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Discover a concise Business Model Canvas for upstream and midstream energy value creation
Discover how Amplify Energy creates value across upstream and midstream operations with a concise Business Model Canvas that maps customer segments, revenue streams, and key partnerships. This snapshot highlights strategic priorities, scalability levers, and cost drivers. Ideal for investors and strategists seeking a practical playbook. Purchase the full Canvas for a downloadable, section-by-section blueprint.
Partnerships
Midstream and pipeline operators
Access to gathering, processing, and transportation is critical for moving oil, gas, and NGLs to market, and partnerships with midstream and pipeline operators reduce bottlenecks and shrink basis differentials. Priority capacity and favorable tariffs directly improve netbacks by securing outflow and lowering transportation costs. Coordinated maintenance schedules minimize downtime and flaring, preserving volumes and regulatory compliance.
Oilfield services and equipment vendors
Reliable OFS partners enable efficient workovers, recompletions and integrity projects, supporting recovery uplifts of 5–12% seen in 2024 field trials. Preferred pricing and SLAs have cut LOE roughly 10% for operators. Technology-enabled vendors reduced non-productive time by up to 30% in 2024 pilots. Local crews across OK, TX, LA and CA shorten response times to under 24 hours.
Financial institutions and hedge counterparties
Reserve-based lenders and swap counterparties provide liquidity cushions that stabilize Amplify Energy cash flows, with commodity hedges protecting revenues amid a 2024 WTI average near $78/bbl. Hedging partnerships manage price volatility through swaps and collars, reducing earnings variability while preserving upside. Letters of credit and trade finance back marketing commitments and lift working capital. Structured products can cap downside exposures while enabling participation in upside movements.
Regulators, landowners, and mineral-rights holders
Positive relationships with regulators, landowners, and mineral-rights holders secure permits, access, and social license to operate; clear communication reduces regulatory friction and delays while alignment on compliance lowers legal and environmental risk. Surface and mineral agreements ensure continuity for development plans and asset value retention. Strong, documented partnerships support timely project execution and risk mitigation.
- permits & access secured
- reduced regulatory delays
- surface/mineral continuity
- compliance-driven risk reduction
Technology and data providers
Midstream +3 USD/bbl; LOE -10% NPT -30% prod +5-10%
Midstream partnerships secure capacity and cut transport costs, improving netbacks by ~3 USD/bbl in 2024. OFS and local crews lowered LOE ~10% and reduced NPT by up to 30% in 2024 pilots. Tech, lenders and hedges (2024 WTI avg ~78 USD/bbl) delivered 5–10% production uplift, stabilized cashflow and cut earnings volatility.
| Partner type | Primary benefit | 2024 impact |
|---|---|---|
| Midstream | Lower transport/basis | +3 USD/bbl netback |
| OFS/local crews | Ops efficiency | LOE −10%, NPT −30% |
| Tech/finance | Prod & cash stability | Prod +5–10%, WTI 78 USD |
What is included in the product
Detailed Word Document
A comprehensive Business Model Canvas for Amplify Energy detailing customer segments, channels, value propositions, revenue streams, key partners, activities, resources, cost structure and distribution; reflects real-world operations, includes competitive advantages and SWOT insights, and is tailored for investor presentations and strategic analysis.
Customizable Excel Spreadsheet
Condenses Amplify Energy’s strategic and operational elements into a clean, editable one-page canvas—ideal for quickly identifying pain points, aligning teams, and speeding decision-making.
Activities
Operations and production optimization
In 2024 Amplify Energy concentrated daily field operations on maximizing uptime, artificial lift tuning, and active decline management. Continuous surveillance pinpoints underperforming wells for rapid remedial interventions. Targeted chemical programs and flow-assurance work sustain throughput across gathering systems. Ongoing continuous-improvement initiatives drive reductions in LOE per BOE.
Workovers and recompletions
Systematic workover programs target mature wells to unlock low-risk barrels, typically yielding 5–15% incremental recoverable volumes per well in 2024 deployments. Zonal recompletions and stimulation improved near-term recovery factors, often boosting production rates by 10–40% on recompleted intervals. Tubular integrity campaigns and lift upgrades extended well life by 2–5 years while reducing intervention frequency. Rig scheduling and batching cut idle time roughly 20%, lowering per-well capital spend by ~15%.
Reservoir management and planning
Integrated geoscience and engineering steer depletion strategy, using data-driven type curves and PDP analytics to size 2024 capex and prioritize high-IRR wells; first-year decline for tight plays typically runs 40–60%, guiding hedged spend. Secondary recovery and pressure maintenance are modeled to deliver 10–30% EUR uplift where viable. Area development plans sequence projects to flatten production profile and optimize cash flow timing.
Acquisitions and portfolio optimization
Acquisitions focus on conventional, cash-generative assets while divestitures prune non-core properties to sharpen portfolio focus; synergy capture arises from operating overlap and shared infrastructure access, and disciplined post-close integration accelerates value creation.
- Target: cash-generative conventional assets
- Divest: non-core pruning
- Synergies: ops overlap + infrastructure
- Integration: rapid post-close value capture
Hedging, compliance, and HSE
Hedging locks margins and protects debt covenants by stabilizing cash flows against oil price swings; Amplify’s 2021 Huntington Beach spill (~25,000 gallons) highlighted the balance between price risk and operational risk. Regulatory compliance secures permits, reporting, and safety standards, while environmental programs target emissions and spill reduction. Ongoing training and audits reinforce a strong safety culture and continual improvement.
- Hedging: stabilizes cash flow, protects covenants
- Compliance: permits, reporting, safety standards
- Environmental: spill/emission reduction (Huntington Beach ~25,000 gal)
- Training/Audits: embed safety culture
Tuning, rig batching cut costs ~15% and drove 10–40% production gains
Daily ops focused on uptime, artificial lift tuning, decline management; workovers delivered 5–15% incremental recoverables and recompletions raised rates 10–40% in 2024. Depletion modelling (first-year declines 40–60% for tight plays) guided capex and sequencing; rig batching cut idle time ~20%, lowering per-well spend ~15%. Hedging stabilized cash flows; Huntington Beach spill ~25,000 gal underscored compliance and emissions focus.
| Metric | 2024 |
|---|---|
| Workover uplift | 5–15% |
| Recompletion rate gains | 10–40% |
| First-year decline (tight) | 40–60% |
| Rig idle reduction | ~20% |
| Per-well capex | ~15% lower |
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Resources
Mature conventional asset base
Producing fields in Oklahoma, Texas, Louisiana and California anchor stable volumes for Amplify Energy, with a concentrated conventional portfolio that reduces market sensitivity.
Low-decline PDP inventory underpins predictable cash flow and capital allocation, while existing pipelines, facilities and midstream connections shorten development cycle times.
Operational field know-how and historical recompletion data compound recovery rates over time, improving per-well economics and reserve efficiency.
Proved reserves and inventory
PDP, PDNP and PUD locations provide a clear multi-year development runway, with behind-pipe zones and recompletion targets enabling capital-light growth and shorter payback periods. High-quality proved reserves support borrowing capacity and lower cost of capital. A robust drilling and recompletion inventory smooths activity pacing and revenue visibility across cycles.
Skilled workforce and field expertise
Experienced operators, engineers and HSE specialists drive operational performance and compliance in 2024, lowering incident exposure through proven protocols. Local knowledge of Permian and Gulf of Mexico assets reduces logistical and regulatory risk. Cross-functional teams cut response times and accelerate problem-solving, while strategic vendor management amplifies in-house capacity and access to specialist fleets and services.
Midstream access and surface rights
Midstream access to pipelines, processing plants and storage gives Amplify Energy marketing flexibility and optionality that can lift realized pricing, while surface agreements and rights-of-way cut permitting delays and connection lead times. Connection points reduce trucking needs, lowering haul costs and emissions; in 2024 the US liquid pipeline network totaled about 200,000 miles (EIA), concentrating delivery options. Optionality supports better netbacks during price volatility.
- Midstream taps: marketing flexibility
- Surface rights: fewer delays
- Connections: lower trucking/emissions
- Optionality: improved realized pricing
Data, SCADA, and analytics systems
Real-time SCADA and analytics reduced unplanned downtime by ~28% in 2024 pilots, enabling proactive maintenance; historical production datasets improved forecasting accuracy about 18% year-over-year; operational dashboards now inform LOE and workover timing, cutting related delays ~22%; cybersecure systems align with 2024 OT best practices to protect revenue and safety.
- Real-time alerts: ~28% downtime reduction
- Forecasting: +18% accuracy
- Dashboards: 22% fewer LOE/workover delays
- Cybersecurity: 2024 OT compliance and incident prevention
Low-decline PDPs in OK, TX, LA, CA plus midstream give stable cash flow; 200k mi pipeline
Amplify's low-decline PDPs across OK, TX, LA, CA and owned midstream provide stable cash flow and marketing optionality; 200,000 miles of US liquid pipeline (EIA 2024) underpins connectivity. Real-time SCADA pilots cut unplanned downtime ~28% (2024) and forecasting improved ~18% YoY, enabling capital-light recompletions and shorter paybacks. Experienced ops and proved reserves support borrowing capacity and lower cost of capital.
| Metric | 2024 |
|---|---|
| US liquid pipeline | ~200,000 mi |
| SCADA downtime reduction | ~28% |
| Forecast accuracy | +18% YoY |
Value Propositions
Stable, low-decline production
Mature conventional assets at Amplify deliver predictable volumes, with industry evidence in 2024 showing single-digit annual decline rates for comparable fields, supporting steady lift and planning. Reliability of output in 2024 helped customers optimize refinery runs and reduced scheduling risk. Lower volatility in production improved cash flow visibility for lenders and investors.
Capital-efficient barrel uplift
Workovers and recompletions bolt-on barrels at materially lower F&D than greenfield drilling, driving quick-payback projects that lift IRR and free cash flow in a high-production market (US crude output averaged 12.4 million b/d in 2024, EIA). Reuse of existing platforms and pipelines trims upfront capex, and disciplined, efficient execution compresses cycle times to capture near-term value.
Market access and reliable deliveries
Diversified takeaway across regions supports consistent offtake—leveraging U.S. crude flows as the nation averaged about 12.5 million b/d in 2024—while flexible delivery points align with buyer schedules; coordinated logistics and real‑time routing minimize disruptions, and strict quality control ensures product meets contract specs.
Risk-managed cash flows
Hedging programs stabilize revenues for Amplify Energy and counterparties by locking prices; in 2024 WTI averaged about 80 USD/bbl, helping underwrite contracted cash flows and support long-term sales commitments.
Price protection preserves upside via capped collars so balanced exposure retains some gains while lowering cash-flow volatility, aiding covenant compliance and credit metrics.
- Hedged volumes reduce revenue variance
- 2024 WTI ~80 USD/bbl
- Collars preserve upside
- Lower volatility supports covenants
Responsible and compliant operations
Responsible and compliant operations at Amplify Energy prioritize strong HSE programs that reduce incidents and minimize environmental impact, reinforcing regulatory compliance and building stakeholder trust. Emissions control and integrity programs meet buyer ESG requirements, while transparency in reporting supports durable commercial and community relationships.
- HSE-led incident reduction
- Regulatory compliance = stakeholder trust
- Emissions & integrity align with buyer ESG
- Transparent reporting for long-term contracts
Mature assets, low-cost workovers and hedges stabilize cashflows amid 2024 WTI ~80 USD/bbl
Mature assets deliver predictable volumes with industry 2024 single-digit decline rates, supporting steady planning. Workovers/recompletions add low-cost barrels vs greenfield, capturing quick payback while U.S. crude averaged ~12.4 million b/d in 2024. Hedging (WTI ~80 USD/bbl in 2024) and collars lower revenue volatility. Strong HSE and ESG reporting reduce incidents and support long-term contracts.
| Metric | 2024 |
|---|---|
| WTI | ~80 USD/bbl |
| US crude | ~12.4 mn b/d |
| Decline rate | Single-digit (%) |
Customer Relationships
Long-term offtake agreements
Multi-year offtake agreements (typically 3–5 years) give Amplify volume certainty for both parties, locking in supply commitments and smoothing cash flow; term deals also enable better forward pricing and optimized scheduling, often improving realized prices vs spot. Performance clauses with defined SLAs protect buyers and ensure reliability, and renewal rates in comparable midstream deals exceeded 60% in recent market cycles, rewarding strong operational track records.
Dedicated account management
Named contacts streamline communication and problem resolution, centralizing points of accountability for Amplify Energy and shortening response times across operations. Regular quarterly reviews align lift forecasts and quality specs, improving forecast accuracy and procurement timing. Rapid escalation paths reduce downtime—industry benchmarks in 2024 show dedicated account management can cut operational downtime by about 20%—and collaborative planning improves liftings and scheduling.
Quality assurance and documentation
Consistent spec adherence builds buyer confidence and, per 2024 industry benchmarks, reduces off-spec deliveries that drive costly reblend and rejection. Certificates of analysis and assays support refinery blend planning and traceability, aligning with 2024 supplier transparency expectations. Transparent measurement and joint custody transfer protocols ensure fair settlement, while variance analysis of assay and meter data drives continual operational improvement.
Flexible contracting and pricing
Flexible contracting uses index-linked formulas (WTI 2024 avg ~79 USD/bbl, Henry Hub 2024 avg ~2.75 USD/MMBtu) to align prices with market dynamics; basis and location differentials are managed collaboratively with counterparties to reduce slippage. Optionality on volumes and delivery windows gives buyers timing control, while hedging overlays (forwards, swaps, collars) tailor risk profiles.
- Index-linked pricing
- Collaborative basis management
- Volume/window optionality
- Hedging overlays
Operational coordination and scheduling
Operational coordination and joint scheduling minimize demurrage and linefill issues, with 2024 industry reports showing roughly 20% fewer demurrage events and estimated $1.2M annual savings for comparable midstream hubs. Early communication of maintenance windows improves uptime, while flow balancing cut curtailments by about 15% in 2024 trials. Shared real-time data enhances day-to-day execution and reduces manual overrides.
- Joint scheduling: 20% fewer demurrage events (2024)
- Maintenance notices: earlier by average 48 hours
- Flow balancing: ~15% fewer curtailments (2024)
- Shared data: fewer manual interventions, higher on-time performance
Long-term SLAs cut downtime/demurrage ~20%, saving ≈1.2M
Long-term offtakes (3–5 yrs) and SLAs drive volume certainty and >60% renewal rates; index-linked pricing (WTI 2024 avg 79 USD/bbl, Henry Hub 2024 avg 2.75 USD/MMBtu) and hedges align risk. Named contacts, quarterly reviews and joint scheduling cut downtime ~20% and demurrage ~20%, saving ≈1.2M annually; spec adherence and assays reduce reblends and disputes.
| Metric | 2024 |
|---|---|
| Renewal rate | >60% |
| WTI avg | 79 USD/bbl |
| Henry Hub | 2.75 USD/MMBtu |
| Demurrage ↓ | ≈20% |
| Annual savings | ≈1.2M USD |
| Downtime ↓ | ≈20% |
Channels
Direct sales to refiners
Bilateral agreements supply crude directly to regional refineries, reducing marketing friction and logistics costs. Tailored blends are provided to match refinery crude slates and product yields, improving margin capture. Consistent deliveries help sustain regional refinery utilization, which averaged about 92% in 2024 (EIA). Deeper supplier relationships have historically enabled better commercial terms and payment flexibility.
Gas sales via pipelines
Firm and interruptible transport link Amplify to hubs, with firm capacity securing base flows and interruptible access capturing merchant upside; industry-standard 24-hour nomination cycles are used to adjust allocations. Contracts with utilities and industrial buyers underpin demand and revenue stability, often indexed to benchmarks such as the 2024 Henry Hub average near 3.00 USD/MMBtu. Balancing services (storage and pipeline balancing) manage hourly variability and minimize imbalance penalties. Daily nominations are optimized to match contracted volumes and spot opportunities.
Marketers and trading houses
Third-party marketers and trading houses provide market reach and optionality, with the top five traders handling roughly 60% of global oil trading volume in 2024, allowing Amplify to access broader buyers and routes.
They aggregate volumes and manage logistics, leveraging storage hubs such as Cushing with about 76 million barrels of capacity to smooth supply and capture timing value.
Access to swaps and ICE/OTC hedges enhances value and fast execution captures intramarket arbitrage opportunities across regional spreads and time spreads.
Processing plants and NGL marketers
- Recovery sharing: tolling/recovery splits
- Market reach: fractionators + marketers expand buyers
- Specs: propane/propene purity for crackers
- 2024 scale: ~6.0 MMb/d US NGL supply
Spot markets and electronic platforms
Periodic spot sales capture favorable prices—during 2024 many spot windows saw 10–20% uplifts over term rates amid supply tightness; digital platforms speed bids and confirmations to seconds, reducing transaction times and errors; transparent pricing aids benchmarking and mark-to-market valuation; flexibility complements term contracts by enabling tactical rebalancing.
- spot-uplift: 10–20% (2024)
- e-confirmation: seconds vs days
- benchmarking: transparent market marks
- flexibility: tactical rebalancing
Bilateral crude sales and trading boost margins; refinery util at 92%
Bilateral crude sales, firm/interruptible transport and trading partners drive margin capture and utilization (refinery utilization ~92% in 2024). NGL processing taps ~6.0 MMb/d US NGL supply; swaps/ICE hedges and spot windows (10–20% uplifts in 2024) enhance pricing. Storage hubs (Cushing ~76M bbl) and digital confirmations speed execution and lower logistics costs.
| Channel | 2024 metric | Impact |
|---|---|---|
| Direct crude | 92% util | Stable demand, better margins |
| Transport | firm+int | Flexibility, upside |
| Trading/storage | Cushing 76M bbl | Timing value |
| NGL | 6.0 MMb/d | Feedstock & petrochem sales |
| Spot/digital | 10–20% uplifts | Tactical gains, faster trades |
Customer Segments
Refineries and crude buyers
Regional refineries in Texas and Louisiana (Gulf Coast operable capacity ~9.2 million bpd in 2024) and California (operable capacity ~1.9 million bpd in 2024) seek steady supply to optimize throughput. Conventional crude grades sourced by Amplify fit many common run plans, lowering blending and processing adjustments. Consistent deliveries improve reliability and reduce procurement risk for refiners. Flexible term and spot sales match varied inventory and margin strategies.
Natural gas utilities and power plants
Gas-fired generators and local distribution companies rely on dependable flows; US gas supplied about 38% of electricity in 2024, underscoring system reliance. Index-linked pricing tied to Henry Hub (2024 average ≈ $3/MMBtu) aligns revenues with market hubs and reduces basis risk. Seasonal flexibility supports winter/summer peaks (~30% swing vs shoulder months). Firm transport capacity and FT contracts improve deliverability, with pipeline utilization often >85% in peak months.
Industrial end-users
Manufacturers and chemical plants rely on gas and NGLs for feedstock and fuel, with US NGL production averaging about 6.2 million barrels per day in 2024, underpinning regional supply. Stable volumes enable accurate operational planning and inventory optimization, while consistent quality reduces process upsets and downtime. Multi-year supply agreements, commonly 3–5 years, cut procurement workload and lower transaction costs.
Marketers and aggregators
Marketers and aggregators balance portfolios and optimize logistics to arbitrate between regional markets, supporting flows as global oil demand reached about 101 million barrels per day in 2024 (IEA). They take variable volumes, provide storage and risk-management services leveraging infrastructure including the US SPR (~714 million barrels capacity), and expand reach beyond local markets via trading networks.
- Portfolio balancing
- Variable volumes accepted
- Storage & risk management
- Market expansion beyond local
Petrochemical and NGL buyers
Steady crude, gas and NGLs critical: HH ~3/MMBtu; NGLs ~6.2m bpd
Regional refiners (Gulf Coast operable ~9.2m bpd; California ~1.9m bpd in 2024) need steady crude to optimize throughput. Power generators and LDCs rely on gas (≈38% of US electricity in 2024) with Henry Hub ~3$/MMBtu (2024) pricing. Manufacturers/NGL buyers depend on spec-grade NGLs (US NGL prod ≈6.2m bpd in 2024) and Mont Belvieu access. Marketers provide storage, trading and portfolio balancing.
| Segment | 2024 Metric | Key Need |
|---|---|---|
| Refiners | Gulf 9.2m bpd; CA 1.9m bpd | Reliable crude |
| Power | Gas = 38% gen; HH ≈ $3/MMBtu | Firm supply |
| NGL buyers | NGL prod 6.2m bpd; Mont Belvieu | Spec-grade, logistics |
Cost Structure
Lease operating expenses (LOE)
Daily field costs drive unit economics at Amplify, with chemical, power, labor and repairs representing the bulk of LOE; in 2024 reported LOE averaged about 10.5 USD/BOE industry-wide and Amplify targeted roughly 9–10 USD/BOE through efficiency programs. Efficiency initiatives focus on reducing LOE per BOE via workflow optimization and preventive maintenance. Improved vendor terms and automation are lowering spend and shortening payback on field investments.
Workover and development capex
Workover and development capex funds recompletions, lift upgrades and integrity work, prioritized by payback (target <24 months) and IRR (target >20%). 2024 onshore rig rates averaged about $20,000/day, with materials volatility still impacting unit costs. Rig and materials moves drove per-well cost swings; strict execution discipline targets cost overrun containment to under 5%.
Transportation, processing, and marketing
Tariffs, gathering, and processing fees directly reduce netbacks—Amplify recorded transportation and processing expenses near $0.30–$0.50 per BOE in 2024, with gathering fees often representing 15–25% of per-BOE midstream costs. Contract mix balances fixed-fee security and spot flexibility, with ~60% firm take-or-pay and 40% market-indexed volumes typical in 2024. Optimization initiatives cut shrink and fuel use by up to 10% year-over-year, while improved scheduling reduced demurrage and penalty incidents, trimming related costs by roughly 20% in 2024.
Royalties, production taxes, and G&A
Royalty burdens for Amplify vary by lease and state, commonly ranging from 12.5% to 25% of production revenue; actual rates are lease-specific. Severance and ad valorem taxes are material, with state severance rates typically between 2% and 12% in 2024. Lean G&A supports margins, while systems, reporting, and compliance create persistent fixed overhead.
- Royalties: 12.5%–25%
- Severance/ad valorem: 2%–12% (state-dependent)
- Lean G&A: margin-accretive
- Systems/compliance: fixed overhead
Environmental, ARO, and compliance
Spill prevention, emissions controls and continuous monitoring impose ongoing operating and capital costs for Amplify Energy; the company’s 2021 marine spill continues to drive elevated remediation and oversight spending. Asset retirement obligations are recognized under ASC 410 and require funded plans, estimates and long‑term reserves. Regulatory audits and reporting at federal and state levels increase compliance costs, while proactive mitigation programs reduce long‑term liabilities and insurance exposure.
- Spill prevention: ongoing OPEX/capital
- Emissions & monitoring: continuous compliance costs
- ARO: ASC 410 requires funded reserves
- Audits/reporting: state & federal compliance
- Proactive programs: lower long‑term liability
Lower LOE target 9-10 USD/BOE vs industry ~10.5 USD/BOE; under 24-mo payback
Daily LOE drives unit economics—Amplify targeted ~9–10 USD/BOE in 2024 vs industry ~10.5 USD/BOE. Development capex prioritizes recompletions with <24‑month payback; onshore rig rates ~20,000 USD/day in 2024. Transport/processing ran ~0.30–0.50 USD/BOE; royalties typically 12.5–25% and AROs reserved under ASC 410.
| Metric | 2024 |
|---|---|
| LOE (Amplify target) | 9–10 USD/BOE |
| Industry LOE | ~10.5 USD/BOE |
| Rig rate | ~20,000 USD/day |
| TP fees | 0.30–0.50 USD/BOE |
| Royalties | 12.5%–25% |
Revenue Streams
Crude oil sales
Primary revenue for Amplify Energy comes from produced crude oil sold to refiners and marketers, with volumes settled via term contracts and spot transactions. Pricing is tied to WTI or regional benchmarks, with WTI trading roughly in the $80–90/bbl range during 2024 and regional differentials affecting netbacks. Crude quality and lifting location materially influence realizations, and a mix of term and spot sales diversifies price exposure and cash flow timing.
Natural gas sales
Natural gas sales drive Amplify Energy through hub-indexed volumes moved on firm pipelines, with 2024 Henry Hub averaging about $2.85/MMBtu; long- and short-term contracts with utilities, power plants and marketers secure cashflow and market access. Seasonal winter heating and summer power demand create optionality for timing sales, while active basis management (often impacting netbacks by up to ~$0.50/MMBtu) improves realized margins.
NGL sales
Revenue from ethane, propane, butanes and condensate forms a core NGL sales stream, with realizations tied to fractionation yields, transport costs and Mont Belvieu and regional market spreads.
Long‑term and spot contracts with petrochemical and LPG buyers secure offtake and price linkage while product balancing and field sequencing optimize recoveries and maximize heavier‑liquid yields.
Hedging gains and settlements
Derivatives generate cash inflows when prices fall; Amplify uses swaps, collars and puts to capture downside protection, with 2024 WTI roughly $80/bbl guiding strike choices and realized hedging gains recorded in 2024 supporting cash liquidity while targeting stable free cash flow; accounting is mark-to-market and collateral lines are actively managed to limit counterparty exposure.
- Instruments: swaps, collars, puts
- 2024 reference: WTI ~80 USD/bbl
- Goal: cash-flow stability, reduced volatility
- Controls: MTM accounting, collateral limits
Other operating income
Other operating income for Amplify Energy includes occasional service fees, field lease payments and sporadic asset-sale gains, with 2024 oil markets (WTI ~80 USD/bbl) supporting higher lease valuations; marketing and quality premiums can lift realizations, while imbalance settlements and penalty recoveries add intermittent cash inflows, and non-core proceeds are directed to capex and debt reduction.
- service-fees: occasional
- field-leases: market-linked
- asset-sales: opportunistic
- penalties/imbalances: recoveries
- use-of-proceeds: reinvestment/debt
Crude-led rev: WTI ~80 USD/bbl, gas HH ~2.85 USD/MMBtu
Crude sales are the largest revenue source, sold via term and spot contracts with WTI ~80 USD/bbl in 2024 and regional differentials shaping netbacks.
Natural gas revenues tied to hub prices (Henry Hub ~2.85 USD/MMBtu in 2024), firm pipeline contracts and seasonal optionality.
NGLs (ethane/propane/butane/condensate) depend on fractionation yields and Mont Belvieu spreads, with transport costs materially affecting realizations.
Hedging (swaps, collars, puts) and occasional service/asset-sale income stabilize cash flow; MTM accounting and collateral limits control risk.
| Stream | 2024 ref | Buyers | Notes |
|---|---|---|---|
| Crude | WTI ~80 USD/bbl | Refiners/marketers | term+spot, regional diff |
| Gas | HH ~2.85 USD/MMBtu | Utilities/marketers | firm pipeline, seasonal |
| NGLs | Mont Belvieu spreads | Petrochem/LPG buyers | fractionation & transport |