Instructors: Mark Kittridge, MUREX Petrophysics & Rock Physics, LLC.

  • Date: Saturday, June 2, 2018
  • Time: 9:00 am – 5:00 pm
  • Fee: $375 for registered attendees; $475 non-registered (includes lunch)
  • Limit: 35 persons

About the course:

Petrophysics has a rich history of model-based interpretation relying on a variety of models constrained by properties measured on relevant rock and fluid samples. Similarly, geophysicists – and particularly those engaged in ‘rock physics’ – frequently apply both heuristic and theoretical models calibrated using measurements of elastic properties (Vp, Vs) on core samples.  Integration of these petrophysical and geophysical core data relies on established ‘seismic petrophysics’ workflows to effectively integrate lab- and well-based results to develop models applied in seismic-based reservoir characterization workflows.

In this workshop, we will examine in detail an integrated approach to the modeling of rock properties for conventional reservoir (siliciclastic, carbonate) and non-reservoir (mudrocks) lithologies where quantitative geophysical interpretation is commonly applied. The learning objective will be an increased understanding of model(s), model calibration, and the opportunity for more complete integration of petrophysics in geophysical (rock physics) modeling workflows.

Topical segments will include:

  1. Rock properties fundamentals;
  2. Seismic Petrophysics (data QC, fluid replacement modeling, and shear log estimation);
  3. Siliciclastic reservoir rock physics (unconsolidated sand, consolidated sandstone);
  4. Non-reservoir (mudrock) properties;
  5. Carbonate reservoir rock physics (calcite, dolomite); and
  6. Multi-physics integration (transport and elastic properties).

Each segment will highlight data requirements, available analog data, and details of frequently applied rock physics model(s). The workshop will emphasize an approach that seeks to develop causal model(s), grounded in realistic granular media, where attention to the ‘physics of rocks’ ensures that petrophysical and geophysical models are fully integrated.

The workshop content relies on public-domain data and reported models; no limitations are imposed by proprietary data or methods/workflows that have not been publicly documented. Course notes will include a set of annotated speaker slides and an extensive set of references.  Course format will be instructor-led discussion.



Instructors: Hanming Wang, Chevron,  Hezhu Yin, ExxonMobil Upstream Research Company,  John Rasmus, Schlumberger and Teruhiko Hagiwara, Aramco Services

  • Date: Saturday, June 2, 2018
  • Time: 9:00 am – 5:00 pm
  • Fee: $375 for registered attendees; $475 non-registered (includes lunch)
  • Limit: 35 persons

About the course:

This event is an updated version of successful course held during the 53nd & 54rd Annual Symposium in Cartagena and New Orleans.

Resistivity logs continue to gain importance in Formation Evaluation, Well Placement, Reservoir Mapping. This one-day short course describes the latest technologies in electrical logging and dielectric logging and their multiple applications in the domains of petrophysics, reserve evaluation, and real time decisions. Several topics will be covered in this one-day workshop.

Electrical Anisotropy

Resistivity anisotropy logging plays a dual role. For the petrophysicist, it is one of the preferred methods for evaluating hydrocarbon content in laminated reservoirs, including turbidites. For the geologist anisotropy logs also measure structural dip. Wireline and LWD sensors for measuring anisotropy, and practical applications of the measurements will be presented and discussed. Case study from triaxial induction logging to identify potentially by-passed low resistivity pay formation, to predict folded geological structure nearby the salt frank and many more will be shared in the class.

Dielectric Log and Resistivity Frequency Dispersion

Introduced in the 1970’s to help evaluate fresh water bearing formations, the dielectric log is also used to describe formation texture and other petrophysical parameters, based on electrical dispersion. In this topic, modern dielectric dispersion tool and interpretation methodology will be discussed. Case study will demonstrate the main applications of the dispersion measurement such as shallow resistivity curve from dielectric logging, water filled porosity independent from water salinity and “Archie” parameters, saturation in formation with variable water salinity, thin bed analysis and carbonate texture analysis and many more.

Interpretation of Resistivity Logs in HA/HZ Wells

In HAHZ wells, deep reading resistivity logs may be significantly influenced by nearby boundaries. This phenomenon sometimes called “polarization horns” which is very useful for geosteering, but detrimental for accurate formation evaluation. Advanced resistivity sensors and dedicated workflow helps lift the associated uncertainties. In this topic, we will discuss tool response characteristics of resistivity tools (wireline induction, LWD propagation, LWD azimuthal resistivity) in HAHZ well, briefly review modeling and inversion technique to achieve “true” resistivity and formation boundary and share case studies to demonstrate improving petrophysical analysis and reserve calculation through advanced processing.

LWD Deep, Ultra-Deep Azimuthal Resistivity:

Since LWD azimuthal resistivity was first introduced a decade ago followed by ultra-deep azimuthal resistivity a few years ago, the new service brought significant upside to oil business. The main application of deep, ultra-deep azimuthal resistivity are, but not limited to, well placement, reservoir mapping, geo-stopping and look-ahead. In this topic, we will discuss the measurement physics, how to interpret Picasso-plot offered by service providers, the measurement sensitivity to distance-to-boundary, to dip angle and to anisotropy. We will share the successful stories, lessons learned and the best practice through case studies.

The format will be a combination of presentations by the instructors, interactive discussion and exercises in small groups working on real problems.



Instructors: Geoff Page, Baker Hughes, a GE Company and Weijun Guo, Halliburton

  • Date: Saturday, June 2, 2018
  • Time: 9:00 am – 5:00 pm
  • Fee: $375 for registered attendees; $475 non-registered (includes lunch)
  • Limit: 35 persons

About the course:

Our petrophysics society is facing an epic challenge from multiple fronts: commodity price, people transitioning, and the need for technology innovation to develop new types of assets with lower costs. This short course is designed for G&G personnel, engineers, researchers, and supervisors to develop a broad petrophysical knowledge of data sources, applications, and how to get the most from each technology used. Subject matter experts will share their knowledge on available techniques and technologies in both open and cased wellbores for determining reservoir properties.

The introductory session will set the scene by reviewing the challenge: What do we need to know to evaluate a hydrocarbon prospect, what are the reservoir properties: Size, reservoir type/mineralogy, porosity, fluid types and volumes and producibility. Additionally information may be required both in the reservoir and in the overburden such as geomechanical properties to ensure efficient drilling and stable production, and information to confirm conceptual models.

We will start from the big picture with an overview of surface and wellbore seismic and other large-scale evaluation techniques, well testing and pressure responses. Reducing in scale – logs to fill in the finer details down to images for structure and sedimentology.

How can we identify the rocks and minerals that have been drilled in clastics and carbonates, conventional and unconventional reservoirs. What are the sources of rock related information from core, cuttings and logs, and implications of the data for reservoir quality.

What are the fluid volumes and fluid types held within the rock: Defining porosity, saturations and fluid properties. What are the advantages and limitations of available techniques.

Finally the most difficult, but also most important properties – Fluid Flow. Determining reservoir flow characteristics, permeability sources and model uncertainties. If the hydrocarbon cannot flow neither will the $$!

The focus of this course is to emphasize the practical applications of Petrophysical technologies while enhancing measurement understanding to allow optimum cost/benefit. We look forward to having you in the classroom for a 1-day interactive class.  A course survey will be collected afterwards to assist organizers in offering suitable future courses to enhance the petrophysics knowledge in our society.




Instructors: Mike Millar, Consultant

  • Date: Saturday, June 2, 2018
  • Time: 9:00 am – 5:00 pm
  • Fee: $375 for registered attendees; $475 non-registered (includes lunch)
  • Limit: 35 persons

About the course:

We will review the log quality control (LQC) issues surrounding the acquisition and use of open-hole logs, whether they are run on wireline or LWD. This course will give our less experienced colleagues the tools and insights they need to have the confidence that the logs they use are fit for purpose. There will be opportunities for the participants to explore the issues with real examples.

The course will emphasize the importance of working closely with the service company and the drilling department during the planning and acquisition of open-hole logs to ensure that the very best quality data are acquired and used in an effective manner.

Drilling changes the rocks and fluids at and near the borehole wall and all borehole measurements are affected to some extent by the drilling process. Logging tools are designed to be run in specific ways and under specific conditions, and we will explore how variations from these conditions can affect the quality of log measurements. Accuracy of depth measurements are just as important as accuracy in other log data, and we will show how depth measurements are also subject to uncertainty and potential error.

The course will highlight why the calibration and quality control of logging tools and log curves is so important. Open-hole logs are frequently the only safe and cost effective way of collecting the accurate borehole data that we need to describe the subsurface, so they add considerable value to our business.

The following topics will be covered;

  • Why do we log wells and why does log quality concern us;
    • The importance of borehole data to understanding the subsurface in the discovery and development of hydrocarbons,
    • -Planning data acquisition to get the best logs.
  • What happens when we drill a well and how does this affect data acquisition;
    • The drilling process and mud invasion,
    • Borehole quality.
  • How we get accurate and precise logs;
    • Accuracy and precision,
    • Calibration and verification,
    • Understanding depth measurements.
  • How do logging tools operate and what are their limitations;
    • Conveyancing and tool position,
    • Temperature, mud type and hole limitations,
    • Measurement uncertainty,
    • Resolution and depth of investigation.
  • Assuring the logs and our interpretations are fit for purpose;
    • Environmental corrections,
    • Recognizing and dealing with borehole issues, operational issues, and interpretation issues.



Instructors: James Howard, Consultant, Ben Lowden, RPS Energy and Paul Basan, Consultant

  • Date: Sunday, June 3, 2018
  • Time: 8:00 am – 4:00 pm
  • Fee: $375 for registered attendees; $475 non-registered (includes lunch)
  • Limit: 35 persons

About the course:

Modern-day NMR core and log technology is now nearly 30-years old. Today, we have a choice of three or four different laboratory instruments, six primary logging tools- not counting clones and old-technology tools still used in some places- and three LWD tools.  Consequently, the acquisition of NMR data, and how to use it, is a substantial topic requiring more than one-day to cover the subject thoroughly. We will therefore concentrate on the practical workflows for planning jobs, investigating data quality and interpreting the data, along with illustrations of data deliverables.  This course will demonstrate the core and log workflows the leaders find most useful for dealing with and interpreting NMR data.

The course has three sections:

  1. Introduction to NMR tools, LQC and data deliverables along with the briefest discussion on the theory;
  2. Workflows for conducting NMR laboratory experiments on conventional and unconventional rocks;
  3. Workflows for interpreting NMR log data, which includes the integration of core data and other logs.

Laboratory NMR measurements play an important role in both establishing NMR tool acquisition parameters and providing guidance on validating the tool response. Stand-alone, NMR lab measurements can also provide geological information about pore size and wettability, as well as a tool for monitor-ing dynamic experiments.

The laboratory workflow discussed in the course include the selection of the proper tests, data acquisition and processing procedures and interpretation, within the context of the three major roles of lab NMR tests. Compared to hydrocarbon liquids in conventional sandstone and carbonate reservoirs, lab NMR on organic-rich unconventional reservoir rocks has an added layer of complexity and richness due to the lower porosity, smaller pore sizes and distinct T1-T2 behavior of solid organics.

NMR logs

This part of the workshop is aimed at building a workflow for NMR log data, from the initial decision to acquire the log to the final delivery of the interpretation. The presentation is built around a hypothetical reservoir containing different lithologies and different fluids, and drawing on examples from real logs to illustrate the procedures.  Having made the case for running an NMR log, we will follow a typical FE program with a summary of the essential guidelines at each step, starting with the acquisition set up, moving through data requests, processing raw data, quick-look  evaluation,  advanced analysis, calibration to core, and the final deliverable.



Instructors: Michael Webster, Production Petrophysics Limited

  • Date: Sunday, June 3, 2018
  • Time: 8:00 am – 4:00 pm
  • Fee: $375 for registered attendees; $475 non-registered (includes lunch)
  • Limit: 35 persons

About the course:

This workshop will give attendees an introduction to fiber optics sensing in reservoirs and wells. Attendees will gain an insight into the types of fiber available, how it can be deployed, the range of measurements that can be made and how these can be applied to resolving common well and reservoir issues.  The emphasis in the workshop will be on distributed measurements rather than point measuring sensors.

The workshop will discuss the differences between the main types of fiber available, the underlying physics of the measurements, and the principles of operation for the different measurements and sensor types.

Attendees will learn about the variety of conveyance and deployment methods currently available on the market and what impacts the choice and selection of the deployment method. Some hypothetical examples will be used to illustrate the different deployment cases.

The workshop will give examples of the type of measurement available and how the operator can use fiber measurements in combination with other data to help design an integrated surveillance program to diagnose common well and reservoir performance issues. Hypothetical class examples will be used within discussion groups to explore the choices available to Operators.

The variety and range of fiber optic interrogation units will be discussed along with the flexibility in setup that can be applied to help enhance the system’s ability to identify specific well and reservoir issues.   We aim to have live demonstrations during the short course from service providers illustrating the capabilities of their interrogation units.

Examples will be shown of how this data can be integrated with other data forms to help optimize the interpretation process and generate robust well and reservoir diagnosis.

By the end of the workshop the attendee should have a grasp of the types and variety of measurement available, how fiber could be deployed in their well, and the types of well and reservoir problem the data can be used to resolve.



Instructors: Carlos Torres-Verdín, University of Texas at Austin and Michael Rabinovich, BP Americas

  • Date: Sunday, June 3, 2018
  • Time: 8:00 am – 4:00 pm
  • Fee: $375 for registered attendees; $475 non-registered (includes lunch)
  • Limit: 35 persons

About the course:

Numerical modeling is often necessary to reliably interpret well logs acquired in complex geological environments. Apparent resistivity and apparent porosity (density and neutron) logs cannot always be used as received from service companies to quantify petrophysical and compositional properties, especially in cases of spatially heterogeneous rock formations, high-angle and horizontal wells, dipping beds, presence of invasion, thin beds, and asymmetric shoulder beds, to mention but a few common cases. With the advent of fast and compact computers, well-log correction charts have become obsolete and inadequate to account for complex environmental effects on well logs. In addition, most of the modern wireline and LWD resistivity instruments such as multi-component induction, dielectric, azimuthal and extra-deep azimuthal resistivity acquire measurements that cannot be interpreted by simple log-correction techniques. Very often only numerical modeling can explain the observed measurement behavior and inversion or iterative forward modeling are the only options available to estimate accurate formation properties from a multitude of measurements, especially in well geosteering applications. The purpose of this practical and interpretation-oriented workshop is to describe and exercise the basic principles and concepts behind the numerical simulation and inversion of nuclear and resistivity logs, with emphasis on hands-on demonstrations, numerical modeling and field cases. Participants will be able to identify and examine specific field conditions where numerical modeling and inversion are the proper alternative to interpret well logs. Hands-on demonstrations will be given about the benefits and limitations of numerical modeling and inversion. At the end of this course, participants will be able to assess when modeling and inversion are or are not needed in the interpretation of resistivity and nuclear logs; they will also have a practical formative base to resort to numerical modeling and inversion in the planning of their logging operations.


  • Introduction to concepts and principles of resistivity and nuclear log modeling.
  • Live demonstrations of modeling in vertical and high-angle wells:
    • Effects of thin beds on resistivity, gamma-ray, density, and neutron logs.
    • Modeling in vertical wells: shoulder-bed effects, thin beds, non-asymmetric shoulder effects, resistivity contrast, induction and laterolog, invasion effects.
    • Modeling in high-angle wells: relative dip effects, resistivity anisotropy effects, and “horn” effects.
  • Introduction to concepts and principles of resistivity and nuclear log inversion. Automatic and user-guided inversion methods: Quo Vadis Inversion?
  • Field cases of modeling and benefits to petrophysical interpretation.
  • Best practices for when to model and when not to model well logs.
  • Distance-to-boundary inversion in well geosteering applications
  • Conclusions, recommendations, and best practices.



Instructors: Adam Moss, AKM Geoconsulting, Jules Reed, Lloyd’s Register and Craig Lindsay, Core Specialist Services Limited

  • Date: Sunday, June 3, 2018
  • Time: 8:00 am – 4:00 pm
  • Fee: $375 for registered attendees; $475 non-registered (includes lunch)
  • Limit: 35 persons

About the course: (All participants should bring a laptop or equivalent with MS Excel capability)

Data acquired from core acquired over hydrocarbon bearing formations is of profound importance in formation evaluation and reservoir modelling. Core studies cover petrophysics, reservoir engineering and many other critically important disciplines. From a petrophysicists viewpoint core data benchmarks log calibration and interpretation.

Yet, the value & validity of core data is dependent upon a number of factors which may not be apparent to the non-expert. Effective quality control of laboratory studies and the resultant data is one of the most critical factors.

The objective of the short course is to provide the attendees with an overview of the principals of core selection, porosity and permeability from core and application of core capillary pressure data for the purpose of saturation modelling in the reservoir model. The critical importance of robust Quality Control and the relative importance of reservoir parameters impacting hydrocarbon volume and saturation is illustrated by a strong emphasis on practical exercises.

We have access to a 20m section of Southern North Sea core which if possible we would like to have out on display during the workshop. This will be used as a focal point for a lot of the day’s discussions.

How to design an effective core selection workflow – Adam Moss

  • Methods for defining core heterogeneity and fine scale mineralogy
  • Discussions on scale of measurement, representative volume element and upscaling
    • Exercise – Core viewing and discussion on log vs core plug scale of measurement
  • Core plug sampling strategies
  • Rock Typing
    • Exercise – Defining flow zone index groups
    • The Fundamentals of Core Porosity & Permeability – Jules Reed
  • Porosity
  • Theory and measurement, Effective vs total porosity, Porosity Errors, Effect of Difficult Lithologies (vuggy, conglomerate, low reservoir quality)
  • Impact on saturation and electric correlations (m, n)
    • Exercise – calculate and compare porosity (including errors and Sw impact)
  • Permeability
  • Absolute, Effective
  • Gas, Klinkenberg, Liquid/
    • Exercise – calculate Klinkenberg permeability & derive RCA transform
  • Stressed Conditions
  • Porosity compaction factor (PCF)
  • Permeability correction factor (KCF)
  • QC, data correlations, interpretation & impact on GIP/OIP
    • Exercise – Calculate and QC PCF data, determine impact in GIP
    • Exercise – Calculate KCF and determine impact on reservoir flow
    • Capillary Pressure (Pc) & Saturation Height Modelling – not all Pc curves are equal – Craig Lindsay
  • Introduction – Overview of theory and concepts
    • Exercise – Convert reservoir to laboratory units
  • Laboratory measurement methods
    • Exercise – Apply Forbes solution to model centrifuge data
  • Quality Control of laboratory Pc data
    • Exercise – Excluding erroneous data
  • Data corrections
    • Exercise – Impact of stress, fluids and clay on Sw
  • Saturation Height Functions – An Overview
    • Exercise – Illustrating why Pc curve QC is so important
  • Fluid contacts
    • Exercise – Impact of rock quality and FWL on reservoir volumetrics
  • Open Discussion

All participants will be provided with a flash drive containing interactive spreadsheets in Excel format for each exercise and additional worked examples, plus the presentation material.