Press Release

Chaparral Energy

Chaparral Announces Q4 and FY 2018 Results

Chaparral Announces Q4 and FY 2018 Results.pdf

Oklahoma City, March 14, 2019 — 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.

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)