The Heavy Oil and Tarmat Evaluation Training Course by Institute For Oil & Gas Training develops the specialist petrophysical skills required for reliable Heavy Oil / Tarmat Evaluation, reservoir characterisation, and assessment of hydrocarbon mobility in challenging oil and gas reservoirs. Designed for professionals in the Oil & Gas Petrophysics category, the course focuses on distinguishing movable hydrocarbons from restricted fluid systems, interpreting nuclear magnetic resonance measurements, and integrating reservoir data to support technically sound development decisions.
Heavy oil and tarmat reservoirs present distinct evaluation challenges because conventional interpretation approaches do not always provide a reliable representation of fluid distribution, pore occupancy, producibility, and formation response. High oil viscosity, complex pore structures, variable wettability, and limited fluid mobility affect the relationship between conventional logging measurements and actual reservoir performance. Tarmat intervals introduce additional complexity where heavy hydrocarbon accumulations or tar-like materials restrict pore space, obstruct fluid movement, or influence the interpretation of potentially productive formations.
For exploration and production organisations, these conditions create a direct need for stronger reservoir evaluation practices. Inaccurate identification of movable hydrocarbons can lead to unrealistic production expectations, inappropriate completion decisions, inefficient well placement, and uncertainty in thermal recovery planning. A disciplined evaluation workflow connects petrophysical measurements with geological context, fluid properties, core analysis, and reservoir engineering requirements to produce a more defensible interpretation of subsurface conditions.
The programme delivered by Institute For Oil & Gas Training examines the technical principles and practical workflows used to assess heavy oil and tarmat intervals. Participants develop an understanding of conventional wireline logs, nuclear magnetic resonance measurements, porosity and saturation interpretation, fluid mobility indicators, and the limitations associated with evaluating viscous hydrocarbons. Particular attention is given to NMR T2 interpretation and the way relaxation-time distributions support the assessment of pore environments, fluid associations, and potential mobility.
A central theme is the distinction between hydrocarbon presence and hydrocarbon producibility. An interval containing substantial hydrocarbon saturation does not necessarily deliver commercially useful production if the fluid remains highly viscous, pore connectivity is poor, or formation conditions restrict movement towards the wellbore. Participants learn to integrate multiple measurements rather than relying on a single log response or an isolated interpretation parameter.
The course also considers how reservoir evaluation supports thermal recovery decisions. Steam-based recovery methods and other thermal approaches depend on an understanding of reservoir continuity, fluid properties, formation characteristics, and the distribution of potentially recoverable hydrocarbons. Petrophysical evidence contributes to screening, reservoir modelling, development planning, and the identification of uncertainties that require additional investigation.
Through applied interpretation exercises and integrated case studies, Institute For Oil & Gas Training connects subsurface evaluation with operational decision-making. Participants examine how data quality, calibration, uncertainty management, and cross-disciplinary communication influence the reliability of reservoir assessments. The emphasis remains on practical application in exploration, appraisal, field development, and mature asset management.
This training is relevant to organisations operating heavy oil assets, evaluating bitumen-rich formations, assessing tarmat-bearing intervals, or reviewing reservoirs where conventional production mechanisms are constrained by fluid viscosity and formation characteristics. It supports a consistent technical approach to identifying reservoir potential, understanding restricted fluid mobility, and improving the evidence available for investment and development decisions.
The overall course duration is 15 to 20 hours. Across five integrated modules, participants progress from the fundamental characteristics of heavy oil and tarmat systems to log interpretation, NMR T2 interpretation, integrated reservoir evaluation, and the application of petrophysical findings to thermal recovery planning. The resulting capability strengthens the connection between subsurface measurements and the practical requirements of reservoir development.
Explain the geological, petrophysical, and fluid-property characteristics that influence heavy oil and tarmat reservoir evaluation.
Distinguish hydrocarbon presence from potentially movable hydrocarbons and assess the implications of restricted fluid mobility.
Interpret conventional wireline logs in formations containing viscous hydrocarbons and identify limitations affecting standard evaluation methods.
Analyse NMR T2 distributions and relate relaxation-time behaviour to pore environments, fluid properties, and potential mobility.
Integrate porosity, saturation, resistivity, permeability indicators, core measurements, and geological information into a coherent reservoir interpretation.
Recognise the effects of heavy oil viscosity, pore connectivity, wettability, and formation heterogeneity on expected reservoir performance.
Identify tarmat-related interpretation challenges and assess their potential influence on reservoir continuity and producibility.
Evaluate data quality, calibration requirements, interpretation assumptions, and uncertainty before finalising petrophysical conclusions.
Connect reservoir evaluation findings with screening requirements for thermal recovery and other appropriate development approaches.
Communicate petrophysical findings effectively to geology, reservoir engineering, production technology, and asset management teams.
Recommend additional measurements, core analysis, or specialist investigations where the existing evidence does not support a confident conclusion.
Prepare structured technical recommendations that improve reservoir characterisation, appraisal planning, and development decision-making.
Institute For Oil & Gas Training uses an applied, industry-oriented delivery approach that combines technical briefings, interpretation exercises, case studies, structured group discussions, and reservoir evaluation scenarios. The methodology reflects the multidisciplinary nature of Heavy Oil / Tarmat Evaluation, where reliable conclusions depend on integrating petrophysical evidence with geological observations, fluid behaviour, core measurements, and reservoir engineering considerations.
Technical sessions establish the principles behind heavy oil properties, tarmat distribution, conventional well logging, and nuclear magnetic resonance measurements. These principles are then applied to representative subsurface datasets so that participants can evaluate how different measurements contribute to an interpretation. The focus is on the practical meaning of the evidence, the limitations of individual techniques, and the implications of uncertainty for reservoir decisions.
Case studies examine situations in which conventional log responses require additional investigation before a formation can be classified as productive. Participants assess variations in porosity, resistivity, saturation indicators, and NMR relaxation-time distributions. They identify evidence of potentially movable hydrocarbons, distinguish fluid presence from likely producibility, and consider alternative explanations for ambiguous responses.
NMR interpretation exercises concentrate on the distribution and significance of T2 relaxation times. Participants explore how pore geometry, fluid properties, viscosity, measurement conditions, and interpretation assumptions affect the conclusions drawn from NMR data. The exercises emphasise the need to avoid treating a single relaxation-time threshold as a universal boundary between movable and immovable fluids.
Integrated group exercises bring together conventional logs, core data, geological descriptions, and reservoir information. Participants develop a structured interpretation, identify missing evidence, and communicate the confidence and limitations associated with their conclusions. These activities reflect the decisions faced by petrophysicists and reservoir teams when evaluating intervals for further appraisal, completion, or development.
Thermal recovery scenarios connect petrophysical interpretation with development requirements. Participants consider how reservoir continuity, porosity, saturation, permeability indicators, and the distribution of viscous hydrocarbons influence screening decisions. They examine how uncertainties in fluid mobility and formation characteristics affect the quality of inputs provided to reservoir simulation and thermal recovery planning.
The methodology also incorporates facilitated technical discussions that encourage participants to compare interpretations and explain the reasoning behind their decisions. This supports consistent interpretation practices across multidisciplinary teams and improves the quality of technical handovers between petrophysics, geology, reservoir engineering, production technology, and asset management.
Throughout the programme, the emphasis is on practical reasoning rather than memorising isolated definitions. Participants learn to document assumptions, recognise measurement limitations, identify inconsistencies between datasets, and recommend additional analysis when available evidence is insufficient. These practices help organisations improve the repeatability, transparency, and operational usefulness of reservoir evaluation.
Organisations investing in heavy oil and tarmat assets require dependable subsurface interpretations to manage technical uncertainty and allocate capital effectively. The course supports this requirement by improving the quality of petrophysical evaluation and strengthening the connection between reservoir evidence and development decisions.
Improved reservoir characterisation: Participants develop a more systematic approach to integrating well logs, NMR measurements, core data, and geological observations. This helps teams distinguish between intervals with different reservoir characteristics and document the evidence supporting their classification.
Better assessment of hydrocarbon mobility: A more disciplined distinction between hydrocarbon saturation and producibility reduces the risk of treating every hydrocarbon-bearing interval as equally productive. Improved mobility assessment supports more realistic reservoir descriptions and better-informed discussions about expected production behaviour.
More effective thermal recovery screening: Thermal recovery projects depend on suitable reservoir conditions and an accurate understanding of the formation. Improved petrophysical interpretation provides stronger inputs for screening, reservoir modelling, development planning, and multidisciplinary review. It also helps teams identify uncertainties that require further evaluation before committing resources.
Reduced interpretation rework: Consistent workflows, clear documentation, and improved recognition of data limitations help reduce avoidable inconsistencies between petrophysical interpretations. Teams can identify gaps earlier, prioritise additional analysis, and minimise repeated technical reviews caused by unclear assumptions or conflicting datasets.
Stronger appraisal and completion decisions: Better understanding of tarmat distribution, fluid mobility, and reservoir heterogeneity supports more informed decisions about interval selection, further appraisal, and completion planning. The course does not replace field-specific engineering studies; it improves the quality of the petrophysical evidence used in those studies.
More effective multidisciplinary collaboration: Shared interpretation principles improve communication between petrophysicists, geologists, reservoir engineers, production specialists, and asset managers. Teams gain a clearer basis for discussing uncertainty, comparing alternative interpretations, and agreeing on the additional evidence required.
Improved technical assurance: Structured evaluation practices make assumptions, limitations, and supporting evidence easier to review. This strengthens internal quality assurance, technical reporting, and the consistency of decisions across wells and assets.
More focused data acquisition: Identifying the specific uncertainties affecting a reservoir interpretation helps teams evaluate where additional core measurements, specialised logging, fluid analysis, or laboratory investigations provide the greatest technical value. This supports better prioritisation of subsurface data acquisition.
Stronger knowledge retention: Training personnel in a consistent evaluation methodology helps organisations retain specialist interpretation capability within their technical teams. The resulting knowledge supports repeatable workflows and more effective collaboration across current and future asset development activities.
Organisational benefits should be assessed against relevant operational indicators, including interpretation turnaround time, frequency of technical rework, completeness of evaluation reports, resolution of identified data gaps, and the quality of inputs supplied to development studies. These indicators allow sponsoring companies to assess how the training contributes to their own performance objectives without assuming unsupported financial or production improvements.
Participants strengthen the technical judgement required to evaluate heavy oil and tarmat reservoirs where conventional interpretation approaches demand careful qualification. They gain a clearer understanding of the relationship between petrophysical measurements, fluid properties, reservoir architecture, and potential production performance.
The programme develops practical confidence in NMR T2 interpretation, helping participants assess relaxation-time distributions alongside conventional log responses and other available evidence. They learn to question simplistic interpretations, recognise the influence of viscous fluids, and distinguish between measurement observations and conclusions that require additional support.
Participants also improve their ability to assess movable hydrocarbons and restricted fluid mobility. This includes understanding why hydrocarbon saturation alone does not establish deliverability and why permeability, pore connectivity, fluid viscosity, formation heterogeneity, and operating conditions must be considered together.
The integrated exercises strengthen data interpretation and technical reporting skills. Participants practise comparing alternative explanations, identifying inconsistencies, documenting assumptions, and explaining the confidence associated with their conclusions. These capabilities support more effective technical reviews and clearer communication with colleagues from other disciplines.
For professionals involved in thermal recovery projects, the course improves their understanding of the petrophysical evidence required for reservoir screening and development planning. They gain a more structured basis for discussing reservoir suitability, identifying knowledge gaps, and supplying relevant information to reservoir engineering teams.
The course also supports professional development by strengthening the participant's contribution to multidisciplinary asset decisions. Petrophysicists gain additional tools for evaluating challenging formations, while reservoir engineers, geologists, and production specialists improve their understanding of the petrophysical factors that influence heavy oil reservoir performance.
Participants finish with a more systematic approach to reservoir evaluation, better awareness of interpretation limitations, and a stronger ability to convert complex subsurface measurements into clear, technically justified recommendations.
Petrophysicists: Strengthen conventional log and NMR interpretation skills for complex heavy hydrocarbon intervals.
Senior Petrophysicists and Petrophysics Team Leaders: Improve interpretation consistency, technical review, and evaluation quality assurance across wells and assets.
Reservoir Engineers: Develop a stronger understanding of fluid mobility, reservoir properties, and the reliability of petrophysical inputs used in reservoir models.
Geologists and Reservoir Geologists: Connect geological observations and formation heterogeneity with petrophysical evidence of reservoir quality and hydrocarbon distribution.
Exploration and Appraisal Professionals: Improve the interpretation of heavy oil and tarmat intervals during prospect assessment, well evaluation, and appraisal planning.
Production Technologists: Understand how viscosity, pore connectivity, and restricted fluid movement influence the interpretation of potential production performance.
Thermal Recovery and Enhanced Oil Recovery Specialists: Strengthen the petrophysical basis for reservoir screening and thermal recovery development studies.
Well Logging and Formation Evaluation Specialists: Improve their ability to interpret conventional logging responses and integrate specialist measurements in viscous hydrocarbon environments.
Core Analysis and Laboratory Specialists: Relate laboratory measurements and core descriptions to log-derived reservoir properties and mobility assessments.
Subsurface Data Analysts: Improve data integration, quality control, and the identification of inconsistencies in complex reservoir datasets.
Field Development and Asset Planning Professionals: Understand how petrophysical uncertainty affects development options, appraisal priorities, and technical investment decisions.
Technical Assurance and Subsurface Managers: Strengthen oversight of evaluation workflows, interpretation assumptions, and the evidence supporting development recommendations.
Oil and Gas Consultants: Expand their capability to assess heavy hydrocarbon reservoirs and communicate technically defensible conclusions to clients.
Professionals Moving into Heavy Oil Asset Assignments: Build the specialist knowledge needed to contribute to multidisciplinary evaluation and development activities.
This module establishes the technical foundation for Heavy Oil / Tarmat Evaluation by examining the geological characteristics, fluid properties, and petrophysical conditions that distinguish heavy hydrocarbon reservoirs from conventional oil-bearing formations. Participants explore the influence of viscosity, pore structure, wettability, permeability, and reservoir heterogeneity on fluid distribution and potential production performance.
The module also examines the distinction between heavy oil accumulations and tarmat-bearing intervals. Participants consider how viscous hydrocarbons and tar-like materials affect pore occupancy, reservoir connectivity, and interpretation confidence. Emphasis is placed on understanding the geological context before assigning significance to individual logging responses or saturation indicators.
The Society of Petroleum Engineers Petroleum Resources Management System provides a recognised framework for classifying and categorising petroleum resources according to project maturity, uncertainty, and commercial considerations.
It supports consistent communication of resource estimates and the assumptions underlying development projects.
Participants examine how reservoir characterisation evidence contributes to resource assessment without treating petrophysical interpretation alone as proof of commercial recoverability.
The framework reinforces the distinction between identifying hydrocarbons in place and establishing the technical and commercial basis for recovery.
Explain the principal characteristics of heavy oil and tarmat-bearing reservoirs.
Identify the effects of viscosity, pore structure, wettability, and permeability on reservoir behaviour.
Distinguish hydrocarbon occurrence from evidence of potential producibility.
Explain the geological and petrophysical factors that contribute to restricted fluid mobility.
Recognise the implications of reservoir heterogeneity for evaluation and development planning.
Relate reservoir characterisation evidence to the classification and communication of petroleum resources.
This module examines conventional wireline logging and core measurements used in the evaluation of heavy oil and tarmat intervals. Participants review the contribution of gamma ray, resistivity, density, neutron porosity, sonic, and other available measurements to formation identification, porosity assessment, lithology interpretation, and hydrocarbon evaluation.
Particular attention is given to the limitations of conventional interpretation in viscous hydrocarbon environments. Participants investigate how fluid properties, mineral composition, borehole conditions, invasion, and formation heterogeneity influence log responses. Core measurements and geological descriptions are introduced as complementary sources of evidence for calibration, validation, and improved confidence in reservoir property estimates.
API Recommended Practice 40, Recommended Practices for Core Analysis, provides established guidance for obtaining and evaluating core-analysis data.
It addresses core-analysis practices relevant to the determination of reservoir properties and the interpretation of laboratory measurements.
Participants consider the importance of representative samples, measurement quality, sample preparation, and documented laboratory procedures.
The recommended practice supports a structured approach to comparing core-derived porosity and permeability with log-derived estimates.
Core data are assessed alongside geological information and measurement limitations rather than treated as automatically representative of the entire reservoir.
Interpret conventional well logs in heavy oil and tarmat-bearing formations.
Assess the contributions of gamma ray, resistivity, density, neutron, and sonic measurements to reservoir evaluation.
Identify factors that affect porosity and saturation interpretation in viscous hydrocarbon systems.
Integrate core-analysis results with conventional log-derived reservoir properties.
Recognise inconsistencies between logging measurements, core data, and geological observations.
Identify data quality issues that require calibration, further investigation, or qualification in technical reports.
This module focuses on nuclear magnetic resonance logging and its application to heavy oil reservoir evaluation. Participants examine the principles of NMR measurements, the significance of transverse relaxation time distributions, and the relationship between T2 responses, pore environments, and fluid characteristics.
The module explores how NMR T2 interpretation contributes to the assessment of pore-size distributions, fluid associations, and potential fluid mobility. Participants investigate the influence of viscosity, pore geometry, wettability, acquisition conditions, and interpretation assumptions on relaxation-time behaviour. The emphasis is on interpreting NMR evidence alongside other available measurements rather than relying on universal T2 cut-offs or isolated indicators.
Participants also examine the limitations of distinguishing movable hydrocarbons from restricted fluid systems. They consider why fluid mobility depends on several interacting factors, including viscosity, pore connectivity, permeability, pressure conditions, and the properties of the fluids occupying the pore network.
ASTM D445, Standard Test Method for Kinematic Viscosity of Transparent and Opaque Liquids, establishes a recognised laboratory method for determining kinematic viscosity.
Viscosity measurements provide relevant fluid-property information when assessing the behaviour of petroleum liquids.
Participants examine how laboratory viscosity data can support interpretation of heavy oil characteristics and the assessment of fluid-mobility constraints.
The method does not establish NMR T2 interpretation thresholds or directly determine reservoir producibility.
Laboratory fluid properties must be interpreted with appropriate consideration of temperature, sample representativeness, reservoir conditions, and the limitations of the measurement method.
Explain the fundamental principles of NMR logging and transverse relaxation measurements.
Interpret T2 distributions in the context of pore structure and fluid characteristics.
Assess how viscosity and pore geometry influence NMR responses.
Distinguish potential indicators of movable hydrocarbons from evidence of restricted fluid mobility.
Identify the limitations of fixed T2 cut-offs and simplified mobility classifications.
Integrate NMR results with conventional logs, core data, and available fluid-property measurements.
Document assumptions and uncertainties affecting NMR-based reservoir interpretation.
This module brings together conventional logging, NMR measurements, core-analysis results, geological observations, and reservoir information to develop a more complete interpretation of heavy oil and tarmat-bearing formations. Participants examine how individual measurements contribute to an integrated reservoir model and how inconsistencies between datasets affect confidence in the final evaluation.
The module considers tarmat distribution, reservoir continuity, porosity variation, permeability indicators, fluid saturation, and the potential effects of viscous hydrocarbon accumulation on connected pore space. Participants develop a structured approach to distinguishing reservoir-quality variations from measurement artefacts and interpretation uncertainty. Where evidence remains inconclusive, they identify additional data requirements and recommend appropriate follow-up investigations.
Integrated evaluation also addresses the communication of uncertainty. Participants learn to distinguish measured properties from interpreted parameters and model assumptions, ensuring that conclusions remain proportionate to the available evidence. The module reinforces the importance of documenting alternative interpretations and explaining the basis for reservoir classification.
ISO/IEC 17025, General Requirements for the Competence of Testing and Calibration Laboratories, establishes requirements for laboratory competence, impartiality, and consistent operation.
It provides a recognised framework for assessing the reliability of laboratory-generated measurements used in technical evaluation.
Participants consider the importance of traceable methods, appropriate equipment, quality control, and documented measurement procedures when reviewing core and fluid-analysis data.
The standard supports confidence in laboratory results but does not prescribe a specific petrophysical interpretation method or validate a reservoir model automatically.
Laboratory data must still be evaluated for sample representativeness, measurement limitations, and suitability for the intended reservoir application.
Integrate conventional logs, NMR measurements, core data, and geological information into a coherent reservoir interpretation.
Assess the potential distribution and significance of tarmat-bearing intervals.
Evaluate the relationship between porosity, permeability indicators, hydrocarbon saturation, and potential fluid mobility.
Identify inconsistencies between datasets and determine their implications for reservoir confidence.
Distinguish measured observations from interpreted properties and modelling assumptions.
Recommend further measurements or specialist investigations to resolve material uncertainties.
Prepare a structured reservoir evaluation that communicates findings, limitations, and outstanding data requirements.
This module connects petrophysical evaluation with the technical requirements of heavy oil development and thermal recovery planning. Participants examine how reservoir continuity, thickness, porosity, permeability, saturation, fluid viscosity, and the distribution of tarmat-bearing intervals influence development screening and the quality of subsurface inputs supplied to reservoir engineering teams.
The module considers the role of petrophysical evidence in evaluating steam-based recovery approaches and other suitable thermal methods. Participants explore how uncertainty in fluid mobility, reservoir connectivity, and formation properties affects recovery assumptions and the interpretation of potential development performance. The focus is on supplying reliable evidence for multidisciplinary screening rather than selecting a recovery method from petrophysical data alone.
The final module incorporates an integrated case study in which participants review a representative heavy oil reservoir dataset, identify the principal interpretation uncertainties, assess the distribution of potentially productive intervals, and prepare recommendations for further evaluation or development planning. The exercise reinforces the need to connect technical findings with operational requirements and clearly communicate the limits of the available evidence.
The Society of Petroleum Engineers Petroleum Resources Management System provides a recognised basis for classifying petroleum resources and communicating project maturity and uncertainty.
It supports the assessment of how technical evidence and development planning relate to resource categorisation.
Participants consider the relationship between reservoir evaluation findings, recovery project definition, and the technical assumptions underpinning resource estimates.
The framework encourages transparent communication of uncertainty and project status rather than presenting preliminary reservoir interpretations as confirmed commercial outcomes.
Its application complements, but does not replace, detailed reservoir simulation, economic evaluation, thermal recovery engineering, or project-specific technical assurance.
Explain how petrophysical reservoir properties influence thermal recovery screening.
Evaluate the relevance of reservoir continuity, thickness, porosity, saturation, and fluid mobility to development planning.
Identify petrophysical uncertainties that affect thermal recovery assumptions and reservoir modelling inputs.
Integrate heavy oil and tarmat evaluation findings into multidisciplinary development discussions.
Distinguish petrophysical evidence from engineering assumptions and commercial conclusions.
Recommend additional investigations that address material uncertainties before development decisions.
Present clear, evidence-based recommendations for reservoir evaluation, appraisal, and recovery planning.
Attendees who successfully complete the Heavy Oil and Tarmat Evaluation Training Course receive a Certificate of Completion from Institute For Oil & Gas Training.
The certificate recognises completion of the programme and participation in its technical learning activities. Attendees are required to meet the institute's attendance requirement for the course to qualify for the certificate. Participants should attend the required sessions and engage with the relevant course exercises and discussions in accordance with the institute's delivery arrangements.
Fees include tuition, course materials and refreshments. Need different dates or a different city? Ask about your preferred date.
The course covers heavy oil and tarmat reservoir characteristics, conventional well log interpretation, core data integration, NMR T2 interpretation, hydrocarbon mobility assessment, integrated reservoir evaluation, and thermal recovery screening. Participants learn to assess reservoir properties, identify interpretation uncertainties, and prepare evidence-based recommendations for appraisal and development planning.
Heavy oil and tarmat reservoirs present challenges associated with high viscosity, restricted fluid mobility, reservoir heterogeneity, and complex petrophysical responses. Reliable evaluation helps organisations distinguish hydrocarbon presence from potential producibility, improve reservoir characterisation, identify data gaps, and provide better-supported inputs for completion decisions and thermal recovery planning.
NMR T2 interpretation helps professionals examine relaxation-time distributions and assess their relationship with pore environments and fluid characteristics. When integrated with conventional logs, core measurements, and fluid-property data, NMR evidence supports a more informed assessment of potential fluid mobility. Interpretation must account for viscosity, pore geometry, measurement conditions, and other factors rather than relying on a single T2 threshold.
The course is suitable for petrophysicists, reservoir engineers, geologists, formation evaluation specialists, well logging professionals, core analysis specialists, production technologists, and thermal recovery specialists. It also benefits subsurface team leaders, asset development professionals, and technical managers responsible for reviewing heavy oil reservoir evaluations or supporting development decisions.
The course has an overall duration of 15 to 20 hours and is organised into five integrated modules. Attendees who meet the institute's attendance requirement receive a Certificate of Completion from Institute For Oil & Gas Training. The programme combines technical instruction, applied interpretation exercises, and integrated reservoir evaluation case studies.
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