The Petrophysical Properties Training Course by Institute For Oil & Gas Training develops the technical capabilities required to evaluate, interpret and apply core-derived reservoir properties across exploration, development and production operations. Petrophysical Properties provide the foundation for understanding reservoir quality, estimating hydrocarbon storage capacity, evaluating fluid movement and supporting reliable reservoir characterisation decisions.
Accurate knowledge of reservoir rock properties is essential for oil and gas organisations seeking to improve subsurface understanding, optimise field development strategies and maximise hydrocarbon recovery. Porosity, permeability, fluid saturation, pore structure, capillary pressure and wettability determine how effectively a reservoir stores and transmits hydrocarbons. Inconsistent measurements or incorrect interpretation of these properties create uncertainty in reservoir models, production forecasts, completion strategies and recovery assessments.
This Petrophysical Properties Training Course addresses the technical skills gap between laboratory core measurements and their practical application in reservoir engineering and subsurface decision-making. It provides professionals with a structured understanding of routine core analysis, special core analysis and the interpretation of laboratory results within the broader context of reservoir evaluation. Participants examine how rock characteristics influence fluid distribution, reservoir connectivity and production performance.
The course also explores the relationship between core measurements and wireline logging data through core-log integration. This relationship is particularly important when establishing representative reservoir properties across intervals where direct core measurements are limited. Participants learn how to evaluate differences between laboratory measurements and log-derived estimates, identify potential sources of uncertainty and establish more consistent reservoir property interpretations.
A central focus is understanding reservoir heterogeneity and its influence on hydrocarbon distribution and movement. Variations in grain size, mineral composition, pore geometry, cementation and depositional characteristics produce significant differences in reservoir quality. These variations influence permeability distribution, fluid flow behaviour and the identification of representative flow units. Understanding these characteristics enables professionals to distinguish productive reservoir intervals from poor-quality or non-reservoir formations.
The programme covers both fundamental and advanced aspects of core analysis. It examines laboratory measurement techniques, porosity and permeability relationships, saturation measurements, wettability, capillary pressure, relative permeability and the development of reservoir flow units. Participants also explore how special core analysis results support reservoir simulation, enhanced oil recovery planning and production optimisation.
Institute For Oil & Gas Training delivers this programme for organisations requiring stronger technical consistency across geological, petrophysical and reservoir engineering functions. The course connects laboratory procedures with operational requirements, helping professionals translate measured rock properties into meaningful reservoir characterisation information.
With a total course duration of 15 to 20 hours, this programme provides a focused professional development opportunity for oil and gas personnel involved in core evaluation, reservoir studies, formation assessment and field development. It strengthens the ability to interpret petrophysical data, recognise measurement limitations and apply core-derived information to practical subsurface challenges.
Explain the fundamental Petrophysical Properties governing hydrocarbon storage and movement within reservoir rocks.
Identify the geological and physical factors influencing porosity, permeability and reservoir quality.
Understand the principles, procedures and applications of routine core analysis.
Evaluate laboratory measurements and identify potential sources of error and uncertainty.
Interpret grain density, pore volume and fluid saturation measurements in reservoir evaluation.
Explain the principles and applications of special core analysis.
Assess wettability, capillary pressure and relative permeability in different reservoir conditions.
Understand the relationship between pore structure and fluid flow characteristics.
Identify reservoir heterogeneity and evaluate its influence on reservoir connectivity.
Classify reservoir intervals using geological and petrophysical information to establish representative flow units.
Apply core-log integration principles to improve the consistency of reservoir property interpretation.
Evaluate differences between laboratory measurements and wireline logging estimates.
Understand the application of core-derived properties in reservoir modelling and simulation.
Interpret core analysis results to support hydrocarbon recovery and production optimisation.
Improve technical communication between geological, petrophysical and reservoir engineering teams.
Institute For Oil & Gas Training applies an industry-focused delivery methodology that combines technical presentations, practical interpretation exercises, case studies, group discussions and realistic reservoir evaluation scenarios. The approach connects the scientific principles of rock properties with the operational requirements of petroleum exploration, development and production.
The training methodology focuses on the following approaches:
Structured presentations introduce the fundamental principles governing Petrophysical Properties and their importance in reservoir characterisation. Participants examine porosity, permeability, saturation, wettability, pore structure and fluid movement through practical oil and gas applications.
Professional discussions explore the implications of inaccurate core measurements, inconsistent laboratory procedures and incomplete reservoir characterisation. These discussions help participants understand how technical decisions influence field development and production performance.
Participants examine the principles and applications of routine core analysis, including core preparation, porosity determination, permeability measurements, grain density and fluid saturation assessment.
Practical interpretation exercises demonstrate how laboratory measurements establish the basic physical characteristics of reservoir rocks. Participants also examine the limitations of individual measurements and the importance of maintaining consistency when comparing different core samples.
Case studies introduce advanced laboratory investigations used to evaluate reservoir fluid flow behaviour. Topics include relative permeability, capillary pressure, wettability and electrical properties.
Participants investigate how special core analysis results contribute to reservoir simulation, fluid displacement studies and improved recovery planning.
Group exercises explore variations in reservoir quality across different geological intervals. Participants assess the effects of pore structure, grain size, cementation and depositional environments on permeability distribution and reservoir connectivity.
These exercises demonstrate how reservoir heterogeneity influences the identification of flow units and the interpretation of reservoir performance.
Participants work through practical scenarios involving laboratory core measurements and wireline logging information. They evaluate differences between core-derived porosity and log-derived porosity, examine depth matching considerations and discuss methods for improving consistency between datasets.
The exercises strengthen the ability to use core measurements to calibrate petrophysical interpretations and establish more reliable reservoir property models.
Collaborative exercises encourage participants to evaluate reservoir scenarios from geological, petrophysical and engineering perspectives. These activities strengthen communication between technical disciplines and demonstrate how integrated reservoir information supports operational planning.
Accurate interpretation of Petrophysical Properties contributes directly to the quality of subsurface evaluations and the effectiveness of reservoir management strategies. Organisations investing in this training strengthen their technical capabilities in core analysis, reservoir characterisation and integrated formation evaluation.
A stronger understanding of core-derived properties enables technical teams to develop more representative reservoir descriptions. Improved interpretation of porosity, permeability, saturation and pore structure supports better identification of reservoir-quality intervals and reduces uncertainty in subsurface evaluations.
Consistent application of routine core analysis and special core analysis improves the quality of information supplied to geological and reservoir simulation models. Organisations benefit from stronger integration between measured rock properties and reservoir engineering assumptions.
Recognising variations in reservoir quality enables organisations to identify differences in permeability distribution, connectivity and fluid movement. This understanding supports improved reservoir compartmentalisation, flow unit classification and production forecasting.
Reliable core-derived information supports decisions relating to well placement, completion design, production strategies and reservoir development planning. Technical teams gain a stronger basis for evaluating the suitability of different reservoir intervals and development options.
Understanding wettability, relative permeability and capillary pressure strengthens the evaluation of fluid displacement mechanisms. These properties support more informed decisions regarding waterflooding, enhanced oil recovery and other reservoir management strategies.
Improved knowledge of laboratory procedures and interpretation techniques promotes consistency across core analysis programmes. Organisations benefit from better communication between laboratory specialists, petrophysicists, geologists and reservoir engineers.
Understanding the purpose and limitations of different core analysis techniques helps technical teams select appropriate measurements for specific reservoir evaluation requirements. This supports more focused laboratory programmes and more effective use of available technical resources.
Better understanding of measurement quality, sample representativeness and core-log integration helps teams identify discrepancies before they influence reservoir models and development decisions. This strengthens technical assurance and the reliability of subsurface assessments.
The Petrophysical Properties Training Course strengthens the professional capabilities of individuals involved in reservoir evaluation, core analysis and subsurface operations.
Participants develop a stronger understanding of how physical rock properties influence hydrocarbon storage, fluid movement and reservoir productivity. This knowledge improves their ability to interpret core measurements and communicate their technical significance to multidisciplinary teams.
Participants develop a comprehensive understanding of porosity, permeability, saturation, pore geometry, wettability and capillary pressure. They gain the technical foundation required to evaluate reservoir rock properties more confidently.
Professionals strengthen their understanding of routine core analysis and special core analysis results. They become better equipped to recognise measurement limitations, evaluate laboratory findings and identify the relevance of different parameters to reservoir performance.
Participants improve their ability to interpret reservoir heterogeneity, identify representative flow units and assess differences in reservoir quality. These capabilities strengthen their contribution to reservoir characterisation and field development studies.
The course develops practical understanding of core-log integration, enabling participants to relate laboratory measurements to wireline logging information. This improves their ability to contribute to integrated formation evaluation workflows.
Participants gain a broader understanding of how geological characteristics, petrophysical measurements and reservoir engineering requirements interact. This supports more productive collaboration with multidisciplinary technical teams.
The knowledge gained supports professional development across petrophysics, reservoir engineering, geology, core laboratory operations and subsurface management. Participants strengthen their ability to undertake technical responsibilities involving reservoir quality assessment, laboratory data interpretation and reservoir performance evaluation.
Petrophysicists: To strengthen their understanding of core-derived properties and improve the calibration of petrophysical interpretations.
Reservoir Engineers: To understand how porosity, permeability, saturation and relative permeability influence reservoir performance and production forecasts.
Geologists and Development Geologists: To evaluate the relationship between geological characteristics, reservoir heterogeneity and measured rock properties.
Core Analysis Specialists: To improve their understanding of routine core analysis, special core analysis and the interpretation of laboratory measurements.
Core Laboratory Engineers and Technicians: To strengthen their technical knowledge of core preparation, measurement procedures and data quality.
Formation Evaluation Engineers: To improve the integration of laboratory measurements with wireline logging and formation evaluation results.
Subsurface Engineers: To develop a broader understanding of reservoir properties and their application in integrated subsurface studies.
Reservoir Modelling Specialists: To understand how core-derived properties support reservoir model construction and flow simulation.
Production Engineers: To evaluate the influence of reservoir properties on fluid movement, well performance and production optimisation.
Enhanced Oil Recovery Specialists: To understand how wettability, capillary pressure and relative permeability influence displacement efficiency.
Reservoir Management Professionals: To strengthen their understanding of reservoir quality distribution and its implications for field development.
Petroleum Engineering Managers and Technical Supervisors: To improve technical oversight of core analysis programmes and reservoir evaluation workflows.
Exploration and Development Managers: To understand the importance of representative rock property data in exploration assessment and development planning.
This module introduces the fundamental physical properties of reservoir rocks and explains their importance in evaluating hydrocarbon-bearing formations. Participants examine the relationship between geological characteristics, pore structure and the ability of reservoir rocks to store and transmit fluids.
The module establishes the technical foundation for understanding core-derived measurements and their role in reservoir characterisation. It also examines the importance of representative core sampling, sample preparation and reliable laboratory procedures.
Provides recognised industry guidance for petroleum core analysis procedures.
Addresses the preparation, handling and evaluation of reservoir core samples.
Establishes technical principles for obtaining reliable core analysis measurements.
Supports consistent interpretation of core-derived reservoir properties.
Provides a reference for understanding measurement limitations and laboratory practices.
Explain the fundamental characteristics of reservoir rocks.
Identify the geological factors influencing reservoir quality.
Describe the relationship between pore structure and fluid storage.
Distinguish different forms of porosity and their significance.
Explain the importance of representative core sampling.
Recognise factors affecting core measurement reliability.
Evaluate the influence of geological heterogeneity on reservoir properties.
This module focuses on routine core analysis and the laboratory measurement of fundamental reservoir properties. Participants examine the principles and applications of porosity, permeability, grain density, bulk volume and fluid saturation measurements.
The module also explores how laboratory procedures influence measurement quality and how core-derived data contributes to reservoir evaluation. Particular attention is given to understanding the relationship between porosity and permeability and the limitations of using individual measurements to assess reservoir productivity.
Provides a standardised method for measuring the permeability of rocks by flowing air.
Establishes laboratory testing principles for evaluating rock permeability.
Supports the assessment of gas flow through porous rock samples.
Provides a technical reference for comparing permeability measurements.
Helps establish consistency in permeability testing procedures.
Explain the objectives and applications of routine core analysis.
Describe laboratory techniques used to determine porosity and permeability.
Interpret grain density and bulk density measurements.
Understand the significance of fluid saturation measurements.
Evaluate porosity-permeability relationships.
Identify factors influencing the accuracy of laboratory measurements.
Interpret routine core analysis results for reservoir quality assessment.
Recognise the limitations of individual core measurements.
This module examines the relationship between pore structure, fluid distribution and the physical mechanisms controlling hydrocarbon movement within reservoir rocks. Participants explore how pore throat dimensions, rock wettability and interfacial forces influence the distribution of oil, gas and water.
The module introduces capillary pressure measurements and their importance in understanding fluid saturation across reservoir intervals. Participants also examine the application of pore structure analysis techniques to improve reservoir characterisation and interpret fluid distribution within different rock types.
Establishes a test method for determining pore volume and pore size distribution using mercury intrusion porosimetry.
Provides a recognised approach for evaluating pore structure in porous materials.
Supports the assessment of pore throat characteristics.
Helps establish relationships between pore geometry and fluid movement.
Provides useful technical reference information for understanding pore structure measurements.
Explain the relationship between pore structure and fluid distribution.
Interpret pore size and pore throat distribution information.
Understand the principles of capillary pressure measurements.
Distinguish between different reservoir wettability conditions.
Explain drainage and imbibition mechanisms.
Evaluate the significance of irreducible water and residual oil saturation.
Understand the relationship between pore geometry and hydrocarbon recovery.
Interpret saturation height information for reservoir characterisation.
This module introduces special core analysis and its application in understanding reservoir fluid flow behaviour under representative subsurface conditions. Participants examine advanced measurements used to evaluate relative permeability, capillary pressure, wettability and fluid displacement characteristics.
The module also explores the identification and classification of flow units using geological and petrophysical information. Participants investigate how reservoir heterogeneity creates variations in fluid movement and connectivity, and how special core analysis results support reservoir simulation and recovery optimisation.
Provides established industry guidance covering petroleum core analysis practices.
Addresses technical considerations associated with specialised core measurements.
Supports the evaluation of core-derived properties used in reservoir engineering.
Provides a reference for understanding the application and limitations of core analysis procedures.
Helps maintain technical consistency in the evaluation of reservoir rock properties.
Explain the objectives and applications of special core analysis.
Distinguish between routine and special core analysis measurements.
Understand the principles of relative permeability.
Interpret the relationship between wettability and fluid displacement.
Evaluate the importance of capillary pressure in reservoir studies.
Identify flow units using geological and petrophysical information.
Explain how reservoir heterogeneity influences fluid flow.
Understand the application of special core analysis in reservoir simulation.
Assess the contribution of core measurements to recovery optimisation.
This module focuses on integrating laboratory core measurements with wireline logging data to establish more representative reservoir property interpretations. Participants examine the relationship between measured core porosity and log-derived porosity, permeability estimation and the identification of reservoir-quality intervals.
The module also addresses the application of integrated core and log information in reservoir modelling, formation evaluation and field development planning. Participants examine how reliable petrophysical data supports reservoir management decisions, improves geological understanding and strengthens the interpretation of reservoir performance.
Provides an internationally recognised framework for classifying and categorising petroleum resources.
Establishes principles for evaluating recoverable quantities and project maturity.
Supports consistent communication of petroleum resource estimates.
Provides a broader framework within which reservoir characterisation information contributes to resource evaluation.
Reinforces the importance of reliable technical evidence in subsurface assessment and development decisions.
Explain the principles of core-log integration.
Compare laboratory core measurements with wireline logging estimates.
Understand the importance of depth matching and data alignment.
Apply core measurements to improve petrophysical log interpretation.
Evaluate reservoir-quality variations using integrated datasets.
Understand the contribution of flow units to reservoir modelling.
Assess the influence of reservoir heterogeneity on connectivity.
Explain how core-derived properties support reservoir simulation.
Apply integrated petrophysical information to reservoir management and field development decisions.
Upon successful completion of the Petrophysical Properties Training Course, attendees receive a Certificate of Completion from Institute For Oil & Gas Training.
The certificate recognises participation in the professional training programme and the successful completion of its learning requirements. Attendees must satisfy the course attendance requirement and participate in the scheduled training activities to qualify for the certificate.
Fees include tuition, course materials and refreshments. Need different dates or a different city? Ask about your preferred date.
Petrophysical Properties describe the physical characteristics of reservoir rocks that determine their ability to store and transmit fluids. Important properties include porosity, permeability, fluid saturation, pore structure and wettability. These characteristics influence reservoir quality, hydrocarbon distribution, fluid movement and production performance. Accurate evaluation supports reservoir characterisation, field development planning and hydrocarbon recovery optimisation.
Routine core analysis focuses on measuring fundamental rock properties, including porosity, permeability, grain density and fluid saturation. Special core analysis investigates more advanced reservoir characteristics, including relative permeability, capillary pressure and wettability. Both techniques provide complementary information required for understanding reservoir quality and fluid flow behaviour.
Core-log integration combines direct laboratory measurements with continuous wireline logging information. Core measurements provide detailed information about specific rock samples, while wireline logs help evaluate formation properties across larger well intervals. Integrating these datasets improves petrophysical interpretation, supports log calibration and provides a stronger basis for reservoir modelling and characterisation.
The course is designed for petrophysicists, reservoir engineers, geologists, core analysis specialists, formation evaluation engineers, production engineers and other subsurface professionals. It is also suitable for technical supervisors and managers responsible for core analysis programmes, reservoir evaluation and field development activities.
Attendees receive a Certificate of Completion from Institute For Oil & Gas Training upon finishing the programme and meeting the applicable attendance requirement. The certificate recognises their participation in professional training covering Petrophysical Properties, routine core analysis, special core analysis, reservoir heterogeneity and core-log integration.
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Next: 09 Nov 2026
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