FORM 10-Q |
☒ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
☐ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
GOODRICH PETROLEUM CORPORATION (Exact name of registrant as specified in its charter) |
Delaware (State or other jurisdiction of incorporation or organization) | 76-0466193 (I.R.S. Employer Identification No.) |
801 Louisiana, Suite 700 Houston, Texas 77002 (Address of principal executive offices) (Zip Code) (Registrant’s telephone number, including area code): (713) 780-9494 |
Large accelerated filer | ☐ | Accelerated filer | ☐ | |
Non-accelerated filer | ☐ | Smaller reporting company | ☒ | |
(Do not check if a smaller reporting company) | Emerging growth company | ☐ |
Page | ||
PART I | ||
ITEM 1 | ||
ITEM 2 | ||
ITEM 3 | ||
ITEM 4 | ||
PART II | ||
ITEM 1 | ||
ITEM 1A | ||
ITEM 6 |
June 30, 2018 | December 31, 2017 | ||||||
ASSETS | |||||||
CURRENT ASSETS: | |||||||
Cash and cash equivalents | $ | 1,729 | $ | 25,992 | |||
Accounts receivable, trade and other, net of allowance | 1,969 | 1,371 | |||||
Accrued oil and natural gas revenue | 7,317 | 4,958 | |||||
Fair value of oil and natural gas derivatives | 673 | 2,034 | |||||
Inventory | 1,722 | 2,521 | |||||
Prepaid expenses and other | 950 | 1,614 | |||||
Total current assets | 14,360 | 38,490 | |||||
PROPERTY AND EQUIPMENT: | |||||||
Unevaluated properties | 5,878 | 5,984 | |||||
Oil and natural gas properties (full cost method) | 145,074 | 120,333 | |||||
Furniture, fixtures and equipment | 1,291 | 1,039 | |||||
152,243 | 127,356 | ||||||
Less: Accumulated depletion, depreciation and amortization | (24,783 | ) | (15,899 | ) | |||
Net property and equipment | 127,460 | 111,457 | |||||
Fair value of oil and natural gas derivatives | 447 | 566 | |||||
Deferred tax asset | 937 | 937 | |||||
Other | 626 | 691 | |||||
TOTAL ASSETS | $ | 143,830 | $ | 152,141 | |||
LIABILITIES AND STOCKHOLDERS’ EQUITY | |||||||
CURRENT LIABILITIES: | |||||||
Accounts payable | $ | 21,140 | $ | 17,204 | |||
Accrued liabilities | 13,381 | 18,075 | |||||
Fair value of oil and natural gas derivatives | 2,045 | 1,002 | |||||
Total current liabilities | 36,566 | 36,281 | |||||
Long term debt, net | 50,080 | 55,725 | |||||
Accrued abandonment cost | 3,442 | 3,367 | |||||
Fair value of oil and natural gas derivatives | 608 | 517 | |||||
Total liabilities | 90,696 | 95,890 | |||||
Commitments and contingencies (See Note 9) | |||||||
STOCKHOLDERS’ EQUITY: | |||||||
Preferred stock: 10,000,000 shares $1.00 par value authorized, and none issued and outstanding | — | — | |||||
Common stock: $0.01 par value, 75,000,000 shares authorized, and 11,836,986 shares issued and outstanding at June 30, 2018 and $0.01 par value, 75,000,000 shares authorized, and 10,770,962 shares issued and outstanding at December 31, 2017 | 119 | 108 | |||||
Treasury stock (75,475 and zero shares, respectively) | (832 | ) | — | ||||
Additional paid in capital | 74,135 | 68,446 | |||||
Accumulated deficit | (20,288 | ) | (12,303 | ) | |||
Total stockholders’ equity | 53,134 | 56,251 | |||||
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY | $ | 143,830 | $ | 152,141 |
Three Months Ended June 30, | Three Months Ended June 30, | Six Months Ended June 30, | Six Months Ended June 30, | ||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
REVENUES: | |||||||||||||||
Oil and natural gas revenues | $ | 17,784 | $ | 12,115 | $ | 29,627 | $ | 21,526 | |||||||
Other | 51 | 350 | 42 | 352 | |||||||||||
17,835 | 12,465 | 29,669 | 21,878 | ||||||||||||
OPERATING EXPENSES: | |||||||||||||||
Lease operating expense | 2,465 | 2,950 | 5,031 | 7,261 | |||||||||||
Production and other taxes | 669 | 424 | 1,309 | 1,083 | |||||||||||
Transportation and processing | 2,086 | 1,868 | 3,398 | 3,044 | |||||||||||
Depreciation, depletion and amortization | 5,560 | 3,083 | 9,012 | 5,377 | |||||||||||
General and administrative | 4,803 | 3,772 | 9,999 | 8,235 | |||||||||||
Other | 165 | — | 165 | — | |||||||||||
15,748 | 12,097 | 28,914 | 25,000 | ||||||||||||
Operating income (loss) | 2,087 | 368 | 755 | (3,122 | ) | ||||||||||
OTHER INCOME (EXPENSE): | |||||||||||||||
Interest expense | (2,732 | ) | (2,360 | ) | (5,405 | ) | (4,539 | ) | |||||||
Interest income and other expense | 116 | 12 | 109 | 21 | |||||||||||
Gain (loss) on commodity derivatives not designated as hedges | (2,174 | ) | 766 | (3,155 | ) | 506 | |||||||||
(4,790 | ) | (1,582 | ) | (8,451 | ) | (4,012 | ) | ||||||||
Reorganization items, net | 42 | — | (289 | ) | 195 | ||||||||||
Loss before income taxes | (2,661 | ) | (1,214 | ) | (7,985 | ) | (6,939 | ) | |||||||
Income tax expense | — | — | — | — | |||||||||||
Net loss | $ | (2,661 | ) | $ | (1,214 | ) | $ | (7,985 | ) | $ | (6,939 | ) | |||
PER COMMON SHARE | |||||||||||||||
Net loss applicable to common stock - basic | $ | (0.23 | ) | $ | (0.13 | ) | $ | (0.70 | ) | $ | (0.74 | ) | |||
Net loss applicable to common stock - diluted | $ | (0.23 | ) | $ | (0.13 | ) | $ | (0.70 | ) | $ | (0.74 | ) | |||
Weighted average common shares outstanding - basic | 11,629 | 9,670 | 11,424 | 9,381 | |||||||||||
Weighted average common shares outstanding - diluted | 11,629 | 9,670 | 11,424 | 9,381 |
Six Months Ended June 30, | Six Months Ended June 30, | ||||||
2018 | 2017 | ||||||
CASH FLOWS FROM OPERATING ACTIVITIES: | |||||||
Net loss | $ | (7,985 | ) | $ | (6,939 | ) | |
Adjustments to reconcile net loss to net cash provided by operating activities: | |||||||
Depletion, depreciation and amortization | 9,012 | 5,377 | |||||
(Gain) loss on commodity derivatives not designated as hedges | 3,155 | (506 | ) | ||||
Net cash received from (paid for) settlement of commodity derivative instruments | (541 | ) | 147 | ||||
Share based compensation (non-cash) | 3,167 | 3,379 | |||||
Amortization of finance cost, debt discount, paid in-kind interest and accretion | 5,157 | 3,975 | |||||
(Gain) loss from material transfers and inventory write-down | 218 | (73 | ) | ||||
Reorganization items, net | 289 | (78 | ) | ||||
Change in assets and liabilities: | |||||||
Accounts receivable, trade and other, net of allowance | (598 | ) | 1,757 | ||||
Accrued oil and natural gas revenue | (2,359 | ) | (2,626 | ) | |||
Prepaid expenses and other | (20 | ) | (400 | ) | |||
Accounts payable | 3,936 | 11,211 | |||||
Accrued liabilities | (776 | ) | 904 | ||||
Net cash provided by operating activities | 12,655 | 16,128 | |||||
CASH FLOWS FROM INVESTING ACTIVITIES: | |||||||
Capital expenditures | (53,100 | ) | (17,519 | ) | |||
Proceeds from sale of assets | 26,920 | — | |||||
Net cash used in investing activities | (26,180 | ) | (17,519 | ) | |||
CASH FLOWS FROM FINANCING ACTIVITIES: | |||||||
Principal payments of bank borrowings | (16,723 | ) | — | ||||
Proceeds from bank borrowings | 6,000 | — | |||||
Net receipts (payments) related to Convertible Second Lien Notes | 3 | (170 | ) | ||||
Issuance cost, net | (10 | ) | (278 | ) | |||
Other | (8 | ) | — | ||||
Net cash used in financing activities | (10,738 | ) | (448 | ) | |||
DECREASE IN CASH AND CASH EQUIVALENTS | (24,263 | ) | (1,839 | ) | |||
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD | 25,992 | 36,850 | |||||
CASH AND CASH EQUIVALENTS, END OF PERIOD | $ | 1,729 | $ | 35,011 | |||
Supplemental disclosures of cash flow information: | |||||||
Cash paid for reorganization items, net | $ | 543 | $ | 828 | |||
Cash paid for interest | $ | 249 | $ | 581 | |||
Increase (decrease) in non-cash capital expenditures | $ | (2,805 | ) | $ | 1,526 |
(In thousands) | June 30, 2018 | December 31, 2017 | |||||
Trade payables | $ | 8,300 | $ | 4,092 | |||
Revenue payable | 12,234 | 10,692 | |||||
Prepayments from partners | 374 | 2,193 | |||||
Miscellaneous payables | 232 | 227 | |||||
Total Accounts payable | $ | 21,140 | $ | 17,204 |
(In thousands) | June 30, 2018 | December 31, 2017 | |||||
Accrued capital expenditures | $ | 7,706 | $ | 10,511 | |||
Accrued lease operating expense | 843 | 786 | |||||
Accrued production and other taxes | 713 | 449 | |||||
Accrued transportation and gathering | 1,132 | 1,130 | |||||
Accrued performance bonus | 1,854 | 3,869 | |||||
Accrued interest | 3 | 244 | |||||
Accrued office lease | 658 | 696 | |||||
Accrued reorganization costs | 307 | 168 | |||||
Accrued general and administrative expense and other | 165 | 222 | |||||
Total Accrued liabilities | $ | 13,381 | $ | 18,075 |
• | Level 1 Inputs— unadjusted quoted market prices in active markets for identical assets or liabilities. We have no Level 1 instruments; |
• | Level 2 Inputs— quotes that are derived principally from or corroborated by observable market data. Included in this Level are our 2017 Senior Credit Facility and commodity derivatives whose fair values are based on third-party quotes or available interest rate information and commodity pricing data obtained from third party pricing sources and our creditworthiness or that of our counterparties; and |
• | Level 3 Inputs— unobservable inputs for the asset or liability, such as discounted cash flow models or valuations, based on our various assumptions and future commodity prices. Included in this Level would be our initial measurement of asset retirement obligations. |
Three Months Ended June 30, 2018 | Six Months Ended June 30, 2018 | |||||||||||||||||||||||||||||||
(In thousands) | Oil Revenue | Gas Revenue | NGL Revenue | Total Revenue (As Reported) | Oil Revenue | Gas Revenue | NGL Revenue | Total Revenue (As Reported) | ||||||||||||||||||||||||
Operated | $ | 3,835 | $ | 10,900 | $ | — | $ | 14,735 | $ | 7,634 | $ | 16,701 | $ | — | $ | 24,335 | ||||||||||||||||
Non-operated | 133 | 2,912 | 4 | 3,049 | 276 | 5,008 | 8 | 5,292 | ||||||||||||||||||||||||
Total oil and natural gas revenues | $ | 3,968 | $ | 13,812 | $ | 4 | $ | 17,784 | $ | 7,910 | $ | 21,709 | $ | 8 | $ | 29,627 |
Three Months Ended June 30, 2017 | Six Months Ended June 30, 2017 | |||||||||||||||||||||||||||||||
(In thousands) | Oil Revenue | Gas Revenue | NGL Revenue | Total Revenue (As Reported) | Oil Revenue | Gas Revenue | NGL Revenue | Total Revenue (As Reported) | ||||||||||||||||||||||||
Operated | $ | 3,888 | $ | 4,716 | $ | — | $ | 8,604 | $ | 7,867 | $ | 6,062 | $ | — | $ | 13,929 | ||||||||||||||||
Non-operated | 141 | 3,366 | 4 | 3,511 | 272 | 7,315 | 10 | 7,597 | ||||||||||||||||||||||||
Total oil and natural gas revenues | $ | 4,029 | $ | 8,082 | $ | 4 | $ | 12,115 | $ | 8,139 | $ | 13,377 | $ | 10 | $ | 21,526 |
Six Months Ended June 30, 2018 | |||
Beginning balance at December 31, 2017 | $ | 3,367 | |
Liabilities incurred | 122 | ||
Accretion expense | 128 | ||
Dispositions * | (175 | ) | |
Ending balance at June 30, 2018 | $ | 3,442 | |
Current liability | $ | — | |
Long term liability | $ | 3,442 |
June 30, 2018 | December 31, 2017 | |||||||||||||||
Principal | Carrying Amount | Principal | Carrying Amount | |||||||||||||
2017 Senior Credit Facility | $ | 6,000 | $ | 6,000 | $ | 16,723 | $ | 16,723 | ||||||||
Convertible Second Lien Notes (1) | 50,224 | 44,080 | 47,015 | 39,002 | ||||||||||||
Total debt | $ | 56,224 | $ | 50,080 | $ | 63,738 | $ | 55,725 |
Three Months Ended June 30, 2018 | Three Months Ended June 30, 2017 | Six Months Ended June 30, 2018 | Six Months Ended June 30, 2017 | ||||||||||||||||||||||||
Interest Expense | Effective Interest Rate | Interest Expense | Effective Interest Rate | Interest Expense | Effective Interest Rate | Interest Expense | Effective Interest Rate | ||||||||||||||||||||
2017 Senior Credit Facility | $ | 75 | * | $ | — | — | % | $ | 248 | 7.8 | % | $ | — | — | % | ||||||||||||
Exit Credit Facility | — | — | % | 279 | 6.6 | % | — | — | % | 531 | 6.3 | % | |||||||||||||||
Convertible Second Lien Notes (1) | 2,657 | 24.7 | % | 2,081 | 24.3 | % | 5,157 | 24.8 | % | 4,008 | 24.3 | % | |||||||||||||||
Total interest expense | $ | 2,732 | $ | 2,360 | $ | 5,405 | $ | 4,539 |
Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||||
2018 | 2017 | 2018 | 2017 | |||||||||||||
(Amounts in thousands, except per share data) | ||||||||||||||||
Basic and Diluted net loss per share: | ||||||||||||||||
Net loss applicable to common stock | $ | (2,661 | ) | $ | (1,214 | ) | $ | (7,985 | ) | $ | (6,939 | ) | ||||
Weighted average shares of common stock outstanding | 11,629 | 9,670 | 11,424 | 9,381 | ||||||||||||
Basic and Diluted net loss per share (1) (2) | $ | (0.23 | ) | $ | (0.13 | ) | $ | (0.70 | ) | $ | (0.74 | ) | ||||
(1) Common shares issuable on assumed conversion of share-based compensation were not included in the computation of diluted loss per common share since their inclusion would have been anti-dilutive. * | 491 | 334 | 346 | 296 | ||||||||||||
(2) Common shares issuable upon conversion of the Convertible Second Lien Notes and associated warrants and unsecured claim holders were not included in the computation of diluted loss per common share since their inclusion would have been anti-dilutive. | 3,517 | 4,389 | 3,517 | 4,389 |
Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||||
Oil and Natural Gas Derivatives (in thousands) | 2018 | 2017 | 2018 | 2017 | ||||||||||||
Gain (loss) on commodity derivatives not designated as hedges, settled | $ | (156 | ) | $ | 4 | $ | (541 | ) | $ | 147 | ||||||
Gain (loss) on commodity derivatives not designated as hedges, not settled | (2,018 | ) | 762 | (2,614 | ) | 359 | ||||||||||
Total gain (loss) on commodity derivatives not designated as hedges | $ | (2,174 | ) | $ | 766 | $ | (3,155 | ) | $ | 506 |
Contract Type | Daily Volume | Total Volume | Fixed Price | Fair Value at June 30, 2018 (In thousands) | ||||||||||
Oil swaps (Bbls) | ||||||||||||||
2019 | 312 | 114,025 | $ | 51.08 | $ | (1,438 | ) | |||||||
2018 | 350 | 64,400 | $ | 51.08 | (1,216 | ) | ||||||||
Total Oil | $ | (2,654 | ) | |||||||||||
Natural Gas swaps (MMBtu) | ||||||||||||||
2020 (through March 31, 2020) | 40,000 | 3,640,000 | $ | 2.814 | $ | (368 | ) | |||||||
2019 | 42,466 | 15,500,000 | $2.814-$3.033 | 1,048 | ||||||||||
2018 | 38,500 | 7,084,000 | $2.985-$3.033 | 441 | ||||||||||
Total Natural Gas | $ | 1,121 | ||||||||||||
Total Oil and Natural Gas | $ | (1,533 | ) |
Description | Level 1 | Level 2 | Level 3 | Total | ||||||||||||
Fair value of oil and natural gas derivatives - Current Assets | $ | — | $ | 673 | $ | — | $ | 673 | ||||||||
Fair value of oil and natural gas derivatives - Non-current Assets | — | 447 | — | 447 | ||||||||||||
Fair value of oil and natural gas derivatives - Current Liabilities | — | (2,045 | ) | — | (2,045 | ) | ||||||||||
Fair value of oil and natural gas derivatives - Non-current Liabilities | — | (608 | ) | — | (608 | ) | ||||||||||
Total | $ | — | $ | (1,533 | ) | $ | — | $ | (1,533 | ) |
June 30, 2018 | December 31, 2017 | |||||||||||||||||||||||
Fair Value of Oil and Natural Gas Derivatives (in thousands) | Gross Amount | Amount Offset | As Presented | Gross Amount | Amount Offset | As Presented | ||||||||||||||||||
Fair value of oil and natural gas derivatives - Current Assets | $ | 1,227 | $ | (554 | ) | $ | 673 | $ | 2,035 | $ | (1 | ) | $ | 2,034 | ||||||||||
Fair value of oil and natural gas derivatives - Non-current Assets | 885 | (438 | ) | 447 | 633 | (67 | ) | 566 | ||||||||||||||||
Fair value of oil and natural gas derivatives - Current Liabilities | (2,599 | ) | 554 | (2,045 | ) | (1,002 | ) | — | (1,002 | ) | ||||||||||||||
Fair value of oil and natural gas derivatives - Non-current Liabilities | (1,046 | ) | 438 | (608 | ) | (585 | ) | 68 | (517 | ) | ||||||||||||||
Total | $ | (1,533 | ) | $ | — | $ | (1,533 | ) | $ | 1,081 | $ | — | $ | 1,081 |
• | the market prices of oil and natural gas; |
• | volatility in the commodity-futures market; |
• | financial market conditions and availability of capital; |
• | future cash flows, credit availability and borrowings; |
• | sources of funding for exploration and development; |
• | our financial condition; |
• | our ability to repay our debt; |
• | the securities, capital or credit markets; |
• | planned capital expenditures; |
• | future drilling activity; |
• | uncertainties about the estimated quantities of our oil and natural gas reserves; |
• | production; |
• | hedging arrangements; |
• | litigation matters; |
• | pursuit of potential future acquisition opportunities; |
• | general economic conditions, either nationally or in the jurisdictions in which we are doing business; |
• | legislative or regulatory changes, including retroactive royalty or production tax regimes, hydraulic-fracturing regulation, drilling and permitting regulations, derivatives reform, changes in state and federal corporate taxes, environmental regulation, environmental risks and liability under federal, state and foreign and local environmental laws and regulations; |
• | the creditworthiness of our financial counterparties and operation partners; and |
• | other factors discussed below and elsewhere in this Quarterly Report on Form 10-Q and in our other public filings, press releases and discussions with our management. |
Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||||||||||||||||||
(In thousands, except for price and average daily production data) | 2018 | 2017 | Variance | 2018 | 2017 | Variance | ||||||||||||||||||||||||
Revenues: | ||||||||||||||||||||||||||||||
Natural gas | $ | 13,816 | $ | 8,086 | $ | 5,730 | 71 | % | $ | 21,717 | $ | 13,387 | $ | 8,330 | 62 | % | ||||||||||||||
Oil and condensate | 3,968 | 4,029 | (61 | ) | (2 | )% | 7,910 | 8,139 | (229 | ) | (3 | )% | ||||||||||||||||||
Natural gas, oil and condensate | 17,784 | 12,115 | 5,669 | 47 | % | 29,627 | 21,526 | 8,101 | 38 | % | ||||||||||||||||||||
Net Production: | ||||||||||||||||||||||||||||||
Natural gas (MMcf) | 5,170 | 2,795 | 2,375 | 85 | % | 8,122 | 4,628 | 3,494 | 75 | % | ||||||||||||||||||||
Oil and condensate (MBbls) | 57 | 84 | (27 | ) | (32 | )% | 118 | 166 | (48 | ) | (29 | )% | ||||||||||||||||||
Total (Mmcfe) | 5,513 | 3,299 | 2,214 | 67 | % | 8,829 | 5,623 | 3,206 | 57 | % | ||||||||||||||||||||
Average daily production (Mcfe/d) | 60,582 | 36,253 | 24,329 | 67 | % | 48,779 | 31,066 | 17,713 | 57 | % | ||||||||||||||||||||
Average realized sales price per unit: | ||||||||||||||||||||||||||||||
Natural gas (per Mcf) | $ | 2.67 | $ | 2.89 | $ | (0.22 | ) | (8 | )% | $ | 2.67 | $ | 2.89 | $ | (0.22 | ) | (8 | )% | ||||||||||||
Natural gas (per Mcf) including the effect of realized gains/losses on derivatives | $ | 2.76 | $ | 2.89 | $ | (0.13 | ) | (4 | )% | $ | 2.74 | $ | 2.92 | $ | (0.18 | ) | (6 | )% | ||||||||||||
Oil and condensate (per Bbl) | $ | 69.39 | $ | 47.96 | $ | 21.43 | 45 | % | $ | 67.12 | $ | 49.03 | $ | 18.09 | 37 | % | ||||||||||||||
Oil and condensate (per Bbl) including the effect of realized losses on derivatives | $ | 58.69 | $ | 47.96 | $ | 10.73 | 22 | % | $ | 58.33 | $ | 49.03 | $ | 9.30 | 19 | % | ||||||||||||||
Average realized price (per Mcfe) | $ | 3.23 | $ | 3.67 | $ | (0.44 | ) | (12 | )% | $ | 3.36 | $ | 3.83 | $ | (0.47 | ) | (12 | )% |
Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||||||||||||||||||
Operating Expenses (in thousands) | 2018 | 2017 | Variance | 2018 | 2017 | Variance | ||||||||||||||||||||||||
Lease operating expenses | $ | 2,465 | $ | 2,950 | $ | (485 | ) | (16 | )% | $ | 5,031 | $ | 7,261 | $ | (2,230 | ) | (31 | )% | ||||||||||||
Production and other taxes | 669 | 424 | 245 | 58 | % | 1,309 | 1,083 | 226 | 21 | % | ||||||||||||||||||||
Operating Expenses per Mcfe | ||||||||||||||||||||||||||||||
Lease operating expenses | $ | 0.45 | $ | 0.89 | $ | (0.44 | ) | (49 | )% | $ | 0.57 | $ | 1.29 | $ | (0.72 | ) | (56 | )% | ||||||||||||
Production and other taxes | $ | 0.12 | $ | 0.13 | $ | (0.01 | ) | (8 | )% | $ | 0.15 | $ | 0.19 | $ | (0.04 | ) | (21 | )% |
Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||||||||||||||||||
Operating Expenses (in thousands): | 2018 | 2017 | Variance | 2018 | 2017 | Variance | ||||||||||||||||||||||||
Transportation and processing | $ | 2,086 | $ | 1,868 | $ | 218 | 12 | % | $ | 3,398 | $ | 3,044 | $ | 354 | 12 | % | ||||||||||||||
Depreciation, depletion and amortization | 5,560 | 3,083 | 2,477 | 80 | % | 9,012 | 5,377 | 3,635 | 68 | % | ||||||||||||||||||||
General and administrative | 4,803 | 3,772 | 1,031 | 27 | % | 9,999 | 8,235 | 1,764 | 21 | % | ||||||||||||||||||||
Other | 165 | — | 165 | 100 | % | 165 | — | 165 | 100 | % | ||||||||||||||||||||
Operating Expenses per Mcfe | ||||||||||||||||||||||||||||||
Transportation and processing | $ | 0.38 | $ | 0.57 | $ | (0.19 | ) | (33 | )% | $ | 0.38 | $ | 0.54 | $ | (0.16 | ) | (30 | )% | ||||||||||||
Depreciation, depletion and amortization | $ | 1.01 | $ | 0.93 | $ | 0.08 | 9 | % | $ | 1.02 | $ | 0.96 | $ | 0.06 | 6 | % | ||||||||||||||
General and administrative | $ | 0.87 | $ | 1.14 | $ | (0.27 | ) | (24 | )% | $ | 1.13 | $ | 1.46 | $ | (0.33 | ) | (23 | )% | ||||||||||||
Other | $ | 0.03 | $ | — | $ | 0.03 | 100 | % | $ | 0.02 | $ | — | $ | 0.02 | 100 | % |
Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||||||||||||||||||
Other income (expense) (in thousands): | 2018 | 2017 | Variance | 2018 | 2017 | Variance | ||||||||||||||||||||||||
Interest expense | $ | (2,732 | ) | $ | (2,360 | ) | $ | (372 | ) | 16 | % | $ | (5,405 | ) | $ | (4,539 | ) | $ | (866 | ) | 19 | % | ||||||||
Interest income and other | 116 | 12 | 104 | 867 | % | 109 | 21 | 88 | 419 | % | ||||||||||||||||||||
Gain (loss) on commodity derivatives not designated as hedges | (2,174 | ) | 766 | (2,940 | ) | (384 | )% | (3,155 | ) | 506 | (3,661 | ) | (724 | )% | ||||||||||||||||
Average funded borrowings adjusted for debt discount and accretion | $ | 43,401 | $ | 50,488 | $ | (7,087 | ) | (14 | )% | $ | 46,875 | $ | 49,490 | $ | (2,615 | ) | (5 | )% | ||||||||||||
Average funded borrowings | $ | 50,194 | $ | 60,165 | $ | (9,971 | ) | (17 | )% | $ | 54,119 | $ | 59,459 | $ | (5,340 | ) | (9 | )% |
Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||||
(In thousands) | 2018 | 2017 | 2018 | 2017 | ||||||||||||
Net loss (US GAAP) | $ | (2,661 | ) | $ | (1,214 | ) | $ | (7,985 | ) | $ | (6,939 | ) | ||||
Interest expense | 2,732 | 2,360 | 5,405 | 4,539 | ||||||||||||
Depreciation, depletion and amortization | 5,560 | 3,083 | 9,012 | 5,377 | ||||||||||||
Share based compensation expense (non-cash) | 1,491 | 1,651 | 3,167 | 3,379 | ||||||||||||
Mark-to-market (gain) loss on commodity derivatives not designated as hedges | 2,018 | (762 | ) | 2,614 | (359 | ) | ||||||||||
Other items (1) | (240 | ) | (12 | ) | 98 | (216 | ) | |||||||||
Adjusted EBITDA | $ | 8,900 | $ | 5,106 | $ | 12,311 | $ | 5,781 |
(1) | Other items include interest income, reorganization and other non-recurring income and expense. |
• | sale of non-core assets; |
• | joint venture partnerships in our TMS, Eagle Ford Shale Trend, and/or core Haynesville Shale Trend acreage; and |
• | issuance of debt or equity securities. |
Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||||
2018 | 2017 | 2018 | 2017 | |||||||||||||
Cash flow statement information: | ||||||||||||||||
Net cash: | ||||||||||||||||
Provided by operating activities | $ | 6,399 | $ | 10,863 | $ | 12,655 | $ | 15,528 | ||||||||
Used in investing activities | (20,399 | ) | (14,135 | ) | (26,180 | ) | (17,519 | ) | ||||||||
Provided by (used in) financing activities | 5,998 | (266 | ) | (10,738 | ) | (448 | ) | |||||||||
Decrease in cash and cash equivalents | $ | (8,002 | ) | $ | (3,538 | ) | $ | (24,263 | ) | $ | (2,439 | ) |
June 30, 2018 | December 31, 2017 | |||||||||||||||
Principal | Carrying Amount | Principal | Carrying Amount | |||||||||||||
2017 Senior Credit Facility | $ | 6,000 | $ | 6,000 | $ | 16,723 | $ | 16,723 | ||||||||
Convertible Second Lien Notes (1) | 50,224 | 44,080 | 47,015 | 39,002 | ||||||||||||
Total debt | $ | 56,224 | $ | 50,080 | $ | 63,738 | $ | 55,725 |
3.1 | |
3.2 | |
10.1* | |
31.1* | |
31.2* | |
32.1** | |
32.2** | |
101.INS* | XBRL Instance Document |
101.SCH* | XBRL Schema Document |
101.CAL* | XBRL Calculation Linkbase Document |
101.LAB* | XBRL Labels Linkbase Document |
101.PRE* | XBRL Presentation Linkbase Document |
101.DEF* | XBRL Definition Linkbase Document |
* | Filed herewith |
** | Furnished herewith |
GOODRICH PETROLEUM CORPORATION (Registrant) | ||
Date: August 7, 2018 | By: | /S/ Walter G. Goodrich |
Walter G. Goodrich | ||
Chairman & Chief Executive Officer | ||
Date: August 7, 2018 | By: | /S/ Robert T. Barker |
Robert T. Barker | ||
Senior Vice President, Controller, Chief Accounting Officer and Chief Financial Officer |
Parent: | GOODRICH PETROLEUM CORPORATION |
By: /s/Walter G. Goodrich Name: Walter G. Goodrich Title: Chairman & CEO |
Borrower: | GOODRICH PETROLEUM COMPANY, L.L.C. |
By: /s/Walter G. Goodrich Name: Walter G. Goodrich Title: CEO |
JPMORGAN CHASE BANK, N.A., as Administrative Agent, Issuing Lender, and a Lender | |
By: /s/Darren Vanek Name: Darren Vanek Title: Executive Director |
SUNTRUST BANK, as a Lender | |
By: /s/ Benjamin L. Brown Name: Benajmin L. Brown Title: Director |
1. | I have reviewed this quarterly report on Form 10-Q of Goodrich Petroleum Corporation (the “registrant”); |
2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
4. | The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
b) | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
c) | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
d) | Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
5. | The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): |
a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
Date: August 7, 2018 |
/s/ Walter G. Goodrich |
Walter G. Goodrich |
Chief Executive Officer |
1. | I have reviewed this quarterly report on Form 10-Q of Goodrich Petroleum Corporation (the “registrant”); |
2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
4. | The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
b) | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
c) | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
d) | Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
5. | The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): |
a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
Date: August 7, 2018 |
/s/ Robert T. Barker |
Robert T. Barker |
Senior Vice President, Controller, Chief Accounting Officer and Chief Financial Officer |
(1) | The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and |
(2) | The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. |
/s/ Walter G. Goodrich |
Walter G. Goodrich |
Chief Executive Officer |
August 7, 2018 |
(1) | The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and |
(2) | The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. |
/s/ Robert T. Barker |
Robert T. Barker |
Senior Vice President, Controller, Chief Accounting Officer and Chief Financial Officer |
August 7, 2018 |
Document and Entity Information - shares |
6 Months Ended | |
---|---|---|
Jun. 30, 2018 |
Aug. 06, 2018 |
|
Document And Entity Information [Abstract] | ||
Document Type | 10-Q | |
Amendment Flag | false | |
Document Period End Date | Jun. 30, 2018 | |
Document Fiscal Year Focus | 2018 | |
Document Fiscal Period Focus | Q2 | |
Trading Symbol | GDP | |
Entity Registrant Name | GOODRICH PETROLEUM CORP | |
Entity Central Index Key | 0000943861 | |
Current Fiscal Year End Date | --12-31 | |
Entity Filer Category | Smaller Reporting Company | |
Entity Common Stock, Shares Outstanding | 11,838,386 |
Consolidated Balance Sheets (Parenthetical) - $ / shares |
Jun. 30, 2018 |
Dec. 31, 2017 |
---|---|---|
Statement of Financial Position [Abstract] | ||
Preferred Stock, Par Value (in dollars per share) | $ 1.0 | $ 1.0 |
Preferred Stock, Shares Authorized | 10,000,000 | 10,000,000 |
Preferred Stock, Shares Issued | 0 | 0 |
Preferred Stock, Shares Outstanding | 0 | 0 |
Common stock, par value (in dollars per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized | 75,000,000 | 75,000,000 |
Common stock, shares issued | 11,836,986 | 10,770,962 |
Common stock, shares outstanding | 11,836,986 | 10,770,962 |
Treasury Stock, Shares | 75,475 | 0 |
Consolidated Statements Of Operations - USD ($) shares in Thousands |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2018 |
Jun. 30, 2017 |
Jun. 30, 2018 |
Jun. 30, 2017 |
|
REVENUES: | ||||
Oil and natural gas revenues | $ 17,784,000 | $ 12,115,000 | $ 29,627,000 | $ 21,526,000 |
Other | 51,000 | 350,000 | 42,000 | 352,000 |
Total revenues | 17,835,000 | 12,465,000 | 29,669,000 | 21,878,000 |
OPERATING EXPENSES: | ||||
Lease operating expense | 2,465,000 | 2,950,000 | 5,031,000 | 7,261,000 |
Production and other taxes | 669,000 | 424,000 | 1,309,000 | 1,083,000 |
Transportation and processing | 2,086,000 | 1,868,000 | 3,398,000 | 3,044,000 |
Depreciation, depletion and amortization | 5,560,000 | 3,083,000 | 9,012,000 | 5,377,000 |
General and administrative | 4,803,000 | 3,772,000 | 9,999,000 | 8,235,000 |
Other | 165,000 | 0 | 165,000 | 0 |
Operating Expenses, Total | 15,748,000 | 12,097,000 | 28,914,000 | 25,000,000 |
Operating income (loss) | 2,087,000 | 368,000 | 755,000 | (3,122,000) |
OTHER INCOME (EXPENSE): | ||||
Interest expense | (2,732,000) | (2,360,000) | (5,405,000) | (4,539,000) |
Interest income and other expense | 116,000 | 12,000 | 109,000 | 21,000 |
Gain (loss) on commodity derivatives not designated as hedges | (2,174,000) | 766,000 | (3,155,000) | 506,000 |
Nonoperating Income (Expense), Total | (4,790,000) | (1,582,000) | (8,451,000) | (4,012,000) |
Reorganization items, net | 42,000 | 0 | (289,000) | 195,000 |
Loss before income taxes | (2,661,000) | (1,214,000) | (7,985,000) | (6,939,000) |
Income tax expense | 0 | 0 | 0 | 0 |
Net loss | $ (2,661,000) | $ (1,214,000) | $ (7,985,000) | $ (6,939,000) |
PER COMMON SHARE | ||||
Net loss applicable to common stock - basic (in dollars per share) | $ (0.23) | $ (0.13) | $ (0.70) | $ (0.74) |
Net loss applicable to common stock - diluted (in dollars per share) | $ (0.23) | $ (0.13) | $ (0.70) | $ (0.74) |
Weighted average common shares outstanding - basic (shares) | 11,629 | 9,670 | 11,424 | 9,381 |
Weighted average common shares outstanding - diluted (shares) | 11,629 | 9,670 | 11,424 | 9,381 |
Description of Business and Significant Accounting Policies |
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Accounting Policies [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Description of Business and Significant Accounting Policies | Description of Business and Significant Accounting Policies Goodrich Petroleum Corporation (“Goodrich” and, together with its wholly-owned subsidiary, Goodrich Petroleum Company, L.L.C. (the “Subsidiary”), “we,” “our,” or the “Company”) is an independent oil and natural gas company engaged in the exploration, development and production of oil and natural gas on properties primarily in (i) Northwest Louisiana and East Texas, which includes the Haynesville Shale Trend, (ii) Southwest Mississippi and Southeast Louisiana, which includes the Tuscaloosa Marine Shale Trend (“TMS”), and (iii) South Texas, which includes the Eagle Ford Shale Trend. Basis of Presentation The consolidated financial statements of the Company included in this Quarterly Report on Form 10-Q have been prepared, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”) and accordingly, certain information normally included in financial statements prepared in accordance with United States Generally Accepted Accounting Principles (“US GAAP”) has been condensed or omitted. This information should be read in conjunction with our consolidated financial statements and notes contained in our annual report on Form 10-K for the year ended December 31, 2017. Operating results for the three and six months ended June 30, 2018 are not necessarily indicative of the results that may be expected for the full year or for any interim period. Principles of Consolidation—The consolidated financial statements include the financial statements of the Company and the Subsidiary. Intercompany balances and transactions have been eliminated in consolidation. The consolidated financial statements reflect all normal recurring adjustments that, in the opinion of management, are necessary for a fair presentation. Certain data in prior periods’ financial statements have been adjusted to conform to the presentation of the current period. We have evaluated subsequent events through the date of this filing. Use of Estimates— Our management has made a number of estimates and assumptions relating to the reporting of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities to prepare these consolidated financial statements in conformity with US GAAP. Cash and Cash Equivalents—Cash and cash equivalents includes cash on hand, demand deposit accounts and temporary cash investments with maturities of ninety days or less at the date of purchase. Accounts Payable—Accounts payable consisted of the following amounts as of June 30, 2018 and December 31, 2017:
Accrued Liabilities—Accrued liabilities consisted of the following amounts as of June 30, 2018 and December 31, 2017:
Inventory –Inventory consists of casing and tubulars that are expected to be used in our capital drilling program. Inventory is carried on the Consolidated Balance Sheets at the lower of cost or market. Property and Equipment—Under US GAAP, two acceptable methods of accounting for oil and natural gas properties are allowed. These are the Successful Efforts Method and the Full Cost Method. Entities engaged in the production of oil and natural gas have the option of selecting either method for application in the accounting for their properties. The principal differences between the two methods are in the treatment of exploration costs, the computation of Depreciation, Depletion and Amortization (“DD&A”) expense and the assessment of impairment of oil and natural gas properties. We use the Full Cost Method to account for our investment in oil and gas properties. Under the Full Cost Method, we capitalize all costs associated with acquisitions, exploration, development and estimated abandonment costs. We capitalize internal costs that can be directly identified with the acquisition of leasehold, as well as drilling and completion activities, but do not include any costs related to production, general corporate overhead or similar activities. Unevaluated property costs are excluded from the amortization base until we make a determination as to the existence of proved reserves on the respective property or impairment. We review our unevaluated properties at the end of each quarter to determine whether the costs should be reclassified to proved oil and natural gas properties and thereby subject to DD&A and the full cost ceiling test. For the three months ended June 30, 2018 and 2017, we transferred $0.3 million and $1.9 million, respectively, from unevaluated properties to proved oil and natural gas properties. For the six months ended June 30, 2018 and 2017, we transferred $0.4 million and $12.8 million, respectively, from unevaluated properties to proved oil and natural gas properties. Our sales of oil and natural gas properties are accounted for as adjustments to net proved oil and natural gas properties with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves. We amortize our investment in oil and natural gas properties through DD&A expense using the units of production (the “UOP”) method. An amortization rate is calculated based on total proved reserves converted to equivalent thousand cubic feet of natural gas (“Mcfe”) as the denominator and the net book value of evaluated oil and gas asset together with the estimated future development cost of the proved undeveloped reserves as the numerator. The rate calculated per Mcfe is applied against the periods' production also converted to Mcfe to arrive at the periods' DD&A expense. Depreciation of furniture, fixtures and equipment, consisting of office furniture, computer hardware and software and leasehold improvements, is computed using the straight-line method over their estimated useful lives, which vary from three to five years. Full Cost Ceiling Test—The Full Cost Method requires that at the conclusion of each financial reporting period, the present value of estimated future net cash flows from proved reserves (adjusted for hedges and excluding cash flows related to estimated abandonment costs), be compared to the net capitalized costs of proved oil and natural gas properties, net of related deferred taxes. This comparison is referred to as a "ceiling test". If the net capitalized costs of proved oil and natural gas properties exceed the estimated discounted future net cash flows from proved reserves, we are required to write-down the value of our oil and natural gas properties to the value of the discounted cash flows. Estimated future net cash flows from proved reserves are calculated based on a 12-month average pricing assumption. There were no Full Cost Ceiling Test write-downs for the three or six months ended June 30, 2018 or 2017. Fair Value Measurement—Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The fair value of an asset should reflect its highest and best use by market participants, whether in-use or an in-exchange valuation premise. The fair value of a liability should reflect the risk of non-performance, which includes, among other things, our credit risk. We use various methods, including the income approach and market approach, to determine the fair values of our financial instruments that are measured at fair value on a recurring basis, which depend on a number of factors, including the availability of observable market data over the contractual term of the underlying instrument. For some of our instruments, the fair value is calculated based on directly observable market data or data available for similar instruments in similar markets. For other instruments, the fair value may be calculated based on these inputs as well as other assumptions related to estimates of future settlements of these instruments. We separate our financial instruments into three Levels (Levels 1, 2 and 3) based on our assessment of the availability of observable market data and the significance of non-observable data used to determine the fair value of our instruments. Our assessment of an instrument can change over time based on the maturity or liquidity of the instrument, which could result in a change in the classification of the instruments between Levels. Each of these Levels and our corresponding instruments classified by Level are further described below:
As of June 30, 2018 and December 31, 2017, the carrying amounts of our cash and cash equivalents, trade receivables and payables represented fair value because of the short-term nature of these instruments. Asset Retirement Obligations—Asset retirement obligations are related to the abandonment and site restoration requirements that result from the exploration and development of our oil and natural gas properties. We record the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. Accretion expense is included in “Depreciation, depletion and amortization” on our Consolidated Statements of Operations. See Note 3. The estimated fair value of the Company’s asset retirement obligations at inception is determined by utilizing the income approach by applying a credit-adjusted risk-free rate, which takes into account the Company’s credit risk, the time value of money, and the current economic state, to the undiscounted expected abandonment cash flows. Given the unobservable nature of the inputs, the initial measurement of the asset retirement obligations was classified as Level 3 in the fair value hierarchy. Revenue Recognition—Oil and natural gas revenues are recognized upon delivery of our produced oil and natural gas volumes to our customers. Revenues from the production of crude oil and natural gas properties in which we have an interest with other producers are recognized in accordance with when the producing company records revenue on those volumes. We record a liability or an asset for natural gas balancing when we have sold more or less than our working interest share of natural gas production, respectively. At June 30, 2018 and December 31, 2017, the net liability for natural gas balancing was immaterial. Differences between actual production and net working interest volumes are routinely adjusted. See Note 2. Derivative Instruments—We use derivative instruments such as futures, forwards, options, collars and swaps for purposes of hedging our exposure to fluctuations in the price of crude oil and natural gas and to hedge our exposure to changing interest rates. Accounting standards related to derivative instruments and hedging activities require that all derivative instruments subject to the requirements of those standards be measured at fair value and recognized as assets or liabilities in the balance sheet. We offset the fair value of our asset and liability positions with the same counterparty for each commodity type. Changes in fair value are required to be recognized in earnings unless specific hedge accounting criteria are met. All of our realized gain or losses on our derivative contracts are the result of cash settlements. We have not designated any of our derivative contracts as hedges; accordingly, changes in fair value are reflected in earnings. See Note 8. Income Taxes—We account for income taxes, as required, under the liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating loss and tax credit carry-forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. We recognize, as required, the financial statement benefit of an uncertain tax position only after determining that the relevant tax authority would more likely than not sustain the position following an audit. For tax positions meeting the more likely-than-not threshold, the amount recognized in the financial statements is the largest benefit that has a greater than 50 percent likelihood of being realized upon ultimate settlement with the relevant tax authority. See Note 7. Net Income or Net Loss Per Share—Basic income (loss) per common share is computed by dividing net income (loss) applicable to common stockholders for each reporting period by the weighted-average number of common shares outstanding during the period. Diluted income (loss) per common share is computed by dividing net income (loss) applicable to common stockholders for each reporting period by the weighted average number of common shares outstanding during the period, plus the effects of potentially dilutive restricted stock calculated using the treasury stock method and the potential dilutive effect of the conversion of convertible securities, such as warrants and convertible notes, into shares of our common stock. See Note 6. Commitments and Contingencies—Liabilities for loss contingencies, including environmental remediation costs, arising from claims, assessments, litigation, fines and penalties, and other sources are recorded when it is probable that a liability has been incurred and the amount of the assessment and/or remediation can be reasonably estimated. Recoveries from third parties, when probable of realization, are separately recorded and are not offset against the related environmental liability. See Note 9. Share-Based Compensation—We account for our share-based transactions using the fair value as of the grant date and recognize compensation expense over the requisite service period. Guarantee—As of June 30, 2018, Goodrich Petroleum Company LLC, the wholly owned subsidiary of Goodrich Petroleum Corporation, was the Subsidiary Guarantor of our 13.50% Convertible Second Lien Senior Secured notes due 2019 (the “Convertible Second Lien Notes”). Debt Issuance Cost—The Company records debt issuance costs associated with its Convertible Second Lien Notes as a contra balance to long term debt, net in our Consolidated Balance Sheets, which is amortized straight-line over the life of the Convertible Second Lien Notes. Debt issuance costs associated with our revolving credit facility debt are recorded in other assets in our Consolidated Balance Sheets, which is amortized straight-line over the life of such debt. New Accounting Pronouncements On June 20, 2018, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2018-07, Compensation—Stock Compensation (Topic 718): Improvements to Nonemployee Share-Based Payment Accounting. The amendments in this ASU expand the scope of Topic 718 to include share-based payment transactions for acquiring goods and services from nonemployees. The amendments specify that Topic 718 applies to all share-based payment transactions in which a grantor acquires goods or services to be used or consumed in a grantor’s own operations by issuing share-based payment awards. The amendments also clarify that Topic 718 does not apply to share-based payments used to effectively provide (1) financing to the issuer or (2) awards granted in conjunction with selling goods or services to customers as part of a contract accounted for under Topic 606, Revenue from Contracts with Customers. For public entities, the amendments in this ASU are effective for annual periods beginning after December 15, 2018. We have not granted or issued share-based payments to nonemployees. We have evaluated the provisions of this ASU and do not expect it to have a material impact on our consolidated financial statements. On March 13, 2018, the FASB issued ASU 2018-05, Income Taxes (Topic 740). The ASU adds seven paragraphs to the Accounting Standards Codification “ASC” 740, Income Taxes, that contain SEC guidance related to Staff Accounting Bulletin 118 (“Income Tax Accounting Implications of the Tax Cuts and Jobs Act”) as a result of the tax legislation passed in 2017 known as the “Tax Cuts and Jobs Act”. Specifically, the staff intended to address situations where the accounting under ASC Topic 740 is incomplete for certain income tax effects of the Tax Cuts and Jobs Act upon issuance of an entity’s financial statements for the reporting period in which the Tax Cuts and Jobs Act was enacted. The Company notes that it has considered the updates to ASC 740 as a result of the Tax Cuts and Jobs Act and has prepared its consolidated financial statements in accordance with the Tax Cuts and Jobs Act. See Note 7 for further discussion. On August 28, 2017, the FASB issued ASU 2017-12, Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities. This ASU is intended to improve the financial reporting of hedging relationships to better portray the economic results of an entity’s risk management activities in its financial statements. In addition, the amendments in this ASU make certain targeted improvements to simplify the application of the hedge accounting guidance in current GAAP based on the feedback received from preparers, auditors, users, and other stakeholders. For public entities, the amendments in this ASU are effective for annual periods beginning after December 15, 2018. We do not expect this ASU to have a material impact on our consolidated financial statements as we currently mark-to-market all of our derivative positions; however, we are evaluating the impact of this ASU should we choose to utilize hedge accounting in the future. On February 25, 2016, the FASB issued ASU 2016-02, Leases (Topic 842) and subsequently issued ASU 2018-10, Codification Improvements to Topic 842, Leases in July 2018. The key difference between the existing standards and ASU 2016-02 is the requirement for lessees to recognize on their balance sheet all lease contracts with lease terms greater than 12 months, including operating leases. Specifically, lessees are required to recognize on the balance sheet at lease commencement, both (i) a right-of-use asset, representing the lessee’s right to use the leased asset over the term of the lease, and (ii) a lease liability, representing the lessee’s contractual obligation to make lease payments over the term of the lease. For lessees, ASU 2016-02 requires classification of leases as either operating or finance leases, which are similar to the current operating and capital lease classifications. However, the distinction between these two classifications under the ASU does not relate to balance sheet treatment, but relate to treatment and recognition in the statements of income and cash flows. Lessor accounting is largely unchanged from current US GAAP. The amendments are effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years, for public entities. Early application is permitted. The Company has developed a project plan to guide the implementation of ASU 2016-02, which includes assessing our portfolio of leases and determining a process for ensuring completeness of our repository of active leases. We have not yet completed our evaluation of the impact the new lease accounting guidance will have on our consolidated financial statements; however, we do expect to recognize right of use assets and lease liabilities for our operating leases with terms longer than 12 months in the consolidated balance sheet upon adoption. |
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Asset Retirement Obligation Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||
Asset Retirement Obligations | Asset Retirement Obligations The reconciliation of the beginning and ending asset retirement obligation for the six months ended June 30, 2018 is as follows (in thousands):
* - See Note 10 for further information on the dispositions during the three and six months ended June 30, 2018. |
Revenue Recognition |
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Revenue Recognition | Revenue Recognition On January 1, 2018, we adopted ASU 2014-09, Revenue from Contracts with Customers, and the series of related ASU's that followed under ASC Topic 606 (collectively, “Topic 606”). Under Topic 606, revenue will generally be recognized upon delivery of our produced oil and natural gas volumes to our customers. Our customer sales contracts include oil and natural gas sales. Under Topic 606, each unit (Mcf or barrel) of commodity product represents a separate performance obligation which is sold at variable prices, determinable on a monthly basis. The pricing provisions of our contracts are primarily tied to a market index with certain adjustments based on factors such as delivery, product quality and prevailing supply and demand conditions in the geographic areas in which we operate. We will allocate the transaction price to each performance obligation and recognize revenue upon delivery of the commodity product when the customer obtains control. Control of our produced natural gas volumes passes to our customers at specific metered points indicated in our natural gas contracts. Similarly, control of our produced oil volumes passes to our customers when the oil is measured either by a trucking oil ticket or by a meter when entering an oil pipeline. The Company has no control over the commodities after those points and the measurement at those points dictates the amount on which the customer's payment is based. Our oil and natural gas revenue streams include volumes burdened by royalty and other joint owner working interests. Our revenues are recorded and presented on our financial statements net of the royalty and other joint owner working interests. Our revenue stream does not include any payments for services or ancillary items other than sale of oil and natural gas. We record revenue in the month our production is delivered to the purchaser. However, settlement statements and payments for our oil and natural gas sales may not be received for up to 60 days after the date production is delivered, and as a result, we are required to estimate the amount of production delivered to the purchaser and the price that will be received for the sale of the product. We record any differences, which historically have not been significant, between the actual amounts ultimately received and the original estimates in the period they become finalized. As of June 30, 2018 and December 31, 2017, receivables from contracts with customers were $7.3 million and $5.0 million, respectively. Topic 606 will not change our pattern of timing of revenue recognition. We utilized the full retrospective method for adoption of Topic 606, and in accordance with this method our consolidated financial statements for periods prior to January 1, 2018 were not materially affected or revised. We also do not anticipate a material impact on our financial statements on an ongoing basis. The following tables present our oil and natural gas revenues disaggregated by revenue source and by operated and non-operated properties:
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Equity |
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Jun. 30, 2018 | |
Equity [Abstract] | |
Equity | Equity During the three months ended June 30, 2018, certain holders of the 10 year costless warrants associated with the Convertible Second Lien Notes exercised 273,437 warrants for the issuance of an equal amount of our one cent par value common stock. The Company received cash for the one cent par value for the issuance of 273,437 common shares. During the six months ended June 30, 2018, certain holders of the 10 year costless warrants associated with the Convertible Second Lien Notes exercised 862,812 warrants for the issuance of an equal amount of our one cent par value common stock. The Company received cash for the one cent par value for the issuance of 315,937 common shares. As of June 30, 2018, 207,500 of such warrants remain un-exercised. During the three and six months ended June 30, 2017, holders of the 10 year costless warrants attached to the Convertible Second Lien Notes, exercised 1,375,000 warrants for the issuance of an equal amount of our one cent par value common stock. The Company received cash for the one cent par value for issuance of 625,000 common shares and the remaining common shares were issued cashless, which resulted in 564 shares repurchased by the Company and held in treasury stock. These treasury stock shares were subsequently retired. The Company had no material vestings of its share based compensation units during the three or six months ended June 30, 2018 or 2017. |
Debt |
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Debt Disclosure [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Debt | Debt Debt consisted of the following balances as of the dates indicated (in thousands):
(1) The debt discount is being amortized using the effective interest rate method based upon a maturity date of August 30, 2019. The principal includes $10.2 million and $7.0 million of paid in-kind interest at June 30, 2018 and December 31, 2017, respectively. The carrying value includes $6.1 million and $8.0 million of unamortized debt discount at June 30, 2018 and December 31, 2017, respectively. The following table summarizes the total interest expense for the periods shown including contractual interest expense, amortization of debt discount, accretion and financing costs and the effective interest rate on the liability component of the debt (amounts in thousands, except effective interest rates):
* - Not meaningful due to the timing of borrowings during the three months ended June 30, 2018. (1) Interest expense for the three months ended June 30, 2018 included $1.0 million of debt discount amortization and $1.6 million of paid in-kind interest, and interest expense for the three months ended June 30, 2017 included $0.7 million of debt discount amortization and $1.4 million of paid in-kind interest. Interest expense for the six months ended June 30, 2018 included $1.8 million of debt discount amortization and $3.2 million of paid in-kind interest, and interest expense for the six months ended June 30, 2017 included $1.2 million of debt discount amortization and $2.8 million of paid in-kind interest. Exit Credit Facility On October 12, 2016, upon consummation of the plan of reorganization and emergence from bankruptcy, the Company entered into an Exit Credit Agreement (the “Exit Credit Agreement”) with the Subsidiary, as borrower (the “Borrower”), and Wells Fargo Bank, National Association, as administrative agent, and certain other lenders party thereto. Pursuant to the Exit Credit Agreement, the lenders party thereto agreed to provide the Borrower with a $20.0 million senior secured term loan credit facility (the “Exit Credit Facility”). On October 17, 2017, the Exit Credit Facility was paid off in full and replaced with the 2017 Senior Credit Facility described below. 2017 Senior Credit Facility On October 17, 2017, the Company entered into the Amended and Restated Senior Secured Revolving Credit Agreement (the “Credit Agreement”) with the Subsidiary, as borrower, JP Morgan Chase Bank, N.A. as administrative agent, and certain lenders that are party thereto, which provides for revolving loans of up to the borrowing base then in effect (the “2017 Senior Credit Facility”). The 2017 Senior Credit Facility amends, restates and refinances the obligations under the Exit Credit Facility. The 2017 Senior Credit Facility matures (a) October 17, 2021 or (b) if the Convertible Second Lien Notes (as defined below) have not been voluntarily redeemed, repurchased, refinanced or otherwise retired by September 30, 2019, September 30, 2019. The maximum credit amount under the 2017 Senior Credit Facility at June 30, 2018 was $250.0 million with a borrowing base of $40.0 million. The borrowing base is scheduled to be redetermined in March and September of each calendar year, and is subject to additional adjustments from time to time, including for asset sales, elimination or reduction of hedge positions and incurrence of other debt. Additionally, each of the Borrower and the administrative agent may request one unscheduled redetermination of the borrowing base between scheduled redeterminations. The amount of the borrowing base is determined by the lenders in their sole discretion and consistent with their oil and gas lending criteria at the time of the relevant redetermination. On July 13, 2018, the borrowing base was increased to $60.0 million with an elected draw limit of $50.0 million in recognition of the limitation set forth in the Convertible Second Lien Notes. The Company may also request the issuance of letters of credit under the Credit Agreement in an aggregate amount up to $10.0 million, which reduce the amount of available borrowings under the borrowing base in the amount of such issued and outstanding letters of credit. All amounts outstanding under the 2017 Senior Credit Facility bear interest at a rate per annum equal to, at the Company's option, either (i) the alternative base rate plus an applicable margin ranging from 1.75% to 2.75%, depending on the percentage of the borrowing base that is utilized, or (ii) adjusted LIBOR plus an applicable margin from 2.75% to 3.75%, depending on the percentage of the borrowing base that is utilized. Undrawn amounts under the 2017 Senior Credit Facility are subject to a 0.50% commitment fee. To the extent that a payment default exists and is continuing, all amounts outstanding under the 2017 Senior Credit Facility will bear interest at 2.00% per annum above the rate and margin otherwise applicable thereto. As of June 30, 2018, the interest rate on the 2017 Senior Credit Facility was 6.75%. The 2017 Senior Credit Facility also contains certain financial covenants, including (i) the maintenance of a ratio of Total Debt (as defined in the Credit Agreement) to EBITDAX not to exceed 4.00 to 1.00 as of the last day of any fiscal quarter, (ii) a current ratio (based on the ratio of current assets to current liabilities) not to be less than 1.00 to 1.00 and (iii) until no Convertible Second Lien Notes remain outstanding, (A) the maintenance of a ratio of Total Proved PV10% attributable to the Company’s and Borrower’s Proved Reserves (as defined in the Credit Agreement) to Total Secured Debt (net of any Unrestricted Cash not to exceed $10.0 million) not to be less than 1.50 to 1.00 and (B) minimum liquidity requirements. The obligations under the Credit Agreement are guaranteed by the Company and are secured by a first lien security interest in substantially all of the assets of the Company and the Subsidiary. As of June 30, 2018, the Company had $6.0 million outstanding borrowings. The Company also had $0.5 million of unamortized debt issuance costs recorded as of June 30, 2018 related to the 2017 Senior Credit Facility. As of June 30, 2018, the Company was in compliance with all covenants within the 2017 Senior Credit Facility. 13.50% Convertible Second Lien Senior Secured Notes Due 2019 On October 12, 2016, upon emergence from bankruptcy, the Company and the Subsidiary, entered into a purchase agreement (the “Purchase Agreement”) with each entity identified as a Shenkman Purchaser on Appendix A to the Purchase Agreement (collectively, the “Shenkman Purchasers”), CVC Capital Partners (acting through such of its affiliates to managed funds as it deems appropriate), J.P. Morgan Securities LLC (acting through such of its affiliates or managed funds as it deems appropriate), Franklin Advisers, Inc. (as investment manager on behalf of certain funds and accounts), O’Connor Global Multi-Strategy Alpha Master Limited and Nineteen 77 Global Multi-Strategy Alpha (Levered) Master Limited (collectively, and together with each of their successors and assigns, the “Purchasers”), in connection with the issuance of $40.0 million aggregate principal amount of the Company’s 13.50% Convertible Second Lien Senior Secured Notes due 2019 (the “Convertible Second Lien Notes”). The aggregate principal amount of the Convertible Second Lien Notes is convertible at the option of the Purchasers at any time prior to the scheduled maturity date at $21.33 per share, subject to adjustments. At closing, the Purchasers were issued 10-year costless warrants to acquire 2.5 million shares of common stock. Holders of the Convertible Second Lien Notes have a second priority lien on all assets of the Company, and have a continuing right to appoint two members to our Board of Directors (the “Board”) as long as the Convertible Second Lien Notes are outstanding. The Convertible Second Lien Notes as set forth in the agreement, will mature on August 30, 2019 or six months after the maturity of our current revolving credit facility but in no event later than March 30, 2020. The 2017 Senior Credit Facility matures no earlier than September 30, 2019; consequently, the Convertible Second Lien Notes will mature on March 30, 2020. The Convertible Second Lien Notes bear interest at the rate of 13.50% per annum, payable quarterly in arrears on January 15, April 15, July 15 and October 15 of each year. The Company may elect to pay all or any portion of interest in-kind on the then outstanding principal amount of the Convertible Second Lien Notes by increasing the principal amount of the outstanding Convertible Second Lien Notes or by issuing additional Second Lien Notes (“PIK Interest Notes”). The PIK Interest Notes are not convertible. During such time as the Exit Credit Agreement (but not any refinancing or replacement thereof) was in effect, interest on the Convertible Second Lien Notes had to be paid in-kind. As to the new 2017 Senior Credit Facility, interest on the Convertible Second Lien Notes must be paid in-kind; provided however, that after the quarter ending March 31, 2018, if (i) there is no default, event of default or borrowing base deficiency that has occurred and is continuing, (ii) the ratio of total debt to EBITDAX as defined under the 2017 Senior Credit Facility is less than 1.75 to 1.0 and (iii) the unused borrowing base is at least 25%, then the Company can pay the interest on the Convertible Second Lien Notes in cash, at its election. The indenture governing the Convertible Second Lien Notes (the “Indenture”) contains certain covenants pertaining to us and our subsidiary, including delivery of financial reports; environmental matters; conduct of business; use of proceeds; operation and maintenance of properties; collateral and guarantee requirements; indebtedness; liens; dividends and distributions; limits on sale of assets and stock; business activities; transactions with affiliates; and changes of control. The Indenture also contains certain financial covenants, including the maintenance of (i) a Total Proved Asset Coverage Ratio (as defined in the Exit Credit Agreement) not to be less than 1.50 to 1.00 after September 30, 2017, to be determined as of January 1 and July 1 of each year and (ii) minimum liquidity requirements. Upon issuance of the Convertible Second Lien Notes in October 2016, in accordance with accounting standards related to convertible debt instruments that may be settled in cash upon conversion as well as warrants on the debt instrument, we recorded a debt discount of $11.0 million, thereby reducing the $40.0 million carrying value upon issuance to $29.0 million and recorded an equity component of $11.0 million. The debt discount is amortized using the effective interest rate method based upon an original term through August 30, 2019. $6.1 million of debt discount remains to be amortized on the Convertible Second Lien Notes as of June 30, 2018. As of June 30, 2018, the Company was in compliance with all covenants within the Indenture governing the Convertible Second Lien Notes. |
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Net Income (Loss) Per Common Share | Net Income (Loss) Per Common Share Net loss applicable to common stock was used as the numerator in computing basic and diluted loss per common share for the three and six months ended June 30, 2018 and 2017. The following table sets forth information related to the computations of basic and diluted loss per share:
* - Common shares issuable on assumed conversion of share-based compensation assumes a payout of the Company's performance share awards at 100% of the initial performance units granted (or a ratio of one unit to one common share). The range of common stock shares which may be earned ranges from zero to 250% of the initial performance units granted. |
Income Taxes |
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Jun. 30, 2018 | |
Income Tax Disclosure [Abstract] | |
Income Taxes | Income Taxes We recorded no income tax expense or benefit for the three or six months ended June 30, 2018. We recorded a valuation allowance for our net deferred tax asset at December 31, 2016. The valuation allowance was $86.7 million at December 31, 2017, which resulted in a net non-current deferred tax asset of $0.9 million appearing on our statement of financial position. We recorded this valuation allowance at this date after an evaluation of all available evidence (including our recent history of net operating losses in 2017 and prior years) that led to a conclusion that based upon the more-likely-than-not standard of the accounting literature, these deferred tax assets were unrecoverable. The tax benefit recorded for 2017 is due to Alternative Minimum Tax (“AMT”) credits that are expected to be recognized by the Company, which have been reduced for the anticipated sequestration. The remaining $0.9 million of AMT credits, which is less anticipated sequestration, are expected to be fully refundable in tax years 2018 - 2021 regardless of the Company's regular tax liability as a result of the repeal of the Corporate AMT under the Tax Cuts and Jobs Act. The Company no longer has a valuation allowance recorded against our estimate of refundable AMT credits. Considering the Company’s taxable income forecasts, our assessment of the realization of our deferred tax assets has not changed, and we continue to maintain a full valuation allowance for our net deferred tax assets as of June 30, 2018 aside from the deferred tax asset related to the AMT credits. As of June 30, 2018, we have no unrecognized tax benefits. There were no significant changes to the calculation since December 31, 2017. On December 22, 2017, the United States enacted tax reform legislation known as the H.R.1, commonly referred to as the “Tax Cuts and Jobs Act”, resulting in significant modifications to existing law. Our financial statements for the year ended December 31, 2017 and now for the three and six months ended June 30, 2018 reflect the effects of the Tax Cuts and Jobs Act which includes a reduction in the corporate tax rate from 35% to 21% effective January 1, 2018, as well as other changes. The Company follows the guidance in SEC Staff Accounting Bulletin 118 (“SAB 118”), which provides additional clarification regarding the application of ASC Topic 740 in situations where the Company does not have the necessary information available, prepared, or analyzed (including computations) in reasonable detail to complete the accounting for certain income tax effects of the Tax Cuts and Jobs Act for the reporting period in which the Tax Cuts and Jobs Act was enacted. SAB 118 provides for a measurement period beginning in the reporting period that includes the Tax Cuts and Jobs Act’s enactment date and ending when the Company has obtained, prepared, and analyzed the information needed in order to complete the accounting requirements but in no circumstances should the measurement period extend beyond one year from the enactment date. We calculated the impact of the Tax Cuts and Jobs Act in our year ended December 31, 2017 income tax provision in accordance with our understanding of the Tax Cuts and Jobs Act and guidance available. We continue to gather and evaluate the income tax impact of the Tax Cuts and Jobs Act. The ultimate impact of the Tax Cuts and Jobs Act on our reported results in 2018 and beyond may differ, possibly materially, due to, among other things, changes in interpretations and assumptions we have made, guidance that may be issued, and other actions we may take as a result of the Tax Cuts and Jobs Act. |
Commodity Derivative Activities |
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Derivative Instruments and Hedging Activities Disclosure [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Commodity Derivative Activities | Commodity Derivative Activities We use commodity and financial derivative contracts to manage fluctuations in commodity prices. We are currently not designating our derivative contracts for hedge accounting. All derivative gains and losses are from our oil and natural gas derivative contracts and have been recognized in “Other income (expense)” on our Consolidated Statements of Operations. The following table summarizes gains and losses we recognized on our oil and natural gas derivatives for the three and six months ended June 30, 2018 and 2017:
Commodity Derivative Activity We enter into swap contracts, costless collars or other derivative agreements from time to time to manage commodity price risk for a portion of our production. Our policy is that all derivatives are approved by the Hedging Committee of the Board, and reviewed periodically by the Board. Despite the measures taken by us to attempt to control price risk, we remain subject to price fluctuations for natural gas and crude oil sold in the spot market. Prices received for natural gas sold on the spot market are volatile due primarily to seasonality of demand and other factors beyond our control. Decreases in domestic crude oil and natural gas spot prices will have a material adverse effect on our financial position, results of operations and quantities of reserves recoverable on an economic basis. We routinely exercise our contractual right to net realized gains against realized losses when settling with our financial counterparties. Neither our counterparties nor we require any collateral upon entering into derivative contracts. We would have been at risk of losing $0.2 million had BP Energy Company been unable to fulfill their obligations as of June 30, 2018. As of June 30, 2018, the open positions on our outstanding commodity derivative contracts, all of which were with JPMorgan Chase Bank, N.A. and BP Energy Company, were as follows:
The following table summarizes the fair values of our derivative financial instruments that are recorded at fair value classified in each Level as of June 30, 2018 (in thousands). We measure the fair value of our commodity derivative contracts by applying the income approach. See Note 1—“Description of Business and Significant Accounting Policies” for our discussion regarding fair value, including inputs used and valuation techniques for determining fair values.
We enter into oil and natural gas derivative contracts under which we have netting arrangements with each counter party. The following table discloses and reconciles the gross amounts to the amounts as presented on the Consolidated Balance Sheets for the periods ending June 30, 2018 and December 31, 2017:
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Commitments and Contingencies |
6 Months Ended |
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Jun. 30, 2018 | |
Commitments and Contingencies Disclosure [Abstract] | |
Commitments and Contingencies | Commitments and Contingencies We are party to various lawsuits from time to time arising in the normal course of business, including, but not limited to, royalty, contract, personal injury, and environmental claims. We have established reserves as appropriate for all such proceedings and intend to vigorously defend these actions. Management believes, based on currently available information, that adverse results or judgments from such actions, if any, will not be material to our consolidated financial position, results of operations or liquidity. Operating Leases—We have commitments under operating lease agreements for office space and office equipment. Total rent expense for the three months ended June 30, 2018 and 2017 was approximately $0.4 million and $0.5 million, respectively. Total rent expense for the six months ended June 30, 2018 and 2017 was approximately $0.8 million and $0.9 million, respectively. |
Dispositions |
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Jun. 30, 2018 | |
Discontinued Operations and Disposal Groups [Abstract] | |
Dispositions | Dispositions On May 21, 2018, the Company closed on the sale of working interests in certain oil and gas leases, including wells, facilities and leasehold acres, in our Tuscaloosa Marine Shale Trend operating area located in East and West Feliciana Parish, Louisiana for total consideration of approximately $3.3 million with an effective date of May 1, 2018. The disposition was subject to customary post-closing adjustments. The disposition was recorded as a reduction to our oil and natural gas properties (full cost method) on our Consolidated Balance Sheet. On February 28, 2018, the Company closed, in two separate transactions, the sale of working interests in certain oil and gas leases, wells, units and facilities and certain net leasehold interests in a portion of its undeveloped acreage in the Angelina River Trend in Angelina and Nacogdoches Counties, Texas to BP America Production Company for total consideration of $23.0 million, with an effective date of January 1, 2018. The disposition was subject to customary post-closing adjustments. The disposition was recorded as a reduction to our oil and natural gas properties (full cost method) on our Consolidated Balance Sheet. The Company utilized the proceeds from these dispositions to pay down the outstanding balance of the 2017 Senior Credit Facility on March 2, 2018 and to fund our capital expenditures program. The Company also sold other miscellaneous acreage during the three and six months ended June 30, 2018 for $0.4 million and $0.7 million, respectively, which was also recorded as a reduction to our oil and natural gas properties (full cost method) on our Consolidated Balance Sheet. |
Subsequent Events |
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Subsequent Events [Abstract] | |
Subsequent Events | Subsequent Events On July 13, 2018, the Company entered into the First Amendment to Credit Agreement (the “First Amendment”) with the Subsidiary, as borrower, JP Morgan Chase Bank, N.A. as administrative agent, and certain lenders that are party thereto. The First Amendment amends the 2017 Senior Credit Facility. The First Amendment increased the borrowing base under the Credit Agreement from $40.0 million to $50.0 million. Additionally, the First Amendment, among other things, modifies the terms of the 2017 Senior Credit Facility to provide the Company with the right to elect to reduce the proposed Borrowing Base (as defined in the First Amendment) to a lower Draw Limit (as defined in the First Amendment) by providing notice to the lenders contemporaneously with each scheduled and interim redetermination of the Borrowing Base under the 2017 Senior Credit Facility. Upon approval by the lenders of a proposed lower Draw Limit, such Draw Limit will be the Borrowing Base until the next scheduled or interim redetermination pursuant to the terms of the 2017 Senior Credit Facility, as amended by the First Amendment. |
Description of Business and Significant Accounting Policies (Policies) |
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Accounting Policies [Abstract] | |||||||||||||
Basis of Presentation | Basis of Presentation The consolidated financial statements of the Company included in this Quarterly Report on Form 10-Q have been prepared, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”) and accordingly, certain information normally included in financial statements prepared in accordance with United States Generally Accepted Accounting Principles (“US GAAP”) has been condensed or omitted. This information should be read in conjunction with our consolidated financial statements and notes contained in our annual report on Form 10-K for the year ended December 31, 2017. Operating results for the three and six months ended June 30, 2018 are not necessarily indicative of the results that may be expected for the full year or for any interim period. |
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Principles of Consolidation | Principles of Consolidation—The consolidated financial statements include the financial statements of the Company and the Subsidiary. Intercompany balances and transactions have been eliminated in consolidation. The consolidated financial statements reflect all normal recurring adjustments that, in the opinion of management, are necessary for a fair presentation. Certain data in prior periods’ financial statements have been adjusted to conform to the presentation of the current period. We have evaluated subsequent events through the date of this filing. |
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Use of Estimates | Use of Estimates— Our management has made a number of estimates and assumptions relating to the reporting of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities to prepare these consolidated financial statements in conformity with US GAAP. |
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Cash and Cash Equivalents | Cash and Cash Equivalents—Cash and cash equivalents includes cash on hand, demand deposit accounts and temporary cash investments with maturities of ninety days or less at the date of purchase. |
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Inventory | Inventory –Inventory consists of casing and tubulars that are expected to be used in our capital drilling program. Inventory is carried on the Consolidated Balance Sheets at the lower of cost or market. |
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Property and Equipment | Property and Equipment—Under US GAAP, two acceptable methods of accounting for oil and natural gas properties are allowed. These are the Successful Efforts Method and the Full Cost Method. Entities engaged in the production of oil and natural gas have the option of selecting either method for application in the accounting for their properties. The principal differences between the two methods are in the treatment of exploration costs, the computation of Depreciation, Depletion and Amortization (“DD&A”) expense and the assessment of impairment of oil and natural gas properties. We use the Full Cost Method to account for our investment in oil and gas properties. Under the Full Cost Method, we capitalize all costs associated with acquisitions, exploration, development and estimated abandonment costs. We capitalize internal costs that can be directly identified with the acquisition of leasehold, as well as drilling and completion activities, but do not include any costs related to production, general corporate overhead or similar activities. Unevaluated property costs are excluded from the amortization base until we make a determination as to the existence of proved reserves on the respective property or impairment. We review our unevaluated properties at the end of each quarter to determine whether the costs should be reclassified to proved oil and natural gas properties and thereby subject to DD&A and the full cost ceiling test. For the three months ended June 30, 2018 and 2017, we transferred $0.3 million and $1.9 million, respectively, from unevaluated properties to proved oil and natural gas properties. For the six months ended June 30, 2018 and 2017, we transferred $0.4 million and $12.8 million, respectively, from unevaluated properties to proved oil and natural gas properties. Our sales of oil and natural gas properties are accounted for as adjustments to net proved oil and natural gas properties with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves. We amortize our investment in oil and natural gas properties through DD&A expense using the units of production (the “UOP”) method. An amortization rate is calculated based on total proved reserves converted to equivalent thousand cubic feet of natural gas (“Mcfe”) as the denominator and the net book value of evaluated oil and gas asset together with the estimated future development cost of the proved undeveloped reserves as the numerator. The rate calculated per Mcfe is applied against the periods' production also converted to Mcfe to arrive at the periods' DD&A expense. Depreciation of furniture, fixtures and equipment, consisting of office furniture, computer hardware and software and leasehold improvements, is computed using the straight-line method over their estimated useful lives, which vary from three to five years. Full Cost Ceiling Test—The Full Cost Method requires that at the conclusion of each financial reporting period, the present value of estimated future net cash flows from proved reserves (adjusted for hedges and excluding cash flows related to estimated abandonment costs), be compared to the net capitalized costs of proved oil and natural gas properties, net of related deferred taxes. This comparison is referred to as a "ceiling test". If the net capitalized costs of proved oil and natural gas properties exceed the estimated discounted future net cash flows from proved reserves, we are required to write-down the value of our oil and natural gas properties to the value of the discounted cash flows. Estimated future net cash flows from proved reserves are calculated based on a 12-month average pricing assumption. |
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Fair Value Measurement | Fair Value Measurement—Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The fair value of an asset should reflect its highest and best use by market participants, whether in-use or an in-exchange valuation premise. The fair value of a liability should reflect the risk of non-performance, which includes, among other things, our credit risk. We use various methods, including the income approach and market approach, to determine the fair values of our financial instruments that are measured at fair value on a recurring basis, which depend on a number of factors, including the availability of observable market data over the contractual term of the underlying instrument. For some of our instruments, the fair value is calculated based on directly observable market data or data available for similar instruments in similar markets. For other instruments, the fair value may be calculated based on these inputs as well as other assumptions related to estimates of future settlements of these instruments. We separate our financial instruments into three Levels (Levels 1, 2 and 3) based on our assessment of the availability of observable market data and the significance of non-observable data used to determine the fair value of our instruments. Our assessment of an instrument can change over time based on the maturity or liquidity of the instrument, which could result in a change in the classification of the instruments between Levels. Each of these Levels and our corresponding instruments classified by Level are further described below:
As of June 30, 2018 and December 31, 2017, the carrying amounts of our cash and cash equivalents, trade receivables and payables represented fair value because of the short-term nature of these instruments. |
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Asset Retirement Obligations | Asset Retirement Obligations—Asset retirement obligations are related to the abandonment and site restoration requirements that result from the exploration and development of our oil and natural gas properties. We record the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. Accretion expense is included in “Depreciation, depletion and amortization” on our Consolidated Statements of Operations. See Note 3. The estimated fair value of the Company’s asset retirement obligations at inception is determined by utilizing the income approach by applying a credit-adjusted risk-free rate, which takes into account the Company’s credit risk, the time value of money, and the current economic state, to the undiscounted expected abandonment cash flows. Given the unobservable nature of the inputs, the initial measurement of the asset retirement obligations was classified as Level 3 in the fair value hierarchy. |
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Revenue Recognition | Revenue Recognition—Oil and natural gas revenues are recognized upon delivery of our produced oil and natural gas volumes to our customers. Revenues from the production of crude oil and natural gas properties in which we have an interest with other producers are recognized in accordance with when the producing company records revenue on those volumes. We record a liability or an asset for natural gas balancing when we have sold more or less than our working interest share of natural gas production, respectively. At June 30, 2018 and December 31, 2017, the net liability for natural gas balancing was immaterial. Differences between actual production and net working interest volumes are routinely adjusted. |
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Derivative Instruments | Derivative Instruments—We use derivative instruments such as futures, forwards, options, collars and swaps for purposes of hedging our exposure to fluctuations in the price of crude oil and natural gas and to hedge our exposure to changing interest rates. Accounting standards related to derivative instruments and hedging activities require that all derivative instruments subject to the requirements of those standards be measured at fair value and recognized as assets or liabilities in the balance sheet. We offset the fair value of our asset and liability positions with the same counterparty for each commodity type. Changes in fair value are required to be recognized in earnings unless specific hedge accounting criteria are met. All of our realized gain or losses on our derivative contracts are the result of cash settlements. We have not designated any of our derivative contracts as hedges; accordingly, changes in fair value are reflected in earnings. |
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Income Taxes | Income Taxes—We account for income taxes, as required, under the liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating loss and tax credit carry-forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. We recognize, as required, the financial statement benefit of an uncertain tax position only after determining that the relevant tax authority would more likely than not sustain the position following an audit. For tax positions meeting the more likely-than-not threshold, the amount recognized in the financial statements is the largest benefit that has a greater than 50 percent likelihood of being realized upon ultimate settlement with the relevant tax authority. |
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Net Income or Net Loss Per Share | Net Income or Net Loss Per Share—Basic income (loss) per common share is computed by dividing net income (loss) applicable to common stockholders for each reporting period by the weighted-average number of common shares outstanding during the period. Diluted income (loss) per common share is computed by dividing net income (loss) applicable to common stockholders for each reporting period by the weighted average number of common shares outstanding during the period, plus the effects of potentially dilutive restricted stock calculated using the treasury stock method and the potential dilutive effect of the conversion of convertible securities, such as warrants and convertible notes, into shares of our common stock. |
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Commitments and Contingencies | Commitments and Contingencies—Liabilities for loss contingencies, including environmental remediation costs, arising from claims, assessments, litigation, fines and penalties, and other sources are recorded when it is probable that a liability has been incurred and the amount of the assessment and/or remediation can be reasonably estimated. Recoveries from third parties, when probable of realization, are separately recorded and are not offset against the related environmental liability. |
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Share-based Compensation | Share-Based Compensation—We account for our share-based transactions using the fair value as of the grant date and recognize compensation expense over the requisite service period. |
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Debt Issuance Cost | Debt Issuance Cost—The Company records debt issuance costs associated with its Convertible Second Lien Notes as a contra balance to long term debt, net in our Consolidated Balance Sheets, which is amortized straight-line over the life of the Convertible Second Lien Notes. Debt issuance costs associated with our revolving credit facility debt are recorded in other assets in our Consolidated Balance Sheets, which is amortized straight-line over the life of such debt. |
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New Accounting Pronouncements | New Accounting Pronouncements On June 20, 2018, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2018-07, Compensation—Stock Compensation (Topic 718): Improvements to Nonemployee Share-Based Payment Accounting. The amendments in this ASU expand the scope of Topic 718 to include share-based payment transactions for acquiring goods and services from nonemployees. The amendments specify that Topic 718 applies to all share-based payment transactions in which a grantor acquires goods or services to be used or consumed in a grantor’s own operations by issuing share-based payment awards. The amendments also clarify that Topic 718 does not apply to share-based payments used to effectively provide (1) financing to the issuer or (2) awards granted in conjunction with selling goods or services to customers as part of a contract accounted for under Topic 606, Revenue from Contracts with Customers. For public entities, the amendments in this ASU are effective for annual periods beginning after December 15, 2018. We have not granted or issued share-based payments to nonemployees. We have evaluated the provisions of this ASU and do not expect it to have a material impact on our consolidated financial statements. On March 13, 2018, the FASB issued ASU 2018-05, Income Taxes (Topic 740). The ASU adds seven paragraphs to the Accounting Standards Codification “ASC” 740, Income Taxes, that contain SEC guidance related to Staff Accounting Bulletin 118 (“Income Tax Accounting Implications of the Tax Cuts and Jobs Act”) as a result of the tax legislation passed in 2017 known as the “Tax Cuts and Jobs Act”. Specifically, the staff intended to address situations where the accounting under ASC Topic 740 is incomplete for certain income tax effects of the Tax Cuts and Jobs Act upon issuance of an entity’s financial statements for the reporting period in which the Tax Cuts and Jobs Act was enacted. The Company notes that it has considered the updates to ASC 740 as a result of the Tax Cuts and Jobs Act and has prepared its consolidated financial statements in accordance with the Tax Cuts and Jobs Act. See Note 7 for further discussion. On August 28, 2017, the FASB issued ASU 2017-12, Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities. This ASU is intended to improve the financial reporting of hedging relationships to better portray the economic results of an entity’s risk management activities in its financial statements. In addition, the amendments in this ASU make certain targeted improvements to simplify the application of the hedge accounting guidance in current GAAP based on the feedback received from preparers, auditors, users, and other stakeholders. For public entities, the amendments in this ASU are effective for annual periods beginning after December 15, 2018. We do not expect this ASU to have a material impact on our consolidated financial statements as we currently mark-to-market all of our derivative positions; however, we are evaluating the impact of this ASU should we choose to utilize hedge accounting in the future. On February 25, 2016, the FASB issued ASU 2016-02, Leases (Topic 842) and subsequently issued ASU 2018-10, Codification Improvements to Topic 842, Leases in July 2018. The key difference between the existing standards and ASU 2016-02 is the requirement for lessees to recognize on their balance sheet all lease contracts with lease terms greater than 12 months, including operating leases. Specifically, lessees are required to recognize on the balance sheet at lease commencement, both (i) a right-of-use asset, representing the lessee’s right to use the leased asset over the term of the lease, and (ii) a lease liability, representing the lessee’s contractual obligation to make lease payments over the term of the lease. For lessees, ASU 2016-02 requires classification of leases as either operating or finance leases, which are similar to the current operating and capital lease classifications. However, the distinction between these two classifications under the ASU does not relate to balance sheet treatment, but relate to treatment and recognition in the statements of income and cash flows. Lessor accounting is largely unchanged from current US GAAP. The amendments are effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years, for public entities. Early application is permitted. The Company has developed a project plan to guide the implementation of ASU 2016-02, which includes assessing our portfolio of leases and determining a process for ensuring completeness of our repository of active leases. We have not yet completed our evaluation of the impact the new lease accounting guidance will have on our consolidated financial statements; however, we do expect to recognize right of use assets and lease liabilities for our operating leases with terms longer than 12 months in the consolidated balance sheet upon adoption. |
Description of Business and Significant Accounting Policies (Tables) |
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Accounting Policies [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Accounts Payable | Accounts Payable—Accounts payable consisted of the following amounts as of June 30, 2018 and December 31, 2017:
Accrued Liabilities—Accrued liabilities consisted of the following amounts as of June 30, 2018 and December 31, 2017:
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Asset Retirement Obligations (Tables) |
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Asset Retirement Obligation Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||
Reconciliation of Asset Retirement Obligations | The reconciliation of the beginning and ending asset retirement obligation for the six months ended June 30, 2018 is as follows (in thousands):
* - See Note 10 for further information on the dispositions during the three and six months ended June 30, 2018. |
Revenue Recognition (Tables) |
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Revenue Recognition and Deferred Revenue [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Disaggregation of Revenue | The following tables present our oil and natural gas revenues disaggregated by revenue source and by operated and non-operated properties:
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Debt (Tables) |
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Debt Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Components of Debt | Debt consisted of the following balances as of the dates indicated (in thousands):
(1) The debt discount is being amortized using the effective interest rate method based upon a maturity date of August 30, 2019. The principal includes $10.2 million and $7.0 million of paid in-kind interest at June 30, 2018 and December 31, 2017, respectively. The carrying value includes $6.1 million and $8.0 million of unamortized debt discount at June 30, 2018 and December 31, 2017, respectively. |
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Schedule of Interest Expense and Effective Interest | The following table summarizes the total interest expense for the periods shown including contractual interest expense, amortization of debt discount, accretion and financing costs and the effective interest rate on the liability component of the debt (amounts in thousands, except effective interest rates):
* - Not meaningful due to the timing of borrowings during the three months ended June 30, 2018. (1) Interest expense for the three months ended June 30, 2018 included $1.0 million of debt discount amortization and $1.6 million of paid in-kind interest, and interest expense for the three months ended June 30, 2017 included $0.7 million of debt discount amortization and $1.4 million of paid in-kind interest. Interest expense for the six months ended June 30, 2018 included $1.8 million of debt discount amortization and $3.2 million of paid in-kind interest, and interest expense for the six months ended June 30, 2017 included $1.2 million of debt discount amortization and $2.8 million of paid in-kind interest. |
Net Income (Loss) Per Common Share (Tables) |
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Earnings Per Share [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Computation of Net Income (Loss) Per Common Share | The following table sets forth information related to the computations of basic and diluted loss per share:
* - Common shares issuable on assumed conversion of share-based compensation assumes a payout of the Company's performance share awards at 100% of the initial performance units granted (or a ratio of one unit to one common share). The range of common stock shares which may be earned ranges from zero to 250% of the initial performance units granted. |
Commodity Derivative Activities (Tables) |
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Derivative Instruments and Hedging Activities Disclosure [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Summary of Gains and Losses on Derivatives | The following table summarizes gains and losses we recognized on our oil and natural gas derivatives for the three and six months ended June 30, 2018 and 2017:
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Schedule of Price Risk Derivatives | As of June 30, 2018, the open positions on our outstanding commodity derivative contracts, all of which were with JPMorgan Chase Bank, N.A. and BP Energy Company, were as follows:
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Derivative Assets and Liabilities Recorded at Fair Value | The following table summarizes the fair values of our derivative financial instruments that are recorded at fair value classified in each Level as of June 30, 2018 (in thousands). We measure the fair value of our commodity derivative contracts by applying the income approach. See Note 1—“Description of Business and Significant Accounting Policies” for our discussion regarding fair value, including inputs used and valuation techniques for determining fair values.
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Offsetting Assets | We enter into oil and natural gas derivative contracts under which we have netting arrangements with each counter party. The following table discloses and reconciles the gross amounts to the amounts as presented on the Consolidated Balance Sheets for the periods ending June 30, 2018 and December 31, 2017:
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Offsetting Liabilities | The following table discloses and reconciles the gross amounts to the amounts as presented on the Consolidated Balance Sheets for the periods ending June 30, 2018 and December 31, 2017:
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Description of Business and Significant Accounting Policies - Schedule of Accounts Payable (Details) - USD ($) $ in Thousands |
Jun. 30, 2018 |
Dec. 31, 2017 |
---|---|---|
Accounting Policies [Abstract] | ||
Trade payables | $ 8,300 | $ 4,092 |
Revenue payable | 12,234 | 10,692 |
Prepayments from partners | 374 | 2,193 |
Miscellaneous payables | 232 | 227 |
Total Accounts payable | $ 21,140 | $ 17,204 |
Description of Business and Significant Accounting Policies - Schedule of Accrued Liabilities (Details) - USD ($) $ in Thousands |
Jun. 30, 2018 |
Dec. 31, 2017 |
---|---|---|
Accounting Policies [Abstract] | ||
Accrued capital expenditures | $ 7,706 | $ 10,511 |
Accrued lease operating expense | 843 | 786 |
Accrued production and other taxes | 713 | 449 |
Accrued transportation and gathering | 1,132 | 1,130 |
Accrued performance bonus | 1,854 | 3,869 |
Accrued interest | 3 | 244 |
Accrued office lease | 658 | 696 |
Accrued reorganization costs | 307 | 168 |
Accrued general and administrative expense and other | 165 | 222 |
Total Accrued liabilities | $ 13,381 | $ 18,075 |
Description of Business and Significant Accounting Policies - Narrative (Detail) - USD ($) |
3 Months Ended | 6 Months Ended | |||
---|---|---|---|---|---|
Jun. 30, 2018 |
Jun. 30, 2017 |
Jun. 30, 2018 |
Jun. 30, 2017 |
Oct. 12, 2016 |
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Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items] | |||||
Transfers from unevaluated to proved oil and natural gas properties | $ 300,000 | $ 1,900,000 | $ 400,000 | $ 12,800,000 | |
Full Cost Ceiling Test write-downs | $ 0 | $ 0 | $ 0 | $ 0 | |
13.5% Convertible Second Lien Notes [Member] | |||||
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items] | |||||
Stated interest rate | 13.50% | 13.50% | 13.50% | ||
Minimum [Member] | |||||
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items] | |||||
Estimated useful lives | 3 years | ||||
Maximum [Member] | |||||
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items] | |||||
Estimated useful lives | 5 years |
Reconciliation of Asset Retirement Obligations (Detail) - USD ($) $ in Thousands |
6 Months Ended | |
---|---|---|
Jun. 30, 2018 |
Dec. 31, 2017 |
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Asset Retirement Obligation, Roll Forward [Roll Forward] | ||
Beginning balance at December 31, 2017 | $ 3,367 | |
Liabilities incurred | 122 | |
Accretion expense | 128 | |
Dispositions | (175) | |
Ending balance at June 30, 2018 | 3,442 | |
Current liability | 0 | |
Long term liability | $ 3,442 | $ 3,367 |
Equity (Details) - $ / shares |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2018 |
Jun. 30, 2018 |
Jun. 30, 2017 |
Dec. 31, 2017 |
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Class of Warrant or Right [Line Items] | ||||
Common stock, par value (in dollars per share) | $ 0.01 | $ 0.01 | $ 0.01 | |
Warrant [Member] | Costless Warrants For Common Stock [Member] | ||||
Class of Warrant or Right [Line Items] | ||||
Costless warrants, term | 10 years | 10 years | ||
Common stock, par value (in dollars per share) | $ 0.01 | 0.01 | $ 0.01 | |
Warrant exercise price (in dollars per share) | $ 0.01 | $ 0.01 | ||
Common stock issued during the period | 273,437 | 315,937 | 625,000 | |
Warrant outstanding | 207,500 | 207,500 | ||
Treasury stock repurchased during the period | 564 | |||
Warrant [Member] | Costless Warrants For Common Stock [Member] | 13.5% Convertible Second Lien Notes [Member] | ||||
Class of Warrant or Right [Line Items] | ||||
Number of securities exercised by warrants in the period | 273,437 | 862,812 | 1,375,000 |
Debt - Components of Debt (Detail) - USD ($) $ in Thousands |
3 Months Ended | 6 Months Ended | 15 Months Ended | 21 Months Ended | ||
---|---|---|---|---|---|---|
Jun. 30, 2018 |
Jun. 30, 2017 |
Jun. 30, 2018 |
Jun. 30, 2017 |
Dec. 31, 2017 |
Jun. 30, 2018 |
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Debt Instrument [Line Items] | ||||||
Principal | $ 56,224 | $ 56,224 | $ 63,738 | $ 56,224 | ||
Carrying amount | 50,080 | 50,080 | 55,725 | 50,080 | ||
2017 Senior Credit Facility [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Principal | 6,000 | 6,000 | 16,723 | 6,000 | ||
Carrying amount | 6,000 | 6,000 | 16,723 | 6,000 | ||
Convertible Second Lien Notes [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Principal | 50,224 | 50,224 | 47,015 | 50,224 | ||
Carrying amount | 44,080 | 44,080 | 39,002 | 44,080 | ||
Paid-in kind interest | 1,600 | $ 1,400 | 3,200 | $ 2,800 | 7,000 | 10,200 |
Unamortized discount | $ 6,100 | $ 6,100 | $ 8,000 | $ 6,100 |
Debt - Components of Debt, Interest Expense and Effective Interest Rate (Details) - USD ($) $ in Thousands |
3 Months Ended | 6 Months Ended | 15 Months Ended | 21 Months Ended | ||
---|---|---|---|---|---|---|
Jun. 30, 2018 |
Jun. 30, 2017 |
Jun. 30, 2018 |
Jun. 30, 2017 |
Dec. 31, 2017 |
Jun. 30, 2018 |
|
Debt Instrument [Line Items] | ||||||
Interest Expense | $ 2,732 | $ 2,360 | $ 5,405 | $ 4,539 | ||
2017 Senior Credit Facility [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Interest Expense | 75 | $ 0 | $ 248 | $ 0 | ||
Effective Interest Rate | 0.00% | 7.80% | 0.00% | |||
Exit Credit Facility [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Interest Expense | $ 0 | $ 279 | $ 0 | $ 531 | ||
Effective Interest Rate | 0.00% | 6.60% | 0.00% | 6.30% | ||
Convertible Second Lien Notes [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Interest Expense | $ 2,657 | $ 2,081 | $ 5,157 | $ 4,008 | ||
Effective Interest Rate | 24.70% | 24.30% | 24.80% | 24.30% | ||
Debt discount amortization | $ 1,000 | $ 700 | $ 1,800 | $ 1,200 | ||
Paid-in kind interest | $ 1,600 | $ 1,400 | $ 3,200 | $ 2,800 | $ 7,000 | $ 10,200 |
Income Taxes - Narrative (Detail) - USD ($) |
3 Months Ended | 6 Months Ended | |||
---|---|---|---|---|---|
Jun. 30, 2018 |
Jun. 30, 2017 |
Jun. 30, 2018 |
Jun. 30, 2017 |
Dec. 31, 2017 |
|
Income Tax Disclosure [Abstract] | |||||
Income tax expense or benefit | $ 0 | $ 0 | $ 0 | $ 0 | |
Valuation allowance | $ 86,700,000 | ||||
Deferred tax asset | 937,000 | 937,000 | 937,000 | ||
Unrecognized tax benefits | $ 0 | $ 0 | $ 0 |
Commodity Derivative Activities - Summary of Gains and Losses on Derivatives (Detail) - USD ($) $ in Thousands |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2018 |
Jun. 30, 2017 |
Jun. 30, 2018 |
Jun. 30, 2017 |
|
Derivative [Line Items] | ||||
Total gain (loss) on commodity derivatives not designated as hedges | $ (2,174) | $ 766 | $ (3,155) | $ 506 |
Commodity Contract [Member] | ||||
Derivative [Line Items] | ||||
Gain (loss) on commodity derivatives not designated as hedges, settled | (156) | 4 | (541) | 147 |
Gain (loss) on commodity derivatives not designated as hedges, not settled | (2,018) | 762 | (2,614) | 359 |
Total gain (loss) on commodity derivatives not designated as hedges | $ (2,174) | $ 766 | $ (3,155) | $ 506 |
Commodity Derivative Activities - Commodity Derivative Activities - Additional Information (Detail) $ in Millions |
Jun. 30, 2018
USD ($)
|
---|---|
Supplier Concentration Risk [Member] | Commodity Contract [Member] | |
Derivative [Line Items] | |
Estimate of possible loss | $ 0.2 |
Commitments and Contingencies (Details) - USD ($) $ in Millions |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2018 |
Jun. 30, 2017 |
Jun. 30, 2018 |
Jun. 30, 2017 |
|
Commitments and Contingencies Disclosure [Abstract] | ||||
Rent expense | $ 0.4 | $ 0.5 | $ 0.8 | $ 0.9 |
Dispositions (Details) - Discontinued Operations, Disposed of by Sale [Member] - USD ($) $ in Millions |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2018 |
Jun. 30, 2018 |
May 21, 2018 |
Feb. 28, 2018 |
|
Tuscaloosa Marine Shale Trend [Member] | ||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||
Disposition total consideration | $ 3.3 | |||
Angelina River Trend [Member] | ||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||
Disposition total consideration | $ 23.0 | |||
Other Miscellaneous Acreage [Member] | ||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||
Proceeds from sale of miscellaneous acreage | $ 0.4 | $ 0.7 |
Subsequent Events (Details) - Senior Secured Revolving Credit Facility [Member] - USD ($) |
Jul. 13, 2018 |
Jul. 12, 2018 |
Oct. 17, 2017 |
---|---|---|---|
Subsequent Event [Line Items] | |||
Current borrowing capacity | $ 40,000,000 | ||
Subsequent Event [Member] | |||
Subsequent Event [Line Items] | |||
Current borrowing capacity | $ 50,000,000 | $ 40,000,000 |
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