INPAC Development Company (IDC)
Providing Quality high-end Field Development Plans in and for Nigeria and West Africa,
FDP-related project development and finance services. Subsurface technical training.
Nigeria - Angola - Benin - Cameroon - Equatorial Guinea - Gabon - Ghana - Guinea - Guinea-Bissau - Ivory Coast  
Victoria Island
Lagos, Nigeria
An Affiliate of INPAC
Integrated Pan-African
Energy Company, Ltd.
Victoria Island
Lagos, Nigeria
www.inpac-energy.com
FDP@inpac-energy.com
Field Development Plans WBS for Nigeria

I. Introduction
    The location of the field
    The size of the field
    All the past activities that led to the discovery of the field
    The quality of seismic acquired
    The quantity that was processed
    The area that was interpreted
    Structural maps, isopatch maps and relevant logs
    Number of wells drilled and if production has started - cumulative production and remaining
    services
    Structural models and any other previous study carried out
    STOIIP / Ultimate Recovery / Recovery Factor

II. Development Driver and Objectives
    This should be clearly stated and also should be in line with the policy of the Federal
    Government of increasing reserve, production and maximizing profitability (Business
    technical objectives).

III. Scope of Work
    Predevelopment activities
    Development wells
    All the surface processing facilities, e.g. fabrication of the FPSO (if required), well jackets,
    laying of flow lines and hooking up of the wells to existing facilities or new facilities

IV. Subsurface
    IV.1  GEO-PHYSICS
    Seismic acquired (2D, 3D or even 4D with years)
    Seismic processed and years
    Area of seismic interpreted (with years)
    Any other geophysical activities carried out should be stated
    Result of all the geophysical activities should be stated
    Seismic coverage
    Seismic interpretation
    Velocity model and depth conversion
    Structure and quantitative interpretation
    DHI and AVO analysis
    Reservoir prognosis
    Uncertainties Analysis
    Amplitude Maps
    IV.2  GEOLOGY
    Structural analysis (results)
    All the isopatch maps
    Deposition models
    Result of sedimentological interpretation
    Result of stratigraphic correlations
    All the modeling result
    Hydrocarbon initially in place include low case, medium case, and high case
    Risk Analysis result
    Others
    IV.3  PETROPHYSICAL EVALUATION
    Reservoir rock and fluid properties
    Rock compressibility
    Hydrocarbon sand
    Porosity
    Water saturation
    Net to Gross
    Log analysis (result)
    The thickness and the sizes of the sand
    Original fluid contacts
    GUT
    GDT
    OUT
    ODT
    OWC
    Core analysis data

V. Petroleum Engineering
    V.1  RESERVOIR
    The upscaled geostatic model of the field / reservoir.
    The reservoir discovered
    Summary of the PVT analysis result
    SCAL data
    Well Test Analysis
    Laying approach
    Tank model material balance
    Communication study where applicable
    Porosity and Permeability, Viscosity, etc.
    The drainage pattern
    The reservoir drive mechanism
    Pressure maintenance type: water, gas, artificial lift and facilities
    required
    The dynamic model should include the following:
    Oil PVT plot
    Relative permeability plots
    Capillary pressure plots
    Reservoir pressure plots
    Fluid contacts
    Aquifer modeling
    History matching
    Modeling assumptions
    Inflow performance of wells
    Well potential estimates
    Sensitivities runs on gross rock volume contact and the
    resolution in place volumes
    The reserve data should be classified into proved, probable
    and possible.
    V.2  DRILLING PROGRAMME
    The number of wells to be drilled
    The types and drilling schedule should be indicated
    The number of wells should be such as to optimally recover the ultimate
    recoverable reserves without jeopardizing the energy available in the reservoir for
    primary recovery purposes.
    The ultimate number of wells required should be dictated by the number required in
    the simulation model to optimally and efficiently sweep the reserve in the field.
    The number of wells to be drilled and completed and their cost estimate should be
    included.
    The drilling and completion cost should be separated.
    The wells should reflect the requirement for effective and efficient exploitation of
    the field taking cognizance of the need for wells optimization and regulations.
    Drainage options should be stated.
    All the well design options
    Well types
    Straight holes
    Horizontal
    Multilateral or splinter wells
    Smart wells
    Deviated wells
    Deviated and horizontal (combined wells)
    Completion material selection
    Completion accessories
    Sand control type or option
    Any new technology
    Completion type
    Smart production
    Multilaterals
    Swellable packers
    Casing design
    Completion design
    Mud programme
    Cement programme
    Waste management strategies
    V.3  PRODUCTION
    All the sensitivities runs on the production rates should be included

VI. Surface Facilities
    All the surface production facilities scenarios considered
    Detailed breakdown of the option selected and how such option was considered, sizes, type
    of materials, etc.
    The major risks
    All the uncertainties
    Summary of all the concepts selected (subsurface / surface)
    The production forecast – field schedule

VII. Project Execution
    The contracting strategy
    Project organization
    Project schedule
    Local content strategy
    The estimated cost of the facilities required should be provided

VIII. Cost of the Project
    The CAPEX and OPEX costs should also be provided
    All the existing facilities (subsurface / surface)
    The project economics (the cost of the project / Summary of the economic indicators – NPV,
    IRR, PI, etc.)

IX. Report of Environmental Assessment
    All the environmental impact assessment reports.

X. Abandonment
    All abandonment programs should be included  in the report.
Offshore
Onshore
Marginals
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