Core Analysis for Reservoir Characterization

RCM/CONSCAL

Who should attend?

  • This course provides a comprehensive and practical understanding of methods, procedures and issues related to laboratory conventional and special core analysis for describing and evaluating reservoir rock properties, and all considerations that should be taken into account for reservoir characterization.
Audience :
  • Geoscientists, petrophysicists, reservoir engineers, petroleum engineers and other E&P professionals willing to deepen their knowledge in conventional and special core analysis.

Level : Proficiency

Course Content

  • CORING & CORE ANALYSIS

      • Introduction.
      • Business value of core analysis demonstrated on real life examples.
      • Necessary quality procedures at the start of a measurement program.
      • Coring methods (conventional vs. pressure coring, decompression during tripping).
      • Core preservation.
      • Core cleaning.
      • Representative wettability (fresh vs. restored state).
      • Conventional and Special Core Analysis (SCAL).
  • GENERALITIES ON TWO-PHASE FLOW PROPERTIES

      • Darcy’s law for two phases, relative permeability.
      • Capillary pressure.
      • Wettability (Amott and USBM methods).
      • Impact of wettability on relative permeability and capillary pressure.
      • Basics of JBN analysis for the UnSteady-State experiment.
      • Effect of capillary pressure demonstrated by hands-on simulation, using the SCORES SCAL simulator.
  • CONVENTIONAL CORE ANALYSIS

      • Porosity definition and measurement.
      • Permeability (absolute) definition and measurements.
      • Formation factor and Resistivity Index definition and measurement.
      • Mercury injection (MICP) for reservoir saturation height function and pore size distribution.
      • Recent developments in MICP showing important problems in MICP for low permeability rock when assessing transition zones.
  • SPECIAL CORE ANALYSIS (SCAL), MEASUREMENTS OF SCAL PROPERTIES

      • Overview of measurement methods and data interpretation for relative permeability and capillary pressure.
      • Steady-state technique, in-situ saturation monitoring.
      • Unsteady-state technique, in-situ saturation monitoring.
      • Multi-speed centrifuge technique.
      • Single-speed centrifuge technique.
      • Porous plate technique.
      • Analysis of centrifuge data using Hassler-Brunner, Forbes methods.
      • Analysis of centrifuge data using Hagoort method.
      • Effect of relative permeability on capillary pressure measurement demonstrated by hands-on simulations using the SCORES SCAL simulator.
  • QUALITY CONTROL OF AVAILABLE DATA

      • Sample selection using X-ray CT for homogeneity assessment.
      • Representative wettability, special considerations for transition zones.
      • Recognizing unusual features.
  • AVERAGING PETROPHYSICAL PROPERTIES

      • Saturation height function assessment.
      • Leverett-J function.
      • Initial water saturation.
      • Rock typing.
      • Gridding for reservoir simulation.
  • DESIGN OF SCAL PROGRAM

      • Demonstration step-by-step approach.
      • Establish SCAL program objective.
      • Understanding of strength and weaknesses of each SCAL method.
      • Need for imbibition capillary pressure to interpret relative permeability data.

Learning Objectives

  • Upon completion of the course, participants will be able to:
  • discuss rock properties used in reservoir modeling and reservoir simulation models,
  • discuss, interpret and validate a CCAL and a SCAL report and review a quality control process,
  • design a SCAL program with regard to given objectives.

Ways & Means

  • Highly interactive course alternating theory, exercises and field cases.
  • Use of the SCAL (Special Core Analysis) license free simulator SCORES.