CDN NEWS | 
US NEWS 
OKLAHOMA CITY, March 14, 2019 (GLOBE NEWSWIRE) — Chaparral Energy, Inc. (NYSE: CHAP) announced today its fourth quarter and full year 2018 financial and operational results with the filing of its form 10-K. The company will hold its financial and operating results call this morning, March 14 at 9 a.m. Central.
2018 Highlights
- Recorded 2018 full year STACK production of 14.5 thousand barrels of oil equivalent per day (MBoe/d), representing a 52% year-over-year increase
- Achieved 2018 full year total company production of 20.5 MBoe/d
- Reported full year 2018 net income of $33.4 million, or 73 cents per diluted share
- Achieved full year 2018 adjusted EBITDA, as defined below, of $125 million
- Grew 2018 total proved reserves to 94.8 million barrels of oil equivalent (MMBoe), which adjusted for 2018 divestitures marks a 35% year-over-year increase, and represents a PV-10 value of $686 million
- Increased STACK proved reserves by 50% year-over-year to 74.1 MMBoe, while replacing 519% of STACK production
- Invested $194.7 million in STACK drilling and completion (D&C) activities in 2018
- Reduced total company lease operating expense per barrel of oil equivalent (LOE/Boe) almost $4 from $10.96 in 2017 to $7.24 in 2018
- Strengthened the balance sheet by issuing $300 million of unsecured senior notes and increasing the borrowing base to $325 million in 2018
“Our team is extremely proud of all we accomplished in 2018,” said Chief Executive Officer Earl Reynolds. “From strategically adding to our STACK acreage position to uplisting to the New York Stock Exchange to successfully completing a $300 million senior notes offering and increasing our borrowing base, we were able to increase the value of our assets while also strengthening our balance sheet. In addition, our outstanding operational and drilling results allowed us to significantly grow production and reserves in 2018.”
“While we continue to monitor market conditions and plan to be flexible with our capital expenditures, our current plan for 2019 is to invest $275 to $300 million in capital, more than 80% of which is dedicated to low-cost, high-return STACK/Merge D&C activity. Chaparral remains committed to low-cost operations, as is evident in our cost per lateral drilling foot, efficient frac designs and systematic development approach. This focus will continue to drive our efforts as we move toward partial and full section development, with additional spacing tests throughout the first half of 2019 across Canadian and Kingfisher counties. We are extremely proud of the differentiated STACK position we have built. We will continue to prudently manage our capital and protect our balance sheet as we grow production and reserves, work to become cash flow neutral and deliver long-term value for our shareholders.”
Operational Update – STACK Production Soars in 2018
Chaparral increased its STACK production to 16.6 MBoe/d during the fourth quarter, which is up 6% as compared to the previous quarter. Full year STACK production grew by 52% to 14.5 MBoe/d compared to the previous year. Total company production was 21.7 MBoe/d during the fourth quarter, which is a 2% quarter-over-quarter increase. Total company production for the full year was 20.5 MBoe/d, which represents an 11% decrease from the previous year. Excluding production from divested EOR assets in 2017, total company production increased by 13% on a year-over-year basis. Total company production for 2018 was 36% oil, 25% natural gas liquids (NGLs) and 39% natural gas.
Chaparral operated four drilling rigs during the fourth quarter of 2018. The company brought 13 new gross operated STACK wells on production during the quarter, two of which were part of its drilling joint venture. For the full year 2018, Chaparral brought 48 gross operated STACK wells online, of which 20 were in Garfield County, 18 in Canadian County and 10 in Kingfisher County. This includes 19 joint venture wells. Additional details on recent well results are included in the company’s current investor presentation, which is available on the investors page of its website.
Overall, 2018 average results from the company’s Meramec and Osage programs continued to exceed type curve expectations. The company believes it has de-risked more than 50% of its Garfield County position, as well as 80% of its Canadian County Merge position. The table below represents the average results of the Meramec and Osage wells, which had first production in 2018.
| Reservoir Target | Gross Wells |
Average WI |
Lateral Length |
IP-301 | Liquids | Type Curve IP-302 |
||
| Meramec & Osage | 44 | 63 | % | 4,691 | 750 | 73 | % | 709 |
1IP 30s represent the gross three-phase, peak 30-day production rate in Boe/d and are scaled to type curve lateral length of 4,800 feet
2 Represents the average gross three-phase, peak 30-day production rate in Boe/d of the STACK Meramec, Upper Osage, Lower Osage and Merge Miss type curves
Chaparral’s total oil and natural gas capital expenditures (CAPEX) during the fourth quarter were $76 million, of which $67.7 million was associated with the STACK. Of its STACK CAPEX, $55.4 million was related to D&C activities, which included $4.2 million of non-operated CAPEX and $5.4 million of inflation driven drilling joint venture CAPEX. Additionally, $10.7 million was spent on acquisition activities, including $5.1 million in non-cash acreage trades. The company’s oil and natural gas CAPEX for the full year 2018 was $341 million, of which STACK CAPEX D&C was $194.7 million. STACK D&C CAPEX includes $38 million of non-operated CAPEX and $13.2 million of inflation driven drilling joint venture CAPEX. The company also invested $111.4 million in STACK acquisitions, including $54.8 million for its 7,000-acre, bolt-on acquisition in Kingfisher County, $10.9 million in non-cash acreage trades and $7.7 million for seismic data.
Chaparral acquired 24,600 net acres through leasing and poolings associated with its D&C activities in 2018 and drilled or participated in 165 gross (37 net) horizontal STACK wells. The table below summarizes total oil and natural gas capital expenditures for the fourth quarter and full year 2018.
| Capital Expenditures (in millions) | Q4 2018 | Full Year 2018 | ||
| STACK Acquisitions1 | $10.7 | $111.4 | ||
| STACK D&C2 | $55.4 | $194.7 | ||
| STACK Enhancements | $1.6 | $4.8 | ||
| Total STACK | $67.7 | $310.9 | ||
| Other Enhancements | $0.6 | $6.2 | ||
| Corporate Allocations3 | $7.7 | $23.9 | ||
| Total CAPEX | $76.0 | $341.0 | ||
1For Q4 2018 and full year 2018, includes non-cash acreage trades of $5.1 million and $10.9 million respectively.
2For Q4 2018 and full year 2018, includes non-operated of $4.2 million and $38.0 million respectively and $5.4 million and $13.2 million
of drilling joint venture respectively
3For Q4 2018 and full year 2018, includes capitalized G&A, capitalized interest and asset retirement obligations
2018 Reserves
Chaparral previously announced year-end SEC 2018 proved reserves of 94.8 MMBoe, which adjusted for 2018 divestitures, marks a 35% year-over-year increase. The company’s reserve estimates were prepared by third-party reserve consultant Cawley, Gillespie and Associates. The net present value of the company’s year-end SEC proved reserves, discounted at 10%, was approximately $686 million. This marks a 38% increase compared to the previous year. Chaparral’s reserves were classified as 59% proved developed and were 34% oil, 27% NGLs and 39% natural gas.
Proved reserves for Chaparral’s STACK assets increased 50% on a year-over-year basis, from 49.4 MMBoe to 74.1 MMBoe. In the STACK, Chaparral replaced 519% of 2018 STACK production, with a drillbit finding and development cost of $7.80 per Boe. The following table illustrates the change in Chaparral’s estimated net proved reserves from December 31, 2017 to December 31, 2018.
Total Proved Developed and Undeveloped Reserves
| Oil (MBbls) | Natural Gas (MMcf) | NGLS (MBbls) | Total (MBoe) | |||||
| As of December 31, 2017 | 29,604 | 170,166 | 18,322 | 76,287 | ||||
| Revisions | 1,254 | 12,596 | 1,411 | 4,7641 | ||||
| Extensions and Discoveries | 6,545 | 69,189 | 9,329 | 27,406 | ||||
| Divestitures | (2,422 | ) | (14,184 | ) | (1,374 | ) | (6,160 | ) |
| Production | (2,684 | ) | (17,549 | ) | (1,881 | ) | (7,490 | ) |
| As of December 31, 2018 | 32,297 | 220,218 | 25,807 | 94,807 | ||||
1STACK only revisions, excluding the impact of price, were 623 MBoe.
Financial Summary
Chaparral reported net income of $79 million, or $1.73 per diluted share, during the fourth quarter of 2018 and $33.4 million for the full year, or 73 cents per diluted share. Net income in the fourth quarter and full year was driven by a $94 million and $38 million non-cash change in fair value of hedge derivative instruments, respectively. Chaparral’s adjusted EBITDA for the fourth quarter was virtually flat on a quarter-over-quarter basis at $34.4 million. The company’s full year 2018 adjusted EBITDA was $125 million. Its adjusted EBITDA, as well as its production, revenues and expenses mentioned in this release were impacted on a year-over-year basis by the sale of its EOR assets in November 2017, as well as other non-core asset sales.
Total gross commodity sales for the fourth quarter of 2018 were $65.1 million, which included $39.4 million from oil, $10.8 million from NGLs and $14.9 million from natural gas. For the full year, Chaparral recorded $258.8 million in total gross commodity sales, including $171.7 million from oil, $45.6 million from NGLs and $41.5 million in natural gas. This represents a 12% year-over-year decline compared to $293 million in 2017.
Chaparral’s average realized price for crude oil, excluding derivative settlements, decreased to $58.06 per barrel in the fourth quarter of 2018. For the full year, however, the company’s realized crude oil price increased 31% on a year-over-year basis to $63.99. Chaparral’s realized NGL price during the quarter was $22.84 per barrel and $24.24 per barrel for the full year, which represents a 7% year-over-year increase. The company’s realized natural gas price during the quarter was $2.95 per thousand cubic feet (Mcf) and $2.37 per Mcf for the year, which represents a decrease of 10% compared to 2017.
Total company LOE for the fourth quarter of 2018 was $12.1 million, or $6.11 per Boe, which was down 4% on a quarter-over-quarter basis compared to $6.36 per Boe in the third quarter. Chaparral’s STACK LOE/Boe for the fourth quarter was up slightly from $4.34 in the previous quarter to $4.64. For the full year, total company LOE/Boe was down significantly from $10.96 in 2017 to $7.24 in 2018. This decrease was driven primarily by the sale of its EOR properties in 2017 and other non-core divestitures executed in 2018. Full year STACK LOE/Boe was $4.86 compared to $4.31 in 2017.
Chaparral’s net G&A expense was $10 million, or $5.05 per Boe, during the fourth quarter of 2018 and $38.8 million, or $5.18 per Boe, for the full year 2018. Adjusted for non-cash compensation, the company’s cash G&A expense per Boe in the fourth quarter was $3.91 and $3.73 for full year 2018.
Divestitures
The company divested of $50.5 million in non-core assets in 2018, including portions of its legacy and Oklahoma/Texas Panhandle acreage, as well as portions of its saltwater disposal infrastructure. At the time of sale, these properties accounted for approximately 1.9 MBoe/d of production.
Balance Sheet and Liquidity
As of December 31, 2018, Chaparral had approximately $37.4 million in cash and cash equivalents and no borrowings under its $325 million borrowing base. As of March 8, 2019, the company had $29.1 million of cash and cash equivalents and $30 million of borrowings under its $325 million borrowing base. The company’s balance sheet remains strong with no significant debt maturities due until 2022.
In 2018, the company had a non-cash ceiling test impairment of $20.1 million associated with non-core leasehold outside of the STACK, which it does not intend to develop. There is currently no production associated with this acreage.
2019 Guidance
Chaparral expects total company production to be between 25 and 27 MBoe/d, which marks a 22% to 32% year-over-year growth. Total STACK production is forecasted to increase to 21 to 23 MBoe/d or 45% to 59% on a year-over-year basis. First quarter production is expected to be impacted by the timing of first sales associated with Chaparral’s spacing tests and remaining joint venture wells. Only approximately 10% of the company’s 2019 operated D&C program’s net wells are estimated to record first sales during the first quarter, while its 11-well Canadian County Merge spacing test is slated to come online during the second quarter.
Chaparral plans to invest between $275 and $300 million in capital in 2019, of which $228 to $248 million is dedicated to STACK D&C activities. The company plans to decrease its rig count from four to three rigs during the second quarter and invest approximately 60% of its operated D&C in Canadian County, 20% in Kingfisher County and 20% in Garfield County. Additionally, it plans to complete the remaining eight wells in its drilling joint venture program with Bayou City Energy.
The company’s 2019 acquisition budget is expected to be significantly less than in 2018. It plans to invest between $12.5 and $17.5 million on acquisitions primarily associated with acreage poolings in support of its operated D&C program.
Total company LOE/Boe for 2019 is estimated to be between $5.00 and $5.50, while its STACK LOE/Boe is expected to be between $3.75 and $4.25. Chaparral’s cash G&A expense per Boe cost is expected to be between $2.85 and $3.35.
| 1Q19E1 | 2019E | |
| Total Company Average Daily Production (MBoe/d) |
20.5 – 21.5 | 25.0 – 27.0 |
| STACK Average Daily Production (MBoe/d) |
15.5 – 16.5 | 21.0 – 23.0 |
1First quarter 2019 total company and STACK production guidance reflects impact due to timing associated with production from the company’s
multi-well spacing tests and remaining drilling joint venture wells.
| Financial Guidance (in millions unless otherwise stated) | 2019E | |
| Operated D&C | $210 – $225 | |
| Non-Operated D&C | $17.5 – $22.5 | |
| Acquisitions | $12.5 – $17.5 | |
| Other1 | $35 | |
| Total Capital Expenditures | $275 – $300 | |
| Total Company LOE ($/Boe) | $5.00 – $5.50 | |
| STACK LOE ($/Boe) | $3.75 – $4.25 | |
| Cash G&A Expense ($/Boe) | $2.85 – $3.35 | |
| Anticipated Proceeds from Asset Sales | $5 – $10 | |
1Includes workovers, capitalized interest and capitalized G&A
Earnings Call Information
Chaparral will hold its financial and operating results call this morning, Thursday, March 14, at 9 a.m. Central. Interested parties may access the call toll-free at 877-790-7727 and ask for the Chaparral Energy conference call 10 minutes prior to the start time. The conference ID number is 4093425. A live webcast of the call will also be available through the Investor section of the company’s website. For those who cannot listen to the live call, a recording will be available shortly after the call’s conclusion at chaparralenergy.com/investors.
The company has also provided an updated investor presentation for the quarter, which along with its form 10-K, is available at chaparralenergy.com/investors, as well as the Securities and Exchange Commission’s website at sec.gov.
Statements made in this release contain “forward-looking statements.” These statements are based on certain assumptions and expectations made by Chaparral, which reflect management’s experience, estimates and perception of historical trends, current conditions, anticipated future developments, potential for reserves and drilling, completion of current and future acquisitions and growth, benefits of acquisitions, future competitive position and other factors believed to be appropriate. These forward-looking statements are subject to certain risks, trends and uncertainties that could cause actual results to differ materially from those projected. Among those risks, trends and uncertainties are our ability to find oil and natural gas reserves that are economically recoverable, the volatility of oil and natural gas prices, the uncertain economic conditions in the United States and globally, the decline in the reserve values of our properties that may result in ceiling test write-downs, our ability to replace reserves and sustain production, our estimate of the sufficiency of our existing capital sources, our ability to raise additional capital to fund cash requirements for future operations, the uncertainties involved in prospect development and property acquisitions or dispositions and in projecting future rates of production or future reserves, the timing of development expenditures and drilling of wells, the impact of natural disasters on our present and future operations, the impact of government regulation and the operating hazards attendant to the oil and natural gas business. Initial production (IP) rates are discreet data points in each well’s productive history. These rates are sometimes actual rates and sometimes extrapolated or normalized rates. As such, the rates for a particular well may decline over time and change as additional data becomes available. Peak production rates are not necessarily indicative or predictive of future production rates or economic rates of return from such wells and should not be relied upon for such purpose. The ability of the company or the relevant operator to maintain expected levels of production from a well is subject to numerous risks and uncertainties, including those referenced and discussed above. In addition, methodology the company and other industry participants utilize to calculate peak IP rates may not be consistent and, as a result, the values reported may not be directly and meaningfully comparable. Please read “Risk Factors” in our annual reports, form 10-K or other public filings. We undertake no duty to update or revise these forward-looking statements.
About Chaparral
Chaparral Energy (NYSE: CHAP) is an independent oil and natural gas exploration and production company headquartered in Oklahoma City. Founded in 1988, Chaparral is a pure-play operator focused in Oklahoma’s highly economic STACK Play, where it has approximately 131,000 net acres primarily in Kingfisher, Canadian and Garfield counties. The company has approximately 260,000 net surface acres in the Mid-Continent region. For more information, visit chaparralenergy.com.
Investor Contact
Scott Pittman
Chief Financial Officer
405-426-6700
[email protected]
Media Contact
Brandi Wessel
Communications Manager
405-426-6657
[email protected]
Chaparral Energy, Inc. and Subsidiaries
Consolidated Statements of Operations (Unaudited)
| Successor | Predecessor | ||||||||||||||||
| Period from | Period from | Period from | Period from | ||||||||||||||
| January 1, 2018 | March 22, 2017 | January 1, 2017 | January 1, 2016 | ||||||||||||||
| through | through | through | through | ||||||||||||||
| (in thousands, except share and per share data) | December 31, 2018 | December 31, 2017 | March 21, 2017 | December 31, 2016 | |||||||||||||
| Revenues: | |||||||||||||||||
| Commodity sales | $ | 242,569 | $ | 226,493 | $ | 66,531 | $ | 252,152 | |||||||||
| Sublease revenue | 4,793 | 586 | — | — | |||||||||||||
| Total revenues | 247,362 | 227,079 | 66,531 | 252,152 | |||||||||||||
| Costs and expenses: | |||||||||||||||||
| Lease operating | 54,219 | 72,132 | 19,941 | 90,533 | |||||||||||||
| Transportation and processing | — | 9,503 | 2,034 | 8,845 | |||||||||||||
| Production taxes | 13,150 | 11,750 | 2,417 | 9,610 | |||||||||||||
| Depreciation, depletion and amortization | 87,888 | 92,599 | 24,915 | 122,928 | |||||||||||||
| Loss on impairment of oil and gas assets | 20,065 | 42,146 | — | 281,079 | |||||||||||||
| Loss on impairment of other assets | — | 179 | — | 1,393 | |||||||||||||
| General and administrative | 38,793 | 39,617 | 6,843 | 20,953 | |||||||||||||
| Liability management | — | — | — | 9,396 | |||||||||||||
| Cost reduction initiatives | 1,034 | 691 | 629 | 2,879 | |||||||||||||
| Other | 2,036 | 3,728 | — | — | |||||||||||||
| Total costs and expenses | 217,185 | 272,345 | 56,779 | 547,616 | |||||||||||||
| Operating income (loss) | 30,177 | (45,266 | ) | 9,752 | (295,464 | ) | |||||||||||
| Non-operating (expense) income: | |||||||||||||||||
| Interest expense | (11,383 | ) | (14,147 | ) | (5,862 | ) | (64,242 | ) | |||||||||
| Loss on extinguishment of debt | — | (635 | ) | — | — | ||||||||||||
| Non-hedge derivative gains (losses) | 19,297 | (30,802 | ) | 48,006 | (22,837 | ) | |||||||||||
| Write-off of Senior Note issuance costs, discount and premium | — | — | — | (16,970 | ) | ||||||||||||
| (Loss) gain on sale of assets | (2,582 | ) | (25,996 | ) | 206 | (117 | ) | ||||||||||
| Other income, net | 248 | 686 | 1,167 | 528 | |||||||||||||
| Net non-operating (expense) income | 5,580 | (70,894 | ) | 43,517 | (103,638 | ) | |||||||||||
| Reorganization items, net | (2,392 | ) | (3,091 | ) | 988,727 | (16,720 | ) | ||||||||||
| Income (loss) before income taxes | 33,365 | (119,251 | ) | 1,041,996 | (415,822 | ) | |||||||||||
| Income tax (benefit) expense | (77 | ) | (349 | ) | 37 | (102 | ) | ||||||||||
| Net income (loss) | $ | 33,442 | $ | (118,902 | ) | $ | 1,041,959 | $ | (415,720 | ) | |||||||
| Earnings per share: | |||||||||||||||||
| Basic for Class A and Class B | $ | 0.74 | $ | (2.64 | ) | * | * | ||||||||||
| Diluted for Class A and Class B | $ | 0.73 | $ | (2.64 | ) | * | * | ||||||||||
| Weighted average shares used to compute earnings per share: | |||||||||||||||||
| Basic for Class A and Class B | 45,288,980 | 44,984,046 | * | * | |||||||||||||
| Diluted for Class A and Class B | 45,730,171 | 44,984,046 | * | * | |||||||||||||
Chaparral Energy, Inc. and Subsidiaries
Consolidated Balance Sheets (Unaudited)
| December 31, | ||||||||
| (dollars in thousands, except share data) | 2018 | 2017 | ||||||
| Assets | ||||||||
| Current assets: | ||||||||
| Cash and cash equivalents | $ | 37,446 | $ | 27,732 | ||||
| Accounts receivable, net | 66,087 | 60,363 | ||||||
| Inventories, net | 4,059 | 5,138 | ||||||
| Prepaid expenses | 2,814 | 2,661 | ||||||
| Derivative instruments | 24,025 | — | ||||||
| Total current assets | 134,431 | 95,894 | ||||||
| Property and equipment, net | 43,096 | 50,641 | ||||||
| Oil and natural gas properties, using the full cost method: | ||||||||
| Proved | 915,333 | 634,294 | ||||||
| Unevaluated (excluded from the amortization base) | 466,616 | 482,239 | ||||||
| Accumulated depreciation, depletion, amortization and impairment | (221,431 | ) | (124,180 | ) | ||||
| Total oil and natural gas properties | 1,160,518 | 992,353 | ||||||
| Derivative instruments | 2,199 | — | ||||||
| Other assets | 425 | 418 | ||||||
| Total assets | $ | 1,340,669 | $ | 1,139,306 | ||||
| Liabilities and stockholders’ equity | ||||||||
| Current liabilities: | ||||||||
| Accounts payable and accrued liabilities | $ | 73,779 | $ | 75,414 | ||||
| Accrued payroll and benefits payable | 10,976 | 11,276 | ||||||
| Accrued interest payable | 13,359 | 187 | ||||||
| Revenue distribution payable | 26,225 | 17,966 | ||||||
| Long-term debt and capital leases, classified as current | 3,479 | 3,273 | ||||||
| Derivative instruments | — | 8,959 | ||||||
| Total current liabilities | 127,818 | 117,075 | ||||||
| Long-term debt and capital leases, less current maturities | 303,992 | 141,386 | ||||||
| Derivative instruments | 1,542 | 4,167 | ||||||
| Deferred compensation | 540 | 696 | ||||||
| Asset retirement obligations | 22,090 | 33,216 | ||||||
| Commitments and contingencies (Note 17) | ||||||||
| Stockholders’ equity: | ||||||||
| Preferred stock | — | — | ||||||
| Class A Common stock | 467 | 389 | ||||||
| Class B Common stock | — | 79 | ||||||
| Additional paid in capital | 974,616 | 961,200 | ||||||
| Treasury stock | (4,936 | ) | — | |||||
| Accumulated deficit | (85,460 | ) | (118,902 | ) | ||||
| Total stockholders’ equity | 884,687 | 842,766 | ||||||
| Total liabilities and stockholders’ equity | $ | 1,340,669 | $ | 1,139,306 | ||||
Chaparral Energy, Inc. and Subsidiaries
Consolidated Statements of Cash Flows (Unaudited)
| Successor | Predecessor | ||||||||||||||||
| Period from | Period from | Period from | Period from | ||||||||||||||
| January 1, 2018 | March 22, 2017 | January 1, 2017 | January 1, 2016 | ||||||||||||||
| through | through | through | through | ||||||||||||||
| (in thousands) | December 31, 2018 | December 31, 2017 | March 21, 2017 | December 31, 2016 | |||||||||||||
| Cash flows from operating activities | |||||||||||||||||
| Net income (loss) | $ | 33,442 | $ | (118,902 | ) | $ | 1,041,959 | $ | (415,720 | ) | |||||||
| Adjustments to reconcile net (loss) income to net cash provided by operating activities: | |||||||||||||||||
| Non-cash reorganization items | — | — | (1,012,090 | ) | — | ||||||||||||
| Depreciation, depletion and amortization | 87,888 | 92,599 | 24,915 | 122,928 | |||||||||||||
| Loss on impairment of assets | 20,065 | 42,325 | — | 282,472 | |||||||||||||
| Write-off of Senior Note issuance costs, discount and premium | — | — | — | 16,970 | |||||||||||||
| Deferred income taxes | — | — | — | — | |||||||||||||
| Derivative losses (gains) | (19,297 | ) | 30,802 | (48,006 | ) | 22,837 | |||||||||||
| Loss (gain) on sale of assets | 2,582 | 25,996 | (206 | ) | 117 | ||||||||||||
| Loss on extinguishment of debt | — | 635 | — | — | |||||||||||||
| Other | 5,470 | 1,573 | 645 | 3,611 | |||||||||||||
| Change in assets and liabilities: | |||||||||||||||||
| Accounts receivable | (6,337 | ) | (12,092 | ) | 198 | (9,243 | ) | ||||||||||
| Inventories | 236 | (489 | ) | 466 | 3,576 | ||||||||||||
| Prepaid expenses and other assets | (160 | ) | 3,245 | (497 | ) | (1,620 | ) | ||||||||||
| Accounts payable and accrued liabilities | 3,441 | 2,622 | 8,733 | 25,987 | |||||||||||||
| Revenue distribution payable | 8,649 | 6,941 | (1,875 | ) | 509 | ||||||||||||
| Deferred compensation | 10,262 | 9,714 | 143 | (5,257 | ) | ||||||||||||
| Net cash provided by operating activities | 146,241 | 84,969 | 14,385 | 47,167 | |||||||||||||
| Cash flows from investing activities | |||||||||||||||||
| Expenditures for property, plant, and equipment and oil and natural gas properties | (324,063 | ) | (157,718 | ) | (31,179 | ) | (146,296 | ) | |||||||||
| Proceeds from asset dispositions | 50,523 | 189,735 | 1,884 | 1,349 | |||||||||||||
| Proceeds from (payments for) derivative instruments | (18,510 | ) | 15,676 | 1,285 | 90,590 | ||||||||||||
| Cash in escrow | — | 42 | — | 48 | |||||||||||||
| Net cash (used in) provided by investing activities | (292,050 | ) | 47,735 | (28,010 | ) | (54,309 | ) | ||||||||||
| Cash flows from financing activities | |||||||||||||||||
| Proceeds from long-term debt | 116,000 | 33,000 | 270,000 | 181,000 | |||||||||||||
| Repayment of long-term debt | (243,722 | ) | (176,407 | ) | (444,785 | ) | (1,952 | ) | |||||||||
| Issuance of Senior Notes | 300,000 | — | — | — | |||||||||||||
| Proceeds from rights offering, net | — | — | 50,031 | — | |||||||||||||
| Principal payments under capital lease obligations | (2,683 | ) | (2,017 | ) | (568 | ) | (2,491 | ) | |||||||||
| Treasury stock purchased | (4,936 | ) | — | — | — | ||||||||||||
| Payment of other financing fees | (9,136 | ) | (4,671 | ) | (2,410 | ) | — | ||||||||||
| Net cash provided by (used in) financing activities | 155,523 | (150,095 | ) | (127,732 | ) | 176,557 | |||||||||||
| Net increase (decrease) in cash and cash equivalents | 9,714 | (17,391 | ) | (141,357 | ) | 169,415 | |||||||||||
| Cash and cash equivalents at beginning of period | 27,732 | 45,123 | 186,480 | 17,065 | |||||||||||||
| Cash and cash equivalents at end of period | $ | 37,446 | $ | 27,732 | $ | 45,123 | $ | 186,480 | |||||||||
Non-GAAP Financial Measures and Reconciliations
Adjusted EBITDA is a Non-GAAP financial measure and is described and reconciled to net income in the table “Adjusted EBITDA Reconciliation, NON-GAAP.”
Adjusted EBITDA Reconciliation, Non-GAAP
| Successor | Predecessor | ||||||||||||||||
| Period from | Period from | Period from | Period from | ||||||||||||||
| January 1, 2018 | March 22, 2017 | January 1, 2017 | January 1, 2016 | ||||||||||||||
| through | through | through | through | ||||||||||||||
| (in thousands) | December 31, 2018 | December 31, 2017 | March 21, 2017 | December 31, 2016 | |||||||||||||
| Net income (loss) | $ | 33,442 | $ | (118,902 | ) | $ | 1,041,959 | $ | (415,720 | ) | |||||||
| Interest expense | 11,383 | 14,147 | 5,862 | 64,242 | |||||||||||||
| Income tax (benefit) expense | (77 | ) | (349 | ) | 37 | (102 | ) | ||||||||||
| Depreciation, depletion, and amortization | 87,888 | 92,599 | 24,915 | 122,928 | |||||||||||||
| Non-cash change in fair value of non-hedge derivative instruments | (37,807 | ) | 46,478 | (46,721 | ) | 176,607 | |||||||||||
| Impact of derivative repricing | (5,649 | ) | — | — | — | ||||||||||||
| Loss (gain) on settlement of liabilities subject to compromise | 48 | — | (372,093 | ) | — | ||||||||||||
| Fresh start accounting adjustments | — | — | (641,684 | ) | — | ||||||||||||
| Upfront premiums paid on settled derivative contracts | — | — | — | (20,608 | ) | ||||||||||||
| Proceeds from monetization of derivatives with a scheduled maturity date more than 12 months from the monetization date excluded from EBITDA |
— | — | — | (12,810 | ) | ||||||||||||
| Interest income | (12 | ) | (21 | ) | (133 | ) | (188 | ) | |||||||||
| Stock-based compensation expense | 10,873 | 9,833 | 155 | (5,238 | ) | ||||||||||||
| Loss (gain) on sale of assets | 2,582 | 25,996 | (206 | ) | 117 | ||||||||||||
| Loss on extinguishment of debt | — | 635 | — | — | |||||||||||||
| Write-off of debt issuance costs, discount and premium | — | — | 1,687 | 16,970 | |||||||||||||
| Loss on impairment of assets | 20,065 | 42,325 | — | 282,472 | |||||||||||||
| Restructuring, reorganization and other | 2,344 | 7,313 | 24,297 | 19,599 | |||||||||||||
| Adjusted EBITDA | $ | 125,080 | $ | 120,054 | $ | 38,075 | $ | 228,269 | |||||||||
STACK Drillbit F&D and Reserve Replacement
| STACK Drillbit F&D and Reserve Replacement | 2017 Metrics | 2018 Metrics | Calculation | ||||
| Total Company Production (MBoe) | 8,399 | 7,490 | |||||
| STACK Production (MBoe) | 3,464 | 5,279 | (A) | ||||
| Proved Reserves (MBoe) | |||||||
| Total Company Proved Reserves | 76,827 | 94,807 | |||||
| STACK Extensions and Discoveries | 20,927 | 27,406 | (B) | ||||
| STACK Revisions (excluding price revisions) | 597 | 623 | (C) | ||||
| Capital Costs Incurred (in thousands) | |||||||
| Total Company | $ | 212,505 | $ | 341,018 | |||
| Development & Exploration Costs | $ | 174,994 | $ | 218,709 | (D) | ||
| STACK Reserve Replacement | 604 | % | 519 | % | (B)/(A) | ||
| STACK Drillbit F&D | $ | 8.13 | $ | 7.80 | (D)/(B+C) | ||
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