance taxes and is currently expected to approximate this level for the remainder of the year.
Depreciation, depletion and amortization ("DD&A") averaged $21.66 per Boe in the second quarter of 2018 compared to $25.78 per Boe in the second quarter of 2017. Lower DD&A on a per unit basis compared to the second quarter of 2017 was primarily the result of proved reserves added at lower costs.
Three Months Ended Three Months Ended
June 30, March 31,
2018 2017 Change 2018 Change
---- ---- ------ ---- ------
Average Costs (per Boe):
------------------------
Lease operating expenses $3.15 $3.61 (13)% $3.27 (4)%
Gathering, transportation
and processing expense 0.42 0.35 20% 0.22 91%
Production tax expenses 4.02 2.25 79% 2.70 49%
Depreciation, depletion
and amortization 21.66 25.78 (16)% 21.41 1%
General and
administrative expense 4.83 5.86 (18)% 5.28 (9)%
Debt and Liquidity
At June 30, 2018, the principal debt balance was $627.1 million, while cash and cash equivalents were $107.4 million, resulting in net debt of $519.7 million. Cash and cash equivalents were primarily used during the quarter to execute on the second quarter development program.
The Company currently has $274 million in available borrowing capacity on its $300 million credit facility, after taking into account a $26 million letter of credit.
Capital Expenditures
Capital expenditures for the second quarter of 2018 totaled $145.0 million. The Company operated three drilling rigs and capital projects included spudding 28 XRL wells and placing 27 XRL wells on initial flowback, including six DUCs in Hereford.
Capital expenditures included $135.4 million for drilling and completion operations, $2.0 million for leasehold, and $7.6 million for infrastructure and corporate assets.
OPERATIONAL UPDATE
The Company is operating three drilling rigs in the DJ Basin with one rig in NE Wattenberg and two rigs in Hereford. The Company currently anticipates maintaining this pace of development and plans to drill approximately 120-125 gross XRL wells in 2018. Two completion crews will be utilized in 2018 and the Company has the ability to add a third completion crew, as necessary, based on the timing of well completions.
NE Wattenberg
The Company produced an average of 23,900 Boe/d (61% oil) in the second quarter of 2018, representing a 65% increase over the second quarter of 2017. For the second quarter of 2018, the Company drilled 20 XRL wells and placed 21 XRL wells on initial flowback. The Company is currently operating a one-rig drilling program and expects to maintain this level of development activity for the remainder of the year.
Recent activity was highlighted by DSU 5-61-27, which includes 10 XRL wells and is located in the east-central portion of NE Wattenberg. Initial flowback began in the second quarter and the wells have performed consistent with the type-curve expectations. This is a step-out to DSU 5-61-20, which was placed on flowback in the fourth quarter of 2017 and continues to perform in line with the base type-curve after 260 days of production.
In addition, DSUs 4-62-28 and 4-62-33 are located in the southern portion of NE Wattenberg and were also placed on initial flowback during the second quarter. The DSUs include 10 XRL and 9 XRL wells, respectively, and continue to trend towards peak production.
The Company continues to mitigate the impact of inflationary pressure on well costs as wells drilled during the first half of 2018 averaged approximately $4.85 million, which is in line with internal expectations. In addition, total drilling and completion cycle times averaged approximately 16.5 days for the first half of 2018, which is a 6% improvement over the 2017 average and was driven by a reduction in the number of frac and drill out days.
Hereford Field
Production sales volumes for the second quarter of 2018 averaged approximately 2,550 Boe/d (79% oil). Drilling operations commenced in April on DSU 11-63-14, which includes 10 XRL wells (6 Niobrara, 4 Codell). Drilling was completed in June and it is anticipated that the wells will be placed on initial flowback during the third quarter of 2018. A full-time completion crew began operating in April and completion operations commenced on three pads (three wells each) of DUCs, which incorporated optimized completions, including controlled flowback methods. The first three wells were placed on flowback in May and continue to trend towards peak production. Early production data is encouraging as the wells are performing consistent with the base type-curve of 550 MBoe for the 60 days of production following initial oil sales. It is anticipated that peak production will be achieved after approximately 90 days of production. The remaining six DUCs were placed on production in June and July and are in the initial flowback stage.
The Company expects to maintain two drilling rigs for the remainder of the year and the focus of the 2018 program will be on full DSU development to maximize drilling and completion efficiencies. The Company has already begun to realize significant savings due to synergies generated as completion costs for the 9 DUCs were 29% below legacy completion costs. In addition, drilling costs for the initial DSU were 17% below legacy wells with drilling days to rig release averaging approximately 8.5 days per well, including a best-in-class well that was drilled in 6.9 days.
MARKETING UPDATE
The Company experienced midstream curtailments in the first half of 2018 due to high line pressures in the DJ Basin that led to minor production impacts in NE Wattenberg, but expects that line pressures and gas processing capacity will improve in the second half of 2018. Natural gas processing capacity has improved as DCP's Mewbourn 3 plant recently became operational, which increased the Company's allocated gas volumes by approximately 25%. In addition, the Company has worked diligently to diversify its gas processing capacity and has signed agreements with several third-party midstream providers that will increase the Company's available gas processing capacity by over 70% by the end of 2018. This provides the flexibility to direct approximately 35% of expected fourth quarter NE Wattenberg volumes to processing facilities outside of the legacy DCP system.
Hereford natural gas volumes are processed by Summit midstream, which is in the process of expanding its gas processing capacity to 60 MMcf/d by the end of 2018.
The Company continues to maintain no oil marketing or oil pipeline delivery commitments and expects that oil price differentials to benchmark pricing will be less than $3.00 per barrel versus WTI for the foreseeable future.
2018 OPERATING GUIDANCE
The Company is updating its 2018 operating guidance and providing third quarter of 2018 guidance for capital expenditures and production as discussed below. The Company is reiterating its previously announced outlook for 2019.
See "Forward-Looking Statements" below.
-- Capital expenditures of $500-$550 million, unchanged
-- Third quarter capital expenditures are expected to total $140-$150
million
-- Pro forma production of 10.5-11.0 MMBoe, revised from a previous
guidance range of 11.0-11.5 MMBoe
-- Updated to reflect actual production volumes for the first half of
2018 and the anticipated impact of midstream constraints in NE
Wattenberg in the third quarter, including high line pressures, a
greater amount of processing facility outages due to unseasonably
warm weather and lower processing plant product recoveries
associated with interim processing facilities
-- Includes production volumes of approximately 0.3 MMBoe associated
with Hereford for the first quarter of 2018
-- Pro forma oil volumes are expected to be in a range of 6.6-6.9 MMBbls or
approximately 63% of total production volumes, an increase from previous
oil weighting guidance of 60-62% of total production volumes
-- Includes oil volumes of approximately 0.2 MMBbls associated with
Hereford for the first quarter of 2018
-- Third quarter production sales volumes are expected to approximate
2.65-2.95 MMBoe (approximately 63% oil)
-- Lease operating expense of $28-$32 million, unchanged
-- General and administrative expenses of $36-$40 million, unchanged
-- Gathering, transportation and processing costs of $5-$10 million,
unchanged
-- Unused commitment for firm natural gas transportation charges of $18-$19
million, unchanged
COMMODITY HEDGES UPDATE
The following table summarizes our current hedge position as of August 8, 2018:
Oil (WTI) Natural Gas (NWPL)
Period Volume Price Volume Price
Bbls/d $/Bbl MMBtu/d $/MMBtu
3Q18 13,843 54.62 5,000 2.68
4Q18 13,806 54.63 5,000 2.68
1Q19 17,774 58.33 5,000 2.05
2Q19 17,750 58.34 5,000 2.05
3Q19 17,231 58.64 5,000 2.05
4Q19 17,212 58.65 5,000 2.05
FY2020 3,500 59.71
Realized sales prices will reflect basis differentials from the index prices to the sales location.
UPCOMING EVENTS
Second Quarter Conference Call and Webcast
The Company plans to host a conference call on Thursday, August 9, 2018, to discuss second quarter of 2018 results. The call is scheduled at 10:00 a.m. Eastern time (8:00 a.m. Mountain time). Please join the webcast conference call live or for replay via the Internet at www.hpres.com, accessible from the home page. To join by telephone, call (855) 760-8152 ((631) 485-4979 international callers) with passcode 8494357. The webcast will remain on the Company's website for approximately 7 days and a replay of the call will be available through August 16, 2018 at (855) 859-2056 ((404) 537-3406 international) with passcode 8494357.
Investor Events
Members of the Company's management are currently scheduled to participate in the following investor events:
-- August 20-22, 2018 - EnerCom's The Oil & Gas Conference in Denver, CO
-- August 28, 2018 - Seaport Global Energy & Industrials Conference in
Chicago, IL
-- September 25-26, 2018 - Johnson Rice & Co. Energy Conference in New
Orleans, LA
Presentation materials will be posted to the investor relations section of the Company's website prior to the start of each event.
DISCLOSURE STATEMENTS
Forward-Looking Statements
All statements in this press release, other than statements of historical fact, are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Words such as expects, forecast, guidance, anticipates, intends, plans, believes, seeks, estimates and similar expressions or variations of such words are intended to identify forward-looking statements herein; however, these are not the exclusive means of identifying forward-looking statements. In particular, the Company is providing "2018 Operating Guidance," which contains projections for certain 2018 full-year and third quarter operational and financial metrics. Additional forward-looking statements in this release relate to, among other things, future capital expenditures, costs, projects and opportunities; and the availability of adequate natural gas processing capacity, future line pressures and the timing and effect of new midstream facilities, and future diversification of gas processing capacity.
These and other forward-looking statements in this press release are based on management's judgment as of the date of this release and are subject to numerous risks and uncertainties. Actual results may vary significantly from those indicated in the forward-looking statements. Please refer to the Bill Barrett Corporation's Annual Report on Form 10-K for the year ended December 31, 2017 filed with the SEC, and other filings, including our Current Reports on Form 8-K and Quarterly Reports on Form 10-Q, all of which are incorporated by reference herein, for further discussion of risk factors that may affect the forward-looking statements. The Company encourages you to consider the risks and uncertainties associated with projections and other forward-looking statements and to not place undue reliance on any such statements. In addition, the Company assumes no obligation to publicly revise or update any forward-looking statements based on future events or circumstances.
ABOUT HIGHPOINT RESOURCES CORPORATION
HighPoint Resources Corporation (NYSE: HPR) is a Denver, Colorado based company focused on the development of oil and natural gas assets located in the Denver-Julesburg Basin of Colorado. Additional information about the Company may be found on its website at www.hpres.com.
HIGHPOINT RESOURCES CORPORATION
Selected Operating Highlights
(Unaudited)
Three Months Ended Six Months Ended
June 30, June 30,
2018 2017 2018 2017
---- ---- ---- ----
Production Data:
----------------
Oil (MBbls) 1,507 902 2,644 1,727
Natural gas (MMcf) 3,096 1,920 5,652 3,810
NGLs (MBbls) 386 304 737 597
Combined volumes (MBoe) 2,409 1,526 4,323 2,959
Daily combined volumes
(Boe/d) 26,473 16,769 23,884 16,348
Average Sales Prices (before the effects of realized hedges):
-------------------------------------------------------------
Oil (per Bbl) $65.07 $45.83 $63.09 $46.83
Natural gas (per Mcf) 1.29 2.43 1.59 2.54
NGLs (per Bbl) 20.84 16.20 20.59 18.09
Combined (per Boe) 45.71 33.38 44.18 34.25
Average Realized Sales Prices (after the effects of realized hedges):
---------------------------------------------------------------------
Oil (per Bbl) $54.59 $52.39 $53.91 $52.40
Natural gas (per Mcf) 1.40 2.56 1.66 2.59
NGLs (per Bbl) 20.84 16.20 20.59 18.09
Combined (per Boe) 39.29 37.42 38.66 37.56
Average Costs (per Boe):
------------------------
Lease operating expenses $3.15 $3.61 $3.20 $3.84
Gathering, transportation
and processing expense 0.42 0.35 0.33 0.35
Production tax expenses 4.02 2.25 3.44 1.27
Depreciation, depletion
and amortization 21.66 25.78 21.55 26.25
General and
administrative expense
(1) 4.83 5.86 5.03 6.18
(1) Includes long-term cash and equity
incentive compensation of $0.93
per Boe and $1.10 per Boe for the
three months ended June 30, 2018
and 2017, respectively, and $0.85
per Boe and $0.95 per Boe for the
six months ended June 30, 2018 and
2017, respectively.
HIGHPOINT RESOURCES CORPORATION
Consolidated Condensed Balance Sheets
(Unaudited)
As of As of
June 30, December 31,
-------- ------------
2018 2017
---- ----
(in thousands)
Assets:
-------
Cash and cash equivalents $107,379 $314,466
Other current assets 66,140 53,197
Property and equipment, net 1,905,620 1,018,880
Other noncurrent assets 3,814 4,163
Total assets $2,082,953 $1,390,706
========== ==========
Liabilities and Stockholders' Equity:
-------------------------------------
Current liabilities (1) $264,247 $148,934
Long-term debt, net of debt
issuance costs 616,625 617,744
Other long-term liabilities
(1) 186,878 25,474
Stockholders' equity 1,015,203 598,554
--------- -------
Total liabilities and
stockholders' equity $2,082,953 $1,390,706
========== ==========
(1) At June 30, 2018, the
estimated fair value of all
of the Company's commodity
derivative instruments was a
liability of $85.3 million,
comprised of $66.4 million of
current liabilities and $18.9
million of non-current
liabilities. This amount will
fluctuate based on estimated
future commodity prices and
the current hedge position.
HIGHPOINT RESOURCES CORPORATION
Consolidated Statements of Operations
(Unaudited)
Three Months Ended Six Months Ended
June 30, June 30,
2018 2017 2018 2017
---- ---- ---- ----
(in thousands, except per share amounts)
Operating Revenues:
-------------------
Oil, gas and NGL production $110,118 $50,941 $190,949 $101,366
Other operating revenues,
net 280 125 259 236
Total operating revenues 110,398 51,066 191,208 101,602
------- ------ ------- -------
Operating Expenses:
-------------------
Lease operating 7,594 5,506 13,845 11,368
Gathering, transportation
and processing 1,012 535 1,431 1,024
Production tax 9,684 3,434 14,859 3,756
Exploration 7 3 20 30
Impairment, dry hole costs
and abandonment 108 1 425 8,075
(Gain) Loss on sale of
properties 564 - 972 (92)
Depreciation, depletion and
amortization 52,175 39,337 93,160 77,677
Unused commitments 4,572 4,558 9,110 9,130
General and administrative
(1) 11,624 8,943 21,731 18,292
Merger transaction expense 1,277 - 6,040 -
Other operating expenses,
net 9 (755) 48 (1,328)
--- ----
Total operating expenses 88,626 61,562 161,641 127,932
Operating Income (Loss) 21,772 (10,496) 29,567 (26,330)
------ ------- ------ -------
Other Income and Expense:
-------------------------
Interest and other income 701 492 1,392 698
Interest expense (13,093) (16,137) (26,183) (30,088)
Commodity derivative gain
(loss) (2) (56,286) 15,598 (76,619) 32,062
Gain (loss) on
extinguishment of debt - (7,904) - (7,904)
Total other income and
expense (68,678) (7,951) (101,410) (5,232)
------- ------ -------- ------
Income (Loss) before Income
Taxes (46,906) (18,447) (71,843) (31,562)
(Provision for) Benefit
from Income Taxes - - - -
Net Income (Loss) $(46,906) $(18,447) $(71,843) $(31,562)
======== ======== ======== ========
Net Income (Loss) per Common Share
Basic $(0.22) $(0.25) $(0.43) $(0.42)
Diluted $(0.22) $(0.25) $(0.43) $(0.42)
Weighted Average Common Shares Outstanding
Basic 209,393 74,794 166,731 74,670
Diluted 209,393 74,794 166,731 74,670
(1) Includes long-term cash and equity
incentive compensation of $2.2
million and $1.7 million for the
three months ended June 30, 2018
and 2017, respectively, and $3.7
million and $2.8 million for the
six months ended June 30, 2018 and
2017, respectively.
(2) The table below summarizes the
realized and unrealized gains and
losses the Company recognized
related to its oil and natural gas
derivative instruments for the
periods indicated:
Three Months Ended Six Months Ended
June 30, June 30,
2018 2017 2018 2017
---- ---- ---- ----
(in thousands)
Included in commodity
derivative gain (loss):
Realized gain (loss) on
derivatives (1) $(15,460) $6,167 $(23,848) $9,799
Prior year unrealized
(gain) loss transferred
to realized (gain) loss
(1) 5,788 (737) 20,940 (2,114)
Unrealized gain (loss) on
derivatives (1) (46,614) 10,168 (73,711) 24,377
Total commodity
derivative gain (loss) $(56,286) $15,598 $(76,619) $32,062
======== ======= ======== =======
(1) Realized and unrealized gains and
losses on commodity derivatives
are presented herein as separate
line items but are combined for a
total commodity derivative gain
(loss) in the Consolidated
Statements of Operations. This
separate presentation is a non-
GAAP measure. Management believes
the separate presentation of the
realized and unrealized commodity
derivative gains and losses is
useful because the realized cash
settlement portion provides a
better understanding of the
Company's hedge position. The
Company also believes that this
disclosure allows for a more
accurate comparison to its peers.
HIGHPOINT RESOURCES CORPORATION
Consolidated Statements of Cash Flows
(Unaudited)
Three Months Ended Six Months Ended
June 30, June 30,
2018 2017 2018 2017
---- ---- ---- ----
(in thousands)
Operating Activities:
---------------------
Net income (loss) $(46,906) $(18,447) $(71,843) $(31,562)
Adjustments to reconcile to net cash provided by
operations:
Depreciation, depletion and
amortization 52,175 39,337 93,160 77,677
Impairment, dry hole costs and
abandonment 108 1 425 8,075
Unrealized derivative (gain) loss 40,826 (9,432) 52,771 (22,264)
Incentive compensation and other non-
cash charges 2,655 1,686 3,490 3,654
Amortization of deferred financing
costs 568 597 1,131 1,155
(Gain) loss on sale of properties 564 - 972 (92)
(Gain) loss on extinguishment of debt - 7,904 - 7,904
Change in operating assets and liabilities:
Accounts receivable (13,363) (1,160) (4,197) 2,427
Prepayments and other assets (978) (330) (1,089) (1,377)
Accounts payable, accrued and other
liabilities (36,855) (14,550) (36,033) (5,585)
Amounts payable to oil and gas
property owners 15,923 1,583 25,532 2,673
Production taxes payable (147) (7,088) 4,568 (4,486)
Net cash provided by (used in)
operating activities $14,570 $101 $68,887 $38,199
Investing Activities:
---------------------
Additions to oil and gas properties,
including acquisitions (131,962) (46,273) (220,816) (104,236)
Additions of furniture, equipment and
other (348) (190) (470) (201)
Repayment of debt associated with
merger, net of cash acquired - - (53,357) -
Proceeds from sale of properties and
other investing activities 687 (11,840) 530 (615)
Net cash provided by (used in)
investing activities $(131,623) $(58,303) $(274,113) $(105,052)
Financing Activities:
---------------------
Proceeds from debt - 275,000 - 275,000
Principal payments on debt (116) (322,001) (232) (322,113)
Proceeds from sale of common stock,
net of offering costs - (74) - (298)
Deferred financing costs and other (144) (5,045) (1,629) (6,012)
Net cash provided by (used in)
financing activities $(260) $(52,120) $(1,861) $(53,423)
----- -------- ------- --------
Increase (Decrease) in Cash and Cash
Equivalents (117,313) (110,322) (207,087) (120,276)
Beginning Cash and Cash Equivalents 224,692 265,887 314,466 275,841
Ending Cash and Cash Equivalents $107,379 $155,565 $107,379 $155,565
======== ======== ======== ========
HIGHPOINT RESOURCES CORPORATION
Reconciliation of Discretionary Cash Flow, Adjusted Net Income (Loss) and EBITDAX
(Unaudited)
Discretionary Cash Flow Reconciliation
Three Months Ended Six Months Ended
June 30, June 30,
2018 2017 2018 2017
---- ---- ---- ----
(in thousands)
Net Cash Provided by (Used
in) Operating Activities $14,570 $101 $68,887 $38,199
Adjustments to reconcile to discretionary
cash flow:
Exploration expense 7 3 20 30
Merger transaction expense 1,277 - 6,040 -
Changes in working capital 35,420 21,545 11,219 6,348
Discretionary Cash Flow $51,274 $21,649 $86,166 $44,577
======= ======= ======= =======
Adjusted Net Income (Loss) Reconciliation
Three Months Ended Six Months Ended
June 30, June 30,
2018 2017 2018 2017
---- ---- ---- ----
(in thousands, except per share amounts)
Net Income (Loss) $(46,906) $(18,447) $(71,843) $(31,562)
Provision for (Benefit
from) income taxes - - - -
Income (Loss) before income
taxes (46,906) (18,447) (71,843) (31,562)
Adjustments to net income (loss):
Unrealized derivative
(gain) loss 40,826 (9,432) 52,771 (22,264)
Impairment expense - - - 8,010
(Gain) loss on sale of
properties 564 - 972 (92)
(Gain) loss on
extinguishment of debt - 7,904 - 7,904
One-time item:
Merger transaction expense 1,277 - 6,040 -
(Income) expense related to
properties sold 9 (755) 48 (1,328)
Adjusted Income (Loss)
before income taxes (4,230) (20,730) (12,012) (39,332)
Adjusted (provision for)
benefit from income taxes
(1) 1,047 7,869 2,959 14,911
Adjusted Net Income (Loss) $(3,183) $(12,861) $(9,053) $(24,421)
======= ======== ======= ========
Per share, diluted $(0.02) $(0.17) $(0.05) $(0.33)
(1) Adjusted (provision for)
benefit from income taxes is
calculated using the
Company's current effective
tax rate prior to applying
the valuation allowance
against deferred tax assets.
EBITDAX Reconciliation
Three Months Ended Six Months Ended
June 30, June 30,
2018 2017 2018 2017
---- ---- ---- ----
(in thousands)
Net Income (Loss) $(46,906) $(18,447) $(71,843) $(31,562)
Adjustments to reconcile to
EBITDAX:
Depreciation, depletion and
amortization 52,175 39,337 93,160 77,677
Impairment, dry hole and
abandonment expense 108 1 425 8,075
Exploration expense 7 3 20 30
Unrealized derivative
(gain) loss 40,826 (9,432) 52,771 (22,264)
Incentive compensation and
other non-cash charges 2,655 1,686 3,490 3,654
Merger transaction expense 1,277 - 6,040 -
(Gain) loss on sale of
properties 564 - 972 (92)
(Gain) loss on
extinguishment of debt - 7,904 - 7,904
Interest and other income (701) (492) (1,392) (698)
Interest expense 13,093 16,137 26,183 30,088
EBITDAX $63,098 $36,697 $109,826 $72,812
======= ======= ======== =======
Discretionary cash flow, adjusted net income (loss) and EBITDAX are non-GAAP measures. These measures are presented because management believes that they provide useful additional information to investors for analysis of the Company's performance. If used as a liquidity measure, they should be reconciled to cash flow from operations as well as adjusting net income (loss) for certain items to allow for a more consistent comparison from period to period. In addition, the Company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry, and that many investors use the published research of industry research analysts in making investment decisions.
These measures should not be considered in isolation or as a substitute for net income, income from operations, net cash provided by operating activities or other income, profitability, cash flow or liquidity measures prepared in accordance with GAAP. The definition of these measures may vary among companies, and, therefore, the amounts presented may not be comparable to similarly titled measures of other companies.
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SOURCE HighPoint Resources Corporation
