An Interactive 5-Day Training Course
Mineralogy & Petrology for Petroleum Geologists
Minerals, Rocks and Reservoir Quality
Secure your spot now!
Duration
5 Days
Price
$ 3,000
Starting From
11 Jan 2027
Home Geology and Geoscience Mineralogy & Petrology for Petroleum Geologists
Mineralogy & Petrology for Petroleum Geologists
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Mineralogy & Petrology for Petroleum Geologists - GG-MIN-PEA27
| Code | Date | Time | Duration | Location | Currency | Early Bird Fee Per Person |
|---|---|---|---|---|---|---|
| GG-MIN-PEA27 | 11 - 15 Jan 2027 | 10 AM CST | 4 Hours Per Day |
Online |
USD |
3000 |
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Mineralogy & Petrology for Petroleum Geologists
Description
Two sandstones with identical grain size and sorting can have permeabilities that differ by three orders of magnitude, and the difference is mineralogical. Quartz cement filling pore throats, authigenic illite growing as fibres across them, kaolinite booklets sitting in pores, or chlorite coating grains and preventing quartz overgrowth, each produces a different outcome from the same starting sand. Understanding that chain, from depositional mineralogy through burial history to present reservoir quality, is what allows reservoir quality to be predicted rather than only measured.
This training covers that chain. Mineralogy is developed first, covering the silicates, carbonates, evaporites and oxides that make up reservoir and seal rocks, with particular attention to clay minerals because they dominate reservoir quality, petrophysical response and completion problems. Clastic petrography follows: framework composition, provenance, texture, classification and the interpretation of depositional and burial history from thin section. Carbonate petrology is then covered with its distinctive classification schemes, grain types, porosity systems and diagenetic pathways. Diagenesis is developed in full across compaction, cementation, dissolution, replacement and fracturing. Analytical methods are then covered, and the training closes with the application of mineralogy to reservoir quality prediction, petrophysical interpretation, drilling fluid selection, formation damage and stimulation design.
Clay minerals are the practical core of the subject. Kaolinite occupies pore space but leaves pore throats relatively open; illite grows as delicate fibres that block throats and destroy permeability at low volume fractions; smectite swells on contact with fresh water and can shut a formation down; chlorite coats grains and, by preventing quartz overgrowth, preserves porosity to depths where it would otherwise be lost. Each has a different effect on permeability, on log response, on drilling fluid compatibility and on acid treatment. A rock described only as containing ten percent clay conveys almost none of this.
Diagenetic history explains why porosity-depth relationships fail. Porosity generally declines with burial depth as compaction and cementation proceed, and a regional trend line can be fitted. Individual reservoirs scatter widely around it because their diagenetic histories differed: early hydrocarbon charge that halted cementation, chlorite coats that inhibited quartz overgrowth, overpressure that reduced effective stress and slowed compaction, or secondary dissolution that created porosity after the fact. Predicting reservoir quality ahead of the drill bit requires reasoning about these processes rather than reading a trend.
Mineralogy also governs how a rock responds to everything done to it. Water-sensitive clays dictate drilling and completion fluid selection. Carbonate content determines acid response. Clay and feldspar content determines whether mud acid will precipitate silica gel. Brittleness, which controls hydraulic fracture behaviour, correlates with quartz and carbonate content against clay content. Treating a formation without knowing its mineralogy means guessing at all of these.
Finally, petrophysical interpretation rests on mineral assumptions. Matrix density, photoelectric factor, neutron response and the shale models used in saturation calculation all depend on what minerals are present and in what form. A log suite interpreted with an assumed quartz matrix in a formation containing significant feldspar, carbonate or heavy minerals produces porosity and saturation values that are systematically wrong.
By the end of this training, participants will be able to:
- Identify the principal rock-forming minerals and describe their properties and occurrence
- Distinguish clay mineral types and explain their differing effects on reservoir quality and behaviour
- Classify and describe sandstones from thin section including framework composition and texture
- Interpret provenance and depositional history from clastic petrography
- Classify and describe carbonates using recognised schemes and identify grain and porosity types
- Analyse diagenetic sequences and reconstruct burial history from petrographic evidence
- Explain the controls on porosity and permeability preservation and destruction
- Select appropriate analytical methods and interpret thin section, XRD, SEM and related outputs
- Predict reservoir quality from mineralogical and diagenetic reasoning
- Apply mineralogical understanding to petrophysical interpretation, fluid selection and stimulation design
Organisations sending participants to this training will:
- Improve reservoir quality prediction ahead of drilling and in undrilled areas
- Reduce formation damage through better drilling and completion fluid selection
- Improve stimulation design and reduce failed or counterproductive treatments
- Improve petrophysical interpretation through correct mineral assumptions
- Specify core analysis programmes that answer the questions asked of them
- Strengthen the geological basis of reservoir quality distributions in static models
Participants will:
- Describe and classify reservoir rocks from thin section with confidence
- Explain why a given reservoir has the quality it has
- Predict reservoir quality from mineralogical and diagenetic reasoning
- Specify and interpret analytical programmes
- Advise on fluid selection and stimulation from mineralogical evidence
- Build a specialist capability that distinguishes a petroleum geologist technically
- Petroleum geologists and reservoir geologists
- Petrophysicists requiring stronger mineralogical grounding
- Reservoir engineers working on reservoir quality and rock typing
- Production and completion engineers dealing with formation damage and stimulation
- Laboratory and core analysis staff
- Geoscientists working on static modelling and reservoir characterisation
- Graduate geoscientists entering the oil and gas industry
Module 1 - Mineralogy Fundamentals
- Crystal structure, symmetry and mineral classification
- Physical properties used in identification
- Optical properties and their use in petrography
- Silicate structures and the major silicate groups
- Quartz: varieties, occurrence and behaviour
- Feldspars: composition, alteration and significance
- Micas and their effects on reservoir properties
- Carbonate minerals: calcite, dolomite, siderite, ankerite
- Evaporite minerals and their occurrence
- Oxides, sulphides and heavy minerals
- Accessory minerals and their diagnostic value
Module 2 - Clay Mineralogy
- Clay mineral structure: layer types and interlayer behaviour
- Kaolinite: morphology, occurrence and reservoir effect
- Illite: fibrous habit and its disproportionate permeability damage
- Smectite: swelling behaviour and water sensitivity
- Chlorite: grain coating and porosity preservation
- Mixed layer clays and their significance
- Detrital against authigenic clay distribution
- Clay transformation with burial and temperature
- Cation exchange capacity and its measurement
- Clay effects on log response and saturation calculation
- Clay effects on drilling fluid and completion fluid compatibility
- Clay effects on acid treatment and stimulation
Module 3 - Clastic Petrography
- Framework grains, matrix and cement
- Grain size, sorting, roundness and sphericity
- Textural maturity and its interpretation
- Sandstone classification schemes
- Quartz arenites, arkoses and lithic arenites
- Provenance interpretation from framework composition
- Grain contacts and compaction indicators
- Point counting and modal analysis
- Porosity types in thin section: primary, secondary, microporosity
- Pore geometry and pore throat characterisation
- Thin section description workflow and reporting
Module 4 - Carbonate Petrology
- Carbonate production and depositional settings
- Carbonate grain types: ooids, peloids, bioclasts, intraclasts
- Micrite, sparite and matrix classification
- Dunham classification and its application
- Folk classification and its application
- Carbonate porosity classification schemes
- Intergranular, intragranular, mouldic, vuggy and fracture porosity
- Dolomitisation: mechanisms and porosity consequences
- Karst development and its reservoir significance
- Carbonate diagenetic environments: marine, meteoric, burial
- Carbonate reservoir quality controls and their prediction
- Chalk and other fine-grained carbonate reservoirs
Module 5 - Diagenesis
- Diagenetic realms: eogenesis, mesogenesis, telogenesis
- Mechanical compaction and grain rearrangement
- Chemical compaction and pressure solution
- Quartz cementation: controls, timing and temperature dependence
- Carbonate cementation and its sources
- Clay authigenesis and its distribution
- Feldspar dissolution and secondary porosity
- Replacement textures and their interpretation
- Fracture formation, cementation and reopening
- Paragenetic sequence construction from textural relationships
- Burial history and its reconstruction
- Timing of hydrocarbon charge relative to diagenesis
Module 6 - Reservoir Quality Controls and Prediction
- Depositional control on initial reservoir quality
- Porosity-depth trends and their scatter
- Chlorite coating and anomalous porosity preservation
- Overpressure and its effect on compaction
- Early hydrocarbon charge and cementation inhibition
- Grain size and sorting effects on permeability
- Pore throat size distribution and its measurement
- Permeability prediction from petrographic data
- Rock typing from mineralogy and pore geometry
- Reservoir quality mapping and prediction in undrilled areas
- Reconciling petrographic prediction with core measurement
Module 7 - Analytical Methods
- Sample selection, preparation and thin section production
- Optical petrography: transmitted and reflected light
- Cathodoluminescence and its applications
- Scanning electron microscopy and backscatter imaging
- Energy dispersive spectroscopy for mineral identification
- X-ray diffraction: bulk and clay fraction analysis
- Interpreting XRD traces and quantification limitations
- QEMSCAN and automated mineralogy
- Fluid inclusion analysis and its temperature information
- Stable isotope analysis and cement origin
- Mercury injection capillary pressure and pore throat data
- Designing an analytical programme against the question asked
Module 8 - Applications
- Mineralogical input to petrophysical interpretation
- Matrix density, photoelectric factor and log response
- Shale model selection from clay mineralogy
- Formation damage mechanisms and their mineralogical basis
- Drilling fluid selection for water-sensitive formations
- Completion and workover fluid compatibility
- Acid selection and precipitation risk in sandstone acidising
- Carbonate acidising and mineralogical response
- Brittleness, mineralogy and hydraulic fracture behaviour
- Mineralogy in unconventional reservoir evaluation
- Scale prediction from formation mineralogy and water chemistry
- Communicating mineralogical findings to engineers
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.
