An Interactive 5-Day Training Course
Fundamentals of Applied Geoscience for Oil & Gas, Geothermal and CCS
One Toolkit, Three Energy Sectors
Secure your spot now!
Duration
5 Days
Price
$ 2,500
Starting From
25 Jan 2027
Home Geology and Geoscience Fundamentals of Applied Geoscience for Oil & Gas, Geothermal and CCS
Fundamentals of Applied Geoscience for Oil & Gas, Geothermal and CCS
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Fundamentals of Applied Geoscience for Oil & Gas, Geothermal and CCS - GG-FAG-PEA27
| Code | Date | Time | Duration | Location | Currency | Early Bird Fee Per Person |
|---|---|---|---|---|---|---|
| GG-FAG-PEA27 | 25 - 29 Jan 2027 | 10 AM CST | 4 Hours Per Day |
Online |
USD |
2500 |
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Fundamentals of Applied Geoscience for Oil & Gas, Geothermal and CCS
Description
The three sectors use the same subsurface skills and apply them to different ends. All require characterisation of rock properties, structure, fluids and stress; all use seismic, wells, cores and models. But a hydrocarbon project seeks a trap that has held fluid for geological time and wants to produce what is in it; a geothermal project seeks permeability and heat and intends to circulate fluid indefinitely; a storage project seeks injectivity and containment and must demonstrate that what it injects will remain. Those differences change what is characterised, how it is screened and what must be proven.
This training covers the shared toolkit and the sector-specific requirements together. Basin and geological setting, rock and fluid properties, seismic interpretation, well evaluation, structural geology and geomechanics are developed as the common foundation. The hydrocarbon application follows, covering petroleum systems, traps, reservoir quality and recovery. Geothermal is then developed: resource types, heat in place, permeability requirements, reinjection and thermal breakthrough, induced seismicity and enhanced systems. Carbon storage follows: site screening, capacity, trapping mechanisms, injectivity, containment, legacy wells and monitoring and verification requirements. The training closes with the transferability of skills between sectors, the repurposing of existing data and infrastructure, and the differences in regulation, risk and timescale.
Containment means something different in each sector. A hydrocarbon trap has demonstrated containment over millions of years by the simple fact that hydrocarbons are present, which is the strongest possible evidence. A geothermal system does not require containment at all in the same sense, since fluid is produced and reinjected within a circulating system. A CO2 storage site requires containment that must be demonstrated in advance, for a volume being deliberately injected, to a regulator, with monitoring continuing after injection stops. The same caprock analysis supports all three, but the evidential standard differs enormously.
Permeability requirements run in opposite directions. Hydrocarbon reservoirs can be commercial at a few millidarcies with stimulation, and tight unconventional reservoirs produce at far less. Geothermal needs high permeability because the economics depend on circulating large volumes of fluid to carry heat, and a geothermal well in rock that would make a good oil well may be entirely uneconomic. CO2 storage needs enough permeability to accept the injection rate without exceeding fracture pressure, which is a different constraint again and is often the binding one.
Timescale and reversibility differ fundamentally. A hydrocarbon field is produced and abandoned within decades, and errors are expensive but bounded. A geothermal field is expected to operate for decades with thermal decline managed through well placement and reinjection strategy. A storage site carries obligations extending beyond injection for decades, with liability transfer only after demonstration that the CO2 is stable. This changes how much characterisation is justified before committing and what evidence must be assembled.
Finally, the transferability is real and understated. Subsurface professionals trained in oil and gas carry directly applicable capability in seismic interpretation, well evaluation, reservoir characterisation, modelling, well design and reservoir management. What they typically lack is familiarity with the different objectives, the different screening criteria and the different regulatory frameworks, and those are learnable.
By the end of this training, participants will be able to:
- Apply the shared subsurface characterisation toolkit across geology, geophysics, petrophysics and geomechanics
- Identify what each sector requires differently from subsurface characterisation
- Screen sites for hydrocarbon, geothermal and CO2 storage potential against sector-specific criteria
- Assess reservoir and seal properties against the requirements of each application
- Evaluate geothermal resources including heat in place, permeability and reinjection strategy
- Assess CO2 storage capacity, injectivity, trapping mechanisms and containment
- Evaluate stress state and geomechanical risk including induced seismicity
- Specify monitoring and verification requirements appropriate to each sector
- Assess existing data and infrastructure for repurposing between sectors
- Transfer subsurface skills between oil and gas, geothermal and storage applications
Organisations sending participants to this training will:
- Transfer existing subsurface capability into geothermal and storage activity
- Screen opportunities across sectors on sound and sector-appropriate criteria
- Identify repurposing opportunities for existing data, wells and infrastructure
- Avoid applying hydrocarbon assumptions to projects with different requirements
- Build capability for diversification without recruiting entirely new teams
- Improve the technical quality of cross-sector opportunity assessment
Participants will:
- Apply subsurface skills across three sectors rather than one
- Understand what each sector requires and why the criteria differ
- Screen and assess opportunities in geothermal and storage
- Recognise where hydrocarbon experience transfers and where it misleads
- Contribute to energy transition projects on technical grounds
- Broaden career options as subsurface work diversifies
- Geoscientists moving into geothermal or carbon storage work
- Reservoir and petroleum engineers extending into energy transition projects
- Petrophysicists and geomechanics specialists working across sectors
- Project and development staff evaluating subsurface opportunities
- Technical managers planning capability development
- Regulatory, permitting and policy staff requiring subsurface grounding
- Graduate geoscientists entering a diversifying subsurface industry
Module 1 - Subsurface Resources and Their Objectives
- The three sectors and what each extracts or stores
- Shared subsurface requirements across sectors
- Different objectives: production, circulation, containment
- Screening criteria compared across sectors
- Timescale and reversibility differences
- Regulatory frameworks compared
- Risk profile and liability differences
- Economic drivers in each sector
- Transferability of skills, data and infrastructure
- Where hydrocarbon assumptions mislead in other sectors
Module 2 - Geological Framework
- Plate tectonics and basin formation
- Basin types and their resource relevance across sectors
- Sedimentary, igneous and metamorphic rock types
- Depositional environments and reservoir geometry
- Stratigraphy and correlation
- Structural geology: folds, faults and fractures
- Heat flow and geothermal gradient
- Regional stress regimes
- Geological setting requirements by sector
- Settings suitable for more than one application
Module 3 - Rock and Fluid Properties
- Porosity: types, measurement and distribution
- Permeability: measurement, range and its sector-specific requirements
- Pore throat structure and its control on flow
- Thermal properties: conductivity, heat capacity, diffusivity
- Mechanical properties and rock strength
- Diagenesis and its effect on properties
- Fracture permeability and its importance in geothermal
- Reservoir fluids: hydrocarbons, brine, CO2, steam
- Fluid properties across the relevant pressure and temperature ranges
- Relative permeability and multiphase behaviour
- Capillary entry pressure and sealing capacity
- Property requirements compared by sector
Module 4 - Subsurface Data and Characterisation
- Seismic acquisition, processing and interpretation
- Seismic resolution and what it can and cannot show
- Depth conversion and structural uncertainty
- Well logging and formation evaluation
- Core acquisition and analysis
- Formation testing and pressure measurement
- Temperature measurement and thermal logging
- Image logs and fracture characterisation
- Geomechanical data: stress magnitude and orientation
- Static model construction
- Data requirements by sector and their differences
- Reusing legacy hydrocarbon data for other applications
Module 5 - Oil and Gas Application
- Petroleum system elements and their assessment
- Source rock, maturation and migration
- Reservoir quality and its controls
- Seal and trap assessment
- Play and prospect evaluation
- Volumetric estimation and risking
- Recovery mechanisms and recovery factor
- Field development concepts
- Reserves classification
- Abandonment and the opportunity for repurposing
Module 6 - Geothermal Application
- Geothermal resource types and their settings
- Convective hydrothermal and conductive sedimentary systems
- Enhanced geothermal systems
- Heat in place and recoverable energy estimation
- Permeability requirements and why they are high
- Temperature requirements by end use
- Well testing and resource characterisation
- Two-phase and flashing flow
- Reinjection strategy and thermal breakthrough
- Tracer testing and flow path identification
- Scaling, corrosion and brine chemistry
- Induced seismicity in geothermal operations
- Sustainable production and resource management
Module 7 - CO2 Storage Application
- Storage options: saline formations, depleted fields, basalt
- CO2 properties and behaviour at storage conditions
- Trapping mechanisms: structural, residual, solubility, mineral
- Storage capacity estimation and its methods
- Pressure-limited capacity and brine displacement
- Injectivity and its maintenance
- Plume migration and prediction
- Caprock integrity and containment assessment
- Fault reactivation and induced seismicity
- Legacy wells as leakage pathways
- Monitoring, measurement and verification requirements
- Post-injection obligations and site closure
- Storage resource classification
Module 8 - Geomechanics Across Sectors
- Stress state determination and its measurement
- Pore pressure and effective stress
- Rock strength and failure criteria
- Wellbore stability across applications
- Fracture initiation and propagation
- Fault stability and reactivation potential
- Induced seismicity mechanisms and management
- Thermal stress effects in injection and geothermal operations
- Caprock integrity under pressure and temperature change
- Subsidence and surface deformation
- Monitoring for geomechanical response
- Traffic light systems and operational control
Module 9 - Integration, Repurposing and Practice
- Assessing a site for more than one application
- Repurposing depleted fields for storage or geothermal
- Reusing wells and their assessment
- Reusing seismic, log and core data
- Infrastructure reuse and its constraints
- Timing: assessing reuse before abandonment forecloses it
- Modelling requirements by sector
- Monitoring programme design across applications
- Public acceptance and stakeholder considerations
- Building a cross-sector subsurface team
- Where oil and gas experience transfers directly and where it does not
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.
