Murphy Oil Business Model Canvas

Pipeline and gathering partners ensure takeaway, processing and market access, with Murphy Oil in 2024 leveraging multi-year takeaway agreements to de-bottleneck production and lower basis volatility. Long-term contracts reduce basis risk and stabilize realizations, while coordinated compression, fractionation and storage improve netbacks per barrel. Strategic connectivity in 2024 supported a balanced crude, gas and NGL portfolio across key Gulf Coast and onshore hubs.

Shared-risk JVs (deepwater projects often >$1B) and operator partners expand scale and diversify capital, enabling paced project execution. Service, pipeline and offtake partners secure capacity, logistics and pricing, with 2024 multi-year takeaway agreements reducing basis volatility. Government, landowner and community partnerships across 4 regions (U.S., Canada, Brazil, SE Asia) protect permitting and social license.

In 2024 Murphy prioritized facility uptime and artificial lift optimization to maximize cash flow, targeting reduced downtime across Gulf of Mexico and onshore assets. Routine workovers and integrity programs sustain base decline and protect proved reserves. Flaring minimization and continuous emissions monitoring improved ESG metrics and helped comply with tightening U.S. regulations. Integrated planning aligns maintenance with market conditions to optimize NPV.

Geoscience-led prospecting and appraisal underpin a high‑grading program supporting ~ $1.0–1.1B 2024 capex and ~74,000 boe/d production; standardized drilling and factory operations raise capital productivity and EURs. Facilities uptime, artificial lift, and emissions controls protect cash flow and reserves. Active hedging, asset trades and stage‑gated investments manage risk and liquidity.

Operational infrastructure—processing, gathering, and production facilities—drives cost-efficient throughput across Murphy Oil’s upstream assets, supporting high uptime and lower per-barrel operating costs. Offshore platforms and subsea systems in the Gulf of Mexico enable sustained high-rate production, while dedicated storage and offtake connections mitigate bottlenecks. Digital SCADA and real-time monitoring enhance reliability and optimize maintenance cycles.

Proved and probable reserves back valuation and borrowing capacity while a mix of oil, gas and NGLs moderates commodity exposure; reserve replacement relies on disciplined exploration and targeted M&A. Strategic leaseholds across Gulf of Mexico, onshore U.S. and international blocks preserve development optionality and HBP positions. Operational infrastructure, advanced tech and a ~115 mboe/d average net production in 2024 enable cost-efficient throughput.

Oil-weighted cash flows are complemented by gas and NGL optionality, giving Murphy exposure to crude, natural gas and liquids end-markets that smooth revenue and reduce realized-price volatility; portfolio balance supports more stable free cash flow and buyers gain access to varied hydrocarbon slates across light crude, gas and NGL streams.

Murphy Oil delivered ~154 mboe/d average production in 2024, with guidance ~145 mboe/d, supported by diversified Gulf of Mexico, U.S. onshore and Malaysia assets and strong HSE/process safety programs. 2024 capex was ~$1.1B, enabling reliability and low lifting/finding costs that sustain competitive netbacks and flexible term/spot marketing with hedging optionality.

Technical support on specifications, assays and blending boosts refinery yield and product value while scheduling and nomination support cuts demurrage risk; pipeline and marine logistics coordination reduces downtime and improves asset utilization; secure data sharing and APIs enhance forecasting and planning across trading, operations and supply teams.

Murphy secures volume and price certainty via multi-year offtakes, reducing exposure to 2024 Brent volatility (Brent avg ~86 USD/bbl). Key accounts get direct commercial, technical and logistics support, improving liftings, invoicing cadence and renewal rates. Transparent reporting aligned to GHG Protocol and ISSB (effective 2024) underpins trust and compliance.

Gathering and transmission networks move hydrocarbons from wellheads to market, while terminal access enables blending and storage to match customer specifications. Firm transport contracts improve flow assurance and reduce curtailment risk. Expanded connectivity broadens end-market reach across Gulf Coast and international buyers.

Murphy channels crude via direct refinery nominations (Brent ~86 USD/bbl in 2024) and third‑party traders leveraging US exports (~4.3 mln b/d in 2024) to optimize basis and crack spreads (Brent–WTI ~8–9 USD/bbl). Gathering, terminals and contracted processing secure throughput and netbacks (Henry Hub 2.79 USD/MMBtu). Digital EDI cut transaction time ~25% in 2024.

NGL and residue gas supply feedstock and process heat, supporting roughly 6.0 million b/d of US NGL production in 2024 (EIA estimate), while tight purity/spec adherence (sub-1% contaminants) preserves plant efficiency and yield. Long-term offtake and tolling contracts, commonly 3–10 years, underpin multi‑year capital planning and returns, and regional proximity to Gulf Coast/Permian hubs cuts logistics and truck-to-pipeline costs materially.

Murphy sells to refiners, gas buyers, NGL processors, traders and international offtakers; 2024 benchmarks: global refinery capacity 103 mb/d, oil demand 102 mb/d, Brent avg 86 USD/bbl, US gas 38% of power mix, US NGL prod ~6.0 mb/d. Contracts 1–10 years; quality, logistics and incoterms determine price, timing and risk.

In 2024 industry averages show pipeline tariffs of roughly $2–6/bbl, trucking $3–8/bbl, marine freight $0.5–1.5/bbl and plant/processing fees $1–4/bbl, all directly shaving Murphy Oil netbacks. Firm capacity contracts reduce curtailment risk and volatility. Blending and fractionation can enhance product realizations by $2–15/bbl but incur processing and logistics costs. Active contract optimization limits take-or-pay exposure and preserves cash flow.

Murphy Oil’s 2024 cost structure centers on drilling, completions and facilities to drive short-cycle returns while stage-gating and pad development cut per-well capex. Core Opex in 2024 stems from lifting, labor, chemicals and field services, with reliability and fuel-efficiency programs lowering unit costs. Decommissioning provisioning remains material; Wood Mackenzie estimates global decommissioning liabilities at 300–500 billion USD to 2050.

Y-grade and purity NGL products are monetized via fractionation to deliver specification-grade streams, while condensate is sold to splitters and blenders for azeotropic blending and diluent markets. Product-slate diversification in 2024 helped stabilize Murphy Oil cash flow against oil price swings. Pricing remains closely linked to petrochemical feedstock margins and export parity dynamics. This commercial mix supports margin capture across domestic and export channels.

Crude sales (benchmark Brent 86 USD/bbl, WTI 82 USD/bbl in 2024) drive primary revenue; gas sold at hub-linked prices; NGLs/condensate monetized via fractionation and splitters; marketing, derivatives and periodic divestitures/farm-downs stabilize cash and recycle capital under strict risk limits.