The Reservoir Rock Typing Training Course by Institute For Oil & Gas Training develops the technical capabilities required to classify reservoir rocks, evaluate pore structures, and establish reliable relationships between geological characteristics and fluid flow behaviour. This specialist programme within the Oil & Gas Coring and Core Analysis category equips professionals with practical Rock Typing methods that support reservoir characterisation, permeability modelling, petrophysical interpretation, and field development decisions.
Reservoir rock typing is a fundamental component of integrated reservoir evaluation. Oil and gas reservoirs contain complex combinations of pore geometries, grain sizes, mineral compositions, cementation patterns, depositional textures, and diagenetic alterations. These characteristics influence porosity, permeability, capillary pressure, fluid distribution, and the movement of hydrocarbons through the reservoir. A consistent rock typing methodology provides a structured way to group reservoir intervals according to their geological attributes and flow characteristics, helping technical teams interpret reservoir heterogeneity and predict performance more effectively.
For organisations operating in the oil and gas sector, understanding reservoir quality is essential for making informed decisions about exploration, appraisal, development, production optimisation, and recovery planning. Conventional geological descriptions alone do not always explain variations in fluid flow. Two core samples with comparable porosity can demonstrate substantially different permeability because their pore networks and pore throat distribution differ. Rock Typing bridges this gap by integrating geological observations, core analysis measurements, petrophysical data, and reservoir engineering requirements.
The Institute For Oil & Gas Training programme examines the relationship between depositional facies, diagenetic processes, pore geometry, hydraulic flow units, and reservoir performance. Participants develop an understanding of how facies classification supports geological interpretation and how petrophysical and core-derived data establish meaningful rock types. The course also explores the application of routine core analysis, special core analysis, porosity-permeability relationships, capillary pressure measurements, and flow zone indicators to reservoir classification.
A central focus is the identification of hydraulic flow units that exhibit comparable flow characteristics. These units provide a practical basis for distinguishing intervals with different capacities to transmit fluids, supporting the construction of more representative permeability models. Participants examine the strengths and limitations of different rock typing approaches and learn to select methods that suit the available data, geological setting, and intended engineering application.
The course addresses a common operational challenge: inconsistent reservoir classification across geology, petrophysics, core analysis, and reservoir engineering teams. When disciplines use different classification criteria, the resulting reservoir models can contain inconsistent property distributions, uncertain flow predictions, and avoidable interpretation differences. A shared rock typing framework improves technical communication and establishes a more consistent basis for integrating geological and engineering evidence.
Participants also explore how rock typing supports reservoir simulation, static model construction, well correlation, permeability estimation, and the interpretation of production performance. The programme connects laboratory observations with field-scale applications, helping professionals understand how representative rock types influence reservoir property assignment and uncertainty assessment.
Delivered by Institute For Oil & Gas Training, the Reservoir Rock Typing Training Course is designed for professionals who require a practical understanding of core-based reservoir classification and its contribution to asset performance. The programme combines established industry methods with applied interpretation exercises, enabling participants to strengthen technical judgement and produce more defensible reservoir characterisation outputs.
Explain the principles of Rock Typing and its role in integrated reservoir characterisation.
Evaluate the influence of depositional facies, lithology, mineralogy, and diagenesis on reservoir quality.
Interpret routine core analysis data to identify variations in porosity, permeability, and pore structure.
Explain how pore throat distribution affects capillary pressure, fluid saturation, and permeability behaviour.
Apply appropriate classification concepts to distinguish geological rock types from hydraulic flow units.
Assess the suitability of different rock typing methods for clastic and carbonate reservoir systems.
Integrate facies classification with petrophysical measurements and core-derived evidence.
Evaluate porosity-permeability relationships within individual rock types.
Interpret relevant flow zone indicators and assess their contribution to hydraulic flow unit identification.
Understand the contribution of capillary pressure data and special core analysis to rock type definition.
Assess the impact of rock type classification on permeability modelling and reservoir property assignment.
Identify data quality limitations, outliers, and uncertainties affecting rock typing decisions.
Improve collaboration between geology, petrophysics, core analysis, and reservoir engineering teams.
Communicate rock typing interpretations through clear technical documentation and evidence-based recommendations.
Apply consistent classification principles to support reservoir modelling, development planning, and production optimisation.
Institute For Oil & Gas Training uses an applied, industry-oriented training methodology that connects reservoir geology, petrophysics, core analysis, and reservoir engineering. The delivery approach focuses on practical interpretation, technical reasoning, and the application of rock typing concepts to operational decisions rather than relying solely on theoretical explanations.
Structured technical presentations introduce the principles of Rock Typing, reservoir heterogeneity, pore system characterisation, and flow behaviour. Participants examine the relationship between depositional environments, lithology, diagenesis, porosity, permeability, and pore throat distribution. The sessions establish a common technical foundation for evaluating rock types and interpreting their significance within reservoir studies.
Industry-based case studies demonstrate how routine and special core analysis data support rock classification. Participants examine porosity, permeability, grain density, capillary pressure, and other relevant measurements to identify patterns in reservoir quality. The exercises emphasise data consistency, sample representativeness, and the interpretation of differences between geological appearance and measured flow properties.
Practical exercises introduce methods for identifying hydraulic flow units using appropriate combinations of porosity, permeability, and pore structure indicators. Participants assess how flow units differ from purely lithological or depositional classifications and explore their use in reservoir property modelling. The exercises also address the limitations of applying a single classification method to heterogeneous reservoir systems.
Participants work through representative geological datasets to understand how facies classification contributes to rock typing. The exercises consider depositional texture, grain sorting, mineral composition, cementation, and diagenetic overprinting. They examine how geological observations complement core measurements and how geological boundaries relate to hydraulic behaviour.
Workshop activities focus on establishing meaningful relationships between porosity, permeability, and rock type. Participants evaluate data groupings, review potential outliers, and consider how rock type definitions influence permeability estimation. The exercises illustrate the importance of selecting suitable correlations and documenting assumptions before incorporating rock typing results into reservoir models.
Real-world scenarios connect core analysis results with petrophysical interpretation, static reservoir modelling, and development planning. Participants consider the consequences of assigning inappropriate rock types to reservoir intervals and evaluate how improved classification supports well correlation, uncertainty analysis, and reservoir simulation inputs.
Group exercises encourage participants to compare interpretations, challenge assumptions, and communicate technical findings across disciplines. This approach reflects the collaborative nature of reservoir evaluation, where geologists, petrophysicists, core analysts, and reservoir engineers must reconcile different datasets before agreeing on a representative reservoir model.
Learning is reinforced through practical questions, interpretation tasks, group discussions, and instructor feedback. Participants review their reasoning, identify gaps in data interpretation, and strengthen their ability to justify rock typing decisions using geological and petrophysical evidence. The emphasis remains on practical competence and the transfer of learning to workplace responsibilities.
Consistent Rock Typing gives asset teams a more structured basis for describing reservoir heterogeneity and distinguishing intervals with different flow characteristics. Integrating geological observations with core analysis and petrophysical measurements improves the consistency of reservoir property interpretation. This supports more reliable geological models and more transparent technical decisions during field appraisal and development.
The identification of hydraulic flow units helps organisations establish more meaningful relationships between porosity and permeability. Rather than applying a single correlation across an entire reservoir, technical teams can evaluate property relationships within appropriate rock type groups. This supports better-founded permeability assignments and helps reduce errors associated with oversimplified reservoir property distributions.
A shared classification methodology improves collaboration between geology, petrophysics, core analysis laboratories, and reservoir engineering. Teams gain a common framework for discussing facies, pore structure, hydraulic behaviour, and reservoir quality. This reduces interpretation inconsistencies, improves technical review processes, and makes the reasoning behind modelling decisions easier to communicate and audit.
Core acquisition and laboratory testing generate valuable information about reservoir properties. A structured rock typing approach helps organisations extract greater interpretive value from existing datasets by connecting laboratory measurements to geological and engineering applications. It also supports better identification of data gaps and helps technical teams prioritise additional analysis where uncertainty materially affects decisions.
Rock typing contributes to the evaluation of reservoir continuity, permeability distribution, and fluid movement. Improved classification supports well placement studies, completion planning, reservoir simulation, and the assessment of production performance. Although rock typing does not independently determine development outcomes, it provides a stronger technical foundation for comparing development scenarios and evaluating reservoir behaviour.
Documented classification criteria, consistent data preparation, and clear interpretation assumptions strengthen internal quality assurance. Organisations can review how rock types were established, which datasets informed the classification, and how uncertainties affect the resulting reservoir model. This improves reproducibility across projects and supports more effective peer review.
A clearer understanding of reservoir heterogeneity helps teams identify intervals requiring additional investigation and distinguish between geological complexity and measurement limitations. This improves the focus of laboratory analysis, interpretation reviews, and model updates. The resulting workflow supports more disciplined allocation of technical resources without assuming that every reservoir interval requires the same level of investigation.
Participants develop a structured understanding of how geological characteristics and pore-scale properties influence reservoir behaviour. They become better equipped to interpret core analysis measurements, recognise variations in reservoir quality, and distinguish between lithological similarity and comparable hydraulic performance.
The course strengthens participants' ability to assess different classification approaches and understand when geological, petrophysical, or flow-based methods are appropriate. They gain a clearer understanding of the assumptions behind hydraulic flow units, pore throat distribution analysis, and permeability relationships.
Professionals improve their ability to explain rock typing decisions to colleagues in geology, petrophysics, reservoir engineering, and asset management. They learn to support interpretations with relevant evidence, document limitations, and communicate the implications of classification choices for reservoir models.
Participants develop a more systematic approach to reviewing rock type definitions, evaluating data quality, and challenging unsupported assumptions. This strengthens their contribution to reservoir studies, peer reviews, technical assurance meetings, and integrated asset planning.
The programme supports capability development for professionals involved in core analysis, reservoir characterisation, petrophysical evaluation, and subsurface modelling. Participants gain practical knowledge relevant to expanded technical responsibilities, multidisciplinary projects, and progression into specialist or supervisory roles.
Participants strengthen their approach to technical documentation, evidence-based decision-making, uncertainty assessment, and collaborative problem-solving. These capabilities support the preparation of more transparent interpretations and more consistent technical recommendations across reservoir evaluation projects.
Reservoir Geologists: To connect depositional facies, diagenesis, and geological heterogeneity with reservoir flow characteristics.
Petrophysicists: To integrate core-derived rock types with log interpretation, porosity-permeability relationships, and reservoir property evaluation.
Reservoir Engineers: To improve the geological basis of permeability assignment, reservoir simulation, and production performance analysis.
Core Analysis Specialists: To interpret laboratory measurements in the context of pore structure, hydraulic flow units, and reservoir quality.
Geoscientists: To strengthen the integration of geological observations with petrophysical and engineering evidence.
Subsurface Modelling Specialists: To establish more consistent rock type definitions for static models and reservoir property distribution.
Petroleum Engineers: To understand how rock typing influences reservoir evaluation, development planning, and production optimisation.
Formation Evaluation Specialists: To connect core measurements with log-derived properties and identify differences between measured and interpreted reservoir characteristics.
Reservoir Characterisation Consultants: To improve the technical consistency and defensibility of reservoir classification studies.
Laboratory Managers and Technical Supervisors: To improve the application, review, and communication of core analysis results.
Subsurface Team Leaders: To strengthen technical integration and quality assurance across reservoir evaluation disciplines.
Exploration and Appraisal Professionals: To assess reservoir heterogeneity and improve the interpretation of core data during prospect evaluation and appraisal planning.
Asset Development and Planning Professionals: To understand the implications of reservoir rock classification for development scenarios and model-based decisions.
Early-Career Subsurface Professionals: To build a practical foundation in rock typing and its applications across integrated oil and gas projects.
This module establishes the principles of Rock Typing and its role in integrated reservoir characterisation. Participants examine how lithology, depositional texture, mineral composition, diagenesis, and pore structure influence reservoir quality. The module distinguishes geological rock types from classifications based on petrophysical properties and fluid flow behaviour.
Participants explore how facies classification provides a geological framework for understanding reservoir heterogeneity. The module also considers the relationship between depositional facies, diagenetic overprinting, porosity development, and permeability variation. Emphasis is placed on developing consistent classification criteria that support communication between geological and engineering disciplines.
API Recommended Practice 40, Recommended Practices for Core Analysis, provides established industry guidance for core analysis procedures and the interpretation of core-derived measurements.
It supports understanding of core sample preparation, measurement quality, and the limitations of laboratory data used in reservoir characterisation.
Participants examine how reliable core measurements contribute to defensible rock type definitions and geological interpretation.
Explain the purpose and practical applications of Rock Typing.
Distinguish geological classification from petrophysical and flow-based classification.
Assess the influence of depositional facies and diagenesis on reservoir quality.
Identify relevant geological and laboratory data for rock type definition.
Establish the importance of consistent classification criteria across subsurface disciplines.
This module examines how routine and special core analysis contribute to rock type identification. Participants review porosity, permeability, grain density, pore geometry, and capillary pressure data to understand variations in reservoir quality. They assess why samples with similar porosity values exhibit different permeability characteristics and how pore connectivity influences fluid movement.
The module places particular emphasis on pore throat distribution and its relationship with capillary pressure behaviour and effective fluid pathways. Participants explore the value and limitations of different measurements, including mercury injection capillary pressure and other appropriate pore structure characterisation methods. The focus is on interpreting the evidence without treating individual measurements as sufficient to define every reservoir rock type.
ASTM D4404, Standard Test Method for Determination of Pore Volume and Pore Volume Distribution of Soil and Rock by Mercury Intrusion Porosimetry, addresses the measurement of pore volume and pore size distribution using mercury intrusion.
The method provides a basis for examining pore structure characteristics relevant to reservoir rock evaluation.
Participants consider the interpretation limits of mercury intrusion data and its relationship with other core analysis measurements.
Interpret routine core analysis measurements relevant to rock typing.
Explain the relationship between porosity, permeability, and pore connectivity.
Evaluate how pore throat distribution influences capillary pressure behaviour.
Assess the contribution of special core analysis to reservoir classification.
Identify measurement limitations and data quality issues affecting reservoir quality assessment.
This module focuses on identifying hydraulic flow units and understanding their significance in reservoir characterisation. Participants examine how porosity, permeability, pore geometry, and pore connectivity influence the capacity of reservoir rocks to transmit fluids. They explore the distinction between depositional facies and hydraulic flow units, recognising that geological boundaries and flow boundaries do not always coincide.
The module introduces flow-based classification concepts and the interpretation of relevant flow zone indicators. Participants examine how rock type groups can be established from suitable core-derived data and how these groups support the interpretation of heterogeneous reservoir intervals. Attention is given to selecting appropriate classification methods, validating interpretations, and documenting the evidence supporting each hydraulic unit.
The Society of Petroleum Engineers Petroleum Resources Management System provides a recognised framework for classifying and evaluating petroleum resources.
It emphasises consistent technical evaluation and the use of appropriate geological and engineering information in resource assessment.
Participants consider how defensible reservoir characterisation supports the technical evidence used in integrated asset evaluation. The framework does not prescribe a universal rock typing methodology.
Explain the principles of hydraulic flow unit identification.
Evaluate the relationship between porosity, permeability, and pore structure.
Distinguish geological facies boundaries from hydraulic flow boundaries.
Interpret appropriate flow zone indicators and assess their limitations.
Establish evidence-based criteria for grouping reservoir intervals into hydraulic flow units.
Explain how hydraulic classification contributes to reservoir characterisation and development studies
This module examines how Rock Typing supports permeability modelling and the assignment of reservoir properties. Participants explore the relationship between rock type definitions and porosity-permeability correlations, including the implications of applying a single correlation to intervals with different pore structures. The module explains how classification improves the interpretation of property variation while retaining the need for suitable data and geological validation.
Participants review methods for grouping core measurements, assessing correlation quality, identifying anomalous data points, and evaluating the representativeness of available samples. They examine how rock type definitions influence property distribution in static reservoir models and the inputs used for dynamic simulation. The module also addresses uncertainty, sensitivity analysis, and the importance of documenting assumptions when extrapolating core-derived properties beyond measured intervals.
ISO 31000, Risk Management Guidelines, provides principles and guidance for identifying, analysing, evaluating, and managing risk.
Its risk-based approach supports structured consideration of uncertainty in technical decisions and modelling assumptions.
Participants examine how uncertainty in rock type classification and permeability estimation influences model confidence and reservoir development decisions. The standard does not prescribe a specific permeability modelling technique.
Explain the relationship between rock types and permeability modelling.
Evaluate porosity-permeability correlations within defined rock type groups.
Identify data quality issues and outliers affecting permeability estimates.
Assess the suitability of core-derived properties for reservoir-scale application.
Explain how rock typing influences static reservoir models and simulation inputs.
Evaluate uncertainty associated with classification and property distribution.
Document modelling assumptions and identify areas requiring further investigation.
This module integrates geological classification, core analysis, hydraulic flow units, and permeability modelling into a practical reservoir evaluation workflow. Participants examine how rock typing results support well correlation, reservoir model construction, development planning, and the interpretation of production performance. The module emphasises the importance of integrating geological observations with petrophysical measurements and engineering requirements.
Participants work through applied scenarios involving inconsistent rock type definitions, variable core data quality, and uncertainty in reservoir property assignment. They review classification workflows, assess the implications of alternative interpretations, and develop recommendations for improving technical consistency. The module concludes with an integrated evaluation exercise focused on documenting rock typing decisions and communicating their implications to multidisciplinary teams.
ISO 9001, Quality Management Systems Requirements, establishes requirements for quality management systems and consistent process control.
Its principles support documented workflows, controlled information, evidence-based evaluation, and continual improvement.
Participants consider how quality management practices strengthen the reproducibility and review of rock typing workflows. ISO 9001 does not define technical reservoir classification criteria.
Integrate geological, petrophysical, and core analysis evidence into a rock typing workflow.
Evaluate how rock type definitions influence reservoir modelling and development decisions.
Identify inconsistencies between geological classification and measured flow behaviour.
Develop practical recommendations for improving rock typing data quality and consistency.
Document classification assumptions, limitations, and uncertainties.
Communicate rock typing results effectively across multidisciplinary subsurface teams.
Apply course principles to representative reservoir evaluation scenarios.
Participants who successfully complete the Reservoir Rock Typing Training Course receive a Certificate of Completion from Institute For Oil & Gas Training.
The certificate recognises completion of the training programme and participation in its technical learning activities. Attendees are required to meet the course attendance requirement established by Institute For Oil & Gas Training to qualify for the certificate. Participants should confirm the applicable attendance threshold with the institute before the programme begins.
Fees include tuition, course materials and refreshments. Need different dates or a different city? Ask about your preferred date.
Rock Typing is the process of classifying reservoir rocks into groups with similar geological, petrophysical, or flow characteristics. It helps subsurface professionals understand reservoir heterogeneity, interpret core analysis data, identify hydraulic flow units, and establish more representative reservoir property models.
The course is suitable for reservoir geologists, petrophysicists, reservoir engineers, core analysis specialists, geoscientists, subsurface modelling professionals, and technical supervisors. It is particularly relevant to professionals who use core data and petrophysical measurements to evaluate reservoir quality and fluid flow behaviour.
The programme covers geological facies classification, routine and special core analysis, pore throat distribution, reservoir quality assessment, hydraulic flow units, permeability modelling, uncertainty evaluation, and integrated reservoir characterisation. Participants also examine how rock typing supports static reservoir models and development planning.
Institute For Oil & Gas Training delivers the programme through technical presentations, industry-based case studies, core analysis interpretation exercises, group discussions, and applied reservoir scenarios. These methods connect rock typing principles with practical subsurface evaluation tasks and encourage evidence-based technical decision-making.
The total course duration is 15 to 20 hours. Participants who successfully complete the programme and meet the applicable attendance requirement receive a Certificate of Completion from Institute For Oil & Gas Training. Participants should confirm the attendance threshold with the institute before the course begins.
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