Serica Energy Business Model Canvas

Access to pipelines, terminals and processing hubs is critical for gas and liquids evacuation and in 2024 Serica’s midstream contracts target system availability above 95% to protect cash flow. Commercial arrangements set throughput rights, tariffs and processing windows, with negotiated tariffs linked to throughput volumes and CPI adjustments. Close coordination with infrastructure owners minimizes bottlenecks and downtime and enables new tie-ins and area monetization.

Serica partners with co‑venturers on Bruce, Keith and Rhum to share risk, accelerate tie‑backs and maximise recovery. Frame agreements with service providers secure 2024 capacity and pricing; midstream contracts target >95% availability to protect cash flow. Regulatory engagement supports licence stewardship amid UK decommissioning liabilities >£60bn.

Deliver targeted facility upgrades to extend asset life by 10–15 years, focusing on reliability and integrity workstreams to protect cash flow and reserves. Progress subsea tie-backs to existing hubs to lower unit costs by up to 40% versus standalone developments. Manage engineering, procurement and construction under strict HSE protocols and align project execution with turnaround windows to minimize downtime.

Operate offshore assets targeting >98% uptime, predictive maintenance to cut unplanned outages 30–50% and production surveillance delivering 5–10% throughput uplift.

Apply subsurface modelling and targeted interventions to lift recovery 5–15%, drill infill/sidetracks with 2024 capex focused on high-IRR opportunities.

Pursue accretive late-life acquisitions, fast integration for synergies, and strict hedging/capital allocation while meeting 2024 HSSE and emissions permits.

Experienced offshore crews and subsurface teams at Serica drove 2024 operational performance, leveraging brownfield execution expertise to accelerate projects safely and reduce downtime. A lean operating model supports industry-leading low lifting costs, while established supply-chain relationships improved delivery reliability and schedule certainty across North Sea assets in 2024.

Producing interests delivered c.28,000 boe/d in 2024 with 2P reserves ~127 mmboe and near-field upside ~5–10 mmboe. Platforms, subsea and processing capacity enable low-cost tie-backs and shared-infrastructure economics. Strong balance sheet, hedging and digital programs (18% downtime reduction; 5–12% uplift potential) support low lifting costs and fast paybacks.

Short-payback projects (<3 years) rapidly add barrels and extend field life, improving cash flow profiles. Modular subsea solutions can accelerate first production by 12–18 months versus bespoke builds. Replicable templates reduce execution risk and cut CAPEX 15–25%. Returns stay resilient, with typical IRRs 15–25% at ~85 $/bbl (Brent 2024 avg).

Stable North Sea hubs deliver predictable gas/liquids volumes underpinning UK security; lean brownfield focus and tie-backs cut capex and unit costs; short-payback, modular projects boost cash flow with IRRs typically 15–25% at ~85 $/bbl (Brent 2024); strong HSSE and open-access hubs attract partners and financing.

Dedicated commercial teams maintain close buyer engagement, translating account management into repeat contracts and deeper renewal conversations. Market insights, including 2024 traded price signals and forward curves, inform dynamic pricing and targeted hedging strategies. Continuous feedback loops from buyers drive incremental product quality and delivery improvements. Strong relationship depth materially enhances renewal rates and contract longevity.

Serica secures stable demand via long-term offtakes covering ~75% of 2024 volumes, with pricing tied to NBP/Brent and balancing clauses limiting exposure. Commercial teams and daily nominations drive 98% delivery reliability H1 2024 and c.10% peak-month value uplift. Sustainability premiums and 20% emissions cut since 2019 boost renewal rates.

Export pipelines link Serica’s offshore assets to onshore entry points, enabling steady flows to terminals and national networks; processing arrangements at partner facilities guarantee gas and liquids meet market specifications. Active capacity management and third‑party nominations reduce bottlenecks, while robust logistics and chartering protocols protect delivery schedules and minimize downtime.

Serica sells via direct bilateral offtake with utilities and traders, locking volumes, Brent/NBP‑linked pricing and operational flexibility; 2024 contracts reduced spot exposure. NBP/ICE hubs (ICE UK futures avg >80,000 contracts/day in 2024) provide liquidity for balancing and hedging. Brent averaged 84.7 USD/bbl in 2024; third‑party hub processing monetized spare capacity into service revenues.

Refiners and liquids buyers offtake Serica’s crude, condensate and NGLs aligned to strict quality specifications, prioritising scheduling reliability and maximising netbacks. They require stable blends and consistent assays to minimise refinery processing variability. Longstanding contracts with streamlined lifting procedures reduce logistical risk and payment uncertainty.

Core buyers (shippers, power utilities) demand predictable UK gas volumes as gas-fired generation provided 36% of UK electricity in 2024, favoring 3–10 year contracts and balancing flexibility. Traders/aggregators leverage North Sea throughput (Brent $86/bbl avg 2024) needing index-linked, flexible terms. Refiners/JV partners value stable assays, hub access and fair tariffs; EU gas storage >90% entering winter 2024 underscores security priority.

Pipeline and processing fees materially affect Serica Energy unit economics, with third-party midstream charges treated as variable per-boe operating costs. Contract optimization reduces take-or-pay exposure by aligning minimum commitments to production profiles. Proactive capacity planning avoids congestion premiums at key UK hubs. Tariff negotiations use throughput certainty to secure lower fixed tariffs and interruptible terms.

Offshore staffing, maintenance and logistics ≈60% of OPEX; energy, chemicals and integrity ≈25%. 2024 capex ~£60m focused on infill, workovers and upgrades; tie-backs cut CAPEX ~40%. G&A ~8% of revenue (2024); UK decommissioning liabilities industry-wide £60–80bn press provisions.

In 2024 Serica leverages NGLs and by-product sales to generate incremental revenue from LPG and condensates, with industry NGL yields typically around 5–15% of gas volumes. Processing agreements set yields and product specs, underpinning cashflows and quality-linked pricing. Diversified markets for propane, butane and condensate reduce reliance on a single commodity, while optimized logistics and offload routing can boost netbacks materially.

Revenue driven mainly by UK gas sales (NBP ~37 pence/therm in 2024) and oil/condensate (Brent ~86 USD/bbl in 2024), supplemented by NGLs (5–15% yields) and hub/processing tariffs. Long‑dated offtakes, active scheduling and hedging reduced volatility and improved netbacks. Opportunistic farm‑downs and tariff utilization enhanced cashflow visibility.