An Interactive 5-Day Training Course
Reservoir Characterization of Clastic (Sandstone) Reservoirs
Characterising Sandstone Reservoirs From Core Up
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Duration
5 Days
Price
$ 3,500
Starting From
27 Dec 2027
Home Geology and Geoscience Reservoir Characterization of Clastic (Sandstone) Reservoirs
Reservoir Characterization of Clastic (Sandstone) Reservoirs
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Reservoir Characterization of Clastic (Sandstone) Reservoirs - GG-RCLAS-PEA27
| Code | Date | Time | Duration | Location | Currency | Early Bird Fee Per Person |
|---|---|---|---|---|---|---|
| GG-RCLAS-PEA27 | 27 - 31 Dec 2027 | 10 AM CST | 4 Hours Per Day |
Online |
USD |
3500 |
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Reservoir Characterization of Clastic (Sandstone) Reservoirs
This training covers the characterisation of sandstone reservoirs. It works through sandstone composition and texture, depositional systems and their architecture, diagenesis and reservoir quality, clay minerals and their effects, porosity and permeability controls, heterogeneity at every scale, petrophysical evaluation of sandstones, rock typing and property prediction, and the integration of these into a reservoir description.
Description
Sandstone reservoirs hold the majority of conventional oil and gas production and their behaviour is controlled by a combination of depositional texture and diagenetic modification. Grain size, sorting and clay content set the starting pore system; compaction, cementation and clay authigenesis modify it, sometimes beyond recognition. Predicting reservoir quality means understanding both processes and knowing which dominates in a given basin and interval.
This training covers sandstone characterisation in full. Composition and texture are established first, covering grain size, sorting, mineralogy, framework composition and the textural parameters that control initial porosity and permeability. Depositional systems and their architecture follow, covering the main sandstone-producing environments and the reservoir geometry, continuity and heterogeneity each produces. Diagenesis is then developed in detail, covering compaction, quartz cementation and its temperature dependence, carbonate cement, clay authigenesis, dissolution and the prediction of reservoir quality with depth. Clay minerals are addressed specifically, covering their distribution, their effect on permeability and their severe effect on log response. Porosity and permeability controls are then integrated. Heterogeneity at every scale follows, from lamination to field. Petrophysical evaluation of sandstones is then developed, covering the particular problems of shaly sands. The training closes with rock typing, property prediction and integration.
Quartz cementation is temperature controlled and that makes reservoir quality predictable with depth. Quartz cement precipitation becomes significant above roughly ninety degrees Celsius and accelerates with temperature, so a sandstone's porosity loss depends heavily on its thermal history rather than simply on its present depth. A sandstone now at four kilometres that reached its maximum temperature recently may retain good porosity; one at three kilometres that was deeper and hotter earlier may be tightly cemented. Burial history modelling is therefore part of reservoir quality prediction.
Grain coating chlorite preserves porosity in deeply buried sandstones and its distribution is predictable. A continuous coating of authigenic chlorite on quartz grains prevents quartz cement nucleation, allowing anomalously high porosity to survive to depths where uncoated sandstones are tight. The coatings develop from early iron-rich precursors, which are associated with particular depositional settings, so the distribution of the porosity preservation is tied to depositional facies. This is one of the more valuable predictive relationships in sandstone reservoir quality.
A few per cent of the wrong clay destroys permeability. Authigenic kaolinite booklets, illite fibres and chlorite plates occupy pore throats rather than pore bodies, so a small volume removes a large fraction of the permeability while barely affecting porosity. Fibrous illite is the most damaging, capable of reducing permeability by more than an order of magnitude at a few per cent abundance. The permeability consequence therefore depends on clay type and location, not on total clay volume, which is why X-ray diffraction and electron microscopy are worth their cost.
Finally, shaly sand petrophysics is where sandstone reservoirs are most often misevaluated. Clay bound water conducts, which lowers the measured resistivity and makes an oil-bearing shaly sand look water-bearing if the Archie equation is used unmodified. The shaly sand models correct for this, but they require inputs that have to be derived rather than assumed, and the choice of model and parameters can change the calculated saturation by tens of saturation units. The uncertainty is frequently larger than any other term in the volume calculation.
By the end of this training, participants will be able to:
- Describe sandstone composition and texture and relate them to reservoir properties
- Interpret sandstone depositional systems and their reservoir architecture
- Assess the effect of compaction and cementation on reservoir quality
- Predict reservoir quality with depth using thermal and burial history
- Identify clay mineral types and assess their permeability effects
- Recognise porosity preservation mechanisms and their distribution
- Characterise heterogeneity from lamination to field scale
- Apply shaly sand petrophysical models and select their parameters
- Build rock typing schemes for sandstone reservoirs
- Integrate the characterisation into a reservoir description
The training combines core and thin section observation with data interpretation on sandstone reservoir data sets. Participants describe sandstone texture and relate it to measured properties, interpret diagenetic sequences from petrographic data, and predict reservoir quality for undrilled locations using burial history. Shaly sand evaluations are run with different models and parameters to quantify the saturation uncertainty.
Organisations sending participants to this training will:
- Predict sandstone reservoir quality before drilling
- Improve the evaluation of shaly sand reservoirs
- Identify porosity preservation mechanisms in deep targets
- Characterise heterogeneity at the scale that affects flow
- Specify petrographic and core analysis programmes effectively
- Reduce saturation and volume uncertainty in clastic reservoirs
Participants will:
- Relate sandstone texture and diagenesis to properties
- Predict reservoir quality with depth
- Recognise clay mineral effects on permeability and logs
- Evaluate shaly sands competently
- Characterise clastic heterogeneity
- Build defensible clastic reservoir descriptions
- Reservoir and development geologists working clastic reservoirs
- Petrophysicists evaluating sandstones
- Sedimentologists supporting reservoir studies
- Reservoir modellers working clastic fields
- Reservoir engineers requiring clastic reservoir understanding
- Exploration geologists assessing clastic reservoir risk
- Graduate geoscientists entering clastic asset teams
Module 1 - Sandstone Composition and Texture
- Framework grain composition
- Quartz, feldspar and lithic fragments
- Classification schemes for sandstones
- Grain size and its measurement
- Sorting and its effect on properties
- Grain shape and roundness
- Packing and fabric
- Detrital clay and matrix
- Textural controls on initial porosity
- Textural controls on permeability
- Provenance effects on composition
- Describing sandstone texture usefully
Module 2 - Depositional Systems and Architecture
- Fluvial sandstone reservoirs
- Deltaic sandstone reservoirs
- Shallow marine and shoreface reservoirs
- Deepwater turbidite reservoirs
- Aeolian sandstone reservoirs
- Tidal and estuarine reservoirs
- Reservoir geometry by environment
- Net to gross by environment
- Lateral and vertical continuity
- Barrier distribution and continuity
- Stacking patterns and connectivity
- Analogue dimensions by system
Module 3 - Compaction and Mechanical Processes
- Mechanical compaction and porosity loss
- Grain rearrangement and ductile deformation
- Compaction curves and their variation
- Lithic and ductile grain effects
- Grain contact dissolution
- Chemical compaction and its onset
- Stylolites and their formation
- Pressure solution and cement sourcing
- Overpressure effects on compaction
- Early cement and compaction inhibition
- Compaction prediction in exploration
Module 4 - Cementation and Reservoir Quality Prediction
- Quartz cementation mechanisms
- Temperature dependence of quartz cement
- Quartz cement volume prediction
- Carbonate cement types and distribution
- Early concretionary and nodular cement
- Feldspar dissolution and its products
- Secondary porosity and its preservation
- Grain coating porosity preservation
- Chlorite and microquartz coatings
- Coating distribution and facies control
- Burial history and thermal exposure
- Reservoir quality prediction workflows
Module 5 - Clay Minerals
- Detrital against authigenic clay
- Kaolinite occurrence and effects
- Illite occurrence and permeability damage
- Chlorite occurrence and effects
- Smectite and mixed layer clays
- Clay distribution: dispersed, laminated, structural
- Pore throat occlusion by clay
- Permeability damage by clay type
- Cation exchange capacity
- Clay effects on log response
- X-ray diffraction and clay identification
- Electron microscopy of clay habit
Module 6 - Heterogeneity Across Scales
- Scales of heterogeneity in sandstones
- Lamination and bedding scale
- Cross-bed set permeability variation
- Bedform and bed scale heterogeneity
- Bed boundary and shale drape effects
- Architectural element scale
- Baffles and barriers
- Field scale heterogeneity
- Deformation bands and cataclasis
- Fault related heterogeneity
- Which scale matters for which question
- Measuring heterogeneity
Module 7 - Petrophysical Evaluation
- Log suite for sandstone evaluation
- Lithology determination
- Porosity from density, neutron and sonic
- Clay volume determination methods
- Effective against total porosity
- Archie equation and its limitations
- Shaly sand models: Waxman-Smits, dual water, Indonesia
- Model selection and parameter derivation
- Saturation sensitivity to parameters
- Laminated sand evaluation
- Thin bed resolution and its limits
- Core calibration of log evaluation
Module 8 - Rock Typing and Integration
- Rock typing in sandstone reservoirs
- Texture and diagenesis as rock type controls
- Porosity permeability relationships by rock type
- Capillary pressure and saturation height functions
- Facies to rock type mapping in clastics
- Property prediction away from core
- Reservoir quality mapping
- Integration with the structural framework
- Input to reservoir modelling
- Dynamic validation of the characterisation
- Documenting the characterisation
- Reviewing a clastic reservoir study critically
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.
