An Interactive 5-Day Training Course
Dynamic Reservoir Modelling for Geologists: Static to Simulation
Taking Static Models Into Flow Simulation
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Duration
5 Days
Price
$ 3,500
Starting From
18 Jan 2027
Home Geology and Geoscience Dynamic Reservoir Modelling for Geologists: Static to Simulation
Dynamic Reservoir Modelling for Geologists: Static to Simulation
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Dynamic Reservoir Modelling for Geologists: Static to Simulation - GG-DYNG-PEA27
| Code | Date | Time | Duration | Location | Currency | Early Bird Fee Per Person |
|---|---|---|---|---|---|---|
| GG-DYNG-PEA27 | 18 - 22 Jan 2027 | 10 AM CST | 4 Hours Per Day |
Online |
USD |
3500 |
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Dynamic Reservoir Modelling for Geologists: Static to Simulation
This training covers dynamic reservoir modelling for geoscientists. It works through fluid flow fundamentals, PVT and rock fluid properties, simulator construction and its inputs, well models and controls, history matching and what it does to the geology, forecasting, the geological causes of history match problems and the effective working relationship between static and dynamic modelling.
Description
Geologists build static models and engineers run them, and the handover is where a great deal of geological work is lost. Properties are averaged away, barriers disappear, layering is regrouped and during history matching the permeability field the geologist built is multiplied by whatever makes the match work. Much of this is avoidable, and avoiding it requires the geologist to understand what the simulator does with the model and what the engineer needs from it.
This training provides that understanding. Fluid flow fundamentals are established first, covering Darcy flow, relative permeability, capillary pressure and the force balance that determines displacement behaviour, all at the level a geoscientist needs. PVT and rock fluid properties follow, covering fluid description, compressibility and the data a simulator requires. Simulator construction is then developed, covering the grid, the property inputs, initialisation, equilibration and the common initialisation errors. Well models and controls follow, covering how wells are represented and why completion representation matters geologically. History matching is then addressed in detail, covering the process, the parameters typically adjusted and the geological damage that non-unique matching does. Forecasting follows. The geological causes of history match problems are then developed as the core practical content. The training closes with the static to dynamic working relationship.
History matching routinely overwrites the geology and nobody records it. When the simulated water breakthrough is too early, the engineer may apply a permeability multiplier, adjust the relative permeability curves, or add a transmissibility barrier. All three can produce a match. Only one of them may correspond to a real geological feature. If the multiplier is applied across the field, the geologist's carefully distributed permeability is replaced by a scaled version of itself, and the geological reasoning behind it is no longer in the model. Asking what was changed and why, after each matching iteration, keeps the geology visible.
Most history match difficulties have geological causes and geological solutions. Early water breakthrough is often a missing high permeability streak or a fault that is more open than modelled. Pressure depletion faster than expected indicates a smaller connected volume, which means a barrier is missing. A well that produces less than predicted may be completed across a facies the model has in the wrong place. Each of these is diagnosable from the production signature, and the fix is a change to the geological model rather than a parameter adjustment.
Initialisation errors produce a model that is wrong before a single timestep runs. If the saturation height function and the capillary pressure curves used in the dynamic model are inconsistent, the model will redistribute saturation during equilibration, changing the in-place volume from the static model's value. Differences of ten per cent or more in initial oil in place between static and dynamic models are common and are almost always an initialisation inconsistency rather than a real disagreement. Checking the dynamic model's initial volumes against the static model's is a five-minute test that should be mandatory.
Finally, the geologist should be present during history matching. The engineer running the match is solving a numerical problem and the geologist is the only person who can say whether a proposed change is geologically possible. A transmissibility barrier in a position with no fault and no shale is not a geological feature; a permeability multiplier of four applied to a facies with measured permeability is not consistent with the core. These objections only get made if the geologist is in the room, and when they are made the resulting match is usually both better and more predictive.
By the end of this training, participants will be able to:
- Apply fluid flow fundamentals relevant to reservoir simulation
- Interpret PVT and rock fluid property data
- Describe how a simulator is constructed from a static model
- Check dynamic model initialisation against static model volumes
- Explain how wells and completions are represented in simulation
- Follow and contribute to a history matching process
- Identify the geological causes of common history match problems
- Distinguish geologically valid from invalid history match adjustments
- Interpret production forecasts and their geological dependencies
- Work effectively with reservoir engineers through the modelling cycle
The training runs simulation on static models built by the participants or supplied. Production histories are matched and participants evaluate each proposed adjustment for geological plausibility. Models with deliberately introduced geological errors are history matched to show how parameter adjustment hides geological problems. Initialisation checks are run and volume discrepancies traced to their causes.
Organisations sending participants to this training will:
- Improve the static to dynamic model handover
- Reduce geological information lost in simulation
- Diagnose history match problems geologically
- Catch initialisation and volume inconsistencies early
- Produce history matches that remain predictive
- Improve collaboration between geoscience and engineering
Participants will:
- Understand what simulation does with their models
- Contribute effectively to history matching
- Diagnose production behaviour geologically
- Challenge implausible model adjustments
- Speak the reservoir engineer's language
- Build models that survive the handover
- Reservoir and development geologists
- Reservoir modellers and geomodellers
- Petrophysicists working with asset teams
- Geoscientists in integrated subsurface teams
- Subsurface team leaders
- Geoscientists moving into reservoir management
- Reservoir engineers wanting the geological perspective
Module 1 - Fluid Flow Fundamentals
- Darcy's law and its application
- Single phase and multiphase flow
- Relative permeability concepts
- Relative permeability curve shapes
- Wettability and its flow effects
- Capillary pressure in flow
- Capillary, viscous and gravity forces
- Mobility ratio and its consequences
- Fractional flow and displacement
- Residual saturation and trapping
- Drive mechanisms and their behaviour
- What controls recovery factor
Module 2 - Fluid and Rock Fluid Properties
- Reservoir fluid types
- PVT properties and their measurement
- Formation volume factor and solution gas
- Bubble point and dew point
- Viscosity and its variation
- Compressibility of rock and fluid
- Black oil against compositional description
- Special core analysis data for simulation
- Relative permeability measurement
- Capillary pressure data for simulation
- Rock type dependence of flow functions
- Data gaps and their treatment
Module 3 - Building the Simulation Model
- Static to dynamic model transfer
- Grid import and geometry checks
- Property transfer and upscaling
- Region and rock type assignment
- Fluid in place calculation in the simulator
- Equilibration and initialisation
- Contact and datum specification
- Saturation initialisation from capillary pressure
- Volume comparison against the static model
- Diagnosing initialisation discrepancies
- Aquifer specification
- Model acceptance before running
Module 4 - Wells and Completions
- Well representation in simulation
- Well index and connection factors
- Completion interval specification
- Perforation and layer connection
- Horizontal well representation
- Skin and damage representation
- Well controls: rate, pressure, limits
- Inflow performance and lift
- Group and field controls
- Workovers and recompletions in the model
- Geological input to well representation
- Well model errors and their symptoms
Module 5 - History Matching
- History matching objectives
- Observed data and its quality
- Production allocation uncertainty
- Match quality measures
- Parameters typically adjusted
- Permeability multipliers
- Transmissibility multipliers
- Relative permeability adjustment
- Aquifer parameter adjustment
- Non-uniqueness of history matches
- Assisted and automated history matching
- Recording what was changed and why
Module 6 - Geological Diagnosis of Match Problems
- Early water breakthrough causes
- High permeability streaks and thief zones
- Fault conductivity as a cause
- Late breakthrough causes
- Faster pressure depletion than expected
- Missing barriers and smaller connected volume
- Slower depletion and unmodelled aquifer support
- Low well productivity causes
- Gas and water coning problems
- Diagnosing from the production signature
- Geological fixes against parameter fixes
- Testing geological alternatives in the simulator
Module 7 - Forecasting
- Forecast construction after matching
- Development case definition
- Well schedule and drilling sequence
- Facility and offtake constraints
- Plateau and decline behaviour
- Infill and injection case forecasting
- Forecast sensitivity to geological inputs
- Multiple realisation forecasting
- Forecast uncertainty ranges
- Reserves support from simulation
- Forecast review and its geological content
- Updating forecasts with new production
Module 8 - Static and Dynamic Working Practice
- Handover specification between teams
- Documentation requirements at handover
- Geologist involvement during matching
- Challenging implausible adjustments
- Feeding dynamic results back to the static model
- Model update cycles
- Shared ownership of the reservoir description
- Common failure modes in the relationship
- Terminology differences and their resolution
- Joint review practices
- Building a working static to dynamic loop
- Reviewing a simulation study as a geologist
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.
