Amplify Energy Corp. — 2023 Form 10-K Summary
Business context and reporting period
Amplify Energy is an independent oil and natural gas producer with operations in Oklahoma, Wyoming (Bairoil), offshore Southern California (Beta), East Texas/North Louisiana, and the Eagle Ford. This filing covers the fiscal year ended December 31, 2023, with 2022 as the comparable year. The filing provides annual financial results; it does not provide a complete standalone fourth-quarter income statement or cash-flow statement. Fourth-quarter average net production was 20.8 MBoe/d.
Key financial and operating metrics
| Metric | 2023 | 2022 |
|---|---|---|
| Oil and natural gas sales | $288.3 million | $407.8 million |
| Total revenue, including other revenue | $307.6 million | $458.5 million |
| Operating income | $76.2 million | $72.0 million |
| Net income | $392.8 million | $57.9 million |
| Adjusted EBITDA, non-GAAP | $88.0 million | $93.8 million |
| Net cash provided by operating activities | $141.6 million | $64.5 million |
| Net cash used in investing activities | $38.6 million | $41.5 million |
| Net cash used in financing activities | $82.2 million | $41.8 million |
| Average net production | 20.5 MBoe/d | 20.7 MBoe/d |
| Average realized sales price | $38.54/Boe | $54.02/Boe |
Net income included a $253.8 million deferred tax benefit, largely from releasing the valuation allowance on deferred tax assets, and an $84.9 million litigation settlement. These items materially elevate reported earnings and should be distinguished from recurring operating performance. Adjusted EBITDA declined despite higher operating cash flow.
- Prices and unit costs: 2023 realized prices were $74.17/Bbl for oil, $22.24/Bbl for NGLs, and $2.62/Mcf for natural gas, all down from 2022. Lease operating expense was $18.66/Boe versus $17.45/Boe; gathering, processing and transportation was $2.78/Boe versus $3.86/Boe.
- Reserves: Estimated proved reserves were 98.1 MMBoe at year-end, down from 124.0 MMBoe. Approximately 98% were proved developed. The filing attributes the reduction mainly to lower commodity prices, production, and higher maintenance costs. Standardized measure was $626.1 million; PV-10 was $757.0 million.
- Debt and liquidity: Year-end revolving-credit borrowings were $115.0 million, compared with $190.0 million a year earlier. The $150.0 million borrowing base had elected commitments of $135.0 million, with approximately $20.0 million of available borrowings reported. Cash was $20.7 million. The company disclosed a $15.9 million working-capital deficit excluding commodity derivatives and said it was in compliance with its credit covenants at year-end. The facility matures July 31, 2027; its variable-rate debt had a 9.35% weighted-average interest rate in 2023.
- Capital spending: 2023 capital expenditures were approximately $33.7 million. The 2024 program is expected to be $50–$60 million, primarily funded from internally generated cash flow, with revolver or capital-markets funding available as alternatives.
Material changes versus 2022
- Oil and natural gas sales fell approximately 29%, primarily because of lower realized commodity prices; annual production was broadly stable. Natural gas sales fell to $53.2 million from $147.8 million, while oil sales were $205.7 million versus $212.5 million.
- Beta resumed production in April 2023 after its 2021 pipeline incident. The company recognized $17.9 million of loss-of-production-income insurance revenue in 2023, compared with $50.2 million in 2022; that policy’s coverage expired March 31, 2023.
- Cash operating flows increased, including receipt of approximately $84.9 million net from the settlement with the vessels and related parties that damaged the pipeline. Cash paid on expired derivative positions was substantially lower than in 2022.
- Commodity derivative results shifted from a $106.9 million loss in 2022 to a $40.3 million gain in 2023. Derivative fair-value changes are recognized in earnings, and may be volatile.
Outlook, management commentary, risks, and contingencies
- Management expects commodity-price volatility to continue in 2024 and may adjust capital spending in response to prices and other conditions. It expects operating cash flow and available revolver capacity to cover near-term requirements, but notes that cash generation depends on production and commodity prices.
- The company intends to hedge approximately 50%–75% of estimated production from proved developed producing reserves over a one-to-three-year period, subject to credit-agreement requirements. Hedging can reduce downside exposure but also limit gains when prices rise.
- The Beta incident remains a significant uncertainty. The company estimates total incident costs at $190–$210 million, but the estimate excludes certain potentially unestimable claims, future legal costs, lost revenue during the shutdown, and permanent pipeline repair/restart costs. OPA claims and a natural-resource-damage assessment remain ongoing; additional costs could be material.
- The company agreed to approximately $12 million in federal and California fines and penalties, with related probation and compliance conditions. It also reports $161.3 million of surety bonds for Beta decommissioning and a trust-funding commitment of approximately $15.8 million annually from 2024 through 2033. Additional collateral demands could pressure liquidity.
- Other material risks include borrowing-base reductions at semiannual redetermination, covenant compliance and variable interest rates; declining reserves and production; customer concentration; operating and environmental liabilities; offshore and pipeline hazards; and evolving methane, climate, and other regulatory requirements.
- The company reported no proved-property impairment in 2023 or 2022. It paid no cash dividends and said it does not currently intend to do so.
Most important facts for investors to verify
- Whether the $190–$210 million incident-cost estimate remains adequate as OPA claims, natural-resource assessments, regulatory matters, and pipeline repair obligations develop.
- Whether the 2024 borrowing-base redetermination, covenant requirements, and collateral or decommissioning-funding obligations leave sufficient liquidity to execute the $50–$60 million capital program.
- How much of 2023 net income and operating cash flow reflects nonrecurring tax benefits, the litigation settlement, insurance proceeds, and derivative settlements rather than ongoing operations.
- Whether reserve estimates and production can stabilize after the 2023 reserve decline, particularly given commodity-price assumptions and maintenance costs.
- How hedging positions, customer concentration, and changing environmental rules affect realized prices, cash flow, and operating costs.