For decades, developing an offshore field almost automatically meant one thing: build a massive surface platform. Today, that assumption is rapidly changing. The first question many operators now ask is no longer: “How large should the platform be?” but rather: “Can the field be developed without a conventional platform at all?” This is where the concept of the Subsea Factory begins. 🚀 Modern subsea developments are no longer limited to wells, trees, and flowlines. A growing portion of the production system is being transferred directly to the seabed, including: Subsea Separation Multiphase Boosting Subsea Compression Water Reinjection All-Electric Control Systems Long-Distance Tiebacks In other words, subsea systems are evolving from simple transportation infrastructure into fully integrated processing and production facilities operating on the seafloor. From a technical and economic perspective, the shift is logical. In deepwater developments, conventional surface platforms i...
Field development planning is a multidisciplinary process that defines how an oil or gas field will be produced safely, economically, and efficiently over its entire life cycle.
This lesson introduces the critical decisions that must be addressed before committing to a development concept.
1. Reservoir Depletion Strategy
The first and most fundamental question in field development is:
How will the reservoir energy be managed to produce hydrocarbons?
Common depletion strategies include:
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Natural Depletion
Production relies solely on the reservoir’s natural pressure.-
Lower capital cost
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Production declines as pressure drops
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Water Injection
Water is injected to maintain reservoir pressure and improve recovery.-
Increases ultimate recovery
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Requires injection wells and facilities
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Gas Injection
Gas is injected to support pressure or improve sweep efficiency.-
Common in gas or condensate reservoirs
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Higher operational and compression requirements
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📌 This decision impacts:
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Recovery factor
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Number of wells
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Field life
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Overall project economics
2. Artificial Lift Strategy
As reservoir pressure declines, natural flow may no longer be sufficient.
Artificial lift options include:
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Gas lift
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Electrical Submersible Pumps (ESP)
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Subsea boosting systems
Key questions:
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Will artificial lift be required from day one or later in field life?
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Should the system be designed upfront for future lift installation?
📌 Early planning avoids costly retrofits later.
3. Production Profile Definition
The production profile defines how much and how long the field will produce.
Key parameters:
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Plateau production rate
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Plateau duration
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Decline rate
📌 The production profile directly drives:
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Facility sizing
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Pipeline diameter
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Export capacity
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Financial metrics (NPV, IRR)
4. Phased Development Strategy
Instead of developing the entire field at once, production can be executed in phases.
Advantages of phased development:
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Lower upfront capital expenditure
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Early production and cash flow
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Ability to learn and optimize future phases
📌 Commonly used in:
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Deepwater developments
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High-uncertainty reservoirs
5. Wells and Completion Strategy
Well design is one of the largest cost and risk contributors.
Key decisions:
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Number of wells
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Completion type (open hole, cased and perforated, intelligent completions)
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Sand control requirements
Well trajectories:
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Vertical
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Deviated
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Horizontal
📌 These choices affect productivity, water/gas breakthrough, and long-term recovery.
6. Surface or Subsea Development Concept
A fundamental architectural decision:
Options:
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Surface wells
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Subsea wells
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Hybrid surface–subsea systems
The selection depends on:
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Water depth
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Distance to shore or host facility
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Environmental conditions
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Existing infrastructure
7. Pre-Drilling and Rig Selection
Pre-drilling:
Drilling wells before facility installation can:
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Reduce overall project schedule
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Enable earlier first production
Rig selection depends on:
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Water depth
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Environmental conditions
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Well complexity
Common rig types:
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Jack-up rigs
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Semi-submersibles
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Drillships
8. Safety and Field Layout Considerations
Safety is an integral part of field development planning.
Key considerations:
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Separation or grouping of hazardous functions
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Safe distances between wells, processing, and accommodation
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Emergency access and escape routes
📌 A well-designed layout reduces risk to personnel and assets.
9. Export Strategy
Produced hydrocarbons must be transported to market.
Two main export options:
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Standalone export system
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Tie-in to existing infrastructure
Key trade-offs:
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Capital cost vs. availability
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Schedule impact
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Operational dependency on third-party systems
10. Construction and Execution Strategy
Successful development requires realistic execution planning.
Key aspects:
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Availability of fabrication yards
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Local content requirements
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Offshore installation windows
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Project execution schedule
11. Contractual Strategy
The contracting approach strongly influences cost and risk allocation.
Common strategies:
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EPC (Engineering, Procurement, Construction)
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EPCI (including Installation)
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Multiple package contracting
📌 Contract strategy must align with:
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Project complexity
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Risk tolerance
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Market conditions
Key Takeaway
Field development planning is not a single technical decision, but a system-level optimization balancing:
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Reservoir performance
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Technical feasibility
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Safety
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Cost
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Schedule
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Long-term value
Every early decision has long-lasting consequences throughout the life of the field.
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