The Integrated Petrophysics for Reservoir Characterization Training Course by Institute For Oil & Gas Training develops the technical capabilities required to integrate geological, petrophysical and core analysis data into reliable reservoir characterisation workflows. Designed for professionals operating across exploration, field development and production environments, this course strengthens the interpretation of complex reservoir properties, improves rock typing and facies analysis, and supports more accurate reservoir modelling and permeability prediction.
Reliable reservoir characterisation is fundamental to understanding subsurface uncertainty, evaluating hydrocarbon potential and making commercially sound field development decisions. Oil and gas organisations depend on accurate interpretations of porosity, permeability, lithology, fluid saturation, pore structure and depositional characteristics to assess reservoir quality and establish realistic production expectations. However, interpreting individual datasets in isolation creates inconsistencies between geological models, petrophysical evaluations and laboratory measurements. These inconsistencies affect volumetric estimates, well placement, completion strategies and production forecasting.
Integrated petrophysics addresses this challenge by bringing together open-hole well logs, conventional core analysis, special core analysis, geological descriptions, sedimentological interpretations and formation evaluation results. It establishes a consistent technical foundation for understanding reservoir heterogeneity and identifying the relationships between depositional facies, pore geometry and petrophysical behaviour.
The course examines the practical application of core data integration, rock typing, facies analysis and quantitative petrophysical interpretation. Participants explore how laboratory measurements support the calibration of wireline and logging-while-drilling data, how different reservoir rock types influence permeability prediction, and how integrated interpretations contribute to static and dynamic reservoir modelling. Particular attention is given to understanding the limitations of individual measurement techniques and recognising the uncertainties associated with heterogeneous formations.
A key focus is the relationship between geological characteristics and measurable reservoir properties. Lithology, grain size, sorting, cementation, pore connectivity and diagenetic alteration influence the distribution of porosity and permeability. Understanding these relationships enables technical teams to distinguish between reservoir intervals with similar porosity but significantly different flow characteristics. It also improves the identification of productive intervals, non-reservoir facies, baffles and potential flow barriers.
The programme addresses the increasing importance of multidisciplinary subsurface integration. Geologists, petrophysicists, reservoir engineers and core analysis specialists frequently work with different datasets, software platforms and interpretation assumptions. An integrated approach improves technical communication, strengthens data consistency and establishes a more dependable basis for reservoir management decisions.
Delivered by Institute For Oil & Gas Training, this professional development programme combines established petrophysical principles with practical oil and gas applications. It is particularly relevant to organisations managing complex clastic and carbonate reservoirs, mature producing assets, unconventional formations and fields requiring improved subsurface understanding.
With a total course duration of 15–20 hours, the programme provides a structured understanding of integrated reservoir characterisation, from core and log quality assessment to rock classification, permeability estimation and model-ready data interpretation. Participants develop the ability to evaluate reservoir quality systematically and communicate integrated findings that support exploration, appraisal, development and production optimisation.
Explain the principles and business importance of integrated petrophysical reservoir characterisation.
Evaluate conventional core analysis and special core analysis data for reservoir quality assessment.
Interpret porosity, permeability, water saturation and lithological measurements in relation to reservoir performance.
Integrate geological descriptions, sedimentological observations, laboratory measurements and well log responses.
Apply rock typing approaches to distinguish reservoir units with different petrophysical and flow characteristics.
Conduct facies analysis using geological, sedimentological and petrophysical indicators.
Evaluate the relationships between pore structure, depositional characteristics, diagenesis and reservoir quality.
Assess the reliability and limitations of conventional core measurements and wireline log interpretations.
Apply core data integration techniques to calibrate and improve petrophysical interpretations.
Evaluate permeability prediction methods using core measurements, porosity relationships and rock classification.
Identify reservoir heterogeneity, flow barriers, baffles and variations in reservoir connectivity.
Interpret saturation and pore system characteristics in clastic and carbonate reservoirs.
Prepare consistent petrophysical inputs for static and dynamic reservoir modelling.
Recognise uncertainties in reservoir characterisation and evaluate their implications for development decisions.
Communicate integrated reservoir evaluation findings effectively across multidisciplinary subsurface teams.
Institute For Oil & Gas Training applies an industry-focused training methodology that combines technical presentations, practical interpretation exercises, case studies, collaborative discussions and realistic subsurface scenarios. The approach connects petrophysical concepts with the operational requirements of exploration and production organisations.
The methodology emphasises the interpretation and integration of actual types of subsurface datasets rather than treating core analysis, geological interpretation and well logging as separate technical disciplines. Participants examine how different measurements contribute to reservoir understanding and how inconsistencies between datasets influence technical conclusions.
Structured technical presentations establish the principles of reservoir petrophysics, core analysis, rock typing and quantitative formation evaluation. Participants examine the physical relationships between porosity, permeability, saturation, lithology and pore structure. The sessions also explain the limitations of commonly applied interpretation methods and the importance of selecting appropriate evaluation techniques for different reservoir conditions.
Practical exercises demonstrate how conventional core measurements and well log responses contribute to formation evaluation. Participants examine core porosity, permeability measurements, density logs, neutron logs, sonic responses, gamma ray measurements and resistivity data. They investigate the relationship between laboratory measurements and continuous well log interpretations and identify the factors responsible for differences between measured and interpreted properties.
Case studies demonstrate how geological descriptions, depositional environments and petrophysical properties contribute to reservoir classification. Participants explore the identification of electrofacies, sedimentological facies and hydraulic flow units. They examine how rock typing improves the understanding of reservoir heterogeneity and supports the distribution of representative petrophysical properties throughout reservoir intervals.
Collaborative exercises encourage participants to evaluate datasets from different technical perspectives. Geological, petrophysical and engineering interpretations are compared to establish consistent reservoir descriptions. Participants discuss data quality, interpretation assumptions, permeability prediction and the consequences of uncertainty in reservoir modelling.
Realistic scenarios demonstrate the application of integrated petrophysics to exploration prospects, appraisal wells, producing fields and mature reservoirs. Participants examine situations involving variable lithology, complex pore systems, incomplete core coverage, uncertain permeability relationships and inconsistent log interpretations. These exercises develop a practical approach to resolving interpretation challenges and communicating technical findings.
Facilitated discussions encourage participants to evaluate different approaches to reservoir characterisation and identify appropriate techniques for specific geological settings. The methodology reinforces the importance of data validation, measurement consistency, multidisciplinary collaboration and transparent interpretation assumptions.
Organisations operating in the oil and gas sector require dependable subsurface interpretations to support investment decisions, improve field performance and manage reservoir uncertainty. The Integrated Petrophysics for Reservoir Characterization Training Course strengthens the technical processes that connect geological understanding, laboratory measurements and engineering applications.
The integration of core measurements and well log interpretations establishes a stronger basis for assessing reservoir quality. Organisations gain improved consistency in evaluating porosity, permeability, saturation and lithological variations. This supports more reliable identification of productive intervals and reduces dependence on interpretations based on isolated datasets.
Effective rock typing provides a structured approach to distinguishing reservoir units according to their geological and petrophysical characteristics. Improved classification supports the identification of hydraulic flow units, reservoir quality variations and internal heterogeneity. This strengthens communication between geological and engineering teams and improves consistency in subsurface evaluations.
Integrated petrophysical interpretations provide more representative property distributions for static and dynamic reservoir models. Organisations benefit from improved relationships between geological facies, porosity, permeability and saturation. More consistent model inputs support reservoir simulation, development planning and production forecasting.
Permeability prediction remains challenging where core coverage is limited or reservoir properties vary significantly across formations. Understanding the relationship between rock type, pore structure and measured core permeability improves the selection and calibration of prediction methods. This strengthens the technical basis for estimating flow capacity across uncored intervals.
Inconsistent datasets and poorly documented interpretation assumptions introduce uncertainty into reservoir evaluation. The programme strengthens the ability of technical teams to identify data limitations, assess measurement quality and reconcile differences between laboratory and log-derived properties. Better interpretation practices improve the transparency and defensibility of subsurface decisions.
Integrated reservoir characterisation requires cooperation between geologists, petrophysicists, reservoir engineers and laboratory specialists. A shared understanding of rock classification, core measurements and petrophysical interpretation improves technical discussions and reduces communication gaps between departments.
A consistent approach to data validation, core data integration and reservoir classification supports more efficient interpretation workflows. Technical teams gain a clearer understanding of the datasets required for different evaluation tasks, reducing unnecessary repetition and improving the organisation of subsurface information.
Improved reservoir understanding supports decisions relating to well placement, completion selection, development strategies and reservoir management. Organisations benefit from a more reliable technical foundation for evaluating reservoir compartments, identifying productive zones and understanding the distribution of reservoir properties.
The course develops practical technical capabilities that strengthen participants' contributions to exploration, development and production activities. Attendees gain a broader understanding of the relationships between geology, petrophysics and reservoir engineering.
Participants strengthen their understanding of quantitative petrophysical evaluation and the interpretation of core and well log measurements. They develop a more systematic approach to evaluating reservoir quality and understanding the limitations of individual measurement techniques.
Attendees improve their ability to connect depositional characteristics, lithology, facies and diagenetic features with measurable reservoir properties. This capability supports more effective collaboration with geological and reservoir engineering specialists.
Participants develop the ability to distinguish reservoir units according to their petrophysical and flow characteristics. They gain a clearer understanding of rock typing methods and their application to heterogeneous clastic and carbonate formations.
Attendees strengthen their knowledge of permeability relationships and the factors influencing fluid flow through porous formations. They learn how core measurements, porosity, pore structure and rock classification contribute to permeability estimation.
Participants improve their understanding of the petrophysical inputs required for reservoir models. They gain insight into the relationship between geological frameworks, facies distributions and reservoir property modelling.
The programme develops analytical capabilities for evaluating inconsistent datasets, recognising interpretation limitations and assessing subsurface uncertainty. Participants become better equipped to explain technical assumptions and support evidence-based reservoir decisions.
The acquired capabilities strengthen participants' professional contribution across petrophysics, core analysis, reservoir characterisation and subsurface evaluation. The multidisciplinary knowledge gained supports career development into senior technical, specialist and supervisory positions.
Petrophysicists: Professionals responsible for interpreting well logs, evaluating reservoir properties and integrating core measurements into formation evaluation workflows.
Reservoir Engineers: Specialists who require reliable porosity, permeability, saturation and rock classification inputs for reservoir simulation and development planning.
Geologists: Exploration, development and production geologists seeking to connect geological facies, depositional environments and petrophysical characteristics.
Core Analysis Specialists: Laboratory professionals responsible for conventional and special core analysis who need to understand how laboratory measurements support reservoir characterisation.
Formation Evaluation Specialists: Professionals involved in evaluating hydrocarbon-bearing formations and identifying productive reservoir intervals.
Reservoir Characterisation Engineers: Specialists responsible for integrating geological and petrophysical information into consistent reservoir descriptions and property distributions.
Sedimentologists: Professionals studying depositional environments, sedimentary structures and facies relationships to improve reservoir quality interpretation.
Geoscientists: Subsurface professionals seeking stronger multidisciplinary knowledge of geological, petrophysical and reservoir engineering workflows.
Well Logging Engineers: Specialists responsible for acquiring, quality-checking and interpreting logging measurements used in formation evaluation.
Reservoir Modelling Specialists: Professionals developing static and dynamic models who require consistent geological and petrophysical property inputs.
Exploration and Development Managers: Managers overseeing subsurface evaluation, appraisal activities and technical assessments of exploration and development opportunities.
Petroleum Engineering Managers: Senior professionals responsible for coordinating reservoir engineering, formation evaluation and field development activities.
Technical Team Leaders and Supervisors: Professionals managing multidisciplinary subsurface teams and overseeing the quality of reservoir evaluation deliverables.
Asset and Field Development Managers: Decision-makers responsible for evaluating reservoir performance, development opportunities and technical recommendations across producing assets.
This module establishes the technical foundations of integrated petrophysical reservoir characterisation. Participants examine how geological information, core measurements and well log responses contribute to a consistent understanding of subsurface formations. The module explores the fundamental relationships between lithology, porosity, permeability, fluid saturation and reservoir quality.
Emphasis is placed on understanding the strengths and limitations of different measurement techniques. Participants examine how differences between laboratory measurements and log-derived properties influence formation evaluation and why data quality assessment is essential before integrating datasets into reservoir characterisation workflows.
API Recommended Practice 40, Recommended Practices for Core Analysis, provides established guidance for conventional core analysis procedures.
It addresses the preparation and evaluation of core samples and the measurement of relevant reservoir properties.
It supports consistent interpretation of laboratory-derived porosity and permeability measurements.
It provides an important technical reference when evaluating core data for reservoir characterisation.
Explain the role of integrated petrophysics in reservoir evaluation.
Identify the principal geological and petrophysical parameters controlling reservoir quality.
Interpret common well log measurements in relation to formation properties.
Explain the importance of conventional and special core analysis.
Evaluate the quality and limitations of core and log datasets.
Establish the technical basis for integrating laboratory measurements with well log interpretations.
This module examines the integration of laboratory core measurements with geological descriptions and sedimentological interpretations. Participants explore how core photographs, lithological descriptions, grain size, sedimentary structures, mineral composition and depositional characteristics contribute to a more complete understanding of reservoir architecture.
The module focuses on facies analysis and its relationship with petrophysical properties. Participants investigate how depositional environments and post-depositional alterations influence pore structure, reservoir continuity and fluid flow. They also examine the importance of accurate core-to-log correlation when extending core-based observations across uncored intervals.
ISO 14689 provides a recognised framework for the identification, description and classification of rock materials.
It establishes consistent terminology and descriptive parameters for geological rock characterisation.
It supports the systematic documentation of lithology and relevant rock characteristics.
Its classification principles provide a useful reference for standardising geological descriptions used in integrated subsurface evaluations.
Assess conventional core datasets for reservoir evaluation.
Integrate laboratory measurements with geological and sedimentological descriptions.
Identify important lithological and depositional characteristics.
Apply facies analysis to understand reservoir distribution and heterogeneity.
Correlate core observations with wireline log responses.
Recognise the effects of cementation, compaction and diagenesis on reservoir properties.
Evaluate the representativeness and limitations of core samples.
This module focuses on the classification of reservoir rocks according to their geological, petrophysical and flow characteristics. Participants examine how lithology, pore geometry, pore connectivity, grain relationships and diagenetic processes influence reservoir quality.
The module explores different rock typing approaches and their contribution to understanding heterogeneous formations. Participants investigate the relationships between porosity and permeability, evaluate hydraulic flow units and examine why formations with comparable porosity values demonstrate different flow characteristics. Particular attention is given to the application of rock typing in clastic and carbonate reservoirs.
ASTM D4543 establishes recognised practices for preparing rock core specimens used in laboratory testing.
It addresses specimen dimensions, preparation and geometric requirements.
Consistent specimen preparation supports the reliability and comparability of laboratory measurements.
It provides a relevant reference when evaluating the quality and suitability of core specimens used in reservoir rock characterisation.
Explain the principles of geological and petrophysical rock typing.
Distinguish between lithofacies, electrofacies and hydraulic flow units.
Evaluate the influence of pore geometry and connectivity on reservoir quality.
Interpret porosity-permeability relationships across different rock types.
Identify the geological factors responsible for variations in reservoir properties.
Assess the suitability of different rock classification approaches for clastic and carbonate formations.
Apply rock typing concepts to improve reservoir heterogeneity assessment.
This module develops participants' understanding of permeability prediction and quantitative reservoir property evaluation. It examines the relationship between measured core permeability, interpreted porosity, pore structure, rock classification and formation characteristics. Participants explore how laboratory measurements calibrate petrophysical models and support permeability estimation in uncored intervals.
The module also addresses uncertainty in permeability prediction and the importance of selecting appropriate relationships for different geological settings. Participants evaluate the application of core-derived relationships to reservoir intervals and examine how predicted properties influence formation evaluation and reservoir engineering decisions.
Covers conventional core analysis procedures, including porosity and permeability measurements.
Provides technical guidance on core preparation, laboratory testing and reporting.
Supports understanding of core-derived permeability measurements used to calibrate petrophysical interpretations.
This publication was withdrawn in 2021 and is included only as a historical technical reference, not a current active standard.
Explain the principles of permeability measurement and its importance in reservoir characterisation.
Interpret conventional core analysis results, including porosity and permeability measurements.
Evaluate core preparation, laboratory testing procedures and measurement quality.
Analyse relationships between porosity, permeability and pore structure.
Apply core-derived permeability relationships to petrophysical interpretation.
Evaluate rock type-based and hydraulic flow unit-based permeability prediction methods.
Identify factors affecting permeability distribution across heterogeneous reservoir formations.
Assess uncertainties associated with laboratory measurements and permeability estimation.
Integrate core analysis results with well log data to improve permeability prediction in uncored intervals.
Apply core-calibrated petrophysical interpretations to reservoir evaluation and engineering decisions.
This module brings together the geological, petrophysical and core analysis concepts developed throughout the programme. Participants examine how integrated datasets support reservoir architecture interpretation, property distribution and the construction of consistent static reservoir models.
The module focuses on transferring interpreted rock types, facies, porosity, permeability and saturation information into reservoir modelling workflows. Participants explore the importance of geological consistency, data quality, uncertainty assessment and multidisciplinary validation. The emphasis is on establishing technically defensible reservoir descriptions that support development planning, reservoir simulation and production optimisation.
RESQML is an Energistics data exchange standard for subsurface reservoir models and related information.
It supports the exchange of geological and reservoir modelling information between compatible software applications.
It provides a structured approach to representing subsurface interpretation and modelling objects.
It supports data interoperability and continuity across multidisciplinary reservoir workflows.
It is relevant to the transfer and management of reservoir modelling information generated from integrated petrophysical evaluations.
Integrate geological, core analysis and petrophysical interpretations into a consistent reservoir description.
Evaluate the relationship between facies, rock types and reservoir property distributions.
Prepare representative porosity and permeability inputs for reservoir modelling.
Identify reservoir compartments, heterogeneity and potential flow barriers.
Assess the quality and consistency of model-ready petrophysical datasets.
Recognise uncertainty in reservoir property distribution and its implications for modelling.
Explain how integrated petrophysics supports reservoir simulation and field development planning.
Communicate integrated reservoir characterisation results to multidisciplinary technical teams.
Upon successful completion of the Integrated Petrophysics for Reservoir Characterization Training Course, attendees receive a Certificate of Completion from Institute For Oil & Gas Training.
The certificate recognises participation in the professional training programme and successful completion of its learning requirements. Attendees are required to meet the institute's attendance requirement of at least 80 percent of the total course duration to qualify for the Certificate of Completion.
Fees include tuition, course materials and refreshments. Need different dates or a different city? Ask about your preferred date.
The course develops the skills required to integrate core analysis, well log interpretation, geological descriptions and petrophysical measurements for reliable reservoir characterisation. It covers rock typing, facies analysis, permeability prediction, reservoir quality assessment and reservoir modelling applications.
The programme is designed for petrophysicists, reservoir engineers, geologists, core analysis specialists, formation evaluation professionals, sedimentologists, geoscientists and technical managers involved in subsurface evaluation and reservoir development.
The total course duration is 15–20 hours. The programme is structured into five technical modules covering integrated petrophysics, core data integration, rock typing, permeability prediction and reservoir modelling applications.
Core data integration connects laboratory measurements with geological descriptions and well log interpretations. It improves the understanding of reservoir quality, validates petrophysical interpretations and provides more representative information for permeability prediction and reservoir modelling.
Yes. Attendees who successfully complete the programme and meet the institute's minimum attendance requirement of 80 percent receive a Certificate of Completion from Institute For Oil & Gas Training.
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