Assess the quality of a bottomhole or surface recombination sample before it enters a PVT programme.
Oil, Gas & Energy
Reservoir Fluid PVT Analysis and Equation of State Modelling
Covers reservoir fluid sampling, laboratory PVT testing and equation-of-state modelling, equipping reservoir and process engineers to characterise fluids and build models used in simulation and facilities design.
🗓️Duration5 training days
📚Content4 modules · 8 sessions
🎓On completionAccredited attendance certificate
About the programme
Course Overview
A field development plan built on an untuned equation of state can misjudge the dew point of a gas condensate or the bubble point of a volatile oil badly enough to change the choice of processing facilities. This course takes reservoir and process engineers through reservoir fluid PVT analysis from the wellsite to the simulation deck. Participants examine how bottomhole and surface recombination samples are gathered and quality-checked, interpret the standard laboratory programme of constant composition expansion, differential liberation, constant volume depletion and separator tests, and classify fluids as black oil, volatile oil, gas condensate or dry gas from their phase behaviour. The course then moves into equation-of-state modelling: characterising and lumping the plus fraction, choosing between Peng-Robinson and Soave-Redlich-Kwong formulations, and tuning the model by regression against measured saturation pressure, density and volumetric data. Sessions finish by generating black-oil tables for reservoir simulation and checking fluid model consistency against flow assurance and facilities design requirements, so participants leave able to defend a PVT model in a subsurface review rather than simply run software supplied by others.
Expected Learning Outcomes
Interpret constant composition expansion, differential liberation and separator test results.
Classify a reservoir fluid as black oil, volatile oil, gas condensate or dry gas from its behaviour.
Characterise and lump the plus fraction of a reservoir fluid for equation-of-state modelling.
Tune a Peng-Robinson or Soave-Redlich-Kwong equation of state against measured laboratory data.
Generate black-oil tables and fluid models suitable for reservoir simulation input.
Check a fluid model's consistency against flow assurance and facilities design requirements.
Who Should Attend
Reservoir engineers responsible for fluid characterisation in field development studies.
Process and facilities engineers who size separators and processing trains from fluid data.
Production technologists building integrated production system models.
Flow assurance engineers assessing hydrate, wax and asphaltene risk in a fluid system.
PVT laboratory staff and coordinators managing sampling and testing programmes.
Subsurface team members who review or approve reservoir fluid models.
Course Modules
Select any module to see its sessions and points.
01Reservoir Fluid Sampling and Laboratory Testing
2 sessions · 8 points
Session 1Sample Collection and Quality Control
- Compare bottomhole and surface recombination sampling methods and when each applies.
- Check a wellsite sample for wettability, contamination and single-phase representativeness.
- Plan sampling conditions, including flow rate and drawdown, to avoid two-phase flow at the sandface.
- Interpret opening checks such as flash gas-oil ratio and monophasic pressure on a sample report.
Session 2The Standard PVT Laboratory Programme
- Interpret a constant composition expansion test to identify saturation pressure and liquid dropout.
- Interpret differential liberation and constant volume depletion tests for oils and gas condensates.
- Read separator test data and relate it to field separator operating conditions.
- Extract viscosity, density and compressibility data from a standard PVT report.
02Fluid Characterisation and Classification
2 sessions · 8 points
Session 1Fluid Types and Phase Envelopes
- Construct a pressure-temperature phase envelope from laboratory and field observation data.
- Classify a reservoir fluid as black oil, volatile oil, retrograde gas condensate or dry gas.
- Relate initial reservoir pressure and temperature to the fluid's position on the phase envelope.
- Explain retrograde condensation and its consequences for gas condensate reservoir management.
Session 2Plus-Fraction Characterisation and Lumping
- Split a measured plus fraction into pseudo-components using an extended compositional analysis.
- Assign critical properties to pseudo-components using established correlations.
- Lump pseudo-components into a reduced set without losing key phase behaviour.
- Justify the level of plus-fraction detail needed for a given reservoir engineering application.
03Equation-of-State Modelling and Tuning
2 sessions · 8 points
Session 1Equation-of-State Fundamentals
- Explain the structure and assumptions of the Peng-Robinson and Soave-Redlich-Kwong equations of state.
- Set binary interaction parameters between components in an equation-of-state model.
- Predict saturation pressure and phase volumes from an untuned equation-of-state model.
- Identify where an untuned equation of state is likely to mismatch laboratory data.
Session 2Regression and Tuning to Laboratory Data
- Select regression parameters, such as critical properties and volume shift, for equation-of-state tuning.
- Tune an equation of state against saturation pressure, density and constant volume depletion data.
- Avoid over-tuning an equation of state so it stays predictive outside the calibration range.
- Validate a tuned equation of state against an independent laboratory test not used in regression.
04Applying PVT Models Downstream
2 sessions · 8 points
Session 1Generating Simulation Fluid Models
- Convert a tuned equation-of-state model into black-oil tables for reservoir simulation.
- Decide when a full compositional model is needed instead of a black-oil approximation.
- Check fluid model consistency across separator stages and stock-tank conditions.
- Document PVT model assumptions so a simulation team can apply them correctly.
Session 2Links to Flow Assurance and Facilities Design
- Use PVT data to estimate hydrate formation and wax appearance temperature in a fluid system.
- Relate fluid density and viscosity data to separator and pipeline sizing decisions.
- Flag asphaltene precipitation risk from PVT and compositional trends during depletion.
- Communicate PVT model limitations and uncertainty ranges to a facilities design team.
What the participant receives
4 course modules
A structured syllabus
8 training sessions
across 5 days
32 detailed points
Applied, detailed content
Accredited attendance certificate
On completing the programme
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