Recover Additional Oil with CO2 and Account for What Stays Behind
CO2-EOR
Applied CO2 flooding engineering, covering CO2 phase behaviour and oil interaction, minimum miscibility pressure, displacement and sweep, WAG design, CO2 supply and recycle, corrosion and materials, surveillance, storage accounting within EOR operations and project economics.
CO2-EOR
Have Questions ?
CO2-EOR - RE-CO2EOR-PEA27
| Code | Date | Time | Duration | Location | Currency | Early Bird Fee Per Person |
|---|---|---|---|---|---|---|
| RE-CO2EOR-PEA27 | 21 - 25 Jun 2027 | 10 AM CST | 4 Hours Per Day |
Online |
USD |
4000 |
Boost your team's skills and your budget! Enjoy group discounts for collaborative learning. Send an inquiry to info@peassociations.com.
CO2-EOR
Description
CO2 is the most widely applied miscible injectant because it develops miscibility with a broad range of crude oils at pressures achievable in many reservoirs, and because it swells oil and reduces its viscosity even where full miscibility is not achieved. It is also, increasingly, valued for what remains in the reservoir rather than only for the oil it produces, since CO2 retained in a producing formation constitutes storage that may carry regulatory or commercial value.
This training covers both aspects. CO2 properties are developed first, including phase behaviour, density and viscosity across the conditions encountered from surface through injection to reservoir, and the strong property variation near the critical point that affects every calculation. CO2 and oil interaction follows: swelling, viscosity reduction, extraction of intermediate components and the development of miscibility. Minimum miscibility pressure determination for CO2 systems is covered including the effect of impurities. Displacement efficiency, mobility ratio, viscous fingering and gravity override are then addressed, followed by WAG design specific to CO2. Supply sourcing, purification, compression, recycle and the growth of recycle volume are covered. Corrosion and materials for wet CO2 service follow, then surveillance, storage accounting and the economics including credit mechanisms.
CO2 is favourable for miscibility and unfavourable for sweep. It achieves miscibility with many oils at pressures well below those required for nitrogen or lean hydrocarbon gas, which makes it applicable in reservoirs where other injectants would remain immiscible. But it has low viscosity and low density relative to oil at reservoir conditions, which produces a strongly unfavourable mobility ratio and significant gravity override. The result is a process with excellent microscopic displacement and poor macroscopic sweep, and most of the engineering effort goes into the second problem.
Impurities matter more than they appear. CO2 from natural sources, from gas processing, from power generation and from industrial capture carries different impurity suites, and nitrogen, methane, oxygen and hydrogen sulphide each shift the minimum miscibility pressure. Nitrogen and methane raise it substantially, which can move a reservoir from miscible to immiscible operation. Specifying the impurity limits for a CO2 supply is therefore a reservoir engineering decision as much as a commercial one.
Wet CO2 is aggressively corrosive and dry CO2 is not, which makes water content the governing specification through the whole system. Produced fluids returning to the recycle plant are water saturated, and the dehydration unit between separation and recompression is the component on which the integrity of every downstream pipeline, compressor and injection well depends. Materials selection, particularly for injection wells and produced fluid handling, follows from this.
Finally, the storage dimension changes project accounting. A conventional CO2 flood purchases CO2, recovers oil and recycles produced CO2 to minimise purchase volume, and the retained CO2 is a cost. Where credits or regulatory frameworks value storage, the retained volume becomes revenue, which changes the optimal operating strategy: purchasing and injecting more CO2, and recycling less aggressively, can become economic. Measuring and verifying the retained volume then becomes a technical requirement.
By the end of this training, participants will be able to:
- Characterise CO2 properties across the pressure and temperature range from surface to reservoir
- Explain CO2 and oil interaction including swelling, viscosity reduction and component extraction
- Determine minimum miscibility pressure for CO2 systems and assess the effect of impurities
- Screen reservoirs for CO2 flooding against pressure, depth, oil composition and geological criteria
- Evaluate displacement efficiency, mobility ratio, fingering and gravity override for CO2 floods
- Design WAG schemes appropriate to CO2 flooding
- Specify CO2 supply requirements including purity limits and their reservoir basis
- Design recycle facilities including separation, dehydration and compression, sized for late-life volumes
- Select materials and corrosion controls for CO2 service across wells and facilities
- Account for CO2 retained in the reservoir and evaluate project economics including credit mechanisms
Organisations sending participants to this training will:
- Screen CO2 EOR opportunities correctly against miscibility and sweep criteria
- Specify CO2 supply purity against reservoir requirements rather than accepting supplier specification
- Size recycle and compression facilities against realistic late-life volumes
- Reduce corrosion failures through correct water specification and materials selection
- Improve sweep and recovery through better WAG and conformance design
- Evaluate projects correctly where storage credits form part of the economics
Participants will:
- Understand why CO2 works as an injectant and where it underperforms
- Determine MMP and assess whether a reservoir supports miscible operation
- Design CO2 injection and recycle schemes
- Anticipate corrosion, facility and recycle constraints
- Account for retained CO2 and its commercial treatment
- Build capability bridging enhanced recovery and CO2 storage work
- Reservoir engineers working on CO2 flooding and enhanced recovery
- Facilities and process engineers supporting CO2 injection and recycle
- Simulation engineers modelling CO2 flooding
- Development engineers evaluating recovery and storage options
- Integrity and materials engineers working on CO2 systems
- Technical and commercial staff evaluating CCUS and EOR projects
- Asset managers considering CO2 flood investment
Module 1 - CO2 Properties and Behaviour
- CO2 phase diagram: gas, liquid, supercritical and solid regions
- Critical point and property variation in its vicinity
- Density, viscosity and compressibility across operating conditions
- Equations of state for CO2 systems and their accuracy
- Solubility of CO2 in oil and in water
- Effect of impurities on CO2 properties
- Joule-Thomson behaviour and cooling on expansion
- Hydrate formation with water present
- Properties relevant to injection, transport and reservoir behaviour
Module 2 - CO2 and Oil Interaction
- Oil swelling by CO2 dissolution
- Viscosity reduction and its magnitude
- Extraction of intermediate hydrocarbon components
- Density changes and their effect on gravity segregation
- Asphaltene precipitation induced by CO2
- Immiscible CO2 injection mechanisms and recovery
- Miscibility development by multiple contact
- Swelling test and slim tube data interpretation
- PVT characterisation for CO2 flooding studies
- Effect of oil composition on CO2 performance
Module 3 - Minimum Miscibility Pressure for CO2
- MMP determination methods for CO2 systems
- Slim tube testing and its interpretation
- Rising bubble and vanishing interfacial tension methods
- CO2 specific correlations and their applicability
- Equation of state prediction and fluid model tuning
- Effect of temperature on CO2 MMP
- Effect of oil composition, particularly C5 to C30 content
- Impurity effects: nitrogen, methane, hydrogen sulphide, oxygen
- Setting CO2 purity specifications from MMP requirements
- Assessing the margin between reservoir pressure and MMP
- Near-miscible and immiscible operation and their recovery
Module 4 - Screening and Reservoir Selection
- Screening criteria for CO2 flooding
- Depth and pressure requirements for miscibility
- Oil gravity and composition criteria
- Reservoir temperature limits
- Permeability, heterogeneity and continuity requirements
- Remaining oil saturation and its determination
- Existing waterflood maturity and its influence
- Reservoir geometry and dip considerations
- Well and completion suitability for conversion
- Ranking candidate reservoirs within a portfolio
Module 5 - Displacement, Sweep and WAG Design
- Microscopic displacement efficiency under CO2 miscible flooding
- Residual oil saturation to CO2
- Mobility ratio and its unfavourable magnitude
- Viscous fingering in CO2 floods
- Gravity override and its severity with CO2
- Effect of heterogeneity on CO2 sweep
- WAG concept applied to CO2
- WAG ratio, slug size and cycle design for CO2
- Tapered WAG and late-life adjustment
- Three-phase flow and hysteresis effects
- Trapped gas saturation and its storage relevance
- Foam and conformance control for CO2 mobility
Module 6 - CO2 Supply, Recycle and Facilities
- CO2 sources: natural, gas processing, industrial capture, power generation
- Supply contracts, purity specification and reliability
- CO2 transport by pipeline and its design requirements
- Injection compression and pumping arrangements
- Produced fluid separation with high CO2 content
- CO2 dehydration and its criticality
- Recycle compression and its staging
- Recycle volume growth through project life
- Compression capacity as the binding constraint on project rate
- CO2 removal and purification from recycle streams
- Facility layout, safety and CO2 release considerations
- Facility capital and operating cost drivers
Module 7 - Corrosion, Materials and Integrity
- Wet CO2 corrosion mechanism and its severity
- Water content specification and its integrity basis
- Carbon steel in dry CO2 service
- Corrosion resistant alloys and their application
- Elastomer selection and explosive decompression damage
- Injection well materials and completion design
- Cement systems for CO2 service and their degradation
- Producer well corrosion with high CO2 breakthrough
- Corrosion inhibition in CO2 EOR service
- Corrosion monitoring across the system
- Well integrity monitoring and annulus management
Module 8 - Simulation, Surveillance and Performance
- Compositional simulation for CO2 flooding
- Fluid characterisation and component lumping for CO2 systems
- Numerical dispersion and grid resolution requirements
- Representing WAG, hysteresis and trapping
- History matching CO2 flood performance
- Surveillance: production, injection, composition, pressure
- CO2 breakthrough monitoring and its interpretation
- Tracer programmes in CO2 floods
- 4D seismic monitoring of CO2 movement
- Diagnosing poor sweep and conformance problems
- Optimising injection allocation and WAG parameters in operation
- Performance benchmarking against comparable projects
Module 9 - Storage Accounting and Economics
- CO2 mass balance across a flood: purchased, injected, produced, recycled, retained
- Retention mechanisms: dissolution, residual trapping, structural
- Measuring and verifying retained CO2
- Monitoring, measurement and verification requirements
- Regulatory frameworks recognising EOR storage
- Credit mechanisms and their requirements
- Effect of storage value on optimal operating strategy
- Project economics: CO2 purchase, compression, facilities, oil revenue
- Sensitivity to oil price and CO2 cost
- Transition from EOR operation to dedicated storage at end of oil production
- Site closure, post-injection monitoring and long term liability
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.
