An Interactive 5-Day Training Course
Reservoir Engineering for Geoscientists
How Your Static Model Flows
Secure your spot now!
Duration
5 Days
Price
$ 2,500
Starting From
01 Feb 2027
Home Geology and Geoscience Reservoir Engineering for Geoscientists
Reservoir Engineering for Geoscientists
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Reservoir Engineering for Geoscientists - GG-REG-PEA27
| Code | Date | Time | Duration | Location | Currency | Early Bird Fee Per Person |
|---|---|---|---|---|---|---|
| GG-REG-PEA27 | 01 - 05 Feb 2027 | 10 AM CST | 4 Hours Per Day |
Online |
USD |
2500 |
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Reservoir Engineering for Geoscientists
Description
A static model is a description of rock. A dynamic model is a prediction of what that rock will do when fluid is produced from it, and the connection between the two is reservoir engineering. Geoscientists who understand that connection build better static models, because they know which geological properties the flow calculation is sensitive to and which it barely notices. They also interpret dynamic results better, because production and pressure behaviour is evidence about geology that is available from no other source.
This training covers reservoir engineering from the geoscientist's position. Reservoir fluids are developed first, covering classification, phase behaviour, PVT properties and their effect on production. Flow in porous media follows, including Darcy's law, the diffusivity equation, and in particular relative permeability and capillary pressure, which are where rock description meets flow behaviour. Volumetric estimation and material balance are then covered, with attention to what material balance reveals about connected volume and compartmentalisation. Well testing and production analysis are developed for what they say about permeability, boundaries and connectivity. Recovery mechanisms, displacement, sweep efficiency and the geological controls on bypassed oil follow. The training closes with simulation, upscaling, history matching and the dynamic evidence that should feed back into the geological interpretation.
Relative permeability is where geology enters the flow calculation most directly and is least often supplied by geoscientists. It describes how readily each fluid flows when more than one is present, and it depends on wettability, pore geometry and rock type, all of which are geological properties. Simulation models commonly use one or two relative permeability curves for an entire field, applied across rock types with quite different pore structures, and the resulting predictions of water breakthrough and recovery carry that simplification. Rock-typed relative permeability is a geological contribution with direct engineering consequence.
Material balance is the most useful engineering result for a geoscientist to understand, because it measures connected volume. The static model produces a volume from mapped geometry and properties; material balance produces a volume from how the reservoir actually responds to production. Where they agree, the geological model is supported. Where material balance gives substantially less, part of the mapped volume is not connected, which is direct evidence of compartmentalisation. Where it gives more, there is volume not in the map. Both outcomes are geological information.
Production behaviour is underused as geological evidence. Early water breakthrough in one well and not another, pressure communication between wells across a mapped fault, a well that produces far above or below its neighbours, tracer arriving at an unexpected location: each of these says something about connectivity, barriers and architecture that no static measurement provides. Geoscientists who follow production data revise their interpretations with evidence that only becomes available after the field is producing.
Finally, upscaling is where geological detail meets the simulation grid, and much of it does not survive. A fine model with millions of cells becomes a simulation model with a fraction of that, and thin barriers, permeability contrasts and small-scale heterogeneity are averaged away. Understanding what the upscaling preserved and what it removed determines whether the simulation is testing the geological model or a smoothed version of it.
By the end of this training, participants will be able to:
- Classify reservoir fluids and explain phase behaviour and PVT properties and their production consequences
- Apply flow in porous media concepts including Darcy's law and the diffusivity equation
- Interpret relative permeability and capillary pressure curves and relate them to rock type and wettability
- Estimate hydrocarbon in place volumetrically and understand the sensitivity to each input
- Apply material balance and interpret what it reveals about connected volume and drive mechanism
- Interpret well test results for permeability, skin, boundaries and connectivity
- Apply decline and production analysis methods at a working level
- Compare recovery mechanisms and assess the geological controls on sweep and bypassed oil
- Explain reservoir simulation, its inputs and the effect of upscaling on geological detail
- Use production and pressure behaviour as evidence to revise geological interpretation
Organisations sending participants to this training will:
- Improve static model quality by focusing geological effort on what affects flow
- Improve integration between geoscience and reservoir engineering
- Reduce history matching effort caused by static models that cannot reproduce behaviour
- Use production and pressure evidence to improve geological interpretations
- Improve the geological basis of relative permeability, rock typing and barrier representation
- Build integrated subsurface capability rather than discipline silos
Participants will:
- Understand how a geological model behaves dynamically and why
- Identify which geological properties the flow calculation is sensitive to
- Perform and interpret basic reservoir engineering calculations
- Read production and pressure data as geological evidence
- Contribute effectively to simulation and development work
- Build capability that supports movement into integrated subsurface roles
- Petroleum geologists and reservoir geologists
- Reservoir modellers building static models for simulation
- Geophysicists working on development and producing assets
- Petrophysicists extending into dynamic applications
- Geoscientists working in integrated asset teams
- Geoscience managers and team leaders
- Graduate geoscientists entering development and production roles
Module 1 - Reservoir Fluids and PVT
- Reservoir fluid classification and its basis
- Dry gas, wet gas, gas condensate, volatile oil, black oil, heavy oil
- Phase envelopes and their interpretation
- Bubble point, dew point and retrograde behaviour
- Formation volume factor and shrinkage
- Solution gas-oil ratio and its behaviour
- Compressibility and viscosity
- PVT sampling and laboratory experiments in outline
- Black oil correlations and their limits
- Compositional variation with depth and its geological causes
- Fluid properties as evidence for connectivity and compartmentalisation
Module 2 - Flow in Porous Media
- Darcy's law and its assumptions
- Absolute permeability and its measurement scales
- Permeability anisotropy and its geological origin
- Radial flow and the productivity index
- Diffusivity equation and pressure propagation
- Transient and pseudo-steady state flow
- Radius of investigation and drainage area
- Skin and near-wellbore effects
- Non-Darcy flow in high rate gas wells
- Flow in fractured and dual porosity systems
- Scale dependence of permeability measurement
Module 3 - Multiphase Flow and Rock Properties
- Effective and relative permeability definitions
- Relative permeability curves and their shape
- Endpoints: irreducible water, residual oil, critical gas
- Wettability and its effect on relative permeability
- Wettability measurement and restoration
- Capillary pressure and its measurement
- Saturation height functions and transition zones
- Free water level against oil water contact
- Rock typing and its basis in pore geometry
- Rock-typed relative permeability and its value
- Hysteresis and trapping
- Special core analysis and its specification
Module 4 - Volumetrics and Uncertainty
- Volumetric equation and its parameters
- Gross rock volume and its structural uncertainty
- Net to gross and cut-off sensitivity
- Porosity and saturation inputs
- Formation volume factor and its effect
- Recovery factor and its determinants
- Deterministic and probabilistic estimation
- Parameter distributions and dependencies
- Which inputs actually drive the uncertainty
- Reconciling model volumes with hand calculation
- Presenting a volume range and its basis
Module 5 - Material Balance
- Material balance concept and what it measures
- Connected volume against mapped volume
- General material balance equation and its terms
- Drive mechanisms and their identification
- Drive indices and their interpretation
- Gas material balance and the P over Z plot
- Aquifer support and its recognition
- Data requirements: pressure and production quality
- Interpreting disagreement with volumetric estimates
- Material balance as evidence for compartmentalisation
- Using material balance to test a geological model
Module 6 - Well Testing and Production Analysis
- Well test types and their purposes
- Pressure transient behaviour and flow regimes
- Diagnostic and derivative plots in outline
- Permeability and skin determination
- Boundary detection and its geological interpretation
- Interference and pulse testing for connectivity
- Formation tester pressure gradients and contacts
- Decline curve analysis and production forecasting
- Rate transient analysis in outline
- Production data as geological evidence
- Reconciling well test permeability with core and log permeability
- Tracer testing and flow path identification
Module 7 - Recovery Mechanisms and Sweep
- Primary drive mechanisms and their expected recovery
- Displacement efficiency and residual saturation
- Mobility ratio and displacement stability
- Fractional flow and Buckley-Leverett displacement
- Areal, vertical and volumetric sweep efficiency
- Geological controls on sweep: layering, heterogeneity, barriers
- Bypassed oil and where it accumulates
- Waterflooding and its design
- Gas injection and pressure maintenance
- Improved and enhanced recovery screening in outline
- Coning, cusping and their geological controls
- Well spacing and its geological basis
Module 8 - Simulation, Upscaling and Feedback
- Reservoir simulation purpose and construction
- Grid design and layering decisions
- What the static model contributes to the simulation model
- Upscaling and what it preserves and removes
- Thin barriers and their loss during coarsening
- History matching: objectives and parameters adjusted
- Non-uniqueness and its consequences
- When history match failure indicates a static model problem
- Revising the geological model rather than tuning the dynamic one
- Dynamic data as input to geological reinterpretation
- Working with simulation engineers productively
- Delivering a static model with its uncertainty stated
Upon successful completion of this training course, delegates will be awarded an official Certificate of Completion issued by the Petroleum Engineers Association (PEA), an ISO 9001:2015 certified training organization. The certificate carries 10 Credits and formally records the total learning hours completed.
Each certificate is signed by the Course Facilitator and the CEO of the Petroleum Engineers Association, and serves as verifiable proof of professional training that delegates can present to employers and professional bodies worldwide.
Frequently Asked Questions
All course bookings made through PEA are strictly non-refundable. By registering for a course, you acknowledge and accept that all fees are payable in full and are not subject to refund under any circumstances, including changes in personal or professional commitments or partial attendance.
PEA reserves the right to make reasonable adjustments to course content, trainers, or schedules where necessary, without entitling delegates to a refund. Comprehensive details of each course — including objectives, target audience, and content — are clearly outlined before enrolment, and it is the responsibility of the delegate to ensure the course's suitability prior to booking.
For any inquiries related to cancellations or bookings, please contact our support team, who will be happy to assist you.
