What changed in this filing

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Item 2. Management’s Discussion and Analysis

2020-11-05 compared with 2020-08-07 · 94 added, 74 removed, 70 unchanged (71% of the section changed)

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The COVID-19 pandemic has negatively impacted the global economy, disrupted global supply chains, reduced global demand for oil and natural gas, and created significant volatility and disruption of financial and commodity markets.

In March 2020, announced price reductions and possible production increases by members of the Organization of Petroleum Exporting Countries and other oil exporting nations in combination with the reduced global demand for oil caused the posted price for West Texas Intermediate oil to decline sharply.

The extent of the impact of the COVID-19 pandemic on our operational and financial performance, including our ability to execute our business strategies and initiatives, is uncertain and depends on various factors, including the future demand for oil and natural gas, the availability of personnel, equipment and services critical to our ability to operate and develop our properties and the impact of potential governmental restrictions on travel, transports and operations.

Our natural gas operations, which are primarily in the Haynesville shale in North Louisiana and East Texas, have not been adversely affected so far in 2020.

Our non-operated oil operations have been substantially impacted by the low oil prices and certain operators have shut in production due to low demand.

Our non-operated oil operations have been substantially impacted by low oil prices.

Results of Operations

Three Months Ended June 30,

Six Months Ended June 30,

Three Months Ended

September 30, Nine Months Ended

September 30,

2020 2019 2020 2019

Net Production Data:

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Natural gas (MMcf)

102,560 97,236 341,823 171,313

354 603 1,168 2,108

Natural gas equivalent (MMcfe)

104,687 100,859 348,831 183,964

Natural gas sales

$ 168,374 $ 193,506 $ 547,975 $ 375,589

9,637 30,938 35,449 103,852

Total oil and gas sales

Production taxes

$ 178,011 $ 224,444 $ 583,424 $ 479,441

Production and ad valorem taxes $ 9,798 $ 9,381 $ 27,768 $ 22,703

Gathering and transportation

$ 22,422 $ 23,414 $ 77,423 $ 41,346

Lease operating $ 25,412 $ 26,696 $ 79,110 $ 54,477

Depreciation, depletion and amortization

$ 99,056 $ 80,247 $ 312,828 $ 164,684

$ — $ 241 $ 27 $ 241

Average Sales Price:

Natural gas (per Mcf)

$ 1.64 $ 1.99 $ 1.60 $ 2.19

Oil (per Bbl)

$ 27.20 $ 51.24 $ 30.35 $ 49.26

Average equivalent (Mcfe)

$ 1.70 $ 2.23 $ 1.67 $ 2.61

Expenses ($ per Mcfe):

Production taxes

Production and ad valorem taxes $ 0.09 $ 0.09 $ 0.08 $ 0.12

Gathering and transportation

$ 0.21 $ 0.23 $ 0.22 $ 0.22

Lease operating $ 0.25 $ 0.27 $ 0.23 $ 0.30

Depreciation, depletion and amortization

Includes ad valorem and state franchise taxes.

Oil and natural gas sales of $179.5 million increased by $51.4 million (40%) in the second quarter of 2020 as compared to $128.1 million for the second quarter of 2019 due to higher natural gas production resulting from the acquisition of Covey Park in July 2019.

Our natural gas production for the second quarter of 2020 was 116.5 billion cubic feet ("Bcf") (1.3 Bcf per day), which was sold at an average price of $1.48 per Mcf as compared to 40.9 Bcf (0.5 Bcf per day) sold at an average price of $2.25 per Mcf in the second quarter of 2019.

Oil production of 360 Mbbls (3,947 barrels per day) was sold at an average price of $19.97 per barrel in the second quarter of 2020 as compared to 695 Mbbls (7,628 barrels per day) sold at an average price of $52.10 per barrel in the second quarter of 2019.

Oil and natural gas sales of $405.4 million increased by 150.4 million (59%) in the six months ended June 30, 2020 as compared to $255.0 million for the six months ended June 30, 2019.

Our natural gas production for the first six months of 2020 was 239.3 Bcf (1.3 Bcf per day) was sold at an average price of $1.59 per Mcf as compared to 74.1 Bcf (0.4 Bcf per day) sold at an average price of $2.46 per Mcf in the first six months of 2019.

Oil production of 814 Mbbls (4,471 barrels per day) was sold at an average price of $31.72 per barrel in the first six months of 2020 as compared to 1,505 Mbbls (8,313 barrels per day) sold at an average price of $48.46 per barrel in the first six months of 2019.

We utilize natural gas and crude oil price derivative financial instruments to manage our exposure to natural gas and oil prices and protect returns on investment from our drilling activities.

The following table presents our natural gas and crude oil prices before and after the effect of cash settlements of our derivative financial instruments:

Three Months Ended June 30,

Six Months Ended June 30,

$ 0.95 $ 0.80 $ 0.90 $ 0.90

Oil and natural gas sales of $178.0 million de creased by $46.4 million (21%) in the third quarter of 2020 as compared to $224.4 million for the third quarter of 2019 primarily due to lower oil and natural gas prices.

Our natural gas production for the third quarter of 2020 was 102.6 billion cubic feet ("Bcf"), which was sold at an average price of $1.64 per Mcf as compared to 97.2 Bcf sold at an average price of $1.99 per Mcf in the third quarter of 2019.

Oil production of 354 Mbbls (3,851 barrels per day) was sold at an average price of $27.20 per barrel in the third quarter of 2020 as compared to 603 Mbbls (6,563 barrels per day) sold at an average price of $51.24 per barrel in the third quarter of 2019.

Oil and natural gas sales of $583.4 million in creased by $104.0 million (22%) in the nine months ended September 30, 2020 as compared to $479.4 million for the nine months ended September 30, 2019.

Our natural gas production for the first nine months of 2020 was 341.8 Bcf, which was sold at an average price of $1.60 per Mcf as compared to 171.3 Bcf sold at an average price of $2.19 per Mcf in the first nine months of 2019.

Oil production of 1,168 Mbbls (4,263 barrels per day) was sold at an average price of $30.35 per barrel in the first nine months of 2020 as compared to 2,108 Mbbls (7,723 barrels per day) sold at an average price of $49.26 per barrel in the first nine months of 2019.

We utilize natural gas and oil price derivative financial instruments to manage our exposure to natural gas and oil prices and protect returns on investment from our drilling activities.

The following table presents our natural gas and oil prices before and after the effect of cash settlements of our derivative financial instruments:

Three Months Ended

September 30, Nine Months Ended

September 30,

2020 2019 2020 2019

Average Realized Natural Gas Price:

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Average Realized Oil Price:

Crude oil per Barrel

Oil per Barrel $ 27.20 $ 51.24 $ 30.35 $ 49.26

Cash settlements on derivative financial instruments, per Barrel 6.32 0.03 9.49 0.18

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Costs and Expenses –

Our production taxes increased $0.6 million (11%) to $6.4 million for the second quarter of 2020 from $5.8 million in the second quarter of 2019.

Production taxes increased $0.2 million (2%) to $12.0 million for the first six months of 2020 from $11.8 million in the first six months of 2019.

Production taxes primarily increased due to higher natural gas production.

Gathering and transportation costs for the second quarter of 2020 increased $16.1 million (153%) to $26.6 million as compared to $10.5 million in the second quarter of 2019.

Gathering and transportation costs for the first six months of 2020 increased $37.1 million (207%) to $55.0 million as compared to $17.9 million for the first six months of 2019.

The increase primarily related to the increase in our natural gas production resulting from the Covey Park acquisition and our drilling activities.

Our lease operating expense of $30.9 million for the second quarter of 2020 increased $16.4 million (114%) from lease operating expense of $14.5 million for the second quarter of 2019.

This increase primarily reflects the increase in production of 163%.

Our lease operating expense of $0.27 per Mcfe produced for the three months ended June 30, 2020 was $0.05 per Mcfe lower than the lease operating expense of $0.32 per Mcfe for the same period in 2019.

Our lease operating expense of $59.7 million for the first six months of 2020 increased $30.4 million (103%) from lease operating expense of $29.3 million for the first six months of 2019.

This increase primarily reflects the increase in production of 194%.

Our lease operating expense of $0.24 per Mcfe produced for the first six months of 2020 was $0.11 per Mcfe lower than the lease operating expense of $0.35 per Mcfe for the same period in 2019.

Our production and ad valorem taxes in creased $0.4 million (4%) to $9.8 million for the third quarter of 2020 from $9.4 million in the third quarter of 2019.

Production and ad valorem taxes increased $5.1 million (22%) to $27.8 million for the first nine months of 2020 from $22.7 million in the first nine months of 2019.

The increases were primarily due to the increase in production in the periods.

Gathering and transportation costs for the third quarter of 2020 de creased $1.0 million (4%) to $22.4 million as compared to $23.4 million in the third quarter of 2019 due primarily to lower gathering and transportation rates on the Company's natural gas production.

Gathering and transportation costs for the first nine months of 2020 in creased $36.1 million (87%) to $77.4 million as compared to $41.3 million for the first nine months of 2019 due primarily to the in crease in our natural gas production resulting from our drilling activities and the 2019 acquisition of Covey Park Energy.

Our lease operating expense of $25.4 million for the third quarter of 2020 decreased $1.3 million (5%) from lease operating expense of $26.7 million for the third quarter of 2019.

This de crease relates to the decrease in our higher cost oil production in the third quarter of 2020.

Our lease operating expense of $79.1 million for the first nine months of 2020 increased $24.6 million (45%) from lease operating expense of $54.5 million for the first nine months of 2019.

Production in the same period increased 90% due to the Covey Park Energy acquisition.

Our lease operating expense of $0.23 per Mcfe produced for the first nine months of 2020 was $0.07 per Mcfe lower than the lease operating expense of $0.30 per Mcfe for the same period in 2019.

The lower average per unit cost is related to the growth in our lower cost natural gas production where much of the operating costs are fixed in nature.

Exploration expense in the first six months of 2020 related to impairments of unevaluated properties in the first quarter of 2020.

Depreciation, depletion and amortization ("DD&A") increased $56.5 million (121%) to $103.3 million in the second quarter of 2020 from $46.8 million in the second quarter of 2019 due to the 163% increase in production.

Our DD&A per equivalent Mcf produced decreased $0.17 (16%) to $0.87 per Mcfe for the three months ended June 30, 2020 from $1.04 per Mcfe for the three months ended June 30, 2019.

DD&A increased $129.4 million (153%) to $213.8 million in the first six months of 2020 from $84.4 million in the first six months of 2019 due to the 194% increase in production.

Our DD&A per equivalent Mcf produced decreased

$0.14 (14%) to $0.88 per Mcfe for the first six month s of 2020 from $1.02 per Mcfe for the first six months of 2019.

The lower rates in 2020 reflect the increase in production from our lower cost Haynesville shale properties.

General and administrative expenses, which are reported net of overhead reimbursements, increased to $8.3 million for the second quarter of 2020 from $6.8 million in the second quarter of 2019 due primarily to higher stock-based compensation and higher personnel costs.

Included in general and administrative expenses are stock-based compensation of $1.6 million and $0.6 million for the three months ended June 30, 2020 and 2019, respectively.

General and administrative expenses increased to $17.0 million for the first six months of 2020 from $14.7 million in the first six months of 2019 also mainly due to higher stock-based compensation and higher personnel costs.

Included in general and administrative expenses are stock-based compensation of $3.0 million and $1.3 million for the six months ended June 30, 2020 and 2019, respectively.

Depreciation, depletion and amortization ("DD&A") increased $18.8 million (23%) to $99.1 million in the third quarter of 2020 from $80.2 million in the third quarter of 2019.

Our DD&A per equivalent Mcf produced increased $0.15 (19%) to $0.95 per Mcfe for the three months ended September 30, 2020 from $0.80 per Mcfe for the three months ended

September 30, 2019.

DD&A increased $148.1 million (90%) to $312.8 million in the first nine months of 2020 from $164.7 million in the first nine months of 2019 due to the 90% increase in production in that period.

Our DD&A per equivalent Mcf produced was $0.90 per Mcfe for the first nine months of 2020, the same as the rate for the first nine months of 2019.

General and administrative expenses, which are reported net of overhead reimbursements, increased to $9.0 million for the third quarter of 2020 from $8.1 million in the third quarter of 2019 due primarily to higher stock-based compensation.

Stock-based compensation was $1.8 million and $1.1 million for the three months ended September 30, 2020 and 2019, respectively.

General and administrative expenses increased to $26.0 million for the first nine months of 2020 from $22.8 million in the first nine months of 2019 also mainly due to higher stock-based compensation and higher personnel costs.

Stock-based compensation was $4.7 million and $2.4 million for the nine months ended September 30, 2020 and 2019, respectively.

We use derivative financial instruments as part of our price risk management program to protect our capital investments.

During the three months ended June 30, 2020 and 2019, we had net losses on derivatives of $12.3 million and net gains on derivatives of $14.7 million, respectively.

The losses in the second quarter of 2020 are attributable to the improvement in future natural gas prices since March 31, 2020.

Our realized net gains from our price risk management program were $53.3 million and $1.9 million for the three months ended June 30, 2020 and 2019, respectively.

During the six months ended June 30, 2020 and 2019, we had net gains on derivatives of $49.6 million and $7.1 million, respectively.

Our realized net gains from our price risk management program were $98.7 million and $7.3 million for the six months ended June 30, 2020 and 2019, respectively.

Interest expense of $52.1 million for the three months ended June 30, 2020 and $104.9 million for the six months ended June 30, 2020, included interest on our 7½% senior notes, our 9¾% senior notes and our bank credit facility.

Interest expense of $28.6 million for the three months ended June 30, 2019 and $56.4 million for the six months ended June 30, 2019 includes interest on the 9¾% senior notes and our bank credit facility.

Income taxes for the three months ended June 30, 2020 and 2019 were a benefit of $11.4 million and a provision of $7.1 million, respectively.

Income taxes for the six months ended June 30, 2020 and 2019 were a benefit of $0.1 million and a provision of $11.3 million, respectively.

The provision for income taxes for the three months and six months ended June 30, 2020 reflect an effective tax rate of 18.7% and 0.7%, respectively.

During the three months ended September 30, 2020 and 2019, we had net losses on derivatives of $121.6 million and net gains on derivatives of $24.9 million, respectively.

The losses in the third quarter of 2020 are attributable to the continued improvement in future natural gas prices since June 30, 2020.

Our realized net gains from our price risk management program were $34.0 million and $26.0 million for the three months ended September 30, 2020 and 2019, respectively.

During the nine months ended September 30, 2020 and 2019, we had a net loss on derivatives of $72.0 million and and net gain on derivatives of $31.9 million, respectively.

Our realized net gains from our price risk management program were $132.7 million and $33.4 million for the nine months ended September 30, 2020 and 2019, respectively.

Interest expense was $63.9 million and $168.8 million for the three and nine months ended September 30, 2020, respectively, as compared to $51.0 million and $107.4 million for the three and nine months ended September 30, 2019, respectively.

The increase in interest expense is due to the issuance of $800.0 million principal amount of 9¾% senior notes in the second and third quarters of 2020.

Income taxes for the three months ended September 30, 2020 and 2019 were a benefit of $46.1 million and a provision of $3.8 million, respectively.

Income taxes for the nine months ended September 30, 2020 and 2019 were a benefit of $46.2 million and a provision of $15.2 million, respectively.

The benefit for income taxes for the three months and nine months ended September 30, 2020 reflect an effective tax rate of 26.7% and 25.6%, respectively.

The difference between the federal statutory rate of 21% and our effective rate is primarily due to the impact of state income taxes.

We reported net loss available to common stockholders of $60.0 million, or $0.29 per share, for the three months ended June 30, 2020.

We reported net loss available to common stockholders of $130.9 million or $0.57 per share, for the three months ended September 30, 2020.

Our net loss during this period includes income from operations of $12.4 million, $121.6 million in losses from derivative financial instruments, interest expense of $63.9 million and $4.4 million in preferred stock dividends.

We reported net income of $21.4 million or $0.20 per diluted share for the three months ended June 30, 2019.

In the first six months of 2020, we reported net loss available to common stockholders of $30.0 million or $0.15 per share.

Our net loss during this period includes income from operations of $47.9 million and gains on derivative financial instruments of $49.6 million, which were offset by higher interest expense of $104.9 million and $22.2 million in preferred stock dividends.

We reported net income of $35.0 million or $0.33 per diluted share for the six months ended June 30, 2019.

We reported net loss available to common stockholders of $1.3 million or $0.01 per diluted share for the three months ended September 30, 2019.

In the first nine months of 2020, we reported net loss available to common stockholders of $160.9 million or $0.77 per share.

Our net loss during this period includes income from operations of $60.3 million and losses on derivative financial instruments of $72.0 million, interest expense of $168.8 million and $26.6 million in preferred stock dividends.

We reported net income available to common stockholders of $33.6 million or $0.26 per diluted share for the nine months ended September 30, 2019.

Liquidity and Capital Resources

Funding for our activities has historically been provided by our operating cash flow, debt or equity financings or proceeds from asset sales.

For the six months ended June 30, 2020, we generated $266.1 million in cash flow from operating activities.

We also completed an underwritten public offering of our common stock in which we received $196.5 million in net proceeds and we issued $500.0 million of our 9¾ % senior notes in which we received net proceeds of $441.1 million.

For the six months ended June 30, 2019, cash provided by operating activities was $173.0 million and we had net borrowings under our bank credit facility of $20.0 million.

Our primary needs for capital, in addition to funding our ongoing operations, relate to the acquisition, development and exploration of our oil and natural gas properties and the repayment of our debt.

In the six months ended June 30, 2020, we incurred capital expenditures of $205.2 million to fund our development and exploration activities.

For the nine months ended September 30, 2020, we generated $390.0 million in cash flow from operating activities.

We also completed an underwritten public offering of our common stock in which we received $196.5 million in net proceeds.

The proceeds were used toward the redemption of our Series A Convertible Preferred Stock.

We also issued $800.0 million principal amount of our 9¾% senior notes in which we received net proceeds of $737.5 million.

The proceeds were used to repay outstanding borrowings under our bank credit facility.

For the nine months ended September 30, 2019, our primary source of funds were cash provided by operating activities of $282.8 million.

In the nine months ended September 30, 2020, we incurred capital expenditures of $315.7 million to fund our development and exploration activities.

The following table summarizes our capital expenditure activity:

Six Months Ended June 30,

Nine Months Ended

September 30,

(In thousands)

Property acquisitions $ — $ 2,055,623

Exploration and development:

Exploratory leasehold costs 1,457 —

Development leasehold costs

Development drilling and completion costs

280,383 342,665

Other development costs

Total capital expenditures

During the first six months of 2020, we drilled 38 (21.1 net) wells and completed 36 (17.3 net) Haynesville shale wells.

We expect to spend an additional $195.0 million to $235.0 million in the remaining six months of 2020 to drill 29 (21.7 net) additional

wells, to complete 43 (25.0 net) wells and for other development activity.

$ 315,666 $ 2,411,219

We drilled 54 (29.8 net) wells and completed 51 (27.1 net) Haynesville shale wells during the first nine months of 2020.

We expect to spend an additional $150.0 to $170.0 million in the remaining three months of 2020 to drill 17 (16.4 net) additional wells, to complete 22 (17.6 net) wells and for other development activity.

We expect to fund our future development and exploration activities with future operating cash flow.

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Consequently, we have a significant degree of flexibility to adjust the level of our capital expenditures as circumstances warrant.

As of June 30, 2020, we had four drilling rigs with minimum c ontractual payments of $3.5 million.

As of September 30, 2020, we had six drilling rigs with minimum contractual payments of $5.2 million.

We also have obligations to incur future payments for dismantlement, abandonment and restoration costs of oil and gas properties which are currently estimated to be incurred primarily after 2023.

The proceeds from the common stock offering, along with cash on hand, were used to redeem all of the outstanding shares of Series A Convertible Preferred Stock for an aggregate redemption price of $210.0 million plus accrued and unpaid dividends of approximately $2.9 million.

During the three months ended June 30, 2020, we exchanged 767,096 shares of our common stock, valued at approximately $5.0 million, to retire $5.6 million aggregate principal amount of our 7½% senior notes.

As a result, we recognized a $0.9 million loss on early extinguishment of debt for the three and six months ended June 30, 2020.

On June 23, 2020, we issued $500.0 million principal amount of our 9¾% senior notes and received net proceeds of $441.1 million.

In April and May 2020, we exchanged 767,096 shares of our common stock, valued at approximately $5.0 million, to retire $5.6 million aggregate principal amount of our 7½% senior notes.

As a result, we recognized a $0.9 million loss on early extinguishment of debt for the three and nine months ended September 30, 2020.

On June 23, 2020, we issued $500.0 million principal amount of our 9¾% Senior Notes due 2026 and received net proceeds of $441.1 million.

The proceeds from the senior notes issuance were used to repay borrowings outstanding under our bank credit facility.

At June 30, 2020, we had $800.0 million outstanding under our bank credit facility with a $1.4 billion committed borrowing base which is re-determined on a semi-annual basis and upon the occurrence of certain other events which matures on July 16, 2024.

On August 19, 2020, we issued an additional $300.0 million principal amount of the 9¾% Senior Notes due 2026 and received net proceeds of $296.4 million.

The proceeds were used to further repay borrowings under our bank credit facility.

At September 30, 2020, we had $500.0 million outstanding under our bank credit facility with a $1.4 billion committed borrowing base which is re-determined on a semi-annual basis and upon the occurrence of certain other events which matures on July 16, 2024.

Borrowings under the bank credit facility are secured by substantially all of our assets and those of our subsidiaries and bear interest at our option, at either LIBOR plus 2.25% to 3.25% or a base rate plus 1.25% to 2.25%, in each case depending on the utilization of the borrowing base.

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The only financial covenants are the maintenance of a leverage ratio of less than 4.0 to 1.0 and an adjusted current ratio of at least 1.0 to 1.0.

We were in compliance with the covenants as of June 30, 2020.

We were in compliance with the covenants as of September 30, 2020.

Federal Taxation

The Tax Cuts and Jobs Act repealed the AMT for tax years beginning on or after January 1, 2018 and provides that existing AMT credit carryforwards can be utilized to offset federal taxes for any taxable year.

Due to tax law enacted with the CARES Act, we have $10.2 million of unused credit carryforwards at June 30, 2020 that were refunded in the third quarter of this year.

Due to tax law enacted with the Coronavirus Aid, Relief and Economic Security ("CARES") Act, we received a $10.2 million refund for our outstanding AMT carryforwards in the third quarter of this year.

The shares of common stock issued as a result of the Jones Contribution triggered an ownership change under Section 382 of the Internal Revenue Code.

As a result, our ability to use net operating losses ("NOLs") to reduce taxable income is generally limited to an annual amount based on the fair market value of our stock immediately prior to the ownership change multiplied by the long-term tax-exempt interest rate.

Our NOLs are estimated to be limited to $3.3 million a year as a result of this limitation.

Our NOLs are estimated to be limited to $3.3 million a year as a

result of this limitation.

In addition to this limitation, IRC Section 382 provides that a corporation with a net unrealized built-in gain immediately before an ownership change may increase its limitation by the amount of recognized built-in gain recognized during a recognition period, which is generally the five-year period immediately following an ownership change.

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Compared sentence by sentence after normalising whitespace, quotation marks, case and digits, so re-formatting and restated figures do not read as changed language. Wording changes appear as one removal and one addition. The current filing and the prior one are authoritative.

What changed 10-Q

Item 2. Management’s Discussion and Analysis