Magnolia Oil & Gas Corporation (NYSE: MGY) — 2020 Form 10-K
Reporting period: Fiscal year ended December 31, 2020; this is an annual filing, not a standalone fourth-quarter report. Magnolia explores for and produces oil, natural gas, and NGLs, primarily in the Karnes County Eagle Ford and Giddings Austin Chalk areas of South Texas.
Financial and operating performance
| Metric | 2020 | 2019 |
|---|---|---|
| Oil, gas, and NGL revenue | $534.5 million | $936.1 million |
| Average daily production | 61.8 Mboe/d | 66.8 Mboe/d |
| Operating income (loss) | $(1,925.7) million | $127.5 million |
| Net income (loss) | $(1,869.0) million | $85.0 million |
| Net income (loss) attributable to Class A common stock | $(1,208.4) million; $(7.27) diluted per share | $47.4 million; $0.28 diluted per share |
| Cash from operating activities | $310.1 million | $647.6 million |
| Capital expenditures | $197.9 million | $426.4 million |
| Cash and cash equivalents at year-end | $192.6 million | $182.6 million |
Revenue declined 42.9%, reflecting lower realized prices and production. Average realized oil price fell 40% to $35.99/bbl; natural gas fell 25% to $1.71/Mcf; and NGLs fell 27% to $11.10/bbl. Production decreased about 7.5%. An indicative cash-flow measure—operating cash flow less reported capital expenditures—was approximately $112.3 million in 2020; Magnolia did not identify this as a reported non-GAAP free-cash-flow figure.
Magnolia recorded approximately $1.9 billion of property impairments in the first quarter amid the commodity-price collapse: $1.4 billion for proved properties and approximately $0.6 billion for unproved properties, with amounts rounded as presented in the filing. These charges were the principal cause of the annual loss. Lease operating expense averaged $3.50/boe, down from $3.85; gathering, transportation, and processing averaged $1.27/boe, down from $1.43. The filing does not provide a single comparable operating-margin figure.
Debt, liquidity, and capital allocation
- Year-end principal debt was $400 million of 6.0% Senior Notes due 2026; carrying value, net of financing costs, was $391.1 million. There were no RBL borrowings.
- Reported liquidity was $642.6 million: $192.6 million cash plus $450 million of RBL borrowing-base capacity. The borrowing base was reaffirmed in October 2020, and the company reported compliance with facility covenants.
- Magnolia repurchased 4.475 million Class A shares for $28.7 million in 2020, at a weighted-average $6.41 per share. In February 2021, the board added 10 million shares to the existing repurchase authorization.
- Capital expenditures were reduced substantially year over year, from $426.4 million to $197.9 million. The company also sold its 35% Ironwood midstream interest for $27.1 million cash, recognizing a $5.1 million gain.
Material changes and other key facts
- Proved reserves ended 2020 at 112.3 MMboe, up from 109.3 MMboe. Proved undeveloped reserves rose to 26.5 MMboe; management stated these were planned to be developed within one year. The standardized measure of discounted future net cash flows fell to $1.0 billion from $1.6 billion, largely reflecting price changes.
- Magnolia acquired non-operated Karnes and DeWitt County assets for approximately $69.7 million in February 2020. It operated one rig in Giddings during the fourth quarter.
- The company gave notice in August 2020 that it would terminate its EnerVest operating-services agreement. Transition work was expected to be completed by August 1, 2021; Magnolia had hired field staff and was building internal operating capabilities.
- Magnolia entered natural-gas costless collars for 2021 covering 12.15 million MMBtu, with weighted-average floor and ceiling prices of $2.31 and $3.00/MMBtu. Derivative gains and losses are recognized in earnings rather than hedge-accounted.
Outlook, risks, and contingencies
Management emphasized spending within cash flow, maintaining low leverage, and retaining flexibility to adjust drilling activity. It said existing cash, operating cash flow, and available liquidity were expected to meet requirements, but noted that sustained market deterioration could require additional liquidity measures. No numerical production, capital-spending, or earnings guidance is provided in the supplied filing text.
- COVID-19, oil and gas oversupply, commodity-price volatility, storage or transportation constraints, and possible production curtailments could affect revenue, operations, and liquidity.
- Climate, methane, hydraulic-fracturing, environmental, and permitting policy changes could raise costs or delay or restrict development. Operations and producing properties are concentrated in South Texas.
- Two purchasers—Phillips 66 and EOG Resources—accounted for 56.6% of 2020 combined hydrocarbon revenue, creating customer concentration risk.
- Contractual commitments include delivery of approximately 2.73 million barrels of Karnes oil through September 30, 2021, and firm Giddings gas-transportation capacity with related demand fees.
- Ordinary-course legal matters were not expected by management to have a material effect. A lawsuit involving a claimed minority working interest in certain Karnes assets remained in pre-trial proceedings; exposure was not reasonably estimable, and the filing reported no litigation accrual.
KPMG issued unqualified opinions on the consolidated financial statements and internal control over financial reporting as of year-end 2020.
Investor verification priorities
- Review the impairment assumptions and sensitivity to commodity prices, reserve estimates, costs, and discount rates; the filing identifies these as critical audit matters.
- Assess whether lower prices and production, and the decline in operating cash flow, affect future cash generation, reserve replacement, and development plans.
- Confirm the RBL borrowing base, covenant headroom, and liquidity after year-end, including any changes in commodity prices or borrowing availability.
- Track the transition from EnerVest-provided services, including execution, costs, and operational continuity through the expected August 2021 completion.
- Monitor customer concentration, transportation commitments, and the planned conversion of proved undeveloped reserves to developed reserves.