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SPE Papers - Reservoir Description - Reservoir Engineering

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SPE Papers - Reservoir Description - Reservoir Engineering Powered By Docstoc
					  Nov-09
NOTES:

           The papers listed here have been obtained by search SPE and IPTC papers post 2005 on the SPE's OnePetro
           The papers relating to reservoir engineering have been catergorised for inclusion on the   reservoirengineering.org.uk website
           The affiiations searched were;

                                                                    Total No Papers     Reservoir Engineering Related
                      BP                                                   551                      175
                      Shell                                                575                      279
                      Chevron                                              482                      238
                      ConocoPhillips                                       191                       68
                      Marathon                                             55                        37
                      Total                                                255                      129
                      Schlumberger                                        1130                      563
                      Imperial College, London                             95                        53
                      Heriot Watt University, Edinburgh                    235                      175
                      (Anywhere in Article)
                                                      Total               3569                          1717



                      Total number of papers published post 2005 =             10,000

                                                                   35% of papers published categorised
                                Paper
Organisation             Source No.           Chapter                         Section
TOTAL                      SPE    90226   Reservoir Description        Anisotropic Permeabilities
TOTAL                      SPE   102659   Reservoir Description        Anisotropic Permeabilities
SCHLUMBERGER               SPE   106100   Reservoir Description      Borehole Image Interpretation
SCHLUMBERGER               SPE   101897   Reservoir Description            Capillary Pressure
TOTAL                      SPE   111410   Reservoir description          Carbonate reservoirs
TOTAL                      SPE   118333   Reservoir Description          Carbonate reservoirs
SHELL                      SPE   109094   Reservoir Description       Carbonate Transition Zone
SCHLUMBERGER               SPE   116328   Reservoir Description       Deep Electromagnetic Data
SCHLUMBERGER              IPTC    11622   Reservoir Description        Depositional Environment
SCHLUMBERGER              IPTC    12253   Reservoir Description        Depositional Environment
SCHLUMBERGER               SPE   121945   Reservoir Description        Depositional Environment
SCHLUMBERGER               SPE   108566   Reservoir Description         Downhole Fluid Analysis
SCHLUMBERGER               SPE   108925   Reservoir Description         Downhole Fluid Analysis
SHELL                      SPE   100937   Reservoir Description         Downhole Fluid Analysis
SHELL                      SPE   108566   Reservoir description         Downhole Fluid Analysis

BP                         SPE   105412   Reservoir Description                EOS/SCAL
Imperial College           SPE   100333   Reservoir Description            Facies Connectivity
CONOCO                     SPE   110542   Reservoir Description           Fault Zone Modelling
SCHLUMBERGER               SPE   105014   Reservoir Description        Flow Unit Characterisation
SCHLUMBERGER               SPE   120407   Reservoir Description        Flow Unit Characterisation
Heriot Watt University     SPE   105800   Reservoir Description          Flow Unit Determinaton
CONOCO                     SPE   109971   Reservoir Description           Formation Evaluation
CONOCO                     SPE   110340   Reservoir Description           Formation Evaluation
SCHLUMBERGER               SPE    97224   Reservoir Description           Formation Evaluation
SCHLUMBERGER               SPE   100351   Reservoir Description           Formation Evaluation
SCHLUMBERGER               SPE   101718   Reservoir Description           Formation Evaluation
TOTAL                     IPTC    12849   Reservoir Description           Formation Evaluation
MARATHON                   SPE   123932   Reservoir description           Formation Evaluation
CONOCO                     SPE   103803   Reservoir Description           Formation Evaluation
CONOCO                     SPE   115045   Reservoir Description           Formation Evaluation
TOTAL                      SPE   117908   Reservoir Description           Formation Evaluation
SCHLUMBERGER               SPE   116591   Reservoir Description           Formation Evaluation
SCHLUMBERGER               SPE   119690   Reservoir Description           Formation Evaluation
SCHLUMBERGER               SPE   118380   Reservoir Description           Formation Evaluation
SCHLUMBERGER               SPE   110277                       F
                                          Reservoir Description ormation Evaluation - Enhanced description
SCHLUMBERGER               SPE   102888   Reservoir Description Formation Evaluation - Heterogeneity
SCHLUMBERGER               SPE   110223   Reservoir Description Formation Evaluation - Heterogeneity
SHELL                      SPE   110223   Reservoir Description Formation Evaluation - Heterogeneity
SCHLUMBERGER               SPE   102256   Reservoir Description Formation Evaluation - Heterogeneity
SCHLUMBERGER               SPE   110752   Reservoir Description Formation Evaluation - Heterogeneity

CHEVRON                   SPE    109848   Reservoir Description Formation Evaluation - Heterogeneity
SCHLUMBERGER              SPE    109848   Reservoir Description Formation Evaluation - Heterogeneity
SCHLUMBERGER              SPE    102572   Reservoir DescriptionFormation Evaluation - Horizontal Injectors
SCHLUMBERGER              SPE    121923   Reservoir DescriptionFormation Evaluation - Integrated Well Data
BP                        SPE    116853   Reservoir DescriptionFormation Evaluation - Integrated Well Data
SCHLUMBERGER              SPE    120443   Reservoir Description Formation Evaluation - Unconsolidated
TOTAL                     SPE    105456   Reservoir Description   Fracture and Fault Characterisation
Imperial College   SPE    94186    Reservoir Description           Fracture Connectivity

Imperial College    SPE   100229   Reservoir Description          Fracture Connectivity
TOTAL               SPE   128339   Reservoir Description       Fracture Pressure Prediction
SCHLUMBERGER        SPE   101343   Reservoir Description             Geomechanical
SCHLUMBERGER        SPE   101286   Reservoir Description              Geo-Modelling
SCHLUMBERGER        SPE   101913   Reservoir Description               Geostatistics
SCHLUMBERGER        SPE   115836   Reservoir Description               Geostatistics
CHEVRON            IPTC    12877   Reservoir Description              Heterogeneity
SCHLUMBERGER        SPE   101126   Reservoir Description              Heterogeneity
CHEVRON             SPE   102435   Reservoir Description              Heterogeneity
SCHLUMBERGER        SPE   102435   Reservoir Description              Heterogeneity
SCHLUMBERGER        SPE   122585   Reservoir Description           LWD Interpretation


CHEVRON             SPE   109972   Reservoir Description            LWD Interpretation
SCHLUMBERGER        SPE   109972   Reservoir Description            LWD Interpretation
SCHLUMBERGER        SPE   126044   Reservoir Description            LWD Interpretation
SHELL              IPTC    12191   Reservoir Description             Magnetic Imaging
BP                  SPE   108139   Reservoir Description       Mechanical Rock Properties
SCHLUMBERGER        SPE   116092   Reservoir Description     Mechanism - Stress Orientation
BP                  SPE   105411   Reservoir Description      Modelling - Capillary Pressure
SCHLUMBERGER        SPE   126094   Reservoir Description   Modelling - Geomechanical Properties
SHELL               SPE   114854   Reservoir Description        Modelling - Heterogeneity
SCHLUMBERGER        SPE    95841   Reservoir Description     Modelling - Near Wellbore Stress
SHELL               SPE    95841   Reservoir Description     Modelling - Near Wellbore Stress
SHELL               SPE   118332   Reservoir Description            Modelling - Outcrop
SCHLUMBERGER        SPE   101721   Reservoir Description          Multi-Layered Reservoir
SCHLUMBERGER        SPE   102588   Reservoir Description          Multi-Layered Reservoir
SCHLUMBERGER        SPE   104013   Reservoir Description          Multi-Layered Reservoir
SCHLUMBERGER        SPE   105427   Reservoir Description    Natural Fracture Characterisation
SCHLUMBERGER        SPE   118895   Reservoir Description    Natural Fracture Characterisation
                                                                      Natural Fracture
BP                 SPE    107418   Reservoir Description              Characterisation
SCHLUMBERGER       SPE    103284   Reservoir Description    Natural Fracture Characterisation

CHEVRON            SPE    121293   Reservoir Description       Natural Fracture Detection
SCHLUMBERGER       SPE    105456   Reservoir Description Natural Fracture/Fault Characterisation
SHELL              SPE     90002   Reservoir Description      Naturally Fracture Detection
SCHLUMBERGER       SPE    102562   Reservoir Description     Naturally Fractured Reservoirs
SCHLUMBERGER       SPE    116068   Reservoir Description    Near Wellbore Flow Properties
SCHLUMBERGER       SPE    117073   Reservoir Description    Near Wellbore Flow Properties
SCHLUMBERGER       SPE    110304   Reservoir Description    Near Wellbore Flow Properties
TOTAL              SPE    110304   Reservoir Description    Near Wellbore Flow Properties
SCHLUMBERGER       SPE    112385   Reservoir Description          Near Wellbore Stress
Imperial College   SPE     95428   Reservoir Description            Net Pay Cutoffs
SCHLUMBERGER       SPE    107192   Reservoir Description           NMR Interpretation
SCHLUMBERGER       SPE    115822   Reservoir Description           NMR Interpretation
TOTAL              SPE    115822   Reservoir Description           NMR Interpretation


CHEVRON            SPE    90539    Reservoir Description            NMR Interpretation
SCHLUMBERGER             SPE    110301   Reservoir Description           NMR Interpretation
SCHLUMBERGER             SPE    110803   Reservoir Description           NMR Interpretation
SCHLUMBERGER             SPE     89177   Reservoir Description              NMR Logging
SCHLUMBERGER             SPE    107241   Reservoir Description          Oil Interval Detection
Heriot Watt University   SPE    107263   Reservoir Description               Permeability

CHEVRON                  SPE    102894   Reservoir Description               Permeability
CHEVRON                  SPE    103486   Reservoir Description               Permeability
SHELL                    SPE    115347   Reservoir Description               Permeability
SHELL                    SPE    110472   Reservoir Description         Permeability Prediction
BP                       SPE    109646   Reservoir Description     Permeability/Saturation Analysis
TOTAL                    SPE    116393   Reservoir description   Petrophysical Property Determination
SCHLUMBERGER             SPE    120813   Reservoir Description            PLT Interpretation

CHEVRON                  SPE     96308   Reservoir Description           Porosity Modelling
SCHLUMBERGER             SPE    101176   Reservoir description     Porosity/Permeability Analysis
TOTAL                    SPE    102093   Reservoir Description     Porosity-Permeability Modelling
SCHLUMBERGER             SPE     93974   Reservoir Description       Productivity Interpretation
SHELL                    SPE    106756   Reservoir Description       Productivity Interpretation


CHEVRON                   SPE   102741   Reservoir Description     Relative Permeability Correlation
Heriot Watt University    SPE    83960   Reservoir Description     Relative Permeability Correlation
BP                       IPTC    11576   Reservoir Description          Reservoir Architecture
SCHLUMBERGER              SPE   118152   Reservoir Description          Reservoir Architecture
SHELL                     SPE   100449   Reservoir Description          Reservoir Architecture
SHELL                     SPE   105015   Reservoir Description          Reservoir Architecture
SCHLUMBERGER              SPE   100740   Reservoir Description          Reservoir Architecture
SCHLUMBERGER              SPE   109683   Reservoir Description          Reservoir Architecture
SHELL                     SPE   100740   Reservoir Description          Reservoir Architecture
SHELL                     SPE   109683   Reservoir Description          Reservoir Architecture
SHELL                     SPE   109861   Reservoir Description          Reservoir Architecture



CHEVRON                  IPTC    11488   Reservoir Description         Reservoir Connectivity
SCHLUMBERGER             IPTC    11488   Reservoir Description         Reservoir Connectivity
SCHLUMBERGER              SPE   104018   Reservoir Description          Reservoir Properties
SCHLUMBERGER             IPTC    11350   Reservoir Description         Residual Oil Saturation
TOTAL                     SPE    88756   Reservoir Description        Saturation Height function
Heriot Watt University    SPE   107142   Reservoir Description       Saturation Height Functions
SHELL                    IPTC    11415   Reservoir Description                  SCAL

CHEVRON                  SPE    109810   Reservoir Description                  SCAL

CHEVRON                  SPE    110515   Reservoir Description                  SCAL

CHEVRON                   SPE   114183   Reservoir Description                 SCAL
CONOCO                   IPTC    11813   Reservoir Description         Shared Earth Modelling
TOTAL                    IPTC    11813   Reservoir Description         Shared Earth Modelling
CHEVRON                  SPE   105087   Reservoir Description     Static Reservoir Model
TOTAL                    SPE   123624   Reservoir description     Static Reservoir Model
CONOCO                   SPE   103083   Reservoir Description     Static Reservoir Model
TOTAL                    SPE   103083   Reservoir Description     Static Reservoir Model
CONOCO                   SPE   100307   Reservoir Description     Static Reservoir Model
TOTAL                    SPE   111912   Reservoir Description     Static Reservoir Model
TOTAL                    SPE   101945   Reservoir description     Static Reservoir Model

Imperial College         SPE   100250   Reservoir Description     Static Reservoir Model
TOTAL                    SPE   105423   Reservoir Description     Sweet Spot Detection

Imperial College         SPE    95594   Reservoir Description       WAG Rel Perms
MARATHON                 SPE   113342   Reservoir Description   Water Saturation Estimation
SHELL                    SPE    93624   Reservoir Description    Wettability Determination
Heriot Watt University   SPE   126088   Reservoir Description     Wettability Evaluation
SCHLUMBERGER             SPE   120691   Reservoir Description               WFT
SCHLUMBERGER             SPE   100738   Reservoir Description               WFT
SHELL                    SPE   100738   Reservoir Description               WFT
SCHLUMBERGER             SPE   102456   Reservoir Description               WFT
SCHLUMBERGER             SPE   102413   Reservoir Description               WFT
                        Subject
                Probe Formation test Analysis
                Probe Formation test Analysis
                         Case Study
                    Carbonate Reservoir
                   Stochastic simulations
                        Subtle Faults
                    Carbonate Reservoir
                        Heterogeneity
                      Borehole Images
                      Borehole Images
                    Integrated Well Data
                 Reservoir Characterisation
                 Reservoir Characterisation
                 Reservoir Characterisation
                 Reservoir Characterisation
                    Impact on Reservoir
                        Performance
                     Percolation Theory

                Carbonate Reservoir
                  Deltaic Reservoir
                    DaQing Field
               Deep Reading Resitivity
                        LWD
                        LWD
                        LWD
                LWD vs Gamma Ray
                Neutron Spectroscopy
                     NMR Data
            Pressure Testing while Drilling
            Pressure Testing while Drilling
            Pressure Testing while Drilling
                 Shaly Sand Analysis
                 Shaly Sand Analysis
                      Workflow
           Carbonate and Clastic Reservoirs
                Carbonate Reservoir
                     Deepwater
                     Deepwater
                Perforation Selection
                      Turbidites

Heterogeneity
Heterogeneity
                      LWD Modelling
                   Cambrian Reservoirs
                  Pre-Cambrian Reservoir
                        Deepwater
                High-Resolution Image Logs
     Percolation Theory

    Percolation Theory
        Deepwater
   Carbonate Reservoirs
    Channel Deposition
       Kharaib Field

          Analysis
Formation Evaluation Methods
            NMR
            NMR
  Mediterranean Reservoirs




         Deepwater

     Horizontal Wells
   Carbonate Reservoirs
        Prediction
    Turbidite Channels
        Algorithm
        Algorithm
        Carbonate
    PLT Interpretation
    PLT Interpretation
    PLT Interpretation
     Borehole Seismic
   Formation Evaluation

       Geomechanical
      Integrated Study

      PLT Interpretation
      Borehole Images
   After-Closure Analysis
        Maloichskoe
   Downhole Monitoring
   Downhole Monitoring
    Integrated Well Data
    Integrated Well Data

         Application
     Fractured Clastics
  Optimised WFT Sampling
  Optimised WFT Sampling
     Formation Evalustion
     Carbonate Reservoir

      PLT Interpretation
      PLT Interpretation
     Representative scale
   From Pore Space Images
      LWD Interpretation
       3D Core Scanner
       Horizontal Wells

     Carbonate Reservoirs
     Carbonate Reservoirs
       Statistical Pitalls
             UBD
             UBD


       Gas Condensate
       Gas Condensate
          Connectivity
       Fracture Fairways
       Fracture Fairways
       Fracture Fairways
     Integrated Well Data
     Integrated Well Data
     Integrated Well Data
     Integrated Well Data
     Integrated Well Data



    Downhole Fluid Analysis
    Downhole Fluid Analysis
       PLT Interpretation
     Pulsed Neutron Decay
      Carbonate Reservoirs
Different Estimation Approaches
           Case study

       Gas Condensate

        Thermal Tests

        Thermal Tests
      Seismic Integration
      Seismic Integration
         Case Study
           Dunbar
      minimodels - SAG
      minimodels - SAG
         Permeability
        Seismic Data
      Seismic Upscaling


      Seismic attributes

     Pore Scale Modelling
    Equivalent Rck Element
       NMR Interpretation
      Carbonate Reservoir
        Deltaic Reservoir
      Optimised Sampling
      Optimised Sampling
Stress/Permeability Measurment
         Supercharging
                                               Title
Concept of Geometric Factor and Its Practical Application To Estimate Horizontal and Vertical Permeabilities
Analytical Steady-State Solution of Single-Probe Tests in a Horizontal Well and Its Application to Estimate Horizontal and Vertic
The Importance of Hole Quality for Effective Image Log Interpretation Clearly Demonstrated in an Eight Well Program in Kuwai
Application of NMR T2 Relaxation for Drainage Capillary Pressure in Vuggy Carbonate Reservoirs
Nested Stochastic Simulations: A New Approach in Assessing Spatial Distribution of Carbonate Sedimentary Facies and Assoc
Subtle Faults in Carbonate Reservoirs
Improved Characterization and Modeling of Capillary Transition Zones in Carbonate Reservoirs
Characterization of Reservoir Heterogeneity Through Fluid Movement Monitoring With Deep Electromagnetic and Pressure Me
Integration of borehole image log enhances conventional electrofacies analysis in dual porosity carbonate reservoirs
Reconstructing Sedimentary Depositional Environment With Borehole Imaging and Core: A Case Study From Eastern Offshore
Sedimentary Facies Computation and Stratigraphic Analyses Using Well Logs, Borehole Images and Cores in Triassic Fluvial S
New Downhole-Fluid-Analysis Tool for Improved Reservoir Characterization
Reservoir Fluid Characterization Using Downhole Fluid Analysis in Northern Kalimantan, Indonesia
Downhole Fluid Analysis and Fluid-Comparison Algorithm as Aid to Reservoir Characterization
New Downhole-Fluid-Analysis Tool for Improved Reservoir Characterization

Implication of Properly Tuned EOS and Properly Measured SCAL on Prediction of Rates, Reserves, and Field Performance usi
Facies Connectivity Modelling: Analysis and Field Study
Fluid Flow in a Fractured Reservoir Using a Geomechanically-Constrained Fault Zone Damage Model for Reservoir Simulation
Porosity Partitioning and Flow Unit Characterization From an Integration of Magnetic-Resonance and Borehole-Image Measure
Flow Unit Characterization and Geo-modeling of a Structurally Complex Fluvio-deltaic Reservoir using an Integrated Approach
Principle of a New Flow-unit Auto-subdividing Method and its Application in DaQing Oilfield
A New Azimuthal Deep-Reading Resistivity Tool for Geosteering and Advanced Formation Evaluation
Combining Advanced Real-Time LWD Answers With Accurate and Flexible 3D Rotary-Steerable System for Proactive Reservo
A New-Generation LWD Tool With Colocated Sensors Opens New Opportunities for Formation Evaluation
New Developments in Sourceless Logging-While-Drilling Formation Evaluation: A Case Study From Southern Italy
Why the LWD and Wireline Gamma Ray Measurements May Read Different Values in the Same Well
Comparison of Conventional Log Interpretation With Neutron Spectroscopy Log and X-Ray Diffraction Laboratory Analysis: A C
Utilizing Simultaneous Capture of T1 and T2 NMR Data to Solve Reservoir Evaluation Issues
Formation Pressure Testing While Drilling in Bohai Bay's Challenging Environment
Reservoir Fluid Evaluation from Real Time Pressure Gradient Analysis: Discussions on Principles, Workflow, and Applications
The Value of Formation Pressure Measurements While-Drilling a Case Study from Offshore Abu Dhabi
Development of Water Saturation Error Analysis Charts for Different Shaly Sand Models for Uncertainty Quantification of Volum
Development of Water Saturation Error Analysis Charts for Different Shaly Sand Models for Uncertainty Quantification of Volum
A New Workflow for Comprehensive Petrophysical Characterization of Carbonate Reservoirs Drilled with Water-Base Muds
Enhanced Reservoir Description in Carbonate and Clastic Reservoirs
Case Study of Permeability, Vug Quantification, and Rock Typing in a Complex Carbonate
Applications of NMR Logs and Borehole Images to the Evaluation of Laminated Deepwater Reservoirs
Applications of NMR Logs and Borehole Images to the Evaluation of Laminated Deepwater Reservoirs
Integration of Borehole Imaging, Open Hole Logs, Nuclear Magnetic Resonance/Modular Dynamic Tester, and Advanced Prod
Evaluation of Low-Resistivity-Pay Deepwater Turbidites Using Constrained Thin-Bed Petrophysical Analysis

Formation Evaluation in Thin Sand/Shale Laminations
Formation Evaluation in Thin Sand/Shale Laminations
Formation Evaluation of Horizontal Water Injectors Drilled in Thick Carbonate Reservoirs: Behind-Casing-Analysis and LWD R
Integration of Production, Pressure Transient and Borehole Images in Horizontal Wells Drilled in Cambrian Sandstone Reservo
Using Resistivity Log Invasion Profiles, Multiple Porosity Logs, Core and Test Data to Determine Lithology, Porosity and Perme
Specialized Techniques for Formation Testing and Fluid Sampling in Unconsolidated Formations in Deepwater Reservoirs
Characterization of Fractures and Faults From High-Resolution Image Logs To Optimize the Geological Model of a Fractured C
Fast Estimation of Connectivity in Fractured Reservoirs Using Percolation Theory

Connectivity Prediction in Fractured Reservoirs With Variable Fracture Size: Analysis and Validation
Deep Offshore Fracture Pressure Prediction in the Niger Delta – A New Approach
Geomechanics Insight Into Discrepancies of Core to Image Log Discontinuities and Implications for a Lower Cretaceous Carbo
Exploration Potential of Sinuous (Channellike) Events in Late Cretaceous of Al-Khafji Field, Middle East
Understanding a Reservoir: 3D Geological Modelling Using Scenario-Based Approach and Conventional Geostatistics, Onshor
Frequentist Meets Spatialist: A Marriage Made in Reservoir Characterization and Modeling
Static Connectivity and Heterogeneity (SCH) Analysis and Dynamic Uncertainty Estimation
Methods for Real-Time and High-Resolution Formation Evaluation and Formation Testing of Thinly Bedded Reservoirs in Explo
NMR Petrophysics in Thin Sand/Shale Laminations
NMR Petrophysics in Thin Sand/Shale Laminations
Successful Application of New LWD Platform Provides Integrated Real-Time Formation Evaluation in the Mediterranean Reser

Improving LWD Image and Formation Evaluation by Utilizing Dynamically Corrected Drilling-Derived
LWD Depth and Continuous Inclination and Azimuth Measurements
Improving LWD Image and Formation Evaluation by Utilizing Dynamically Corrected Drilling-Derived LWD Depth and Continuou
From Issues to Solutions – Introducing the Multi Function Logging While Drilling Tool for Reservoir Characterization in the Gr
Recent CSEM Learnings in Deepwater Borneo
A Composite Determination of Mechanical Rock Properties for Stimulation Design (What to Do When You Don’t Have a So
Stress Reorientation Around Horizontal Wells
An Empirical Saturation Modeling of a Complex Carbonate Abu Dhabi Reservoir Using the Routine High-Pressure Mercury and
Prediction of Rock Mechanical Parameters for Hydrocarbon Reservoirs Using Different Artificial Intelligence Techniques
Simplified Modeling of Turbidite Channel Reservoirs
Estimation of Near-Wellbore Alteration and Formation Stress Parameters From Borehole Sonic Data
Estimation of Near-Wellbore Alteration and Formation Stress Parameters From Borehole Sonic Data
Simulating the Outcrop: Surface To Subsurface Integration of a Carbonate Reservoir, Khuff Formation, Oman
Characterization of Multilayer Reservoir Properties Using Production Logs
Characterization of Commingled Reservoir Properties With Production Logs
Evaluation of Commingled Reservoir Properties Using Production Logs
An Approach to Fracture Characterization Using Borehole Seismic Data
Integrated Fracture Study using Formation Micro Imager, Stoneley Waves and Formation Evaluation Results in Carbonate Res

Effects of Stress on Fracture Properties of Naturally Fractured Reservoirs
Continuous Fracture Modeling of a Carbonate Reservoir in West Siberia

Using PLT Data to Estimate the Size of Natural Fractures
Characterization of Fractures and Faults From High-Resolution Image Logs To Optimize the Geological Model of a Fractured C
After-Closure Analysis To Identify Naturally Fractured Reservoirs
Application of an Integrated Approach for the Characterization of a Naturally Fractured Reservoir in the West Siberian Baseme
Determination of In-Situ Two-Phase Flow Properties Through Downhole Fluid Movement Monitoring
The Impact of the Downhole Formation Tester with Comprehensive Data Integration in Pre-Khuff Hydrocarbon Exploration
An Investigation of Near-Wellbore Flow Properties Using Sonic Scanner Measurements and Interval Pressure Transient Testin
An Investigation of Near-Wellbore Flow Properties Using Sonic Scanner Measurements and Interval Pressure Transient Testin
Radial Profiling for Completion Effectiveness With New Sonic Measurement in the Gulf of Thailand
The Application of Cutoffs in Integrated Reservoir Studies
Porosity With Nuclear Magnetic Resonance in Naturally Fractured Clastics Reservoirs in the Devonian of the Bolivian Sub-And
Using the Continuous NMR Fluid Properties Scan to Optimize Sampling with Wireline Formation Testers
Using the Continuous NMR Fluid Properties Scan to Optimize Sampling with Wireline Formation Testers

Limits of 2D NMR Interpretation Techniques to Quantify Pore Size, Wettability, and Fluid Type: A
Numerical Sensitivity Study
The Application of NMR Logs for the Evaluation of Gas Reservoirs With Low Salinity Formation Waters
Porosity Determination From NMR Log Data: The Effects of Acquisition Parameters, Noise, and Inversion
Advances in NMR Logging
Optimization of the Prediction of Hydrocarbon-Producing Zones Through Integration of Petrophysical Evaluation Methodologies
Permeability Estimation Using Hydraulic Flow Units in Carbonate Reservoirs

Permeability From Production Logs - Method and Application
Permeability From Production Logs—Method and Application
Finding the Continuum Scale in Highly Heterogeneous Rocks: Example of a Large Touching Vug Carbonate
Permeability Predictions Based on Two-Dimensional Pore Space Images
Permeability and Saturation Evaluation in Deepwater Turbidite Utilizing Logging-While-Drilling Low-Gradient Magnetic Resonan
Petrophysical Properties Prediction Using 3D Core Scanner Imagery
Comprehensive Reservoir Characterization with Multiphase Production Logging
3D Porosity Modeling of a Carbonate Reservoir Using Continuous Multiple-Point Statistics
Simulation
A New Porosity Partitioning-Based Methodology for Permeability and Texture Analysis in Abu Dhabi Carbonates
Three Statistical Pitfalls of Phi-K Transforms
Simulation of Inflow While Underbalanced Drilling With Automatic Identification of Formation Parameters and Assessment of U
Use of a New Rate-Integral Productivity Index in Interpretation of Underbalanced Drilling Data for Reservoir Characterization


Relative Permeability of Gas-Condensate Fluids: A General Correlation
Variations of Gas/Condensate Relative Permeability With Production Rate at Near-Wellbore Conditions: A General Correlation
Multi-Disciplinary Reservoir Description to Characterize Connectivity in a Complex Minibasin Fill: an Integrated Approach at Ho
Utilizing Real Time Logging While Drilling Resistivity Imaging to Identify Fracture Corridors in a highly fractured Carbonate Rese
Estimating Percentage of Fracture Fairways Detectible by Seismic Data-Two Case Studies From Oman
Devising Knowledge-Based Decision Tree for Detection of Fracture Corridors From Dynamic Data in a Carbonate Reservoir in
Combining Continuous Fluid Typing, Wireline Formation Testers, and Geochemical Measurements for an Improved Understan
Improved Interpretation of Reservoir Architecture and Fluid Contacts Through the Integration of Downhole Fluid Analysis With G
Combining Continuous Fluid Typing, Wireline Formation Testers, and Geochemical Measurements for an Improved Understan
Improved Interpretation of Reservoir Architecture and Fluid Contacts Through the Integration of Downhole Fluid Analysis With G
Advanced Mud Gas Logging in Combination With Wireline Formation Testing and Geochemical Fingerprinting for an Improved



Predicting Downhole Fluid Analysis Logs to Investigate Reservoir Connectivity
Predicting Downhole Fluid Analysis Logs to Investigate Reservoir Connectivity
Characterization of Reservoir Properties Using Production Logs
Remaining Oil Investigation in a High Recovery Oilfield
Modeling Original Water Saturation in the Transition Zone of a Carbonate Oil Reservoir
Estimation of Saturation Height Function Using Capillary Pressure by Different Approaches
Relative Permeability Measurements and Analyses for a Cluster of Fields in South Oman
Experimental Determination of Relative Permeabilities for a Rich Gas/Condensate System Using
Live Fluid
Oil Recovery and Fracture Reconsolidation of Diatomaceous Reservoir Rock by Water Imbibition at
High Temperature

Alteration of Reservoir Diatomites by Hot Water Injection
Incorporating Seismic Characterization Results into Bul Hanine Geological Model
Incorporating Seismic Characterization Results into Bul Hanine Geological Model
The Wafra First Eocene Reservoir, Partitioned Neutral Zone (PNZ), Saudi Arabia and Kuwait:
Geology, Stratigraphy, and Static Reservoir Modeling
Re-Evaluation of a Complex Mature Field (Dunbar, UKCS): A Geosciences Integrated Work
Permeability Modeling for the SAGD Process Using Minimodels
Permeability Modeling for the SAGD Process Using Minimodels
Permeability Determination of the PL19-3 Field for Geologic Model Input
Akpo, Nigeria: From Seismic Interpretation to Geomodel
New Strategy for Seismic Facies Upscaling to the Reservoir Grid Scale
Integration of Well Test Deconvolution Analysis and Detailed Reservoir Modelling in 3D Seismic
Data Interpretation: A Case Study
Identification of High-Porosity Reservoir Sands From 3D-Seismic Attributes Using Neural Network Technique in South Umm G
Pore-Scale Modeling of Three-Phase WAG Injection: Prediction of Relative Permeabilities and
Trapping for Different Displacement Cycles
Improved Water Saturation Estimation Using Equivalent Rock Element Model and Application to Different Rock Types
Wettability-Index Determination by Nuclear Magnetic Resonance
Wettability Studies at the Pore Level of Saudi Aramco Reservoirs
Development and Use of Improved Wireline Formation Tester Technologies in the Challenging Deltaic Reservoirs
Enhancing Formation Testing and Sampling Operations Through the Use of Log-Derived High-Resolution Mineral-Based Lithof
Enhancing Formation Testing and Sampling Operations Through the Use of Log-Derived High-Resolution Mineral-Based Lithof
Direct Measurements of Minimum Horizontal Stress, Permeability, and Permeability Anisotropy in a Siberian Oil Field Using a W
A Method for Analysis of Pressure Response With a Formation Tester Influenced By Supercharging
                                Author                                       Abstract
J.J. Sheng, SPE, D.T. Georgi, SPE, and J. Burge, SPE, Baker Hughes Inc. Summary In a probe-type formation test because
James J. Sheng,* SPE, Baker Hughes * now with Total E&P USA               Summary During a single-probe test in a vertical w
                                                                          Abstract The objective of supplying Halliburton
Saud Jumah, Khaled Saleh, and Haitham I. Al-Mayyan, Kuwait Oil Co., and Mike Turner, Sperry Drilling Servicesreal time LWD
                                                                          Abstract Capillary pressure curves
J. Ouzzane, M. Okuyiga, N. Gomaa, Adma Opco; R. Ramamoorthy, D. Rose, A. Boyd, D.F. Allen, Schlumbergerare a fundame
                                                                          Abstract A major challenge today Total E&P
R. Labourdette, Total E&P; A. Meyer, ADCO, M. Sudrie, Total E&P, F. Walgenwitz, Total E&P; and C. Javaux,is the developme
                                                                           Dugoujard, Perenco
Jacques Pion, SPE, TOTAL Abu Dhabi; Marc Vesseron, ADCO; and Thierry Abstract Subtle or sub-seismic faults in carbonate
                                                                          Summary An oil/water capillary transition zone ofte
S.K. Masalmeh, Shell Abu Dhabi, and I. Abu Shiekah and X.D. Jing, Shell Intl. E&P
                                                                          Abstract Cores open hole logs Aramco; testers
Lang Zhan, SPE, and Fikri Kuchuk, SPE, Schlumberger; S. Mark Ma, SPE, and Ali M. Al-Shahri, SPE, Saudiformation T.S. Ram
                                                                          Abstract Electrofacies based on conventional
Christian Perrin/Schlumberger, Mohamad Rafiq Wani/KGOC, Mahmood Akbar/Schlumberger, Samir Jain/Schlumberger logs
                                                                          Abstract Establishing the depositional sedimentary
Chandramani Shrivastva and Sanchita Ganguly, Schlumberger, and Zuber Khan, GSPC
                                                                          Abstract The Triassic reservoirs of the eastern Sah
Taofeek Ogunyemi, Philippe Montaggioni, SPE, and Ibtissam Boubakeur, Schlumberger North Africa, and Mario�Junguito a
                                                                          Summary Downhole fluid S. Williams, SPE, Stato
C. Dong, SPE, and M. O'Keefe, SPE, Schlumberger; H. Elshahawi, SPE, and M. Hashem, SPE, Shell; analysis (DFA) has eme
                                                                          Abstract Fluid identification is an important objecti
Andry Halim, Pertamina, and Nicolas Orban, Elin Haryanto, and Cosan Ayan, Schlumberger
                                                                           McKinney, Matthew Flannery, and Mohammed Ha
Lalitha Venkataramanan, SPE, Schlumberger; Hani Elshahawi, SPE, Daniel Summary In recent years formation-sampling and
                                                                          Summary Downhole fluid S. Williams, SPE, Stato
C. Dong, SPE, and M. O'Keefe, SPE, Schlumberger; H. Elshahawi, SPE, and M. Hashem, SPE, Shell; analysis (DFA) has eme

Salma Al Hejeri, SPE, Ahmed El Mahdi, SPE, and Shahin Negahban, SPE, Adco     Abstract Reservoir simulation is the most accurate
P.R. Nurafza, SPE, P.R. King, SPE, and M. Masihi, SPE, Imperial College Abstract A statistical approach is proposed and v
                                                                              Abstract Secondary fractures and faults associate
Pijush Paul, SPE, and Mark Zoback, SPE, Stanford University, and Peter Hennings, ConocoPhillips
                                                                              Abstract ONGC Ltd.
Aditi Pal, Kapil Seth, and Udit Guru, Schlumberger, and R.R. Tiwari and D. Dasgupta, The petrophysical evaluation of carbonat
                                                                              Abstract The Mumbai, India, and Indrajit Barua of
Varun Sharma, Sagnik Dasgupta, Arathi. L. Mahesh, and Sachin Sharma, Schlumberger, Lower Tipam sandstone reservoir and
                                                                              Abstract This paper discusses the method on how
Fuming Zhang, Cairui Shao, Hongqi Li, and Cuihua Jiao, China U. of Petroleum, Hongtao Liu, and Yuanjiang Li, DaQing Oilfield
                                                                              Beste, G. Hu, M. Wu, J. Pitcher, companies Altho
M. Bittar, SPE, Halliburton Energy Services; J. Klein, ConocoPhillips; and R. Abstract Drilling services and oil C. Golla, G.have
                                                                              Abstract Development of formation evaluation tech
Trond Gravem, Alf Berle, Sven S. Gundersen, INTEQ, and Jarle Pedersen, Kjell Oddvar Rorvik, and Atle Hansen, ConocoPhill
                                                                              Summary A new logging-while-drilling (LWD) tool
Thomas J. Neville, SPE, Schlumberger; Geoff Weller, SPE, and Ollivier Faivre, SPE, Schlumberger Riboud Product Center; an
                                                                              Abstract F. Allioli, SPE, and M. Evans, SPE, Sch
E. Mirto, SPE, G. Weller, SPE, T. el-Halawani, SPE, J. Grau, SPE, M. Berheide, SPE,Radioactive chemical logging sources ha
                                                                              Abstract J.C. concerns have been expressed re
A. Mendoza, SPE, U. of Texas at Austin; D.V. Ellis, Schlumberger Doll-Research; andManyRasmus, SPE, Schlumberger Suga
Andy Kristianto, Yulianto Jong, and Laurent Moinard, TOTAL E&P INDONESIE      Abstract The Elemental Capture Spectroscopy (EC
                                                                              Abstract Deep basin drilling along the Wichita
Ronald J. Marchel, Marathon Oil Company, and Charles H. Smith and Sandeep Ramakrishna, Halliburton Energy Services Mou
                                                                               Inteq, and Jenson describes the experience and
Ulrich Hahne, Jos Pragt, Martin Venier, and Matthias Meister, Baker HughesAbstract This paperTan and Dai Chunsen, Conoco
L. Zhou, SPE, Baker Hughes; J. Mardambek, SPE, Rice University                Abstract Modern formation pressure testing while d
                                                                              Abstract Formation pore pressure and near-wellbo
Xavier POIRIER-COUTANSAIS, SPE; Emmanuelle BAUD, SPE, TOTAL ABK and Ettore MIRTO, SPE, Schlumberger
                                                                              Abstract Quantifying the uncertainty in the volume
Samiha S. El-Sayed, SPE, and Ahmed M. Daoud, Schlumberger, and El-Sayed A. El-Tayeb, Cairo University
Samiha S. El-Sayed, SPE, Cairo University                                     Abstract � Quantifying the uncertainty in the vo
                                                                              Abstract One Boyd, Raghu Ramamoorthy, Steve N
Asbjorn Gyllensten, Mohamed Ibrahim Al-Hammadi, Emhemed Abousrafa, ADCO; Austin of the top concerns for carbonate res
Zohreh Movahed, Shahid Beheshti University                                    Abstract The reservoir is composed of a mixture o
                                                                               and D. This D. Rose, R. Ramamoorthy, and me
N. Gomaa, A. Al-Alyak, D. Ouzzane, O. Saif, and M. Okuyiga, ADMA OPCO,AbstractAllen, case study demonstrates a new E.ï¿
                                                                              Abstract and Olumide Akinsanmi and are Pillai,
Michel Claverie, Steve Hansen, Saifon Daungkaew, and Zane Prickett, Schlumberger,Deepwater turbidite reservoirsPaul compo
                                                                              Abstract and Olumide Akinsanmi and are Pillai,
Michel Claverie, Steve Hansen, Saifon Daungkaew, and Zane Prickett, Schlumberger,Deepwater turbidite reservoirsPaul compo
                                                                              Abstract Specifying the perforation intervals SPE
A.M. Daoud, SPE, M. Eisa, SPE, R. El-Mahdy, SPE, and M. Emam, Schlumberger, and A.H. Hashem and A.S. Elhawary,and e
                                                                              Abstract ABed Alderman, and S. Bahuguna, Schl
                                                                                           novel methodology has been
R. Bastia, A. Tyagi, and K. Saxena, Reliance Industries Ltd. and T. Klimentos, R. Altman, S. Petrophysical Analysis develope
Chanh Cao Minh and Isabel Joao, Schlumberger, and Jean-Baptiste
Clavaud and Padmanabhan Sundararaman, Chevron                                 Abstract Formation evaluation in thin sand-shale la
                                                                              Abstract Formation evaluation in thin Chevron
Chanh Cao Minh and Isabel Joao, Schlumberger, and Jean-Baptiste Clavaud and Padmanabhan Sundararaman, sand-shale la
                                                                              ABSTRACT Formation evaluation (FE) of horizont
S.M. Ma and A.A. Al-Hajari, Saudi Aramco, and P. Butt and S. Crary, Schlumberger
                                                                              Abstract The economical viability of the Cambrian
Taofeek Ogunyemi, Philippe Montaggioni, SPE, Atmane Azzougen, SPE, and Mourad Kourta, Schlumberger North Africa, and
                                                                              Abstract The Verkhnechonskoye TNK-BP
Eric M. Prasse, SPE, J.W. Hornbrook, SPE, and R.S. Tye, DeGolyer and MacNaughton; Timothy W. Putnam,field was discove
                                                                              Abstract Wireline formation testing (WFT) and fluid
Richard R Jackson, Ilaria De Santo, Peter Weinheber, SPE, Schlumberger, Emilio Guadagnini, SPE, Nigerian Agip Exploration
                                                                              Xavier Poirier-Coutansais, and Jurassic Arab rese
Sandeep Chakravorty, Schlumberger Middle East S.A.; Jean-Louis Lesueur,Abstract The oil-bearing Upper Jean-Yves Gory, T
                                                                            Nurafza, Investigating College
M. Masihi, SPE, Sharif University of Technology; and P.R. King, SPE, and P.Summary SPE, Imperial the impact of geological un

M. Masihi, SPE, P.R. King, SPE, and P. Nurafza, SPE, Imperial College     Abstract Uncertainty in geometrical properties of
                                                                          Abstract Drilling in deepwater is
Joseph Ajienka, SPE, Franck Egbon, SPE, and Uchechukwu Onwuemena, SPE, Total E&P Nigeria Limited becoming more a
                                                                          Abstract Renewed interest Zakum Development in
Jiang YiMing, Sandeep Chakravorty, and�J. Robert Marsden, Schlumberger, and H. Ewart Edwards, in fractures and faults C
                                                                          Abstract Stratigraphic trapping mechanism
Kalyan Chakraborty and Mubarak Al-Hajeri, Kuwait Gulf Oil Co., and Jayanta Ray, Schlumberger Information Solutions plays a
                                                                          Abstract A Geological Model was Gregorio Rodrig
Layla Saleh Al Muhairi, Maria Teresa Ribeiro, Agung Dharmawan, and Mohamed Al Neaimi, ADCO, and Jose built and an Unce
                                                                          Abstract As a branch of spatial statistics geostatis
Y. Z. Ma, SPE, Schlumberger; A. Seto, SPE, Pengrowth Corp.; and E. Gomez, Schlumberger
Hong Tang, SPE, Chevron and Ning Liu, SPE, Chevron                        Abstract Based on previous studies multiple SCH
                                                                          Abstract Thinly bedded reservoirs are increasingly
M. Claverie, Schlumberger; S. Aboel-Abbas, C.S. Mutiara; and H. Harfoushian, S. Hansen, and R. Leech, Schlumberger
C.C. Minh, Schlumberger, and P. Sundararaman, Chevron                     Abstract We use nuclear magnetic resonance (NM
C.C. Minh, Schlumberger, and P. Sundararaman, Chevron                     Abstract We use nuclear magnetic resonance (NM
                                                                          Abstract As the Petrobel
Aristides Orlandi Neto, SPE, and Dhruba Dutta, SPE, Schlumberger, and Saad Hassan, SPE,global power scenario changes w

G.A. Bordakov, A.V. Kostin, J. Rasmus, and D. Heliot, SPE, Schlumberger;
H. Laastad, SPE, Statoil; and E.J. Stockhausen, SPE, Chevron              Abstract The paper illustrates the improvements in
                                                                          Summary SPE, StatoilHydro; and improvements
G.A. Bordakov, A.V. Kostin, J. Rasmus, D. Heliot, SPE, Schlumberger;and H. Laastad, The paper illustrates theE.J. Stockhause
                                                                          Abstract The Greater Kuwait Field consists of thre
Khalid H. Al-Azmi, SPE, Hamdah Al-Enezi, SPE, Rohitkumar Kotecha, and Salem Al-Sabea, SPE, Burgan Oil Company; Ekpo A
                                                                          Abstract and P. Shiner, Sarawak Shell Berhad
M. Choo, Shell Exploration and Production Libya GmbH; C. Young, C.T. Ling, J. Beer Controlled Source Electromagnetic (CSE
                                                                          Abstract
Mike Mullen and Russel Roundtree, Halliburton, and Bob Barree, Barree and Assocs.In the Rocky Mountain region of the US n
                                                                          Abstract The Texas at Austin
Vasudev Singh, SPE, Nicolas P. Roussel, SPE, and Mukul M. Sharma, SPE, University ofproduction and injection of fluids in a
                                                                          Abstract Minimizing uncertainty Jamal Bahmaish,
R.E. Mahmoud Basoni, R.E.C. Shahin Negahban, S.R.E. Ahmed Dawood, S.R.E. Ahmed El Mahdi, and T.L. associated with pr
                                                                          Abstract Rock mechanical parameters of reservoi
A. Abdulraheem, KFUPM, M. Ahmed and A. Vantala, Schlumberger, and T. Parvez, KFUPM
                                                                          Abstract Effective properties can represent fine-sc
Faruk O. Alpak, SPE, Mark D. Barton, Frans F. van der Vlugt, SPE, Carlos Pirmez, Bradford E. Prather, and Steven H. Tennan
                                                                          Summary Highly depleted reservoirs exhibit sharp
Bikash Sinha, SPE, Tom Bratton, SPE, Jesse Cryer, Steve Nieting, Schlumberger OFS, Gustavo Ugueto, Andrey Bakulin, SPE
                                                                          Summary Highly depleted reservoirs exhibit sharp
Bikash Sinha, SPE, Tom Bratton, SPE, Jesse Cryer, Steve Nieting, Schlumberger OFS, Gustavo Ugueto, Andrey Bakulin, SPE
                                                                          Abstract Careful gathering and analysis Valentina
Gert-Jan Reijnders, Nasser Al-Mohannadi, Michael P�ppelreiter, Sharon Finlay, Gerard Bodewitz, Lama Al-Oreibi,of outcrop
B.D. Poe Jr., W.K. Atwood, J. Kohring, and K. Brook, SPE, Schlumberger Abstract This paper presents the results of an inve
                                                                          Schlumberger
B.D. Poe Jr., SPE, W.K. Atwood, SPE, J. Kohring, SPE, and K. Brook, SPE, Abstract This paper presents the results of an inve
B.D. Poe Jr., W.K. Atwood, J. Kohring, and K. Brook, SPE, Schlumberger Abstract This paper presents the results of an inve
                                                                          Summary The Akhtar Sargelu and Akbar, Schl
Pradyumna Dutta, Sunil Kumar Singh, and Jarrah Al-Genai, Kuwait Oil Company; and AzharNajmah and MahmoodMarrat reser
                                                                          Abstract The carbonate reservoirs in Aziza Suez
Essam A.E.A. Bassim and Kaoru Yamaguchi, Arabian Oil Company, Ltd., and Dedi Juandi, Mahmoud Emam, andGulf ofAli, Sc

Abel Chacon, BP America, and Djebbar Tiab, U. of Oklahoma                Abstract This paper analyzes the effect of stress o
                                                                         Abstract The field is located in the southeastern pa
O. Pinous, Schlumberger; Abdel M. Zellou, Gary Robinson, and Ted Royer, Prism Seismic; and N. Svikhnushin, D. Borisenok,
B. Todd Hoffman, SPE, drc consulting, and Wayne Narr, SPE, and Liyong
Li, SPE, Chevron ETC                                                     Abstract In naturally fractured reservoirs determin
                                                                         Xavier Poirier-Coutansais, and Jurassic Arab rese
Sandeep Chakravorty, Schlumberger Middle East S.A.; Jean-Louis Lesueur,Abstract The oil-bearing Upper Jean-Yves Gory, T
Simon Chipperfield, Shell Intl. E&P Inc.                                 Summary After-closure analysis (ACA) in homoge
                                                                         Abstract The Maloichskoe field is located in the so
O. Pinous, Schlumberger; E.P.Sokolov and S.Y.Bahir, Russneft; Abdel M. Zellou, Gary Robinson, and Ted Royer, Prism Seism
                                                                         Abstract In this paper we Saudi Aramco; method
Fikri Kuchuk, SPE, and Lang Zhan, SPE, Schlumberger; S. Mark Ma, SPE, and Ali M. Al-Shahri, SPE, present a novel and T.S.
                                                                         Abstract
Hussain A. Al-Jeshi, Charles Bradford, Saudi Aramco; Murat Zeybek, Schlumberger The process of defining the fluid and rese
                                                                         Abstract Total Indonesie
Cosan Ayan and Mario Petricola, Schlumberger, and Philip Knight and Bruno Lalanne,Wireline Formation Tester (WFT) pretest
                                                                         Abstract Total Indonesie
Cosan Ayan and Mario Petricola, Schlumberger, and Philip Knight and Bruno Lalanne,Wireline Formation Tester (WFT) pretest
                                                                          (Thailand) Ltd.
Long Jiang and Keith Schilling, Schlumberger; Jim Logan, Chevron OffshoreAbstract Acoustic measurements have long been u
Paul F. Worthington, SPE, Gaffney, Cline & Associates                    Summary Methodologies have been developed fo
                                                                         Abstract We have Mengual, Schlumberger
Omar Aguirre and Juan Carlos Glorioso, Repsol YPF, Jeannette Morales and Jean Fran�oisvalidated with superior results th
                                                                         Abstract One of the most important objectives and
Chanh Cao Minh, Peter Weinheber, Wich Wichers, and Adriaan Gisolf, Schlumberger; Emmanuel Caroli, Francois Jaffuel, of fl
                                                                         Abstract One of the most important objectives and
Chanh Cao Minh, Peter Weinheber, Wich Wichers, and Adriaan Gisolf, Schlumberger; Emmanuel Caroli, Francois Jaffuel, of fl
Emmanuel Toumelin, SPE, and Carlos Torres-Verd�n, SPE, U. of
Texas at Austin, and Boqin Sun and Keh-Jim Dunn, Chevron Energy
Technology Co.                                                           Summary Two-dimensional (2D) NMR techniques
                                                                            Abstract Hess
M. Claverie, D. Maggs, and M. Van Steene, Schlumberger, and D. Westacott, CarigaliThe analysis of shaly sand gas reservoirs
                                                                            Abstract An R. Akkurt, SPE, Saudi Aramco
H.N. Bachman, SPE, S. Crary, SPE, R. Heidler, and J. LaVigne, SPE, Schlumberger, andongoing challenge for nuclear magne
Robert Freedman, Schlumberger Oilfield Services                             Distinguished Author Series articles are general d
                                                                            Abstract Up to now
Franco Vittore and Javier Pompei, Repsol YPF, and Oscar Ortiz and Anthony Pol, Schlumberger different petrophysical method
                                                                            Abstract
A. Suat Bagci, Heriot-Watt U., and Ceylan Yildirim Akbas, Middle East Technical U. This study focuses on the evaluation of fo
M.J. Sullivan, D.L. Belanger, M.T. Skalinski, S.D. Jenkins, and P. Dunn,
Chevron                                                                     Abstract Estimation of effective permeability at the
Michael J. Sullivan, SPE, Chevron                                           Distinguished Author Series articles are general d
                                                                            Abstract Many the world's oil fields and aquifers
Narayan Nair, SPE, Steven L. Bryant, SPE, and James W. Jennings*, SPE, The University of Texas at Austin
                                                                             Shell; and model W. Zimmerman, allows accurat
Mathieu Jurgawczynski and Peter A. Lock, Imperial College; X.D. Jing, SPE,Abstract A Robert is developed that SPE, Imperial
                                                                            Abstract The economic recovery of hydrocarbons f
Kevin Turco and Jim Brenneke, BP, and Segun Jebutu, Andrew Kirkwood, Holger Thern, Roland Chemali, and Thomas Kruspe
                                                                            Abstract This paper
Soufiane JOUINI, Francois UMBHAUER, Jean-Pierre LEDUC, Noomane KESKES, TOTAL E&P deals with the use of core scan
                                                                            SPE, and Shauket many of the producers are
Ahmed S. Al-Muthana, SPE, and S.M. Ma, SPE, Saudi Aramco; M. Zeybek, Abstract Currently Malik, SPE, Schlumberger hor
T. Zhang, Stanford U., and S. Bombarde, S. Strebelle, and E. Oatney,
Chevron Corp. ETC                                                           Summary Training images are numerical represen
S. Al Arfi, ADCO, and D. Heliot, J. Li, X. Zhan, and D. Allen, Schlumberger Abstract A new methodology for porosity and perm
Pierre Delfiner, SPE, Total S.A.                                            Summary Phi-k transforms are used widely to pre
                                                                            Summary Underbalanced Mining and Technology
Torsten Friedel, George Mtchedlishvili, Hans-Dieter Voigt, and Frieder H�fner, Freiberg University of drilling (UBD) is defined
                                                                            Abstract The prospect
P.V. Suryanarayana, Kennedy, and R.N. Vaidya, Blade Energy Partners, and J.A. Wind, Shell Intl. of dynamic reservoir charac
V. Bang, SPE, and V. Kumar, SPE, U. of Texas at Austin; P.S.
Ayyalasomayajula, SPE, Chevron; and G.A. Pope, SPE, and M.M. Sharma,
SPE, U. of Texas at Austin                                                  Abstract Predicting production from gas-condensa
M. Jamiolahmady, A. Danesh, D.H. Tehrani, and M. Sohrabi, Heriot-Watt U. Summary It has been demonstrated first by this la
                                                                            BP America Inc.
Wiseman, T R; Ballin, P R; Lederer, M C; Wagerle, R N and McCaslin, N F -Abstract Holstein is a BP operated deepwater oil f
                                                                            Abstract The Minagish structure in southwest corn
Taher El Gezeery, SPE, Kuwait Oil Company, Fawaz Al Saqran, Kuwait Oil Company, Ekpo Ita Archibong, SPE, Schlumberger
                                                                            Abstract This paper discusses the detection of fluid
Sait Ismail Ozkaya, Baker Atlas GeoScience; Pascal Richard, Petroleum Development Oman; and Guy Mueller, Brunei Shell
                                                                            Abstract The subject of this paper is identification
S.I. Ozkaya, Baker Atlas; S. Gordon, A. McFarlane, S. Siyabi, S.M. Al-Busaidi, and M.F. Kramer, Petroleum Development Oma
                                                                            Summary Identifying compartmentalization Mullin
Hani Elshahawi, Shell; Lalitha Venkataramanan, Schlumberger; Daniel McKinney and Matthew Flannery, Shell; Oliver C.and un
                                                                            Abstract Understanding reservoir architecture is c
Chengli Dong, SPE, Schlumberger; Hani Elshahawi, SPE, Shell; Oliver C. Mullins, SPE, and Lalitha Venkataramanan, SPE, Sc
                                                                            Summary Identifying compartmentalization Mullin
Hani Elshahawi, Shell; Lalitha Venkataramanan, Schlumberger; Daniel McKinney and Matthew Flannery, Shell; Oliver C.and un
                                                                            Abstract Understanding reservoir architecture is c
Chengli Dong, SPE, Schlumberger; Hani Elshahawi, SPE, Shell; Oliver C. Mullins, SPE, and Lalitha Venkataramanan, SPE, Sc
                                                                             E&P Inc.; Artur Stankiewicz and architecture is o
Daniel McKinney, Matthew Flannery, and Hani Elshahawi, Shell InternationalAbstract Understanding reservoirEd Clarke, Shell
Soraya S. Betancourt, Francois X. Dubost, and Oliver C. Mullins,
Schlumberger Oilfield Services; Myrt E. Cribbs and�Jefferson L. Creek,
Chevron Energy Technology Corporation; and Syriac G. Mathews,
Schlumberger Oilfield Services                                              Abstract Compartmentalization is perhaps the sing
                                                                            Abstract Compartmentalization is perhaps the sing
Soraya S. Betancourt, Francois X. Dubost, and Oliver C. Mullins, Schlumberger Oilfield Services; Myrt E. Cribbs and�Jeffers
B.D. Poe Jr., W.K. Atwood, J. Kohring, and K. Brook, Schlumberger           Abstract This paper presents the results of an inve
                                                                            Abstract Residual oil estimations are mainly based
Mike Burke, SPE, and M. Bremeier, SPE, Wintershall Libya; Mohamed Shebani, Libyan National Oil Corp.; ChengGang�Xia
                                                                            Summary Accurately modeling water-saturation
Shawket G. Ghedan, SPE; Petroleum Inst. of Abu Dhabi; Bertrand M. Thiebot, SPE; Total; and Douglas A. Boyd, SPE, Zadcova
                                                                            Abstract The saturation-height function
Mahmound Jamiolahmady, Mehran Sohrabi, and Mohammed Tafat, Inst. of Petroleum Engineering, Heriot-Watt U. greatly imp
                                                                            Abstract During a large water Martin Kraaijveld, SP
Mohammed Al-Gharbi, SPE, Petroleum Development Oman, Xudong Jing, SPE, Shell Technology Oman, flood study on a clus
J.F. App, SPE, and J.E. Burger, SPE, Chevron Energy Technology
Company                                                                     Summary Measurement of gas and condensate re

M. Ikeda, G.-Q. Tang, C.M. Ross, and A.R. Kovscek, Stanford University     Abstract Spontaneous imbibition and coreflood ex
C.M. Ross, SPE, M. Ikeda, SPE, Schlumberger, G.-Q. Tang, SPE,
Chevron, and A.R. Kovscek, SPE, Stanford University                        Abstract Pore microstructure and mineral composi
                                                                           Abstract Bul Pellerin and Ga�l Lecante, Beicip-F
Nicolas Desgoutte, Beicip-Franlab; Abdulmalik Al Abdulmalik, Qatar Petroleum; Matthieu Hanine field is located offshore Qatar
                                                                           Abstract Bul Pellerin and Ga�l Lecante, Beicip-F
Nicolas Desgoutte, Beicip-Franlab; Abdulmalik Al Abdulmalik, Qatar Petroleum; Matthieu Hanine field is located offshore Qatar
W. Scott Meddaugh, SPE, Dennis Dull, Raymond A. Garber, and Stewart
Griest, Chevron Energy Technology Co., and David Barge, SPE, Saudia
Arabian Texaco                                                           Abstract The First Eocene reservoir at Wafra Field
                                                                         and S. Varley, Total E&P UK Ltd.
L. Ben Brahim, SPE, T. Coombes, SPE, R. Cooper, J. Fredonnet, D. Taylor, Abstract Dunbar Field (3/14 block) is operated by
                                                                         Abstract The predicted flow performance of Steam
J.A. McLennan and C.V. Deutsch, U. of Alberta; D. Garner and T.J. Wheeler, ConocoPhillips Canada Ltd.; and J.-F. Richy and
                                                                         Abstract The predicted flow performance of Steam
J.A. McLennan and C.V. Deutsch, U. of Alberta; D. Garner and T.J. Wheeler, ConocoPhillips Canada Ltd.; and J.-F. Richy and
M.D. Fetkovich, M.G. Gerard, L.Y. Chin, and D. Shuxing, ConocoPhillips   Abstract The overall structure of the PL19-3 field
                                                                         Abstract Akpo is a very France
Timothy Oluyemi Itiola, Bruno Michel, and Martine Bez, TOTAL, Tour La Coupole, Paris La Defense, light oil to condensate gas
O. Duplantier, N. Hadj-Kacem, and J. Vittori, Total E&P                  Abstract We here present a new strategy for seism

                                                                          Abstract This paper demonstrates how a combin
C. Amudo, J. Turner, J. Frewin, and T.C. Kgogo, PetroSA, and A.C. Gringarten, Imperial College London
                                                                          Abstract The South Umm Gudair
Ram Kumar Thakur, Kuwait Gulf Oil Co., and Frederic Duval, Claude Boibien, and Gilles Pages, Total Kuwait Field is a multi-a

                                                                               Abstract We
V.S. Suicmez, Imperial College; M. Piri, U. of Wyoming; and M.J. Blunt, Imperial College use a three-dimensional mixed-wet r
                                                                               Abstract The second Archie
Bruce Z. Shang, SPE, Jeffry G. Hamman, SPE, and Donald H. Caldwell, SPE, Marathon Oil Company equation relates water
Wim Looyestijn, SPE, and Jan Hofman, Shell Intl. E&P                           Summary Knowing the wetting condition of a rese
Mansour A. Al-Shafei and Taha M. Okasha, Saudi Aramco                          Abstract The wettability of rocks is of critical impor
Nicolas Orban, Cosan Ayan, and Mario Ardila, Schlumberger                      Abstract Many sedimentary features of gas fields
                                                                               and G.R. Kear, A. Lithofacies Ardila, D. being routi
                                                                                          Based Kumar, M. Mapping
H. Elshahawi, Shell Intl. E&P Inc.; E. Donaghy and C. Guillory, Shell Oil Co.; Abstract Wireline formation testers are Williamson
                                                                               and G.R. Kear, A. Lithofacies Ardila, D. being routi
                                                                                          Based Kumar, M. Mapping
H. Elshahawi, Shell Intl. E&P Inc.; E. Donaghy and C. Guillory, Shell Oil Co.; Abstract Wireline formation testers are Williamson
                                                                               Abstract Diyashev I., SPE
Ayan C. and Achourov V., SPE, Schlumberger, Alpatov A., SPE, Sibneft-Khantos and Waterflood management requires the op
                                                                               Abstract Interpretation of
R. Banerjee, SPE, R.K.M. Thambynayagam, SPE, and J. Spath, SPE, Schlumberger Oilfield Services pressure transient tests
 -type formation test because of the geometry of the wellbore and the sealing effect of mudcake the flow pattern is not perfectly spherical. To
 ingle-probe test in a vertical well the probe of a formation tester is set horizontally against a sidewall of the borehole. In a horizontal well the
ve of supplying real time LWD or FE information (Logging While Drilling and Formation Evaluation) should be to enable the client to make qu
essure curves are a fundamental input to reservoir simulators both from the standpoint of initializing fluid saturations and from the perspectiv
  lenge today is the development of carbonate reservoirs. They represent the most significant reservoir formation in the middle-east gulf regio
b-seismic faults in carbonate reservoirs are often mentioned in the geosciences literature but using them as hard data to qualify reservoir con
er capillary transition zone often contains a sizable portion of a field’s initial oil in place especially for those carbonate reservoirs with low
   hole logs formation testers pressure transient tests and production logs are usually used to assess reservoir heterogeneity. A common lim
s based on conventional logs are found as strongly correlated to core lithofacies thin section microfacies and petrophysical measurements (
g the depositional sedimentary environment is the most important task for exploration geologists to model the reservoir heterogeneities. Inter
   reservoirs of the eastern Sahara province represent one of the main oil and gas accumulations in Algeria. This clastic succession correspon
  fluid analysis (DFA) has emerged as a key technique for characterizing the distribution of reservoir-fluid properties and determining zonal co
  cation is an important objective to resolve key uncertainties of a complex reservoir prior to perforation in the developed fields of Eastern Kali
 ears formation-sampling and formation-testing tools have provided a variety of new downhole optical measurements for downhole fluid anal
  fluid analysis (DFA) has emerged as a key technique for characterizing the distribution of reservoir-fluid properties and determining zonal co

  mulation is the most accurate tool for forecasting rates reserves and field performance provided that accurate information is used to build t
   approach is proposed and validated against a realistic field dataset to model connectivity of low to intermediate net-to-gross reservoirs. An
  ractures and faults associated with larger reservoir scale faults affect both permeability and permeability anisotropy and hence may play an
hysical evaluation of carbonate reservoirs in terms of predicting the hydrocarbon potential is trivial. However it is difficult to correctly predict th
Tipam sandstone reservoir of Miocene age in the Jaipur oilfield lies within a highly folded and faulted Assam-Shelf basin in the north eastern
  iscusses the method on how to subdivide the reservoir into zones based on flow-units. Based on the thought of “inner homogeneity in flo
 ices and oil companies have long been interested in acquiring the capability of landing a well accurately in a hydrocarbon reservoir and rema
nt of formation evaluation technologies for azimuthal deep-reading measurements and accurate and flexible 3D rotary steerable drilling syste
ging-while-drilling (LWD) tool that combines traditional measurements of gamma ray propagation resistivity gamma-gamma density and the
e chemical logging sources have been used in the E&P industry for many years to help operators obtain valuable information about their res
 erns have been expressed regarding discrepancies between LWD (Logging-While-Drilling) and WL (Wireline) GR (natural gamma ray) resp
 tal Capture Spectroscopy (ECS) log measures the concentrations of a number of elements (Al Ba Ca Cl Cu Fe Gd H K Mg Na Ni Si
  drilling along the Wichita Mountain front in the Anadarko basin of western Oklahoma poses one of the most difficult log interpretation issues
  escribes the experience and lessons learned to acquire logging while drilling (LWD) formation pressure and near-wellbore mobility data in B
mation pressure testing while drilling (FPWD) tools provide accurate formation pressure measurements even under very challenging drilling a
 ore pressure and near-wellbore mobility are key parameters for reservoir description. Traditionally these data are acquired with wireline form
  the uncertainty in the volumetric estimation of original oil in place (OOIP) is an important process in evaluating the field potential and hence i
 fying the uncertainty in the volumetric estimation of original oil in place (OOIP) is an important process in evaluating the field potential and he
op concerns for carbonate reservoir evaluation is the effect of rock texture on permeability capillary pressure and relative permeability. Rece
oir is composed of a mixture of dolomite limestone anhydrite and shale interstratified with sandstones member. The sandstone is predomina
 tudy demonstrates a new method to compute continuous permeability and estimate reservoir rock type from logs in a complex heterogeneo
 turbidite reservoirs are composed of interbedded porous and permeable sands with variable proportions of thin silt and clay beds.� These
 turbidite reservoirs are composed of interbedded porous and permeable sands with variable proportions of thin silt and clay beds.� These
 he perforation intervals and evaluating the productivity of thin-bedded sands and shales is crucial for well completion cost optimization. This
  physical Analysis

valuation in thin sand-shale lamination seeks first to determine sand resistivity volume fraction and porosity. Afterwards saturation and volu
valuation in thin sand-shale lamination seeks first to determine sand resistivity volume fraction and porosity. Afterwards saturation and volu
on evaluation (FE) of horizontal injectors drilled in water swept reservoirs involves different physical understanding of log responses to fluid f
 ical viability of the Cambrian sandstone reservoirs in the Hassi Messaoud field is closely linked to the presence of fractures. Natural or hydra
echonskoye field was discovered and appraised during the late 1970s and early 1980s. One hundred legacy wells and three modern wells ha
mation testing (WFT) and fluid sampling has long been used for determination of reservoir pressure evaluation of fluid type from in-situ dens
ring Upper Jurassic Arab reservoirs of an offshore Abu Dhabi fractured carbonate field (Abu Al Bukhoosh) have been producing for more tha
 ng the impact of geological uncertainty (i.e. spatial distribution of fractures) on reservoir performance may aid management decisions. The c

y in geometrical properties of fractures affects all aspects of flow in fractured reservoirs. The connectivity of fractures embedded in low perm
eepwater is becoming more and more expensive. There is need to know before hand for well planning purposes the values of the fracture p
 erest in fractures and faults in a giant carbonate oilfield offshore Abu Dhabi involves such aspects as their origin nature orientation and imp
   trapping mechanism plays a critical role for hydrocarbon entrapment within the Middle-Late Cretaceous reservoirs in the Al-Khafji area. 3D
 l Model was built and an Uncertainty Assessment approach was used to better understand the reservoir behaviour. Conceptual models were
  of spatial statistics geostatistics is commonly used to model geologic facies and petrophysical properties. The spatial characteristics of geos
 evious studies multiple SCH parameters are used to quantify reservoir performance. �Static connectivity is quantified by fraction of conne
 ed reservoirs are increasingly a target of offshore exploration in the Malay Basin. These reservoirs exhibit heterolithic interbedding with vertic
clear magnetic resonance (NMR) logging to help with the petrophysical evaluation of thin sand-shale laminations. NMR helps to 1) detect thin
clear magnetic resonance (NMR) logging to help with the petrophysical evaluation of thin sand-shale laminations. NMR helps to 1) detect thin
 al power scenario changes with increased demand for oil and gas remote and challenging (deepwater offshore high pressure-high tempera


 lustrates the improvements in logging while drilling (LWD) images and subsequent formation evaluation by utilizing a new methodology for d
  illustrates the improvements in logging while drilling (LWD) images and subsequent formation evaluation by using a new methodology for de
r Burgan Field consists of three sub fields (Ahmadi Burgan and Magwa). Drilling commenced in this field in 1938 and it went on stream in 19
Source Electromagnetic (CSEM) is an emerging technology with the potential to provide detailed resistivity images of the subsurface. Followi
  Mountain region of the US nearly every well is hydraulic fracture stimulated to produce commercial volumes of oil and gas. The starting poi
 on and injection of fluids in a reservoir results in reorientation of stresses. This phenomenon has been supported by field studies and micro-
uncertainty associated with predicted log water saturation can be best achieved through the integration of log analysis (formation evaluation)
anical parameters of reservoir rocks play an extremely important role in solving problems related to almost all operations in oil or gas produc
 perties can represent fine-scale geologic heterogeneities in simple full-field reservoir models without having to explicitly model them. A comp
 leted reservoirs exhibit sharply lower pore pressures and horizontal stress magnitudes than does the overlying shaly formation. Drilling throu
 leted reservoirs exhibit sharply lower pore pressures and horizontal stress magnitudes than does the overlying shaly formation. Drilling throu
 ering and analysis of outcrop analogue data is a valuable data source for enhancing the understanding of analogue hydrocarbon reservoirs.
presents the results of an investigation concerning the development of a reliable and accurate technique for establishing the stabilized delive
presents the results of an investigation concerning the development of a reliable and accurate technique for establishing the stabilized delive
presents the results of an investigation concerning the development of a reliable and accurate technique for establishing the stabilized delive
ah Sargelu and Marrat reservoirs are the main Jurassic reservoirs in Kuwait. These fractured-carbonate reservoirs that have moderate-to-lo
ate reservoirs in Gulf of Suez area have complex geological structure due to the existence of fractures associated with faults. Thus fracture

nalyzes the effect of stress on the rock properties fracture and matrix compressibilities fracture and matrix porosities and permeability in na
ocated in the southeastern part of the West Siberian basin in Novosibirsk oblast (Fig. 1). It was the first field in the basin where commercial o

 ractured reservoirs determining fracture properties such as size and permeability is difficult due to the limited data about the fractures. The
ring Upper Jurassic Arab reservoirs of an offshore Abu Dhabi fractured carbonate field (Abu Al Bukhoosh) have been producing for more tha
ure analysis (ACA) in homogeneous-matrix reservoirs provides a method for extracting critical reservoir information from pre-frac injection tes
hskoe field is located in the southeastern part of the West Siberian basin in Novosibirsk oblast (Fig. 1). It was the first field in the basin where
   we present a novel method for in situ estimation of two-phase transport properties of porous media using time-lapse resistivity pressure a
s of defining the fluid and reservoir properties of a hydrocarbon discovery represents a significant challenge to the industry. The practice of p
rmation Tester (WFT) pretest success ratio (good versus tight pressure points) has been traditionally low in East Kalimantan-Indonesia over
rmation Tester (WFT) pretest success ratio (good versus tight pressure points) has been traditionally low in East Kalimantan-Indonesia over
 asurements have long been used to evaluate rock properties in the near-wellbore region and these methods are well documented. Compreh
 gies have been developed for applying net reservoir and thence net pay cutoffs in cases of primary and waterflood depletion. The cutoffs are
 idated with superior results that the direct measurement of porosity using Nuclear Magnetic Resonance (NMR) in Naturally Fractured Clasti
most important objectives of fluid sampling using wireline formation testers (WFT) is to ensure that representative samples of the different flu
most important objectives of fluid sampling using wireline formation testers (WFT) is to ensure that representative samples of the different flu


nsional (2D) NMR techniques have been proposed as efficient methods to infer a variety of petrophysical parameters including mixed fluid s
s of shaly sand gas reservoirs with low and variable formation water salinity presents specific challenges. These formations usually exhibit lo
 challenge for nuclear magnetic resonance (NMR) well logging is that the quality and utility of the data depend on the acquisition sequence in
 Series articles are general descriptive representations that summarize the state of the art in an area of technology by describing recent de
 ifferent petrophysical methodologies have been developed to improve the success rate in selecting oil intervals in the Gulf of San Jorge Bas
ocuses on the evaluation of formation permeability for a carbonate reservoir from well logs and core data using the concept of flow units. Cha

of effective permeability at the reservoir scale has been a long standing challenge in carbonate fields.� The carbonate depositional and dia
 Series articles are general descriptive representations that summarize the state of the art in an area of technology by describing recent deve
 world's oil fields and aquifers are found in carbonate strata. Some of these formations contain vugs or cavities several centimeters in size. F
developed that allows accurate prediction of the permeability of a core sample of sedimentary rock based solely on two-dimensional image a
 ic recovery of hydrocarbons from deepwater reservoirs continues to be a major challenge facing the exploration and production industry not
 eals with the use of core scanner imagery for discriminating main representative rock textures to improve core high resolution petrophysical
many of the producers are horizontal wells and a considerable number of them are equipped with smart complex completions. Evaluating the

mages are numerical representations of geological conceptual models that provide prior information on reservoir architecture. A new emergin
odology for porosity and permeability analysis in Carbonates with Inter-granular and Macro porosity is presented. This methodology uses NM
sforms are used widely to predict permeability. Some of the difficulties of this exercise are well identified such as the homogeneity of the pop
 nced drilling (UBD) is defined as a drilling operation in which the pressure of the circulating drilling fluid is lower than the pore pressure of the
 t of dynamic reservoir characterization using flow and pressure data gathered during underbalanced drilling (UBD) is a powerful driver for im


 roduction from gas-condensate wells requires an accurate relative permeability model when a condensate bank forms. At high flow rates typ
 n demonstrated first by this laboratory and subsequently by other researchers that the gas and condensate relative permeability can increas
   BP operated deepwater oil field located in the Gulf of Mexico. Reservoirs comprise stacked Pliocene turbidite sands with the field formed b
 h structure in southwest corner of Kuwait is a multi reservoir field. One of the potential reservoirs is the Mishrif formation. Developed as a lim
  iscusses the detection of fluid conductive fracture fairways using seismic data calibrated with BHI or dynamic data. Fault-related fractures di
   of this paper is identification and mapping fracture corridors in a carbonate field in Oman using a probabilistic approach. A fracture corridor
   compartmentalization and understanding reservoir structure are of critical importance to reservoir development. Traditional methods of iden
 ing reservoir architecture is critically important to effective reservoir management. Misinterpreting reservoir compartmentalization for instanc
   compartmentalization and understanding reservoir structure are of critical importance to reservoir development. Traditional methods of iden
 ing reservoir architecture is critically important to effective reservoir management. Misinterpreting reservoir compartmentalization for instanc
 ing reservoir architecture is one of the critical factors in successful appraisal and development of any oil/gas field. Increasing drilling costs an



ntalization is perhaps the single biggest risk factor in deepwater petroleum production. Downhole fluid analysis (DFA) is a new tool to reduce
ntalization is perhaps the single biggest risk factor in deepwater petroleum production. Downhole fluid analysis (DFA) is a new tool to reduce
 resents the results of an investigation involving the development of a reliable and accurate methodology for establishing the stabilized delive
estimations are mainly based on special analysis of representative core samples (SCAL). In high recovery oil fields where remaining oil satu
  modeling water-saturation variation in transition zones is important to reservoir simulation for predicting recoverable oil and guiding field-dev
on-height function greatly impacts reserve calculations and is used by geologists or reservoir engineers to predict the saturation in the reserv
ge water flood study on a cluster of fields in South Oman it became apparent that relative permeability constituted one of the major uncertain

ment of gas and condensate relative permeabilities typically is performed through steady-state linear coreflood experiments using model fluids

us imbibition and coreflood experiments were conducted on samples from two diatomaceous oil reservoirs to measure oil recovery as a funct

 tructure and mineral composition of diatomaceous reservoir core were analyzed in concert with core-scale thermal recovery tests. Samples f
 ield is located offshore Qatar with primary oil production from the Reservoir-X carbonates. In 2005 and 2006 Qatar Petroleum recognized th
 ield is located offshore Qatar with primary oil production from the Reservoir-X carbonates. In 2005 and 2006 Qatar Petroleum recognized th
ocene reservoir at Wafra Field was discovered in 1954 and has produced about 290 million barrels of 17-19� API high sulfur oil.� The d
d (3/14 block) is operated by Total E&P UK. Situated on an intermediate terrace between the East Shetland Platform and the Viking Graben
ed flow performance of Steam Assisted Gravity Drainage (SAGD) well pairs is sensitive to the spatial distribution of permeability. �A numb
ed flow performance of Steam Assisted Gravity Drainage (SAGD) well pairs is sensitive to the spatial distribution of permeability. �A numb
 structure of the PL19-3 field which is located in Bohai Bay is an asymmetrical wrench anticline that formed by a combination of differential
ery light oil to condensate gas field located offshore Niger Delta discovered end 1999 by Akpo-1 well at a water depth of 1350m by SAPETR
esent a new strategy for seismic facies upscaling to the reservoir grid. This methodology has been developed on the deep offshore Angola G

 demonstrates how a combination of seismic data interpretation advanced well test deconvolution analysis and detailed reservoir modeling
Umm Gudair Field is a multi-accumulation structure with the most prolific production of oil from a Ratawi Oolite reservoir (Neocomian). The h

 hree-dimensional mixed-wet random network model representing Berea sandstone to compute displacement paths and relative permeabiliti
 Archie equation relates water saturation to formation resistivity index through a power function. This important relationship has been widely u
 he wetting condition of a reservoir at an early stage is crucial for selecting optimum field-development options. Paying insufficient attention to
 lity of rocks is of critical importance in understanding reservoir dynamics. Several studies of wettability evaluation on Saudi Aramco reservoir
mentary features of gas fields are multilayered deltaic thinly laminated shaly sandstones consisting of channel and bar sands with limited late
 hofacies Mapping
 hofacies Mapping
 management requires the optimization of hydraulic fracture placement. The lack of direct stress measurements (vertical distribution and dire
  n of pressure transient tests conducted in a dynamic environment like drilling is challenging. One of the difficulties arises due to phenomen
w pattern is not perfectly spherical. To account for the deviation from spherical flow several geometric correction factors were proposed for d
  he borehole. In a horizontal well the probe can be set either horizontally against a sidewall or vertically against the top or bottom wall of the
 ld be to enable the client to make quick accurate decisions on the formations being drilled thus reducing and minimizing the geological unc
d saturations and from the perspective of predicting dynamic reservoir behavior. Traditionally this input has been obtained from special core
  rmation in the middle-east gulf region. In carbonate reservoirs heterogeneity is usually driven by both depositional and diagenetic patterns. T
m as hard data to qualify reservoir connectivity is generally not an accepted standard. The present paper illustrates with field examples that ev
r those carbonate reservoirs with low matrix permeability. The field-development plan and ultimate recovery may be influenced heavily by how
 servoir heterogeneity. A common limitation of these techniques is that they do not provide two-dimensional spatial information of reservoir ch
s and petrophysical measurements (f/k and MICP) as long as the carbonate pore system remains simple. Once dual porosity is present it is
el the reservoir heterogeneities. Interpretation of borehole images has been the key to better understanding of the sedimentary environment i
 ia. This clastic succession corresponds to fluvial estuarine and shallow marine deposits characterized by common lateral and vertical facies
  properties and determining zonal connectivity across the reservoir. Information from profiling the reservoir fluids enables sealing barriers to
n the developed fields of Eastern Kalimantan. This paper explains how using a formation tester equipped with two downhole fluid analyzer mo
 easurements for downhole fluid analysis (DFA). DFA involves an in-situ measurement of optical absorption spectra used to compute propert
  properties and determining zonal connectivity across the reservoir. Information from profiling the reservoir fluids enables sealing barriers to

 ccurate information is used to build the model. To overcome major uncertainties associated with a fully compositional simulation model it is
 rmediate net-to-gross reservoirs. An object based technique is used to model the spatial distribution of aligned isotropic and anisotropic bod
 y anisotropy and hence may play an important role in controlling the production behavior of a faulted reservoir. It is well known from geologic
  ver it is difficult to correctly predict the fluid flow in the absence of proper characterization of the different flow units encountered in these res
 am-Shelf basin in the north eastern part of India. The analysis of this mature field carries a lot of interest not only because the sands within
ought of “inner homogeneity in flow-unit a new and reasonable auto-subdividing method named “slicing-merging was proposed in thi
  in a hydrocarbon reservoir and remaining in it for optimal drainage. Although traditional logging-while-drilling (LWD) propagation resistivity to
xible 3D rotary steerable drilling systems have made it possible to provide truly proactive well placement. Real time use of new and advanced
 vity gamma-gamma density and thermal-neutron porosity with measurements unique to the LWD arena including neutron capture spectros
   valuable information about their reservoirs. Until recently much of the information obtained using these sources could not be obtained with
                                                                                           OnePetro
  reline) GR (natural gamma ray) responses in various wells. It has been suggested that these differences may arise from the variations in to
 Cl Cu Fe Gd H K Mg Na Ni Si S and Ti) in the formation by neutron capture OnePetro        spectroscopy. These are used to compute mass fractions
most difficult log interpretation issues. Advances in the acquisition and processing of 3D seismic have enabled the drilling and production of t
  and near-wellbore mobility data in Bohai Bay. This area is known to be difficult in terms of measuring key parameters for reservoir descriptio
                                                                                           OnePetro
 even under very challenging drilling and formation testing conditions. Pressure data from logging while drilling (LWD) tools are primarily used
                                                                                           number of
e data are acquired with wireline formation pressure tester. However today a large OnePetro wells are being drilled at high deviation as pro
 luating the field potential and hence in designing the proper and the most economical subsurface and surface facilities to produce the field re
n evaluating the field potential and hence in designing the proper and the most economical subsurface and surface facilities to produce the fi
ssure and relative permeability. Recent advances in log analysis combined with new logging sensors that are sensitive to carbonate rock text
member. The sandstone is predominantly poorly consolidated and quartz rich. Much of the sand is medium grained although coarser sand is
 rom logs in a complex heterogeneous Middle Eastern carbonate reservoir.� The 795 ft conventionally cored interval consists of interbed
   of thin silt and clay beds.� These reservoir sands vary in thickness from millimeter to meters in thickness.� The reservoirs are highly p
                                                                                           OnePetro OnePetro
   of thin silt and clay beds.� These reservoir sands vary in thickness from millimeter to meters in thickness.� The reservoirs are highly p
                                                                                           OnePetro
 ll completion cost optimization. This requires the accurate identification of hydrocarbon-bearing sands and their contribution to production. R


osity. Afterwards saturation and volume are simple Archie applications. Resistivity anisotropy techniques can provide estimates of sand resis
osity. Afterwards saturation and volume are simple Archie applications. Resistivity anisotropy techniques can provide estimates of sand resis
erstanding of log responses to fluid flow and distribution than that FE of oil producers drilled in dry oil intervals. In reservoirs swept with water
 esence of fractures. Natural or hydraulically induced fractures control hydrocarbon productivity due to the low porosity low matrix permeabili
gacy wells and three modern wells have been reevaluated and results used to construct a static model that matched test results and was use
 luation of fluid type from in-situ densities identification of fluid contacts and inter-reservoir connectivity. Fluid sampling and downhole forma
 h) have been producing for more than thirty years. All the available informations indicate that the producing layers subdivided into Upper and
ay aid management decisions. The conventional approach to address this is to build a number of possible reservoir models upscale them a

y of fractures embedded in low permeable zones can control fluid movement and influence field performance. This can be analyzed using
purposes the values of the fracture pressure. The Fracture pressure could be determined by predictive or verificative methods. Many correla
eir origin nature orientation and impact on productivity of Lower Cretaceous hydrocarbon reservoirs. Studies identified a conundrum with re
s reservoirs in the Al-Khafji area. 3D seismic data are acquired aiming at to delineate the stratigraphic and possible strati-structural traps and
                                                                                       all of which
   behaviour. Conceptual models were used to constrain the number of realizations OnePetro are equi-probable solutions that honour both h
es. The spatial characteristics of geostatistical methods in variogram kriging and stochastic simulation have made them the tools of choice fo
 ivity is quantified by fraction of connected pore volume between wells. Static heterogeneity is defined by Dykstra-Parson Coefficient Lorenz
bit heterolithic interbedding with vertical heterogeneity and a wide range of layer flow properties. This paper describes methods of real-time a
  inations. NMR helps to 1) detect thin beds 2) determine fluid type and if hydrocarbon is present 3) establish the hydrocarbon type and volu
  inations. NMR helps to 1) detect thin beds 2) determine fluid type and if hydrocarbon is present 3) establish the hydrocarbon type and volu
                                                    OnePetro
offshore high pressure-high temperature high-angle wells) locations are drilled in an ever-demanding exploration effort with minimum or no


  by utilizing a new methodology for depth and survey measurements correction. LWD depth measurements are often considered inaccurate
 n by using a new methodology for depth and survey measurements corrections. LWD depth measurements are often considered inaccurate
                                                      the production comes from a giant oil reservoir in a siliciclastics depositional environment. T
d in 1938 and it went on stream in 1946. Most ofOnePetro
 ty images of the subsurface. Following a string of successes with the deployment of CSEM and drilling performance in DW Borneo in 2004
umes of oil and gas. The starting point for designing these treatments is an understanding of the in-situ stress profile. To calculate the in-situ
supported by field studies and micro-seismic observations. This paper presents a study of stress reorientation around horizontal wells. Stress
of log analysis (formation evaluation) and capillarity (core measured high pressure mercury and oil/water drainage capillary pressure data).ï¿
ost all operations in oil or gas production.� A continuous profile of these parameters along the depth is essential to analyze these problem
ving to explicitly model them. A comprehensive simulation study tests the sensitivity of dynamic connectivity in turbidite channel reservoirs to
 erlying shaly formation. Drilling through such depleted reservoirs can cause severe fluid loss and drilling-induced wellbore instability. Accura
 erlying shaly formation. Drilling through such depleted reservoirs can cause severe fluid loss and drilling-induced wellbore instability. Accura
of analogue hydrocarbon reservoirs. However information from outcrops is commonly limited to static descriptions i.e. reservoir body dimen
  for establishing the stabilized deliverability performance of multi-layer commingled systems using multi-rate production log measurements.ï
  for establishing the stabilized deliverability performance of multi-layer commingled systems using multi-rate production log measurements.ï
  for establishing the stabilized deliverability performance of multi-layer commingled systems using multi-rate production log measurements.ï
e reservoirs that have moderate-to-low porosity were deposited in an inner- to midramp warm marine environment. The fracture systems pla
 ssociated with faults. Thus fracture characterization of this complicated area is very important to understand the reservoir behavior and hen

 trix porosities and permeability in naturally fractured reservoirs (NFRs). In NFRs fluids are stored inside the matrix pore space and inside t
 ield in the basin where commercial oil was produced from the Paleozoic basement. The reservoir consists mostly of limestones and dolomite

                                                 OnePetro
limited data about the fractures. The primary information that is available mainly from image logs or core is known only at the wellbore; how
h) have been producing for more than thirty years. All the available informations indicate that the producing layers subdivided into Upper and
nformation from pre-frac injection tests. This paper extends the theory and practice of ACA to identify the presence of productive natural frac
 was the first field in the basin where commercial oil was produced from the Paleozoic basement. The reservoir consists mostly of limestone
ng time-lapse resistivity pressure and flow rate data from a permanent downhole Electrode Resistivity Array (ERA) and pressure and a pro
nge to the industry. The practice of performing a drill stem test (DST) over a significant reservoir interval and attributing the properties of the
w in East Kalimantan-Indonesia over decades despite technological advances.� One possible reason has been postulated as alteration of
w in East Kalimantan-Indonesia over decades despite technological advances.� One possible reason has been postulated as alteration of
                                                                                      OnePetro
hods are well documented. Comprehensive characterization of the wellbore rock relies on the knowledge of compressional and shear slowne
 waterflood depletion. The cutoffs are dynamically-conditioned to be reservoir-specific (i.e. they are tied back to a reference permeability par
 (NMR) in Naturally Fractured Clastics Reservoirs of very low porosity (≈ 3.5%) in the Devonian of the Bolivian Sub-Andean reveals infor
sentative samples of the different fluids encountered in the formation are obtained. Usually the wireline or LWD petrophysical logs will guide
sentative samples of the different fluids encountered in the formation are obtained. Usually the wireline or LWD petrophysical logs will guide


al parameters including mixed fluid saturation in-situ oil viscosity wettability and pore structure. However no study has been presented to q
s. These formations usually exhibit low resistivity contrast between water and hydrocarbon zones and high apparent clay content. Calculated
epend on the acquisition sequence inversion parameters and the logging environment. Some modern NMR logging sequences are intended
  technology by describing recent developments for readers who are not specialists in the topics discussed. Written by individuals recognize
ntervals in the Gulf of San Jorge Basin oilfields. These methodologies have been successful only in a limited number of cases and a solution
a using the concept of flow units. Characterization of carbonate reservoirs by flow units is a practical way of reservoir zonation. The study rep

½ The carbonate depositional and diagenetic history can be quite complex and this can lead to a permeability field which is quite difficult to c
                                                                                      in the topics
 technology by describing recent developments for readers who are not specialists OnePetro discussed. Written by individuals recognized
 avities several centimeters in size. Flow of fluids through such rocks depends strongly upon the spatial distribution and connectivity of the vu
ed solely on two-dimensional image analysis of its pore structure. The only required input data are the areas and perimeters of the pores obs
ploration and production industry not just contending with the multitude of market uncertainties but also more importantly reservoir delivera
 ve core high resolution petrophysical log quality and to propose a better strategy for plugs sampling. The idea of using tomography images h
complex completions. Evaluating the performance of these horizontal producers is critically important for improved reservoir management. C

eservoir architecture. A new emerging geostatistical approach named multiple-point statistics (MPS) simulation allows extracting multiple-po
                                                                                    OnePetro
esented. This methodology uses NMR log data and electrical image data when available to partition porosity into micro meso and macro c
 such as the homogeneity of the population (rock typing) the matching of cores and logs (especially depth matching) and the problem of pe
s lower than the pore pressure of the target formation of interest. The most widely recognized benefit of UBD is the reduction of formation da
ling (UBD) is a powerful driver for implementation of UBD. The mathematical aspects of this complex ill-posed inverse problem have been


ate bank forms. At high flow rates typical of many gas-condensate wells the relative permeability is rate dependent. Such rate dependence c
sate relative permeability can increase significantly by increasing rate contrary to the common understanding. There are now a number of co
urbidite sands with the field formed by a large steep southeasterly dipping monoclinal structure. Early performance of the field showed a s
Mishrif formation. Developed as a limestone sedimented in a mid-ramp environment it generally consists of fine-grained packstones to wack
namic data. Fault-related fractures display a high degree of clustering at several scales. Fracture cluster within fracture corridors and fracture
bilistic approach. A fracture corridor is a tabular sub-vertical fault-related fracture swarm which intersects the entire reservoir and extends lat
                                                                                         OnePetro OnePetro
 opment. Traditional methods of identifying reservoir compartmentalization such as drillstem tests and extended well tests often become im
 oir compartmentalization for instance can result in non-optimal well placement completion strategy and facilities design as well as large er
 opment. Traditional methods of identifying reservoir compartmentalization such as drillstem tests and extended well tests often become im
 oir compartmentalization for instance can result in non-optimal well placement completion strategy and facilities design as well as large er
/gas field. Increasing drilling costs and environmental challenges has led to the development of alternative appraisal approaches that compli



nalysis (DFA) is a new tool to reduce uncertainty associated with reservoir connectivity. Fluid data from DFA logs and various laboratory anal
nalysis (DFA) is a new tool to reduce uncertainty associated with reservoir connectivity. Fluid data from DFA logs and various laboratory anal
y for establishing the stabilized deliverability performance of multi-layer commingled reservoir systems using multi-rate production log measu
ery oil fields where remaining oil saturations approach residual oil saturations it is possible to test these estimations using Pulsed Neutron D
  recoverable oil and guiding field-development plans. The large transition zone of a heterogeneous Middle East reservoir was challenging to
to predict the saturation in the reservoir for a given height above the free water level. If cores are preserved the water saturation information
onstituted one of the major uncertainties impacting reserves in the cluster. At the onset of the study only two experimental measurements we

 flood experiments using model fluids. This study addresses experimental measurement of relative permeabilities for a rich-gas/condensate

 rs to measure oil recovery as a function of temperature and to quantify changes if any in the rock fabric resulting from the flow of brine and

ale thermal recovery tests. Samples from two diatomaceous oil reservoirs were subjected to spontaneous and forced imbibition coreflood exp
2006 Qatar Petroleum recognized that future development of this mature field would require a modern state of the art reservoir model and
                                                                                 OnePetro modern
2006 Qatar Petroleum recognized that future development of this mature field would require aOnePetrostate of the art reservoir model and
                                                                                   OnePetro OnePetro
  -19� API high sulfur oil.� The dolomite reservoir is Eocene/Paleocene age.� The average porosity is 35% and the average permeab
 and Platform and the Viking Graben the field is characterised by a series of pre-Cretaceous and structurally aligned tilted fault blocks.� T
stribution of permeability. �A number of permeability measurements are taken from small scale core plug data.� The data may be taken
stribution of permeability. �A number of permeability measurements are taken from small scale core plug data.� The data may be taken
                                                                                   OnePetro
 rmed by a combination of differential subsidence strike-slip faulting and normal faulting. Faults form the main trapping components for the
 a water depth of 1350m by SAPETRO (operator) – Total TUPNI (technical advisor) and PETROBAS in OPL246. As for some other turbid
 loped on the deep offshore Angola Girassol field data. Based on seismic attributes it directly assigns facies associations and petrophysical p

 ysis and detailed reservoir modeling helped address the concern of reservoir compartmentalization in the E-M field located offshore South
 Oolite reservoir (Neocomian). The historic ultimate seal held by the thick Ratawi Shale Member displays embedded multilayered oil bearing

ement paths and relative permeabilities for water alternating gas (WAG) flooding. First we reproduce cycles of water and gas injection obse
portant relationship has been widely used to evaluate hydrocarbon saturation. However many rocks don’t obey this empirical rule. The b
ptions. Paying insufficient attention to the wetting condition (e.g. assuming water-wet behavior) may result in incorrect oil-in-place estimates a
 valuation on Saudi Aramco reservoir rocks were reported but to our knowledge none of them have attempted to study wettability on the por
hannel and bar sands with limited lateral and vertical extension. Relying only on conventional openhole log data and performing correlations a


ements (vertical distribution and direction) in the South Priobskoe field in western Siberia has created the need to determine the orientation a
e difficulties arises due to phenomenon known as supercharging which is caused by mud filtrate invasion. The supercharging results in an in
orrection factors were proposed for different analysis techniques (Steward and Wittmann 1979; Wilkinson and Hammond 1990; Dussan and
against the top or bottom wall of the borehole. When the probe is set horizontally against a sidewall the solution for a horizontal well is the sa
 g and minimizing the geological uncertainty and maximizing or increasing the well bore exposure in the desired structure.� During the cou
has been obtained from special core analysis (SCAL) from a limited amount of cores due to time and cost. Rock typing is often used to help m
 epositional and diagenetic patterns. The complex diagenetic history which prevails in these reservoirs influences the final static and dynamic
  illustrates with field examples that even faults with very small throw (<3m) can backscatter energy that this energy appears on seismic displ
 ery may be influenced heavily by how much oil can be recovered from the transition zone. This in turn depends on a number of geological an
 nal spatial information of reservoir characteristics. For example cores and logs have excellent vertical resolutions but very small lateral radi
 e. Once dual porosity is present it is found that neural network using conventional logs can not distinguish 2 rock types having the same ran
 ing of the sedimentary environment in the study area in Krishna-Godavari basin (KG basin) along the east coast of India. The present study
by common lateral and vertical facies changes that are responsible for uncertainties in the modeling of the reservoir heterogeneities. A realis
 oir fluids enables sealing barriers to be proved and compositional grading to be quantified; this information cannot be obtained from convent
d with two downhole fluid analyzer modules helped understand reservoir fluid characteristics identify production zones and optimize perforati
tion spectra used to compute properties such as hydrocarbon composition and gas/oil ratio (GOR). Abrupt changes in these fluid properties
 oir fluids enables sealing barriers to be proved and compositional grading to be quantified; this information cannot be obtained from convent

compositional simulation model it is of utmost important to obtain accurate SCAL data and EOS description. The accuracy of model initializa
aligned isotropic and anisotropic bodies. The connectivity of the model is estimated using percolation theory. First account is made to evalu
  ervoir. It is well known from geologic studies that there is a concentration of secondary fractures and faults in a damage zone adjacent to lar
nt flow units encountered in these reservoirs. The process of identifying the flow units becomes non-trivial in the presence of extensive diage
st not only because the sands within the formation are hydrocarbon bearing but also because of the complexities associated with its evaluatio
œslicing-merging was proposed in this paper. And the main characteristic parameters used by this method such as FZI (Flow zone indicator)
 illing (LWD) propagation resistivity tools can help to achieve this goal their overall effectiveness is not satisfactory because they lack azimuth
. Real time use of new and advanced LWD data in horizontal drilling gives the opportunity to extend the envelope for well planning and reser
 a including neutron capture spectroscopy and capture cross section opens up new opportunities for formation evaluation on LWD. The com
e sources could not be obtained with any other method. While the potential risks involved with the use of such sources have always been k


nabled the drilling and production of targets that previously could not be imaged. Although the increased abilities to identify and target the des
ey parameters for reservoir description in conventional wireline logging (WL) programs. While comparisons between WL and LWD including


urface facilities to produce the field reserves. This uncertainty in the OOIP estimate results from uncertainty in reservoir areal extent net rese
 nd surface facilities to produce the field reserves. This uncertainty in the OOIP estimate results from uncertainty in reservoir areal extent ne
 t are sensitive to carbonate rock texture have led to an improved workflow for petrophysical analysis of carbonates. The authors have earlier
 m grained although coarser sand is common in the lowermost thick sandstone units. Both anhydrite and carbonate cements are present wit
 ly cored interval consists of interbedded limestones and dolomites with anhydrite cement and features a wide variety of textures.� In some
ness.� The reservoirs are highly permeable but the silt and clay laminations affect the reservoir permeability in each layer resulting in cha




 s can provide estimates of sand resistivity and volume fraction but good results depend on the choice of the anisotropic shale point. The sam
 s can provide estimates of sand resistivity and volume fraction but good results depend on the choice of the anisotropic shale point. The sam
ervals. In reservoirs swept with water effects of rock electrical anisotropy on logging-while-drilling (LWD) apparent resistivity measurements
 e low porosity low matrix permeability and heterogeneous sedimentological characteristics of these fluvial deposits. Fracture corridors and
hat matched test results and was used to forecast field potential. The Verkhnechonskoye field is currently operated by TNK-BP. Cores in the
  Fluid sampling and downhole formation fluid analysis measurements also provide information for assessment of fluid complexity compositio
 ing layers subdivided into Upper and Lower Arab are fractured to varying extents. As a result a better understanding of the fracture networ
ble reservoir models upscale them and then run flow simulations. The problem with this approach is that it is computationally very expensive

 mance. This can be analyzed using percolation theory. This approach is used the hypothesis that the permeability can be split into either pe
or verificative methods. Many correlations exists that can be used to predict the fracture pressure. However they are mostly limited to onsho
 tudies identified a conundrum with respect to core and image log correlation of discontinuities: fractures and faults seen on electrical image
nd possible strati-structural traps and their associated reservoir setting. Seismic attribute analysis of 350 sq. km. of 3D seismic data of Al-Kha

 ave made them the tools of choice for reservoir modeling. Such techniques are especially useful to characterize the reservoir connectivity an
 Dykstra-Parson Coefficient Lorenz Coefficient weighted by cell volume. �Two-phase streamline simulation is used to exam the dynamic
per describes methods of real-time and high-resolution formation evaluation and formation testing used to characterize such reservoirs. The
ablish the hydrocarbon type and volume and finally 4) determine the permeability of the sands (as opposed to that of the sand-shale system
ablish the hydrocarbon type and volume and finally 4) determine the permeability of the sands (as opposed to that of the sand-shale system



 ents are often considered inaccurate and therefore not as reliable for well-to-well correlations correlations to offset data acquired with wirelin
ments are often considered inaccurate and therefore not as reliable for well-to-well correlations correlations with data acquired with wireline

performance in DW Borneo in 2004 CSEM data was acquired over a number of similar structures in 2006. Proprietary inversion techniques
 stress profile. To calculate the in-situ stress profile one must have an understanding of the mechanical rock properties and the pore pressur
 tation around horizontal wells. Stress reorientation has been calculated for different scenarios and patterns of horizontal injection and produc
  drainage capillary pressure data).� Further reduction of uncertainty in predicted formation water saturation requires; first the most probab
s essential to analyze these problems which include wellbore stability sand production fracturing reservoir compaction and surface subside
 ivity in turbidite channel reservoirs to a large number of stratigraphic and engineering parameters. Simulations performed using geologically
g-induced wellbore instability. Accurate and reliable estimates of horizontal stresses can provide an early warning of impending drilling proble
g-induced wellbore instability. Accurate and reliable estimates of horizontal stresses can provide an early warning of impending drilling proble
escriptions i.e. reservoir body dimension and geometry. Figure 1 Permo-Triassic Section exposed at Jebel Al Akhdar. Visible is a large-scal
-rate production log measurements.� Both linear and non-linear systems are addressed in this paper providing a basis for the analysis of
-rate production log measurements.� Both linear and non-linear systems are addressed in this paper providing a basis for the analysis of
-rate production log measurements.� Both linear and non-linear systems are addressed in this paper providing a basis for the analysis of
  vironment. The fracture systems play a significant role in production in these reservoirs and it is essential to identify areas of high fracture d
stand the reservoir behavior and hence assigning the best completion intervals for the producing wells. In this paper we developed a workflo

  e the matrix pore space and inside the fractures of the rock. The reservoir characterization parameter indicating the volumetric fraction of flu
 sts mostly of limestones and dolomites that are intensively fractured and contain numerous vugs in some zones. The reservoir properties of


ing layers subdivided into Upper and Lower Arab are fractured to varying extents. As a result a better understanding of the fracture networ
e presence of productive natural fractures. Natural fractures are important to identify before conducting a stimulation treatment because the
eservoir consists mostly of limestones and dolomites that are intensively fractured and contain numerous vugs in some zones. The reservoir
Array (ERA) and pressure and a production logging tool. The primary objective of this Fluid Movement Monitoring (FMM) setup and experim
 and attributing the properties of the produced fluid to a single reservoir fluid compartment is problematic. Overlooking the variation in fluid pr
 has been postulated as alteration of near-wellbore formation properties during drilling operations.� The relatively tight gas sands are drille
 has been postulated as alteration of near-wellbore formation properties during drilling operations.� The relatively tight gas sands are drille

 back to a reference permeability parameter in a way that is driven by the reservoir data themselves). They also honor scale where feasible
e Bolivian Sub-Andean reveals information till now incoherent compared with core data. As it is well known when the rock does not have pa
or LWD petrophysical logs will guide the sample acquisition program. This typically means that resistivity and nuclear logs are used to infer b
or LWD petrophysical logs will guide the sample acquisition program. This typically means that resistivity and nuclear logs are used to infer b


 er no study has been presented to quantify the petrophysical limitations of such methods. We address this problem by introducing a pore-sc
 gh apparent clay content. Calculated water saturations are high and need to be accurately split between clay-bound capillary-bound and fre
NMR logging sequences are intended to be applicable over a wide range of environments and include measurements of transverse relaxatio
 sed. Written by individuals recognized to be experts in the area these articles provide key references to more definitive work and present s
mited number of cases and a solution that has field-wide applicability has been lacking. This project attempts to optimize previous results usin
  of reservoir zonation. The study represents a petrophysical-based method that uses well loggings and core plug data to delineate flow units

 ability field which is quite difficult to characterize.� Permeability in vuggy or fractured intervals can be dramatically different from the matrix

distribution and connectivity of the vugs. Enhanced oil recovery processes such as enriched gas drives and groundwater remediation efforts
 eas and perimeters of the pores observed in for example an SEM image. The hydraulic radius approximation is used to estimate the individ
   more importantly reservoir deliverability uncertainties associated with deeply deposited pay targets. One large field subject of this study is s
e idea of using tomography images has physical bases. In fact scanned data is representative for rock bulk density changes; the perceptual
  improved reservoir management. Conventional production logging tools cannot meet the challenges of logging horizontal wells especially in

mulation allows extracting multiple-point structures from such training images and anchoring these structures to the data actually observed in

pth matching) and the problem of permeability upscaling. Not so well-known however are the pitfalls of a statistical and geostatistical nature
 UBD is the reduction of formation damage by minimizing the drilling-mud leakoff and fines migration into the formation. It also facilitates the
l-posed inverse problem have been the subject of research in the past decade. This paper focuses on practical field implementation of UBD


  dependent. Such rate dependence can be modeled using a capillary number to calculate the decrease in residual saturations and the corres
 nding. There are now a number of correlations in the literature and commercial reservoir simulators accounting for the positive effect of coup
  performance of the field showed a sharper production decline than predicted by the sanction study. Dynamic simulation of early wells sugge
 ts of fine-grained packstones to wackstones that is highly bioturbated. The average thickness is about 300 ft with an average Net of 170ft in
  within fracture corridors and fracture corridors are clustered within fracture fairways which are overall equivalent to fault zones. We compar
 s the entire reservoir and extends laterally for several tens or hundreds of meters.� The only direct indicator of fracture corridors are boreh

nd facilities design as well as large errors in reserves drainage volume and production rate predictions. Downhole fluid analysis along with co
 xtended well tests often become impractical in deepwater settings with costs approaching the costs of new wells and emissions becoming
nd facilities design as well as large errors in reserves drainage volume and production rate predictions. Downhole fluid analysis along with co
ve appraisal approaches that compliment the more costly and traditional methods such as the drill stem or production test. Therefore the ch



DFA logs and various laboratory analyses are studied to elucidate hydrocarbon composition variations in large reservoir sand bodies. This pr
DFA logs and various laboratory analyses are studied to elucidate hydrocarbon composition variations in large reservoir sand bodies. This pr
sing multi-rate production log measurements. Both linear and non-linear systems are considered in this work providing a basis for the analys
 estimations using Pulsed Neutron Decay (PND) logging to monitor water saturation changes. Such monitoring techniques can identify incon
dle East reservoir was challenging to model. Core-calibrated log-derived water saturations were used to generate saturation-height-function
ved the water saturation information can be obtained directly. However cores are often subject to changes from their original state before br
y two experimental measurements were available that had been acquired with the currently recommended approach of wettability restoration

meabilities for a rich-gas/condensate reservoir using a live single-phase reservoir fluid. Using a live single-phase reservoir fluid eliminates th

 c resulting from the flow of brine and synthetic steam condensate (180-230�C pH = 7 and 10) through diatomite subjected to a radial conf

 s and forced imbibition coreflood experiments using hot synthetic steam condensate (180�C to 230�C pH = 10). The effects of these e
 state of the art reservoir model and initiated several projects to achieve that goal: reprocessing and elastic inversion of the 1995 vintage 3D
urally aligned tilted fault blocks.� The principal hydrocarbon accumulations are contained in the Middle Jurassic Brent Group and younger U
plug data.� The data may be taken preferentially from certain geologic locations and there may be inconsistencies in the data.� The me
plug data.� The data may be taken preferentially from certain geologic locations and there may be inconsistencies in the data.� The me

 n OPL246. As for some other turbiditic fields modelling of the 5 to 20m thick individual channels was the main challenge as they act as the
cies associations and petrophysical properties to the reservoir model. The new strategy divided in two steps proposes to be more consistent

he E-M field located offshore South Africa and thus significantly improve the history match. The reservoir is heavily faulted and many of the
ys embedded multilayered oil bearing reservoir sands. Sands were sedimented as thin tidal bars anastomosed with distributary and tidal chan

 cles of water and gas injection observed in previously published experimental studies. We predict the measured oil water and gas relative
 ’t obey this empirical rule. The best Archie fit to these data may not comply with physical bounds and create significant bias in the compu
ult in incorrect oil-in-place estimates and in unexpected dynamic behavior (e.g. under-waterflooding). A novel method is presented to determ
empted to study wettability on the pore scale level. In this study wettability evaluation of carbonate rock samples of Saudi Aramco reservoirs w
og data and performing correlations among nearby wells proved to be inconclusive in identifying gas reservoirs owing to their thin beds high


e need to determine the orientation and magnitude of the least principal stress. The presence of impermeable shales between producing sa
n. The supercharging results in an increase in sandface pressure which is above the reservoir pressure. Therefore any calculation of initial p
 n and Hammond 1990; Dussan and Sharma 1992; Goode and Thambynayagam 1992; Proett and Chin 1996). A geometric factor is used in
 solution for a horizontal well is the same as that for a vertical well if the wellbore curvature is not considered (in other words the wellbore ra
 desired structure.� During the course of drilling an 8 well Horizontal drilling program for the Kuwait Oil Company (K.O.C.) in the Burgan Fi
st. Rock typing is often used to help map the available capillary pressure data to the reservoir layers. Borehole nuclear magnetic resonance
 fluences the final static and dynamic reservoir properties. Dolomitisation is one of the most crucial diagenetic phases because of the way in
 this energy appears on seismic displays as a consistent interference pattern similar to the response of thin beds. The paper further suggests
 epends on a number of geological and petrophysical properties that influence the distribution of initial oil saturation (Sor) against depth and
 esolutions but very small lateral radii of investigation and the pressure transient tests have a large lateral radius of investigation but very po
 sh 2 rock types having the same range of porosity but different porosity-permeability relation. The dual porosity system is illustrated by stron
ast coast of India. The present study aims at reconstructing sedimentary depositional environment with the help of image logs and cores and
he reservoir heterogeneities. A realistic identification of the depositional environment is critical to the delineation and prediction of the best qu
 on cannot be obtained from conventional wireline logs. The DFA technique has been based largely on optical spectroscopy which can provi
 duction zones and optimize perforation zone selection. Relying only on open hole log data and performing correlations among nearby wells
upt changes in these fluid properties with depth may be markers for reservoir compartmentalization. However hydrocarbon differences can b
 on cannot be obtained from conventional wireline logs. The DFA technique has been based largely on optical spectroscopy which can provi

ption. The accuracy of model initialization (including matches of log saturation profiles and oil in place) and prediction of historical field perform
heory. First account is made to evaluate the effect of the aspect ratio of the facies. The outcome is two universal curves for the connectivity
ults in a damage zone adjacent to larger faults. Because there is usually inadequate data to incorporate damage zone fractures and faults int
al in the presence of extensive diagenesis process affecting the original depositional texture. The conventional triple combo logs gives an ave
 plexities associated with its evaluation. The complexities in general relate to a heterogeneous reservoir with complex mineralogy varying wa
od such as FZI (Flow zone indicator) and RQI (Reservoir quality index) were obtained based on core-analysis and well-logging data. This te
 atisfactory because they lack azimuthal sensitivity. Ideally geosteering and advanced formation evaluations such as anisotropy calculations
 envelope for well planning and reservoir information gathered in a single run. Optimum interpretation from real time data acquisition facilitate
rmation evaluation on LWD. The compact design of the new-generation LWD tool greatly increases the likelihood that measurements will be
 of such sources have always been known more awareness in the industry has led to increased efforts towards the reduction or even elimin


abilities to identify and target the desired objective horizon in the well have enhanced prospect economics the petrophysical evaluation of pr
ons between WL and LWD including costs savings associated with the LWD approach are common today in operators’ minds the inta


 nty in reservoir areal extent net reservoir thickness porosity and hydrocarbon saturation. In this work a methodology is presented to asses
 certainty in reservoir areal extent net reservoir thickness porosity and hydrocarbon saturation. In this work a methodology is presented to a
carbonates. The authors have earlier described an approach to estimating permeability in carbonates from borehole NMR logs and electrical
d carbonate cements are present within the sandstone with the anhydrite dominating in the uppermost units. The basal sand syones are ofte
a wide variety of textures.� In some intervals the depositional textures are preserved in others they are highly altered by diagenesis.� V
 eability in each layer resulting in changes in the well productivity and sweep properties. We illustrate the applications of NMR borehole ima




f the anisotropic shale point. The same shale point should be used in the determination of sand porosity. Difficulties will arise when anisotrop
f the anisotropic shale point. The same shale point should be used in the determination of sand porosity. Difficulties will arise when anisotrop
) apparent resistivity measurements (attenuation and phase shift) could be significant. These effects need to be considered in resistivity log i
ial deposits. Fracture corridors and permeable fault zones also represent a major risk of water breakthrough from the underlying aquifer in h
y operated by TNK-BP. Cores in the three modern wells were studied to determine lithology depositional facies and mineralogy. Results we
sment of fluid complexity compositional grading and acquisition of samples for input to PVT studies. Many deepwater reservoirs comprise
understanding of the fracture networks and their relationship with major and sub-seismic faults in this field is now critical to optimize infill drill
at it is computationally very expensive. In this study we use another approach based on the permeability contrasts that control the flow called

permeability can be split into either permeable or impermeable and assumes that the connectivity of permeability contrasts controls the flow
 ver they are mostly limited to onshore and shallow water fields. There is therefore the need to develop correlations that can reliably predict t
 and faults seen on electrical image logs cannot always be discerned as to whether they are of natural or drilling-induced origin. Cross-refer
 sq. km. of 3D seismic data of Al-Khafji oil field shows number of sinuous (channel-like) events in the north and north-east of the main Khafji

racterize the reservoir connectivity and sweep efficiency. However geostatistical modeling methods do not always make an accurate inferen
ulation is used to exam the dynamic performances and validate the SCH analysis. The impact of static modeling parameters on flow respon
 o characterize such reservoirs. The formation evaluation of thinly bedded reservoirs has several objectives: identify the layers that may co
sed to that of the sand-shale system). Formation evaluation in thin sand-shale laminations starts with their detection. NMR vertical resolution
sed to that of the sand-shale system). Formation evaluation in thin sand-shale laminations starts with their detection. NMR vertical resolution



ns to offset data acquired with wireline measurements and formation layer thickness determinations. The reasons for these inaccuracies gen
ions with data acquired with wireline measurements and formation layer thickness determinations. The reasons for these inaccuracies gener

06. Proprietary inversion techniques indicated the possible presence of a shallow surface resistive body while hinting at the presence of sligh
rock properties and the pore pressure variations throughout the wellbore. Pore pressure can be measured in the permeable zones and in-sit
rns of horizontal injection and production wells. Horizontal wells are increasingly being used for production and waterflooding. Long-term inje
 ration requires; first the most probable log porosity solution interpretation; second the most probable log porosity/permeability relationship (m
voir compaction and surface subsidence.� The mechanical parameters can be divided into three main groups viz. elastic parameters st
 ations performed using geologically realistic sector models at multiple levels of stratigraphic resolution show that dynamic connectivity is gov
  warning of impending drilling problems that may be mitigated by appropriate drilling fluid design and drilling practices. We have developed a
  warning of impending drilling problems that may be mitigated by appropriate drilling fluid design and drilling practices. We have developed a
ebel Al Akhdar. Visible is a large-scale layer cake-type carbonate ramp made up of thin but laterally extensive units. The formation has been
  providing a basis for the analysis of reservoirs exhibiting Darcy and non-Darcy flow respectively. Extension of the conventional Selective In
  providing a basis for the analysis of reservoirs exhibiting Darcy and non-Darcy flow respectively. Extension of the conventional Selective In
  providing a basis for the analysis of reservoirs exhibiting Darcy and non-Darcy flow respectively. Extension of the conventional Selective In
ial to identify areas of high fracture density. It has been observed that fractures associated with certain faults have facilitated the flow in the J
In this paper we developed a workflow of integrating formation micro imager Stoneley waves and petrophysical analysis for better fracture c

ndicating the volumetric fraction of fluids deposited inside the fractures is the storage capacity ratio which is function of the fracture and matr
e zones. The reservoir properties of the matrix are generally negligible and the production potential of wells is mostly associated with natura


understanding of the fracture networks and their relationship with major and sub-seismic faults in this field is now critical to optimize infill drill
 a stimulation treatment because their presence may require designs that differ from conventional matrix treatments. Literature shows that n
s vugs in some zones. The reservoir properties of the matrix are generally negligible and the production potential of wells is mostly associate
Monitoring (FMM) setup and experiment is to provide in-situ measurements required to determine multiphase flow properties such as relativ
c. Overlooking the variation in fluid properties that can and do exist in what appears to be a homogeneous reservoir on a typical log analysis
he relatively tight gas sands are drilled with significant overbalance due to a mix of depleted and virgin zone layers using oil based mud syste
he relatively tight gas sands are drilled with significant overbalance due to a mix of depleted and virgin zone layers using oil based mud syste

 ey also honor scale where feasible and are conformable with any pertinent rock-typing. For primary depletion the Leverett equivalent circu
own when the rock does not have paramagnetic elements the porosity measured with the NMR is not affected by the minerals within the ma
y and nuclear logs are used to infer basic fluid types caliper log is used to verify that the borehole is suitable for sampling and NMR logs are
y and nuclear logs are used to infer basic fluid types caliper log is used to verify that the borehole is suitable for sampling and NMR logs are


 his problem by introducing a pore-scale framework to accurately simulate suites of NMR measurements acquired in complex rock/fluid mod
n clay-bound capillary-bound and free water. In addition to these reservoir characterization problems we observe effects caused by the drilli
measurements of transverse relaxation (T2) polarization (T1) and diffusion (D). But compromises are inevitable for any given NMR techniqu
o more definitive work and present specific details only to illustrate the technology. Purpose: to inform the general readership of recent adva
mpts to optimize previous results using an integrated petrophysical characterization workflow. The geological complexity of the Estancia Cho
core plug data to delineate flow units within the most productive carbonate reservoir of Derdere Formation in Y field Southeast Turkey. Derd

 dramatically different from the matrix permeability measured in core plugs.� However realistic estimates of oil recovery and optimized res

and groundwater remediation efforts like soil venting operations depend on the amount of hydrodynamic dispersion of such rocks. Selecting a
 mation is used to estimate the individual pore conductances. Prior to this stereological corrections are used to convert apparent pore geome
ne large field subject of this study is such deposited in stacked Pliocene sandstones. These are high net-to-gross with predominant very fin
bulk density changes; the perceptual texture of these images reveals features like granularity mineralogy both tied to porosity distribution. In
 logging horizontal wells especially in multiphase flow. A new logging tool has been specifically designed to better characterize fluid flow in h

ures to the data actually observed in the reservoir. By reproducing multiple-point statistics inferred from training images MPS enables the mo

 a statistical and geostatistical nature that may create significant biases—always in the same direction—an underestimation of permeability
o the formation. It also facilitates the possibility for reservoir characterization during drilling. The purpose of this paper is to present (1) how to
practical field implementation of UBD reservoir characterization and the problems that consequently arise. Interpretation of data from UBD i


n residual saturations and the corresponding increase in relative permeability as viscous forces become dominant over the interfacial forces
ounting for the positive effect of coupling and the negative effect of inertia at near-wellbore conditions. The available functional forms estimat
 amic simulation of early wells suggested limited drainage acreage confined by baffle regions with limited connection to the larger reservoir. A
00 ft with an average Net of 170ft in the upper layers. An average porosity value will be around 15% and permeability ranges between 0.001â
quivalent to fault zones. We compared the location and spacing of fracture fairways from image logs with seismic faults and lineaments and
dicator of fracture corridors are borehole image logs. Unlike openhole logs and other borehole measurements image logs are available only

Downhole fluid analysis along with complementary techniques including geochemical mud-gas and pressure analyses provide valuable insig
new wells and emissions becoming increasingly undesirable. Thus compartments often have to be identified by some other means. Individ
Downhole fluid analysis along with complementary techniques including geochemical mud-gas and pressure analyses provide valuable insig
or production test. Therefore the challenge of obtaining sufficient reservoir and fluid data from complex wells in short time frames and at m



 large reservoir sand bodies. This procedure was applied in the Deepwater Tahiti field in the Gulf of Mexico uncovering a large concentration
 large reservoir sand bodies. This procedure was applied in the Deepwater Tahiti field in the Gulf of Mexico uncovering a large concentration
work providing a basis for the analysis of reservoirs that exhibit Darcy and non-Darcy flow respectively. An extension of the conventional S
nitoring techniques can identify inconsistencies leading to possible adjustments in recovery strategies and eventual improvements in ultimate
 generate saturation-height-function groups for nine reservoir-rock types. To match the large span of log water saturation (Sw ) in the transiti
ges from their original state before brought to laboratories. Hence capillary pressure (Pc) curves measured on different core samples of a he
ed approach of wettability restoration and a combination of steady state and centrifuge experiments. Therefore the team proposed to core fiv

 le-phase reservoir fluid eliminates the difficulties in designing a relatively simple model fluid that replicates the complicated thermodynamic a

 h diatomite subjected to a radial confining stress. Spontaneous imbibition tests at temperature gauge oil recovery potential at negligible pres

¿½C pH = 10). The effects of these experiments on the rock fabric were determined by comparing mineralogy pore structure and physical p
 stic inversion of the 1995 vintage 3D seismic petrophysical data collection and analysis and comprehensive reservoir characterization. This
e Jurassic Brent Group and younger Upper Jurassic Heather Sands with additional volumes in the Lower Jurassic Statfjord and Triassic. Inte
onsistencies in the data.� The measurement scale is significantly less than that required for input to flow simulation.� Mini-models of po
onsistencies in the data.� The measurement scale is significantly less than that required for input to flow simulation.� Mini-models of po

 he main challenge as they act as the elementary flow units of the reservoir. Although such flow units are under the current available seismic
 eps proposes to be more consistent with the petrophysical data and to ensure a better geological facies organization and a better facies con

oir is heavily faulted and many of the faults have no throw across them suggesting possible communication throughout the reservoir. Severa
mosed with distributary and tidal channels deposited under pro-deltaic to delta front environment. To delineate this complex reservoir a neur

measured oil water and gas relative permeabilities accurately. We discuss the hysteresis trends in the water and gas relative permeabilities
d create significant bias in the computed hydrocarbon saturation. This paper develops a new method for water saturation estimation based o
 novel method is presented to determine the wettability of rocks from nuclear-magnetic-resonance (NMR) data. The method is based on the
amples of Saudi Aramco reservoirs were investigated using environmental scanning electron microscope (ESEM). The data obtained gives a
ervoirs owing to their thin beds high shale content and variable formation water resistivity. Missing gas-bearing formations translates into los


meable shales between producing sands complicates fracturing design and field development to maximize recovery. Permeability and perme
 Therefore any calculation of initial pressure and permeability must take into account the supercharging effect. We present an algorithm tha
  1996). A geometric factor is used in formation rate analysis (FRA) (Kasap et al. 1999) a technique used in analyzing a probe test to estimat
 ered (in other words the wellbore radius is considered to be much larger than the probe radius). However when the probe is set vertically a
 l Company (K.O.C.) in the Burgan Field Kuwait it became apparent that there was a need for clearer and better quality real time log informa
orehole nuclear magnetic resonance (NMR) has been demonstrated to provide pore size distribution information and methods exist in the lite
enetic phases because of the way in which it constrains the permeability behaviour of the field. Detailed diagenetic research has shown that v
hin beds. The paper further suggests a filtering method to distinguish subtle faults from image processing artifacts and proposes a workflow
  saturation (Sor) against depth and on the rock and fluid interactions that control the residual oil saturation (Sor) capillary pressure and rela
 al radius of investigation but very poor vertical resolution. Constructing an appropriate simulation model requires rescaling the data and tha
porosity system is illustrated by strong leaching (i.e. dissolution) overprinting the primary interparticle porosity of a grainstone and responsibl
he help of image logs and cores and other available data set. Data analysis and integration of borehole images in 9 wells of the study area pr
 ineation and prediction of the best quality reservoir facies so that optimized exploitation of the reservoir can be achieved. This paper describe
 ptical spectroscopy which can provide estimates of filtrate contamination gas/oil ratio (GOR) pH of formation water and a hydrocarbon com
 ng correlations among nearby wells may be inconclusive since the channel sands under study have limited lateral extent and hard to correla
wever hydrocarbon differences can be identified reliably only when the significance of uncertainties from measurement and the oil-based mu
 ptical spectroscopy which can provide estimates of filtrate contamination gas/oil ratio (GOR) pH of formation water and a hydrocarbon com

nd prediction of historical field performance are strong function of these measurements. This paper discusses the impact of a�newly mea
universal curves for the connectivity and its associated uncertainty which can be used to estimate the connectivity of all sorts of body sizes
damage zone fractures and faults into reservoir simulation models in this study we utilize the principles of dynamic rupture propagation from
ntional triple combo logs gives an average response when logged against diagenetically altered zone thus overlooking or under-estimating di
 with complex mineralogy varying water salinities across the field which makes the visualization of a conceptual geological model in the pres
nalysis and well-logging data. This technology can be used to subdivide the reservoir into flow-units and identify the type of flow-units simulta
ons such as anisotropy calculations require azimuthally sensitive measurements.� This paper discusses a newly developed propagation
 m real time data acquisition facilitates a reformation of the way horizontal wells are planned and drilled. This paper shows a well where the in
 likelihood that measurements will be made before the onset of significant invasion. The colocation of resistivity- and neutron-based sensors
towards the reduction or even elimination of the use of chemical sources where possible. A new Logging-While-Drilling (LWD) tool has bee


 cs the petrophysical evaluation of prospective zones has never been straightforward. Well-to-well correlations are difficult because of rapid
 day in operators’ minds the intangible benefits gained by real-time acquisition of these critical data are often neglected. Incorporating fo


 a methodology is presented to assess the uncertainty in the hydrocarbon saturation estimated from open hole logs using the commonly used
work a methodology is presented to assess the uncertainty in the hydrocarbon saturation estimated from open hole logs using the commonly
om borehole NMR logs and electrical images and have earlier studied the relationship between NMR T2 distributions and capillary pressure
 nits. The basal sand syones are often shaly and silty. The sandstone porosity value range from 9% to 26% with typical values being from 22%
 e highly altered by diagenesis.� Vugs are developed in several intervals.� Computation of permeability from porosity alone yields scatte
 e applications of NMR borehole images and wireline formation testing technology in oil-base mud to evaluating the lithology the geometry a




 . Difficulties will arise when anisotropy is not caused by sand-shale laminations when no sand-shale point exists or when the nearby thick s
 . Difficulties will arise when anisotropy is not caused by sand-shale laminations when no sand-shale point exists or when the nearby thick s
ed to be considered in resistivity log interpretation. In this study LWD resistivity modeling work was conducted to study relationships between
 ough from the underlying aquifer in horizontal wells. The identification and characterization of open fractures and conductive faults is of critic
 al facies and mineralogy. Results were applied to crossplots of sonic and neutron log data. These crossplots showed six different lithofacies
Many deepwater reservoirs comprise of young turbiditic formations which even at great depths remain unconsolidated or only weakly cement
 ld is now critical to optimize infill drilling and produce the remaining reserves. The present paper focuses on the characterization of different
 contrasts that control the flow called percolation approach. This assumes that the permeability disorder of a rock can be simplified to either

meability contrasts controls the flow. The analysis of the connectivity based on finite size scaling assumes that fractures all have the same
correlations that can reliably predict the fracture pressure for deep water fields. This paper explores the concept of developing and possibly
or drilling-induced origin. Cross-reference with cores from the same sections allows such discrepancies to be reconciled: in an example case
rth and north-east of the main Khafji Structure in Tayarat Formation of Late Cretaceous age. The present study utilizes twenty two well data

not always make an accurate inference of reservoir properties from well-logs to a reservoir model because of the stationarity and ergodicity a
modeling parameters on flow responses is studied. Geological factors include net-to-gross (NTG) interbed connectivity intrabed heterogene
 ives: identify the layers that may contain hydrocarbons verify productivity and fluid types with formation testing and sampling calculate net
heir detection. NMR vertical resolution is mainly controlled by the antenna aperture that is in the case of a high-resolution antenna 6 in. or 1
heir detection. NMR vertical resolution is mainly controlled by the antenna aperture that is in the case of a high-resolution antenna 6 in. or 1



 e reasons for these inaccuracies generally originate from the traditional practice that LWD depth is purposely made equal to the driller’s
reasons for these inaccuracies generally originate from the traditional practice that LWD depth is purposely made equal to the driller’s de

   while hinting at the presence of slightly elevated resistivities at depth. An exploration well campaign was carried out over the prospect late in
 ed in the permeable zones and in-situ stress can be calculated by the modeling of closure stress from pre-fracture pressure testing. But thes
 on and waterflooding. Long-term injection into these wells can result in the creation of fractures that grow over time. The effect of fractures o
   porosity/permeability relationship (match core measured values); and third a quantitative capillary pressure model that represents measured
 n groups viz. elastic parameters strength parameters and in-situ stresses.� Even the profile of in-situ stresses with depth is estimated u
 how that dynamic connectivity is governed by large-scale architectural parameters such as meander belt size net-to-gross and degree of de
 lling practices. We have developed a new multifrequency inversion algorithm for the estimation of maximum and minimum horizontal stress
 lling practices. We have developed a new multifrequency inversion algorithm for the estimation of maximum and minimum horizontal stress
 nsive units. The formation has been subdivided into six composite sequences (KS1 shown in red to KS6 shown in dark blue). The main facie
nsion of the conventional Selective Inflow Performance analysis is also presented in this paper to obtain estimates of the formation and well c
nsion of the conventional Selective Inflow Performance analysis is also presented in this paper to obtain estimates of the formation and well c
nsion of the conventional Selective Inflow Performance analysis is also presented in this paper to obtain estimates of the formation and well c
aults have facilitated the flow in the Jurassic reservoirs. Identification of faults and associated fractures mainly has been on the basis of 3D-/
  physical analysis for better fracture characterization and selecting the best perforation intervals for a producing well. This workflow is applied

 h is function of the fracture and matrix porosity and fracture and matrix total compressibilities. Due to the difficulty to obtain these values in
wells is mostly associated with natural fractures and vugs. The presented study was our first project in Russia where a complete integrated a


 ld is now critical to optimize infill drilling and produce the remaining reserves. The present paper focuses on the characterization of different
x treatments. Literature shows that naturally fractured reservoirs are very susceptible to formation damage and require stimulation treatment
  potential of wells is mostly associated with natural fractures and vugs. The presented study was our first project in Russia where a complet
phase flow properties such as relative permeabilities and capillary pressures. Continuous monitoring of oil displacement by injected water in
us reservoir on a typical log analysis can lead to incorrect assumptions about the economic value of the hydrocarbon discovery the productio
 one layers using oil based mud systems. To further investigate possible near formation alteration an extensive evaluation program was unde
 one layers using oil based mud systems. To further investigate possible near formation alteration an extensive evaluation program was unde

pletion the Leverett equivalent circular pore diameter has been used to distinguish between reservoir and nonreservoir rock. This composite
ffected by the minerals within the matrix and the tool answers mainly to the contained fluids in the pores of the rock. This peculiar characteris
able for sampling and NMR logs are used to gauge if permeability is sufficient for a sample to be taken. However these logs are not able to c
able for sampling and NMR logs are used to gauge if permeability is sufficient for a sample to be taken. However these logs are not able to c


s acquired in complex rock/fluid models. The general pore-scale framework considered in this paper is based on NMR random walks for mul
e observe effects caused by the drilling process such as gas dissolution in OBM filtrate and time-lapse effects between LWD and Wireline l
 evitable for any given NMR technique. For example the overall acquisition time is dictated by operating at reasonable" logging speeds so fu
 e general readership of recent advances in various areas of petroleum engineering. Introduction This summary of the state of the art in n
 gical complexity of the Estancia Cholita Field which is mostly due to limited lateral continuity and small reservoir bed thickness particularly in
on in Y field Southeast Turkey. Derdere Formation is composed of limestones and dolomites. Logs from the 5 wells are the starting point for

tes of oil recovery and optimized reservoir management requires good estimates of the reservoir permeability.� In the Tengiz field a gian

 dispersion of such rocks. Selecting a representative scale to measure permeability and dispersivity in such rocks can be crucial because the
used to convert apparent pore geometries and various hydraulic corrections are applied to account for converging–diverging flow paths. Th
 t-to-gross with predominant very fine-grained sands. The efficient sweep of the oil in place requires a detailed understanding of the network
 y both tied to porosity distribution. In this paper we demonstrate that core scanner images contain information that can be related to petroph
d to better characterize fluid flow in horizontal wells. Advanced sensors provide better resolution among gas oil and water and cover more c

 raining images MPS enables the modeling of complex curvilinear structures (e.g. sinuous channels) in a much more geologically realistic w

—an underestimation of permeability. The passage from Phi to k is performed in three steps: (1) in cored wells an exponential regression e
 of this paper is to present (1) how to use the inflow data for the evaluation of formation properties and (2) how to cope with the uncertainty
se. Interpretation of data from UBD is made difficult by transducer errors operational transients and noise in data. It is therefore often very d


e dominant over the interfacial forces. New steady-state relative permeability data have been measured over a wide range of capillary numbe
 he available functional forms estimate the two effects separately and include a number of parameters which should be determined with mea
d connection to the larger reservoir. A campaign of surveillance data was carried out. Subsequent drilling indicated the reservoirs originally m
  permeability ranges between 0.001–17 mD. The oil in the Mishrif is highly viscous and production is normally enhanced by fractures in the
 h seismic faults and lineaments and estimated the percentage of fracture fairways that can be detected by seismic attribute maps. Correlatio
ments image logs are available only from a limited number of wells. It is necessary to utilize indirect indicators to identify and map fracture co

ssure analyses provide valuable insights into reservoir architecture. Each analytic method relies on different fluid traits and has its own limitat
ntified by some other means. Individual formation-pressure measurements downhole fluid analysis (DFA) and geochemistry are known to p
ssure analyses provide valuable insights into reservoir architecture. Each analytic method relies on different fluid traits and has its own limitat
 wells in short time frames and at manageable costs has pushed game changing improvements to both mud logging and wire line testing te



xico uncovering a large concentration variation of asphaltenes. These asphaltene nanoparticles are shown to be colloidally suspended in the
xico uncovering a large concentration variation of asphaltenes. These asphaltene nanoparticles are shown to be colloidally suspended in the
  An extension of the conventional Selective Inflow Performance analysis is presented in this paper to obtain estimates of the formation and
nd eventual improvements in ultimate recovery. The recovery strategy for As Sarah oilfield in Libya has been based on SCAL. PND logging
g water saturation (Sw ) in the transition zone from the free-water level (FWL) to minimum Sw high in the oil column three saturation-height f
 red on different core samples of a heterogeneous formation are usually correlated to porosity permeability and/or rock type using various te
erefore the team proposed to core five wells and embarked on a large scale special core analysis (SCAL) program covering all predominant

es the complicated thermodynamic and transport properties of a near-critical fluid. Two-phase-flow tests were performed across a range of p

 recovery potential at negligible pressure gradient. Numerous imbibition tests show that oil recovery from diatomite is accelerated and enhan

ralogy pore structure and physical properties of material collected before and after the experiments. One set of reservoir samples consist o
nsive reservoir characterization. This paper illustrates how Qatar Petroleum with contractual assistance from PGS Total and Beicip-Franlab
r Jurassic Statfjord and Triassic. Internally the field is compartmentalised by a number of N-S faults and a secondary alignment of NE-SW f
 ow simulation.� Mini-models of porosity and permeability are constructed and flow simulated in order to establish representative relationsh
 ow simulation.� Mini-models of porosity and permeability are constructed and flow simulated in order to establish representative relationsh

e under the current available seismic resolution the developed methodology with object modelling constrained by sedimentological interpreta
 organization and a better facies continuity than classical upscaling approaches. Step1. Litho-seismic petrophysical properties the dominan

tion throughout the reservoir. Several simulation efforts in the past have failed to reconcile the connected hydrocarbons initially in-place est
 ineate this complex reservoir a neural network technique was applied to estimate effective porosity integrating well information and 3D mult

water and gas relative permeabilities and compare the behavior of water-wet and oil-wet media. We interpret the results in terms of pore-sc
 r water saturation estimation based on the equivalent rock element model (EREM) that has been demonstrated to work well for rock transpo
R) data. The method is based on the additional nuclear relaxation that fluids experience when in direct contact with the rock surface. Reducti
 e (ESEM). The data obtained gives access to the distribution of oil and water in relation with mineral interface which can not be observed by
 bearing formations translates into lost productivity while perforating water zones can have detrimental effects on well performance. Moreove


ze recovery. Permeability and permeability anisotropy at different depths are unknown variables that affect well completion and reservoir man
 effect. We present an algorithm that takes into account the supercharging effect in analysis of pressure transient tests acquired with a sing
d in analyzing a probe test to estimate formation pressure and permeability. Like other geometric correction factors the geometric factor is a
 er when the probe is set vertically against the top or bottom wall the solution for a horizontal well is not available in the literature. This pape
 d better quality real time log information to enable the Drilling team to make quick decisions on were to place the well within the structure. Th
 rmation and methods exist in the literature to derive primary drainage capillary pressure data from the NMR log. In carbonates however it h
diagenetic research has shown that various genetic dolomite types exist including evaporative mixed evolved sea-water - freshwater and lat
 g artifacts and proposes a workflow allowing their integration into reservoir models either as connectivity enhancers related to the presence
ion (Sor) capillary pressure and relative permeability characteristics as a function of initial oil saturation. � Because of the general lack o
  requires rescaling the data and that may introduce significant uncertainties. To address these limitations we explored the use of electrode
osity of a grainstone and responsible for an increase of one order of magnitude in permeability. The dissolution is observed by patchy featur
mages in 9 wells of the study area present a detailed insight into the different architectural elements of the sedimentary environment envisag
can be achieved. This paper describes a methodology that was used to generate a depositional model in the Lower to Upper Triassic reservo
mation water and a hydrocarbon composition in four groups: methane (C1) ethane to pentane (C2–5) hexane and heavier hydrocarbons
ted lateral extent and hard to correlate. Several layers are potential pay zones and may contain oil or gas. �However water zones and sec
 measurement and the oil-based mud (OBM) filtrate have been taken into account. Recently an algorithm called the fluid-comparison algorit
mation water and a hydrocarbon composition in four groups: methane (C1) ethane to pentane (C2–5) hexane and heavier hydrocarbons

 usses the impact of a�newly measured SCAL data and a newly tuned EOS on model prediction for an off-shore complex carbonate field i
connectivity of all sorts of body sizes and aspect ratios very quickly. The approach is then reviewed for variable body sizes as well as a syste
 of dynamic rupture propagation from earthquake seismology to predict the nature of fractured/damage zones associated with reservoir scale
us overlooking or under-estimating diagenetic features occurring in micro scale.� It becomes imperative to look at both micro and macro s
 ceptual geological model in the presence of a complex structure a real challenge. The objective of the study was thus to characterize the res
 identify the type of flow-units simultaneously. This paper analyzed the rationality and petroleum geological meanings. Its application was sho
usses a newly developed propagation resistivity tool that is designed to be azimuthally sensitive for use in geosteering and formation evaluati
 This paper shows a well where the information was extracted and included in the decision making process to an extent that sets a new indus
 sistivity- and neutron-based sensors also means that key measurements are being made at the same depth at the same time and on a simil
 ng-While-Drilling (LWD) tool has been developed using innovative technology to provide a complete suite of formation evaluation measure


elations are difficult because of rapid facies changes in the Pennsylvanian Granite Wash along with complex folding and faulting in deeper h
 are often neglected. Incorporating formation pressure testing into the drilling process on the other hand creates challenges to perform mea


n hole logs using the commonly used empirical and theoretical shaly sand models. This technique is based on development of water saturat
  open hole logs using the commonly used empirical and theoretical shaly sand models. This technique is based on development of water sa
2 distributions and capillary pressure curves in carbonates. Additional enhancements have been made to this workflow to include estimates o
6% with typical values being from 22% to 24% substantially better than the interbedded carbonate units with typical value of 12% to 15%. Per
bility from porosity alone yields scatter of a factor of 700.� Rock typing using only conventional logs was unsatisfactory due to the poor per
aluating the lithology the geometry and the net producible fraction of these reservoirs: We demonstrate that the partitioning of NMR T2 distr




 int exists or when the nearby thick sand-shale is not representative of the sand-shale in the laminations. In producing fields that have underg
 int exists or when the nearby thick sand-shale is not representative of the sand-shale in the laminations. In producing fields that have underg
ducted to study relationships between true formation resistivity and LWD tool responses. In situations where the time-consuming resistivity m
  ures and conductive faults is of critical importance for the completion decisions in this field. Whole cores enable a comprehensive descriptio
splots showed six different lithofacies: basement weathered-basement high permeability sand low permeability sand salt/anhydrite-cement
nconsolidated or only weakly cemented. Experience has shown when sampling fluids from such formations sand grains and solids tend to b
es on the characterization of different types of fractures and faults identified on high-resolution image logs recorded in this field. The objective
r of a rock can be simplified to either permeable or impermeable. The advantage is that by using some universal laws from percolation theor

mes that fractures all have the same sizes. However natural fracture networks involve a relatively wide range of fracture lengths modelled
 concept of developing and possibly modifying some existing correlations to suit deep offshore needs as well as develop an Excel Spreadshe
 to be reconciled: in an example case it was observed that a large number of fractures seen on the images were absent in the cores. This pa
nt study utilizes twenty two well data in the crestal part of the Khafji structure to generate a semi-regional facies log which is turn up-scaled u

 se of the stationarity and ergodicity assumptions and the multiscale of subsurface heterogeneities. This often causes incorrect frequency sta
bed connectivity intrabed heterogeneity and reservoir log cutoff. Intrabed heterogeneity is usually misrepresented due to maximum entropy a
n testing and sampling calculate net pay thickness and uncertainty range. The evaluation is complex because of bed geometry and lithology
  a high-resolution antenna 6 in. or 15 cm. Within that distance NMR tools will cumulatively measure all layers of shales and all layers of san
  a high-resolution antenna 6 in. or 15 cm. Within that distance NMR tools will cumulatively measure all layers of shales and all layers of san



 osely made equal to the driller’s depth which is a static pipe length measurement made by tape at surface. There is almost always a di
 ely made equal to the driller’s depth which is a static pipe length measurement made by tape at the surface. There is almost always a d

s carried out over the prospect late in 2006 but rather than encountering the expected hydrocarbon pay the well encountered a near surface
 re-fracture pressure testing. But these tests are rarely performed in the nonreservoir rocks above and below the fracture stimulation treatme
 w over time. The effect of fractures on reservoir sweep and on problems such as early water breakthrough is largely controlled by fracture / s
sure model that represents measured high pressure mercury and oil/water drainage capillary pressure data. In this paper the classical Leve
 itu stresses with depth is estimated using logs with elastic parameters as an essential input.� The focus of this work is on the prediction of
 lt size net-to-gross and degree of depositional storey amalgamation; and stratigraphic parameters that describe the shale architecture at mu
mum and minimum horizontal stress magnitudes by use of cross-dipole dispersions. Borehole sonic data for the case study presented in this
mum and minimum horizontal stress magnitudes by use of cross-dipole dispersions. Borehole sonic data for the case study presented in this
6 shown in dark blue). The main facies types are: 1 graded peloidal oolitic packstones to grainstones 2 mottled and rooted mudstones 3 gra
  estimates of the formation and well completion properties such as effective permeability radial flow steady state damage /stimulation skin ef
  estimates of the formation and well completion properties such as effective permeability radial flow steady state damage /stimulation skin ef
  estimates of the formation and well completion properties such as effective permeability radial flow steady state damage /stimulation skin ef
mainly has been on the basis of 3D-/2D-seismic data image logs cores and thin sections. The Greater Burgan field consists of the Burgan
oducing well. This workflow is applied on well NWO-1 in the Northwest October Concession in the Gulf of Suez area over the carbonate rese

he difficulty to obtain these values in reservoir engineering computations such as pressure transient analysis and reservoir simulation amon
 ussia where a complete integrated approach was implemented to properly characterize a fractured reservoir. The approach included the follo


es on the characterization of different types of fractures and faults identified on high-resolution image logs recorded in this field. The objective
 ge and require stimulation treatments to account for this issue. The historical problem however has been to confidently characterize the res
 st project in Russia where a complete integrated approach was implemented to properly characterize a fractured reservoir. The approach inc
oil displacement by injected water in all the permeable zones was conducted in a carbonate reservoir in Saudi Arabia. The field experiment w
 hydrocarbon discovery the production facilities required to produce the resource and the predicted ultimate recovery. Recent advances in w
 tensive evaluation program was undertaken using new generation sonic logs WFT-multi-probe interval pressure transient testing (IPTT) an
 tensive evaluation program was undertaken using new generation sonic logs WFT-multi-probe interval pressure transient testing (IPTT) an

nd nonreservoir rock. This composite parameter can incorporate mobility for multiphase work. It is linked to a discrete core porosity under sim
 of the rock. This peculiar characteristic of the NMR response in these low porosity reservoirs with complex and variable lithology become f
 However these logs are not able to capture variations in the hydrocarbon column to allow the operator to ensure that all representative fluids
 However these logs are not able to capture variations in the hydrocarbon column to allow the operator to ensure that all representative fluids


 ased on NMR random walks for multiphase fluid diffusion and relaxations combined with Kovscek’s pore-scale model for two-phase flu
  effects between LWD and Wireline logs. NMR measurements of porosity bound fluid volume pore size distribution and direct fluid identific
 at reasonable" logging speeds so full polarization of long T1 fluids is rarely achieved. Additionally the inversion process creates interdepend
 s summary of the state of the art in nuclear-magnetic-resonance (NMR) well-logging technology is aimed at nonspecialists who would like to
 eservoir bed thickness particularly in the Castillo Formation makes layer-by-layer correlation difficult. Several other factors add to the comp
m the 5 wells are the starting point for the reservoir characterization. The general geologic framework obtained from the logs point out for disc

eability.� In the Tengiz field a giant carbonate reservoir in western Kazakhstan a method has recently been developed to calculate appar

uch rocks can be crucial because the connected vug lengths can be longer than typical core diameters. Large touching vug (centimeter-scal
onverging–diverging flow paths. These various corrections are the principal and crucial differences between our approach and previous m
etailed understanding of the network of the reservoir pore structure and the permeability distribution and capillary bound fluids. To better un
mation that can be related to petrophysical properties. This paper presents a fully automated method based on a stochastic approach for tex
gas oil and water and cover more cross sectional areas of a wellbore for enhanced characterization of multiphase flow regimes. The new to

  a much more geologically realistic way than traditional two-point statistics (variogram-based) techniques. However in the original MPS imple

 ed wells an exponential regression equation is established between core porosity and core permeability k; (2) in uncored wells log porosity
 (2) how to cope with the uncertainty of the results. An in-house multiphase reservoir simulator is used for the simulation of the formation res
 se in data. It is therefore often very difficult to interpret the reservoir characteristics from the instantaneous productivity index (PI). In this pap


 over a wide range of capillary numbers including very high values corresponding to the near-well region.� These measurements have bee
which should be determined with measurements at high-velocity conditions. Measurements of gas/condensate relative permeability at simula
g indicated the reservoirs originally modeled in pressure isolation were experiencing pressure depletion through connections between reser
normally enhanced by fractures in the upper Mishrif layers as they act as the main permeability conduit for the main storage below. The seco
 by seismic attribute maps. Correlation with flow profiles lost circulation and water breakthrough and productivity index was necessary to det
 cators to identify and map fracture corridors such as lost circulation step flow profiles water breakthrough or seismic lineaments. This fits w

 rent fluid traits and has its own limitations. With systematic integration of different methods the synergy delivers a more accurate characteriz
  A) and geochemistry are known to provide important information about reservoir architecture. When these powerful methods are combined
 rent fluid traits and has its own limitations. With systematic integration of different methods the synergy delivers a more accurate characteriz
 h mud logging and wire line testing technologies. In the past interpretation of wireline formation testing data (e.g. static pressure gradient a



wn to be colloidally suspended in the crude oil in agreement with recent laboratory results and settle preferentially lower in the oil column in a
wn to be colloidally suspended in the crude oil in agreement with recent laboratory results and settle preferentially lower in the oil column in a
btain estimates of the formation and well completion properties such as effective permeability radial flow steady state damage /stimulation s
  been based on SCAL. PND logging in producing wells has generally confirmed forecast saturations1 and only slight adjustments to the initia
e oil column three saturation-height functions per rock type (RT) were developed one each for the low- medium- and high-porosity range. T
 ility and/or rock type using various techniques to generate field wide saturation height function. This paper evaluates performance of six sat
L) program covering all predominant rock types in order to get a better handle on the relative permeability characteristics. This paper prese

  were performed across a range of pressures and flow rates to simulate reservoir conditions from initial production through depletion. A sing

m diatomite is accelerated and enhanced at elevated temperature mainly due to a systematic shift toward greater water. Comparison of resul

 ne set of reservoir samples consist of relatively clean calcite-rich opal-A and opal-CT diatomites. Samples from the other reservoir are clay-r
  from PGS Total and Beicip-Franlab has applied advanced reservoir characterization techniques to constrain petrophysical property distribu
d a secondary alignment of NE-SW faults which cross cut and often offset the main N-S faults. The larger scale faults down throw to the eas
 to establish representative relationships/correlations at the grid block scale used in SAGD flow simulation. �The mini-models are construc
 to establish representative relationships/correlations at the grid block scale used in SAGD flow simulation. �The mini-models are construc

ained by sedimentological interpretation and seismic derived Vclay cube allowed to provide reservoir engineers with geologically representa
etrophysical properties the dominant seismic facies and seismic facies probabilities are predicted. This creation is based on interpreted upsc

ed hydrocarbons initially in-place estimated from material balance and those calculated volumetrically leading to unsubstantiated assumptio
 grating well information and 3D multi-attributes between seismically mapped sequences. This method is more efficient than conventional es

erpret the results in terms of pore-scale displacements.�In water-wet media the water relative permeability is lower in the presence of ga
nstrated to work well for rock transport properties to the first order effect. EREM contains two orthogonal pore components one parallel and
ontact with the rock surface. Reduction of oil relaxation time away from its bulk value is generally known as a qualitative wettability indicator
erface which can not be observed by normal techniques. It also improves the understanding of rock/fluid interaction. In this study preserved
effects on well performance. Moreover the limited lateral extent of these relatively tight gas sands leads to extremely depleted reservoirs alte


ect well completion and reservoir management decisions. A set of wireline formation evaluation tools were used for microfracturing (stress te
e transient tests acquired with a single or multiple probe formation tester. The solution is obtained by successive integral transforms to the go
 tion factors the geometric factor is a strong function of permeability anisotropy that is generally unknown before a test. When analyzing the t
  available in the literature. This paper presents an analytical solution to the described problem. The solution shows that the relationship betw
 place the well within the structure. This short paper will show the step change bought about in 3 of the wells drilled and the success and bene
NMR log. In carbonates however it has been pointed out that variations exist in the relationship between pore body size and pore throat size
volved sea-water - freshwater and late thermobaric. Defining static rock-type can therefore be problematic due to the highly imbricate diagen
 ty enhancers related to the presence of open fracture networks in the vicinity of fault surfaces or as indications of faults with minor throws ac
 . � Because of the general lack of relevant experimental data and the insufficient physical understanding of the characteristics of the tran
ns we explored the use of electrode resistivity array (ERA) measurements in a carbonate formation for reservoir characterization. The ERA w
 solution is observed by patchy feature on core. Similarly this high level of heterogeneity can be observed downhole by borehole imaging too
 he sedimentary environment envisaged. This study helps in static modeling of the reservoir with better understanding of process sedimentolo
n the Lower to Upper Triassic reservoirs of the Rhourde El-Khrouf field based on subsurface data from six wells including well logs borehole
 ) hexane and heavier hydrocarbons (C6+) and carbon dioxide (CO2). For single-phase assurance it is possible to detect gas liberation (bu
 s. �However water zones and secondary gas cap formation in a few layers are also common. Nonetheless unexpected fluid production
 m called the fluid-comparison algorithm (FCA) was developed to address this issue. The FCA propagates uncertainties in optical measurem
 ) hexane and heavier hydrocarbons (C6+) and carbon dioxide (CO2). For single-phase assurance it is possible to detect gas liberation (bu

 n off-shore complex carbonate field in Abu Dhabi UAE. The subject reservoir has been put on production using a combination of Gas/Water
 variable body sizes as well as a system with oriented bodies. An effective size based on the square root of the average area of bodies can
zones associated with reservoir scale faults. We include geomechanical constraints in our reservoir model and propose a workflow to more r
 ve to look at both micro and macro scale heterogeneity for evaluation of such reservoirs which has a direct impact on the production and w
 tudy was thus to characterize the reservoir at wellbore level and conduct realistic inter-well and reservoir-scale geo-modeling for improved o
cal meanings. Its application was shown by some examples from DaQing Oilfield. Key words: flow unit slice-merging auto-subdivide inner h
n geosteering and formation evaluation while drilling. It uses the tilted antenna concept to produce directionally sensitive measurements that
ess to an extent that sets a new industry standard. Applying an accurate 3D rotary steerable system with openhole sidetrack capabilities incre
 epth at the same time and on a similar volume of the formation. These features ensure that all measurements are essentially seeing the sam
uite of formation evaluation measurements without having to use a chemical radioactive logging source. The use of a non-chemical radioac


mplex folding and faulting in deeper horizons along the Wichita Mountain Front. Nearby wells are often not connected because of the rapid fa
 creates challenges to perform measurements in a timely manner as well as the need for continuous circulation while testing to ensure wellb


 sed on development of water saturation error analysis charts for the commonly used water saturation models (Simandoux Indonesian Wax
 is based on development of water saturation sensitivity charts for the most commonly used water saturation models (Simandoux Indonesian
o this workflow to include estimates of relative permeability by modeling invasion of mud filtrate utilizing a fluid flow model in combination with
with typical value of 12% to 15%. Permeabilities over 2 Darcies have been measured in this field. The carbonate can have higher permeabilit
 as unsatisfactory due to the poor permeability estimation.� The effect of geological complexity on the log based prediction is overcome by
e that the partitioning of NMR T2 distribution is a robust method for calculating independent volumes of clay silt and sand. We present the e




 . In producing fields that have undergone several waterfloods water resistivity is often unknown in the swept thick sands and might not be re
 . In producing fields that have undergone several waterfloods water resistivity is often unknown in the swept thick sands and might not be re
here the time-consuming resistivity modeling/inversion is not available LWD apparent attenuation is found to be more representative to true f
 s enable a comprehensive description of fractures (morphology and type) over the cored sections of the reservoir. Meso-scale fractures can
meability sand salt/anhydrite-cemented sand and carbonate. Sand was subdivided into relatively high and relatively low permeability sands u
 ons sand grains and solids tend to become mobilized and flow with the fluid being sampled. In some circumstances where significant forma
 s recorded in this field. The objective of this study is to provide a more detailed fracture network to explain the present-day reservoir behavio
universal laws from percolation theory the effect of the complex geometry which influences the global properties (e.g. connectivity or conduc

 range of fracture lengths modelled by either scale-limited laws (e.g. log normal) or power laws. In this paper we extend the applicability of
   well as develop an Excel Spreadsheet and a V-Basic program that can be used to predict fracture pressure for deep offshore fields both in
  es were absent in the cores. This paper describes how geomechanical analyses have been used to address factors leading to the developm
 l facies log which is turn up-scaled using seismic attribute map. As the area is not covered by any well or other form of data a variogram ana

 often causes incorrect frequency statistics of reservoir properties which typically exhibit a non-Gaussian distribution. As a result estimation
presented due to maximum entropy assumption stationary assumption of geostatistics and upscaling. The intrabed heterogeneity is modele
ecause of bed geometry and lithology. The reservoir beds are often thinner than the resolution of the formation evaluation logs. They exhibit
layers of shales and all layers of sands regardless of their individual thicknesses. Because NMR relaxation time in shales is much faster than
layers of shales and all layers of sands regardless of their individual thicknesses. Because NMR relaxation time in shales is much faster than



surface. There is almost always a difference between the actual measured depth (MD) of the LWD sensor downhole and this static pipe me
e surface. There is almost always a difference between the actual measured depth (MD) of the LWD sensor downhole and this static pipe m

  the well encountered a near surface and resistive hydrate layer. Good quality but water-bearing reservoir was encountered at the target dep
elow the fracture stimulation treatment. The challenge for the stimulation design engineer is to determine the mechanical rock properties in a
 gh is largely controlled by fracture / stress reorientation. A systematic study of stress reorientation around horizontal wells and well patterns w
 ata. In this paper the classical Leverett-J method (Leverett 1941) was used in the integration of capillary pressure data with routine core ana
 us of this work is on the prediction of elastic parameters and their variation with the depth of a given reservoir. For an isotropic medium the
 describe the shale architecture at multiple scales e.g. shale drape coverage and frequency of occurrence. We demonstrate how to rapidly g
a for the case study presented in this paper was acquired by a cross-dipole sonic tool in a deepwater well offshore Louisiana in the Gulf of M
a for the case study presented in this paper was acquired by a cross-dipole sonic tool in a deepwater well offshore Louisiana in the Gulf of M
mottled and rooted mudstones 3 graded oolitic grainstones 4 cross-bedded oolitic grainstones.
ady state damage /stimulation skin effect and non-Darcy flow coefficient.� In the specific case where the deliverability performance of a ve
ady state damage /stimulation skin effect and non-Darcy flow coefficient.� In the specific case where the deliverability performance of a ve
ady state damage /stimulation skin effect and non-Darcy flow coefficient.� In the specific case where the deliverability performance of a ve
r Burgan field consists of the Burgan Magwa and Ahmadi structures. The four main reservoir units in the Greater Burgan field are the Wara
of Suez area over the carbonate reservoir. The well was drilled on the peak of anticlinal feature created by fault propagation fold of a normal

 lysis and reservoir simulation among others it is generally assumed that the matrix and the fracture total compressibilities are equal. This in
 rvoir. The approach included the following tasks: 1) Identification of fractured intervals in wells using a special technique of BKZ logs process


 s recorded in this field. The objective of this study is to provide a more detailed fracture network to explain the present-day reservoir behavio
 en to confidently characterize the reservoirs pre-frac in terms of both the reservoir quality and the deliverability mechanism (fractures vs. mat
 fractured reservoir. The approach included the following tasks: 1) Identification of fractured intervals in wells using a special technique of BK
 Saudi Arabia. The field experiment was divided into two stages: 1) Selection of the well location coring and logging experimental setup and
mate recovery. Recent advances in wireline formation testers have enabled the determination of several fluid properties including fluid comp
  pressure transient testing (IPTT) and coring. A Sonic Scanner* survey was conducted in Tunu field to investigate possible nearby formation
  pressure transient testing (IPTT) and coring. A Sonic Scanner* survey was conducted in Tunu field to investigate possible nearby formation

d to a discrete core porosity under simulated reservoir conditions so the adopted net reservoir cutoff is expressed as a limiting porosity. For w
 plex and variable lithology become fundamentally beneficial at the time of determining an immediate porosity value with less uncertainty in c
 o ensure that all representative fluids are sampled. The most important information a continuous fluids type and property log is still not wide
 o ensure that all representative fluids are sampled. The most important information a continuous fluids type and property log is still not wide


 s pore-scale model for two-phase fluid saturation and wettability alteration. We use standard 2D NMR methods to interpret synthetic data set
e distribution and direct fluid identification can be applied to resolve the challenges mentioned above. We demonstrate the use of NMR data
 version process creates interdependencies between T1 T2 and D. These effects conspire to introduce inaccuracies in the reported porosity
ed at nonspecialists who would like to gain some knowledge of the formation-evaluation capabilities of NMR logging tools. The objective is t
 everal other factors add to the complexity of petrophysical evaluations these include: alteration of petrophysical properties in certain zones n
 ained from the logs point out for discriminations within the formation. 58 representative core plug data from 4 different wells are utilized to be

ly been developed to calculate apparent permeability (APERM) based on flow rate from production (PLT) logs.� Incorporation of this flow

  Large touching vug (centimeter-scale) Cretaceous carbonate rocks from an exposed rudist (caprinid) reef buildup at the Pipe Creek Outcro
 tween our approach and previous methods based on two-dimensional images. Finally Kirkpatrick’s effective medium approximation is u
d capillary bound fluids. To better understand and characterize the permeability and to help quantify the potential reserves a novel low gradi
ased on a stochastic approach for textural analysis and segmentation of core scanner images. The technique used to obtain image models is
 multiphase flow regimes. The new tool is also more compact to pass through intervals that have high dog legs. In this paper we will briefly re

s. However in the original MPS implementation all multiple-point statistics moments computed from the training image are exported to the r

 k; (2) in uncored wells log porosity is used instead as input to predict permeability; and (3) the same equation is sometimes used again to p
or the simulation of the formation reservoir-fluid flow during UBD. The model incorporates discrete consideration of the well with appropriate
ous productivity index (PI). In this paper we introduce a parameter known as the Rate Integral Productivity Index (RIPI) which borrows from


 � These measurements have been made on several reservoir rocks as well as outcrop rocks and over a range of temperature pressure
 nsate relative permeability at simulated near-wellbore conditions are very demanding and expensive. Recent experimental findings in this la
  through connections between reservoirs. A major effort was undertaken to recharacterize the reservoir rebuild the static model and genera
or the main storage below. The second Mishrif layer unit 2 (M9 & M8) is a fairly high porous peloidal packstone to grainstones sequence tha
 ductivity index was necessary to determine fraction of fluid conductive seismic faults and fracture corridors from borehole images. The resul
ugh or seismic lineaments. This fits well into a Bayesian scheme to infer the cause from the manifestations. The conditional probability of hav

delivers a more accurate characterization of the reservoir. In this paper we link traditional and novel fluid analysis methods to build a more c
ese powerful methods are combined systematically and applied to data sets the resulting synergy delivers a much more accurate and robus
delivers a more accurate characterization of the reservoir. In this paper we link traditional and novel fluid analysis methods to build a more c
data (e.g. static pressure gradient analysis and downhole fluid analyses) PVT and geochemical fingerprinting have provided major inputs fo



 ferentially lower in the oil column in accord with the Boltzmann distribution. Relevant fluid features in this case the asphaltene concentration
 ferentially lower in the oil column in accord with the Boltzmann distribution. Relevant fluid features in this case the asphaltene concentration
w steady state damage /stimulation skin effect and non-Darcy flow coefficient. In the specific case where the deliverability performance of a v
  d only slight adjustments to the initial strategy have been necessary to achieve a recovery factor greater than 40% at the end of the plateau
  medium- and high-porosity range. Though developed on a different scale from the simulation-model cells the saturation profiles generated
per evaluates performance of six saturation-height methods (i.e. Leverret-J[1] Cap-Log[2] Johnson[3] Cuddy et al. [4] Skelt-Harrison[5] an
 lity characteristics. This paper presents a case study of using a properly measured set of relative permeability data to replace the previously

 production through depletion. A single-phase multirate experiment was also performed to assess inertial or non-Darcy effects. Correlations

d greater water. Comparison of results for cores from different diatomite reservoirs appears to indicate that dissolution of calcium-bearing mi

 es from the other reservoir are clay-rich opal-A diatomites. The hot alkaline fluids produced porosity channels in samples from both reservo
nstrain petrophysical property distribution using elastic inversion products and therein reducing uncertainty in a reservoir model. Following de
er scale faults down throw to the east and subdivide the field into four main areas; the West Flank Central Panel and Frontal Panel with anup
on. �The mini-models are constructed on a by-facies basis honoring the spatial variability within each category. �The uncorrected mini-m
on. �The mini-models are constructed on a by-facies basis honoring the spatial variability within each category. �The uncorrected mini-m

ngineers with geologically representative model to be able to simulate properly the flow behaviour and further estimate the reserves. Introdu
creation is based on interpreted upscaled stratilogs (Facies Groups) and calibrated on all available petrophysical attributes. Step2. Seismic

eading to unsubstantiated assumptions in order to attain a reasonable history match. The paper draws on the strength of an integrated petr
s more efficient than conventional estimation with the ability to build a non-linear relationship between seismic traces and target porosity logs

eability is lower in the presence of gas during waterflooding due to an increase in oil/water capillary pressure that causes a decrease in wettin
  pore components one parallel and the other perpendicular to the direction of transport. Pore structure efficiency is defined as the volume ra
  as a qualitative wettability indicator assuming external factors to be negligible and/or invariant from one experiment to another. Through det
  interaction. In this study preserved rock samples from two distinct reservoirs (Arab-C and Shu'aiba) were used. The mineralogical analysis
 to extremely depleted reservoirs alternating with layers with virgin zone pressures. As a consequence the depleted layers face a significant


ere used for microfracturing (stress tests) at several sand and shale formations. The stress tests were performed by isolating 1 m of formatio
ccessive integral transforms to the governing equations and to the associated initial and boundary conditions. Thus a complex phenomenon
n before a test. When analyzing the test we would logically assume an isotropic formation and use the corresponding isotropic geometric fac
ution shows that the relationship between the pressure drop and flow rate for a single-probe test in a horizontal well depends on the geometri
 ells drilled and the success and benefits realized by using long gauge PDC bits combined with a specialized short bearing pack motors not
n pore body size and pore throat size. NMR is believed to reflect the former while the latter controls capillary pressure. Hence the applicabili
 ic due to the highly imbricate diagenetic phases and their various distributions and extensions. A further major difficulty is the spatial distribu
cations of faults with minor throws acting as buffer or barrier zones. Observations Most current belief based upon decades of paper sections
ding of the characteristics of the transition zone modeling both the static and dynamic properties of carbonate fields with large transition zon
 eservoir characterization. The ERA was installed on tubing in a barefoot well rather than permanently cemented outside the casing as in pre
 d downhole by borehole imaging tool. The heterogeneous porosity map from the image tool is then converted into a single curve representin
 nderstanding of process sedimentology that controls the reservoir properties of sands. The study area has been interpreted from Lower to U
six wells including well logs borehole images cores and the regional knowledge of the basin. Structural and sedimentary dip analyses were
  possible to detect gas liberation (bubblepoint) or liquid dropout (dewpoint) while pumping reservoir fluid to the wellbore before filling a samp
heless unexpected fluid production such as water or excessive gas is an undesirable outcome. A formation tester equipped with an extra la
tes uncertainties in optical measurement and contamination into uncertainties in fluid properties such as color composition and GOR. The
  possible to detect gas liberation (bubblepoint) or liquid dropout (dewpoint) while pumping reservoir fluid to the wellbore before filling a samp

on using a combination of Gas/Water/WAG injection schemes in early 2006. An advanced EOR/PVT study was carried out using representa
t of the average area of bodies can be used to represent the distribution of body sizes. For systems with oriented bodies a new aspect ratio
 el and propose a workflow to more routinely incorporate damage zones into reservoir simulation models. The model we propose calculates
rect impact on the production and water injection scheme of such reservoirs. The NMR data and image based secondary porosity estimatio
r-scale geo-modeling for improved oil-field development by means of a comprehensive interdisciplinary approach. The Jaipur area is mainly
slice-merging auto-subdivide inner homogeneity Integrated Flow Factor (IFF) Introduction The concept of flow-unit or hydraulic unit was pr
 ionally sensitive measurements that are lacking in traditional LWD propagation tools. This paper also discusses the theory and the developm
  openhole sidetrack capabilities increase well design flexibility and the ability to act on the real-time LWD data. The bottom hole assembly us
 ments are essentially seeing the same amount of invasion thus removing a major complication in conventional LWD interpretation. Introduc
  The use of a non-chemical radioactive source significantly reduces the environmental and operational risks normally involved with tradition


ot connected because of the rapid facies changes and the intense faulting and folding. High density/neutron porosities do not relate directly to
 culation while testing to ensure wellbore safety. Formation testing at Bohai Bay is difficult because of the unconsolidated formations and all


 odels (Simandoux Indonesian Waxman & Smits Dual Water and Effective Medium) due to the uncertainty in the different input parameters
ation models (Simandoux Indonesian Waxman & Smits Dual Water and Effective Medium) due to the uncertainty in the different input para
a fluid flow model in combination with array resistivity logs. Analyzing relative permeability in conjunction with formation permeability and capi
arbonate can have higher permeability calculated1 from flow tests as a result of fractures within the carbonate. Borehole imaging provided
e log based prediction is overcome by including pore size distribution data from a combination of NMR and borehole electrical image logs.�
 lay silt and sand. We present the experimental set-up and the application of a novel method to calculate the thin sand fraction of a laminate




wept thick sands and might not be representative of the water in the unswept thin sands. As discussed previously NMR offers useful insight
wept thick sands and might not be representative of the water in the unswept thin sands. As discussed previously NMR offers useful insight
nd to be more representative to true formation resistivity than the apparent phase shift resistivity thus can be used in formation water saturat
  reservoir. Meso-scale fractures can also be identified oriented and characterized (open vs. cemented) on high resolution borehole images
nd relatively low permeability sands using the laterolog and microlaterolog based on the observation that sand with microlaterolog values les
rcumstances where significant formation solids and sand are mobilized deposition of suspended solids can result in the premature ending o
ain the present-day reservoir behavior. A uniform classification scheme of fracture types was devised and specific properties namely density
 operties (e.g. connectivity or conductivity) can be easily estimated in a fraction of a second on a spread sheet. The aim of this contribution i

 paper we extend the applicability of the percolation approach to a system with a distribution of size. For scale-limited distributions we use t
 sure for deep offshore fields both in the Niger Delta region and the Gulf of Mexico. Furthermore the predicted fracture gradient (LOT) values
dress factors leading to the development of drilling-induced features in a borehole and to explain why some fractures on the electrical images
or other form of data a variogram analysis followed by sequential indicator simulation method was used to derive a facies model between Tay

n distribution. As a result estimation of the hydrocarbon in-place and recoverable reserves can be grossly inaccurate and hundreds of million
 he intrabed heterogeneity is modeled by Vdp based permeability multiplier. The flow responses of these modeling factors are examined by a
mation evaluation logs. They exhibit a silty lithology and fine grain texture and require high quality borehole resistivity images to characterize
 on time in shales is much faster than in the productive sands thin sand-shale laminations appear on NMR logs with the characteristic bimod
 on time in shales is much faster than in the productive sands thin sand-shale laminations appear on NMR logs with the characteristic bimod



sor downhole and this static pipe measurement because downhole the drillpipe is subject to an environment that is not representative of the
nsor downhole and this static pipe measurement because downhole the drillpipe is subject to an environment that is not representative of th

oir was encountered at the target depth. This disappointment was the first CSEM negative test in the basin and vindicates the need for furthe
e the mechanical rock properties in and around the treatment interval. Calculating in-situ stress with the uniaxial strain equation requires the
nd horizontal wells and well patterns will allow an operator to (a) select candidate wells for fracturing (b) choose appropriate operating conditio
  y pressure data with routine core analysis and petrophysical rock types to generate a robust model for predicting formation water saturation
 ervoir. For an isotropic medium there are two independent elastic parameters viz. Young’s modulus and Poisson’s ratio.� Gene
 ce. We demonstrate how to rapidly generate effective properties at multiple geologic scales incorporating the effect of channel architecture
 ll offshore Louisiana in the Gulf of Mexico (GOM). The logged interval spans 1 000 ft below the casing shoe. In addition the Modular Dynam
 ll offshore Louisiana in the Gulf of Mexico (GOM). The logged interval spans 1 000 ft below the casing shoe. In addition the Modular Dynam

 the deliverability performance of a vertically fractured well is considered estimates of the effective fracture half-length and average fracture
 the deliverability performance of a vertically fractured well is considered estimates of the effective fracture half-length and average fracture
 the deliverability performance of a vertically fractured well is considered estimates of the effective fracture half-length and average fracture
 e Greater Burgan field are the Wara Mauddud Burgan Third and Burgan Fourth sands. The deeper reservoirs--namely the Lower Cretace
 by fault propagation fold of a normal fault that located nearby the well. The main objective was to determine the structural geology features (

al compressibilities are equal. This induces a big uncertainty in the estimation of the storage capacity ratio and leads to a wrong estimation o
pecial technique of BKZ logs processing 2) Spectral imaging and high-resolution inversion of the seismic data 3) structural analysis of the fi


ain the present-day reservoir behavior. A uniform classification scheme of fracture types was devised and specific properties namely density
rability mechanism (fractures vs. matrix) before committing to these design specifications. This paper presents the results of a simulator use
wells using a special technique of BKZ logs processing 2) Spectral imaging and high-resolution inversion of the seismic data 3) structural an
 and logging experimental setup and completion designs cleanup production profiles pressure transient buildup tests water injection and s
 fluid properties including fluid compositions in real time. In addition mini-DST or Interval Pressure Transient Testing (IPTT) can be carried o
 nvestigate possible nearby formation alteration followed by MDT*-multi-probe IPTT. �The Sonic Scanner dipole radial profiling showed so
 nvestigate possible nearby formation alteration followed by MDT*-multi-probe IPTT. �The Sonic Scanner dipole radial profiling showed so

xpressed as a limiting porosity. For waterflood depletion an extrapolated endpoint relative permeability to oil has proved effective for the sam
rosity value with less uncertainty in comparison to the one from conventional logging tools such as the Neutron the Density and the Sonic w
type and property log is still not widely used in the industry. Modern NMR logging tools can deliver – in addition to conventional porosity a
type and property log is still not widely used in the industry. Modern NMR logging tools can deliver – in addition to conventional porosity a


 ethods to interpret synthetic data sets for diverse petrophysical configurations including two-phase saturations with different oil grades mixe
e demonstrate the use of NMR data to calculate total and effective porosity and volume of irreducible water in productive reservoir sands an
inaccuracies in the reported porosity. We investigate the influence of acquisition parameters inversion parameters and noise on the determ
NMR logging tools. The objective is to explain the basic measurement principles and interpretations needed to understand NMR formation-e
physical properties in certain zones near faults variation of tuffaceous material content formation damage invasion of drilling fluids zones w
om 4 different wells are utilized to better understand the petrophysical framework of the formation. The plots correlating petrophysical param

 ) logs.� Incorporation of this flow calibrated apparent permeability into the static geologic earth model offers an elegant solution to the lon

 eef buildup at the Pipe Creek Outcrop in Central Texas were studied at three different scales. Single-phase airflow and gas-tracer experimen
 effective medium approximation is used to find the effective value of the hydraulic conductances of the individual pores. The method has be
 potential reserves a novel low gradient magnetic resonance LWD tool for application on conventional drilling assemblies was used. This is a
nique used to obtain image models is related to new image processing techniques based on texture models. The accuracy of the model is a
og legs. In this paper we will briefly review the new technologies available today for production logging with examples of evaluating horizonta

e training image are exported to the reservoir model without processing which allows simulating only categorical or discretized variables. This

quation is sometimes used again to populate the cells of a dynamic reservoir model in 3D where input porosity values are obtained by interp
 deration of the well with appropriate time-varying UBD boundary conditions. Capillary forces which facilitate countercurrent imbibition of the
 ty Index (RIPI) which borrows from the theory of rate-transient analyses. The mathematical and physical basis of RIPI and its relationship to


er a range of temperature pressure connate water saturation and hydrocarbon composition typical of gas-condensate reservoirs. PVT data
 ecent experimental findings in this laboratory indicate that measured gas/condensate relative permeability values on cores with different cha
  rebuild the static model and generate new dynamic simulations in order to update the development strategy and develop a mitigation plan.
ckstone to grainstones sequence that is highly fractured at the upper 15 feet of the layer’s “dual porosity system. The fracture corrido
ors from borehole images. The results showed seismic fault maps from one of the two fields detected more than 90 percent of all fracture fa
 ns. The conditional probability of having a fracture corridor given an indirect indicator such as mud loss is calculated from wells with image lo

 id analysis methods to build a more complete interpretation of the reservoir fluids and provide greater insight into reservoir architecture. This
ers a much more accurate and robust picture of the reservoir. In this paper we review a number of case studies in which we have successfu
 id analysis methods to build a more complete interpretation of the reservoir fluids and provide greater insight into reservoir architecture. This
printing have provided major inputs for reservoir modeling related to reservoir continuity. However none of these tools or data sets provide hy



s case the asphaltene concentration gradient are then integrated in a geologic model and used to predict crude oil properties and DFA logs
s case the asphaltene concentration gradient are then integrated in a geologic model and used to predict crude oil properties and DFA logs
e the deliverability performance of a vertically fractured well is considered estimates of the effective fracture half-length and average fracture
 than 40% at the end of the plateau phase. However recent infill drilling allowed for the first time an investigation of recovery efficiency in sw
ells the saturation profiles generated are a good statistical match to the wireline-log-interpreted Sw and bulk volume of water (BVW) and flu
 Cuddy et al. [4] Skelt-Harrison[5] and Sodena[6] methods) employed in the oil industry. Measured capillary pressure data and core propert
eability data to replace the previously used analogue database and hence reduce uncertainties of waterflood recovery predictions. The exper

 l or non-Darcy effects. Correlations were developed to represent both the gas and condensate relative permeabilities as a function of capill

hat dissolution of calcium-bearing minerals tends to retard fines production and delay changes in core wettability. Longterm corefloods exam

annels in samples from both reservoir types. These small channels (10 mm to 2 mm in diameter) form initially at the inlet and grow slowly tow
 ty in a reservoir model. Following detailed rock typing core and log analysis from approximately 5400 feet of core and from 26 wells and log
ral Panel and Frontal Panel with anuplifted Horst (Triassic) Panel in the south. �Each of these panels has specific reservoir and fluid chara
 category. �The uncorrected mini-model flow results lead to a too-narrow range of permeability. �Geostatistical scaling laws are applied
 category. �The uncorrected mini-model flow results lead to a too-narrow range of permeability. �Geostatistical scaling laws are applied

 rther estimate the reserves. Introduction Akpo is a condensate to very light oil field located offshore Niger Delta in OML130 (ex OPL246) a
ophysical attributes. Step2. Seismic facies probabilities are upscaled from the seismic scale to the reservoir one. This upscaling is constrain

  on the strength of an integrated petroleum engineering study that included detailed fault mapping on the re-processed 3D seismic dataset.
 ismic traces and target porosity logs for interpolation. The combination of 20 seismic attributes including impedance derived by model based

 sure that causes a decrease in wetting layer conductance. The gas relative permeability is higher for displacement cycles after first gas inje
efficiency is defined as the volume ratio between the two components. When pores contain conductive and non-conductive fluid phases the
e experiment to another. Through detailed modeling of the NMR response this concept has been developed further to provide a quantitative
ere used. The mineralogical analysis showed that the predominant minerals were calcite and dolomite in both samples. Determination of wet
he depleted layers face a significant overbalance while drilling with an oil-base mud system. Given these complexities fluid identification and


erformed by isolating 1 m of formation using the dual packer module of the wireline formation tester (WFT) and creating a hydraulic fracture b
tions. Thus a complex phenomenon can be modeled using some valid simplifying assumptions with sufficient accuracy for the purpose of te
corresponding isotropic geometric factor. Consequently the FRA-estimated permeability does not represent the true spherical permeability. I
  zontal well depends on the geometric average of horizontal and vertical permeabilities when the probe is set vertically against the borehol
  ized short bearing pack motors not only in the quality of the real time and recorded logs but in the over all bore hole quality as well. Introduc
 llary pressure. Hence the applicability of NMR derived capillary pressure curves in carbonates has been questioned. In a well in a complex
   major difficulty is the spatial distribution of rock-types in reservoir models each linked to different sedimentological and diagenetic processe
  sed upon decades of paper sections interpretation of low fold 2D data is that fault planes are in some rare occasions identified as individual
bonate fields with large transition zones remains an ongoing challenge. In this paper we first review the transition-zone definition and the curr
emented outside the casing as in previous applications. This notable difference introduced particular issues in the ERA data acquisition and i
verted into a single curve representing the secondary porosity. This secondary porosity log is added to the conventional logs as input of the n
 has been interpreted from Lower to Upper Cretaceous. The major lithofacies identified are sandstone (massive laminated and cross-bedded
   and sedimentary dip analyses were performed both on borehole images and oriented full-bore core photos that provided at least twice as m
   to the wellbore before filling a sample bottle. In this paper a new DFA tool is introduced that substantially increases the accuracy of these
 ation tester equipped with an extra large diameter probe and two downhole fluid analyzer modules was used to identify reservoir fluids in new
s color composition and GOR. The output of the FCA is the probability that two fluids are statistically different. Real-time application of the F
   to the wellbore before filling a sample bottle. In this paper a new DFA tool is introduced that substantially increases the accuracy of these

udy was carried out using representative oil and gas samples from the field. The results of experiments were used to build a new EOS fluid d
 h oriented bodies a new aspect ratio is defined and the reduced percolation thresholds of the system are determined. The results show tha
s. The model we propose calculates the extent of the damage zone along the fault plane by estimating the stress perturbation associated with
e based secondary porosity estimation recorded in this well were used for partitioning the porosity into micro meso and macro porosity.� B
 approach. The Jaipur area is mainly characterized by a Tertiary terrigenous sedimentary sequence comprising of fluvial to deltaic deposits o
pt of flow-unit or hydraulic unit was proposed first by C.L. Hearn1 in 1984. A flow unit is defined as a series of reservoir rocks that are continu
scusses the theory and the development of this tool as well as the experimentation and numerical modeling data used to characterize its azi
D data. The bottom hole assembly used consisted not only the standard LWD services such as gamma ray propagation resistivity density n
entional LWD interpretation. Introduction A new-generation LWD tool has been developed that integrates measurements of gamma ray pro
  risks normally involved with traditional LWD tools. The data delivered by this service include not only the traditional measurements such a


 ron porosities do not relate directly to permeability nor does high resistivity relate directly to hydrocarbon production. Advances in the analy
 e unconsolidated formations and all aspects associated with this type of environment such as borehole stability hole washouts sanding wh


ainty in the different input parameters to each model separately. Both analytical and numerical error analysis techniques were used to develo
 uncertainty in the different input parameters to each model separately. Both analytical and numerical error analysis techniques were used to
with formation permeability and capillary pressure leads to new insights in log-based rock typing for comparison with Special Core Analysis (
bonate. Borehole imaging provided is a new way of the characteristics of reservoirs drilled with oil-base-mud. Complicated structures were r
nd borehole electrical image logs.�� This data is sufficient to partition the porosity according the pore size compute permeability and as
te the thin sand fraction of a laminated reservoir from NMR free fluid volume.� The results of this method are compared to the sand count




 previously NMR offers useful insights into the petrophysics of thin sand-shale laminations. Typically 1D high-resolution data is acquired to e
 previously NMR offers useful insights into the petrophysics of thin sand-shale laminations. Typically 1D high-resolution data is acquired to e
 n be used in formation water saturation estimation. An alternative measurement of formation fluid saturation is by pulse neutron (PN) after w
 on high resolution borehole images over the entire open-hole section. When combined with pressure transient analyses and production data
at sand with microlaterolog values less than 10 ohm-m were observed to be highly productive on test. To calculate porosity the neutron soni
 can result in the premature ending of formation testing and sampling jobs or require multiple trips into the well to acquire the required sampl
 d specific properties namely density orientation apertures and porosity of each fracture type wherever applicable were generated. These
 sheet. The aim of this contribution is to establish the percolation framework to examine the connectivity of fracture systems at a given finite

r scale-limited distributions we use the hypothesis that the connectivity of fractures of variable size is identical to the connectivity of fracture
 dicted fracture gradient (LOT) values yielded by the various correlations were compared with actual LOT from a particular deep offshore field
me fractures on the electrical images were also seen in the cores whilst others were not. This method allows differentiation between natural
 o derive a facies model between Tayarat and Bahra Formation of Lower Cretaceous age. A volume extraction method was used to extract c

 ly inaccurate and hundreds of millions of barrels of hydrocarbons can be lost or fictitiously added in a reservoir model. An accurate reservoir
e modeling factors are examined by a D-optimal design. The study is applied to a shallow marine reservoir in the South Africa. The study indi
 ole resistivity images to characterize their geometry. The exploration well offers the best chance to evaluate the prospect but operational an
MR logs with the characteristic bimodal relaxation distribution. The thin laminations are often below the resolution of conventional logs that h
MR logs with the characteristic bimodal relaxation distribution. The thin laminations are often below the resolution of conventional logs that h



ment that is not representative of the derrick such as varying drilling mechanical conditions and temperature changes. We demonstrate the
nment that is not representative of the derrick (e.g. varying drilling mechanical conditions and temperature changes). Here we demonstrate

sin and vindicates the need for further development of processing and interpretation methodologies. This paper will present the key CSEM ex
 uniaxial strain equation requires the knowledge of Poisson’s ratio Young’s modulus pore pressure and overburden pressure. Clas
choose appropriate operating conditions to avoid early water breakthrough and achieve better reservoir sweep (c) choose the right time wind
 redicting formation water saturation profiles.� The classical interpolation method that relates capillary pressure (derived from Leverett J fu
 us and Poisson’s ratio.� Generally logging data consisting of density compressional and shear wave velocities are used to estimate
 ng the effect of channel architecture and reservoir connectivity into simple dynamic models. Use of simple dynamic models in conjunction wi
shoe. In addition the Modular Dynamic Tester (MDT) (�Schlumberger) minifrac tests were performed at three depths in shale thus yieldin
shoe. In addition the Modular Dynamic Tester (MDT) (�Schlumberger) minifrac tests were performed at three depths in shale thus yieldin

ure half-length and average fracture conductivity may be derived from the analysis.� In cases where the multi-rate deliverability tests are p
ure half-length and average fracture conductivity may be derived from the analysis.� In cases where the multi-rate deliverability tests are p
ure half-length and average fracture conductivity may be derived from the analysis.� In cases where the multi-rate deliverability tests are p
 servoirs--namely the Lower Cretaceous Ratawi and Minagish limestone--and the Jurassic Marrat formation contain significant oil reserves b
mine the structural geology features (i.e. fractures) its orientation and the diagenetic features (i.e. vugs) using formation micro imaging tool. A

 io and leads to a wrong estimation of the volume of fluids inside the fractured rock. Changes in pore pressure due to production or injection
 c data 3) structural analysis of the field 4) construction of the reservoir properties model 5) construction of the fracture distribution model u


 d specific properties namely density orientation apertures and porosity of each fracture type wherever applicable were generated. These
resents the results of a simulator used to analyze the mini-frac after-closure period to identify the presence of natural fractures. The simulatio
n of the seismic data 3) structural analysis of the field 4) construction of the reservoir properties model 5) construction of the fracture distrib
 nt buildup tests water injection and subsequent production of all injected water and collection of all relevant data that include time-lapse pre
nsient Testing (IPTT) can be carried out at Downhole Fluid Analysis (DFA) stations to provide more representative and accurate mobility/perm
nner dipole radial profiling showed some radial property change at several zones.� The altered zone radial extent was quantified. �The
nner dipole radial profiling showed some radial property change at several zones.� The altered zone radial extent was quantified. �The

to oil has proved effective for the same purpose. Here the zero endpoint relative permeability is linked to a conventional absolute" core perm
Neutron the Density and the Sonic where there is a need to assume variable values of density and transit time for the matrix. To corrobora
n addition to conventional porosity and permeability information – a continuous fluid log of oil gas water and OBM filtrate (OBMF) at multi
n addition to conventional porosity and permeability information – a continuous fluid log of oil gas water and OBM filtrate (OBMF) at multi


 rations with different oil grades mixed wettability or carbonate pore heterogeneity. Results from our study indicate that for both water-wet a
ater in productive reservoir sands and in shales to validate the petrophysical model. We also present a method based on NMR analysis to e
parameters and noise on the determination of porosity from NMR data. A key focus is on fluids exhibiting the extremes of T1 T2 or D such
eded to understand NMR formation-evaluation techniques and to discuss a few examples of these methods. Introduction of pulsed-NMR lo
ge invasion of drilling fluids zones with viscous oil low and variable formation water salinity. During this study a two step petrophysical eva
plots correlating petrophysical parameters and the frequency histograms suggest the presence of distinctive reservoir trends. These discrimi

l offers an elegant solution to the long-standing problem of how to best incorporate dynamic PLT data into a reservoir model.� A reservoir

ase airflow and gas-tracer experiments were conducted on 2.5 in. diameter by 5 in. long cores (core-scale) and 5- to 10-ft-radius well tests (f
individual pores. The method has been applied to several data sets including consolidated North Sea reservoir sandstones outcrop sandst
 rilling assemblies was used. This is a major departure from the more conventional techniques which use high gradient magnetic resonance
dels. The accuracy of the model is a key point for confidently linking images and physical or geological properties. This approach is demonstr
with examples of evaluating horizontal wells with barefoot smart completions diagnosing water entries flow profiles and fluid break-through.

egorical or discretized variables. This implementation is appropriate with clastic reservoirs for which typically depositional facies are simulat

orosity values are obtained by interpolation. The core-scale regression equation generally underestimates permeability by at least a factor o
 tate countercurrent imbibition of the drilling mud into the formation are taken into account. The production rates during UBD depend on the
al basis of RIPI and its relationship to the instantaneous PI are presented. The behavior of RIPI and its implications for reservoir characteriza


as-condensate reservoirs. PVT data of gas-condensate fluids can be used to predict the ratio of the gas to the condensate relative permeabi
 ity values on cores with different characteristics become more similar if expressed in terms of fractional flow instead of the commonly used s
ategy and develop a mitigation plan. The sanction case geological model described the reservoir sands as being deposited in a ponded intra
 porosity system. The fracture corridors within the layer improve permeability thereby making it a good potential for horizontal well placemen
 ore than 90 percent of all fracture fairways. The fault map could be effectively used for well planning and simulation and in combination with
is calculated from wells with image logs. Some indirect indicators have no direct link to image logs and a Bayesian inference has to be used

sight into reservoir architecture. This leads to improved understanding of structural history hydrocarbon migration and entrapment reservoir
studies in which we have successfully combined continuous fluid/facies mapping pressure-gradient measurements DFA and geochemistry
sight into reservoir architecture. This leads to improved understanding of structural history hydrocarbon migration and entrapment reservoir
of these tools or data sets provide hydrocarbon distributions or fingerprints during the drilling process of a given well; only after the well has r



ct crude oil properties and DFA logs for all hydraulically connected sections of the reservoir. Predicted and newly acquired DFA log data mat
ct crude oil properties and DFA logs for all hydraulically connected sections of the reservoir. Predicted and newly acquired DFA log data mat
ture half-length and average fracture conductivity may be derived from the analysis. In cases where the multi-rate deliverability measuremen
estigation of recovery efficiency in swept but previously un-drilled parts of the reservoir. Higher than expected the remaining oil saturations
  bulk volume of water (BVW) and fluid volumetrics agree with the geological model. RT-guided saturation-height functions proved a good me
illary pressure data and core properties for a well in one of the North Sea reservoirs were used with rock permeability varying from less than
 ood recovery predictions. The experimental programme followed a recommended procedure of wettability restoration and a combination of s

 permeabilities as a function of capillary number. A nearly 20-fold increase in gas relative permeability was observed from the low- to high-ca

ettability. Longterm corefloods examine the ability of diatomite to sustain thermal operations. Core permeabilities following significant volume

nitially at the inlet and grow slowly toward the outlet as experiments progressed. Fines mobilization and perhaps hydraulic action during force
eet of core and from 26 wells and logs from 90 well penetrations the team observed that there was considerable heterogeneity in this “h
 has specific reservoir and fluid characteristics. Discovered in 1973 the field did not start production until 1994 owing to the high levels of com
 eostatistical scaling laws are applied to correct the permeability values. This paper presents a permeability modeling procedure with applica
 eostatistical scaling laws are applied to correct the permeability values. This paper presents a permeability modeling procedure with applica

ger Delta in OML130 (ex OPL246) approximately 135km from the shore in water depth ranging from 1100m to 1700m. The block was awar
voir one. This upscaling is constrained by the dominant seismic facies and/or constrained by pseudo-petrophysical seismic cubes (Vclay Po

 e re-processed 3D seismic dataset. The latter was guided by the outcomes of recent deconvolution well test analyses and a revised geolog
g impedance derived by model based inversion was selected on the basis of ranking of error factors. The network was trained with effective

splacement cycles after first gas injection at high gas saturation due to cooperative pore filling but lower at low saturation due to trapping.ï¿
and non-conductive fluid phases the pore structure efficiency for the conductive phase changes with saturation due to fluid and mineral prop
 ped further to provide a quantitative wettability index. It is based on a model for the microscopic distribution of the crude oil and the wetting s
 both samples. Determination of wettability using ESEM method is very cost effective. It is unlike other traditional methods. It doesn’t use
e complexities fluid identification and pressure measurements have a significant impact in resolving key uncertainties of such reservoirs. Th


FT) and creating a hydraulic fracture by injecting drilling fluid using the downhole pump. Combination of the wireline dual packer and standard
 fficient accuracy for the purpose of test design or interpretation. The rationale for the initial and boundary conditions deployed here which ar
sent the true spherical permeability. In contrast the spherical permeability can be
 s set vertically against the borehol
 all bore hole quality as well. Introduction It was long rec
n questioned. In a well in a complex carbonate reservoir
mentological and diagenetic processes and each with t
are occasions identified as individual reflectors on
 ransition-zone definition and the curre
ues in the ERA data acquisition and interpretation b
he conventional logs as input of the neural network model. T
massive laminated and cross-bedded) shale (thin laminated and slump
otos that provided at least twice as many dips than borehole im
 ally increases the accuracy of these measurements. The tool uses
 used to identify reservoir fluids in newly drilled wells. Two fluid analyzer
 ferent. Real-time application of the FCA can optimize capture of downhole-fluid
 ally increases the accuracy of these measurements. The tool uses

were used to build a new EOS fluid description. In addition a detailed SCAL study
 re determined. The results show that with abov
he stress perturbation associated with dynamic rupture propagation.
 icro meso and macro porosity.� Borehole image logs hav
mprising of fluvial to deltaic deposits overlying the Precambr
es of reservoir rocks that are continuous laterally and vertically and has sim
eling data used to characterize its azimuthal capabili
ray propagation resistivity density neutron porosity and LWD gamma ray
es measurements of gamma ray propagation resistivity gamma-gamma density and thermal-neutron por
he traditional measurements such as gamma ray resistivity density a


 n production. Advances in the analysis of nuclear magnetic r
  stability hole washouts sanding while testing or lost seals. This pap


 lysis techniques were used to develop these charts and hence used as a
 ror analysis techniques were used to develop these charts and hence use
mparison with Special Core Analysis (SCAL) data. This workflow i
 -mud. Complicated structures were resolved utilizing the dip data gathered wi
ore size compute permeability and assess the rock types independently of
 hod are compared to the sand counts from a high resolution bor




  high-resolution data is acquired to estimate sand volume f
  high-resolution data is acquired to estimate sand volume f
 ation is by pulse neutron (PN) after well comple
ansient analyses and production data borehole image logs prov
o calculate porosity the neutron sonic and core porosity were compared. Prelimin
he well to acquire the required samples and fluid profiling stations.
er applicable were generated. These fracture pr
y of fracture systems at a given finite observation scale in 2D

dentical to the connectivity of fractures of
T from a particular deep offshore field in the Niger Delta and the res
 lows differentiation between natural and drilling-induced fractures wh
raction method was used to extract channel events and integra

servoir model. An accurate reservoir characterization should
oir in the South Africa. The study indicates that SCH study is particularly useful
uate the prospect but operational and economical
resolution of conventional logs that have a typical vertical
resolution of conventional logs that have a typical vertical



 ature changes. We demonstrate the applications of the method which allows dynami
ure changes). Here we demonstrate the applications of the method which allows dynam

s paper will present the key CSEM experiences in DW Borneo to date highli
sure and overburden pressure. Classically the static Poisson’s ra
sweep (c) choose the right time window for fractur
 pressure (derived from Leverett J function) to water sat
wave velocities are used to estimate these parameters.� However the
ple dynamic models in conjunction with effective properties p
 at three depths in shale thus yielding two minimum horizontal stress magn
 at three depths in shale thus yielding two minimum horizontal stress magn

 he multi-rate deliverability tests are performed under boun
 he multi-rate deliverability tests are performed under boun
 he multi-rate deliverability tests are performed under boun
ation contain significant oil reserves but are of less importance. However
 using formation micro imaging tool. Also to quantify

essure due to production or injection of
n of the fracture distribution model using the Continu


er applicable were generated. These fracture pr
 ce of natural fractures. The simulation results are dis
 5) construction of the fracture distribution model usin
 vant data that include time-lapse pressure production and inject
esentative and accurate mobility/permeability distribu
 adial extent was quantified. �The MDT-IPTT tests quantified the virgin zon
 adial extent was quantified. �The MDT-IPTT tests quantified the virgin zon

o a conventional absolute" core permeability corrected to r
sit time for the matrix. To corroborate that the obtained effective NMR p
ter and OBM filtrate (OBMF) at multiple depths
ter and OBM filtrate (OBMF) at multiple depths


udy indicate that for both water-wet and mixed-wet rocks T 2 (transverse relaxa
 method based on NMR analysis to estimate net producible pay and its
ng the extremes of T1 T2 or D such as light hydrocarbons gas water at h
hods. Introduction of pulsed-NMR logging tools in the 1990s pro
 s study a two step petrophysical evaluation
ctive reservoir trends. These discriminations are also represent

to a reservoir model.� A reservoir model recently built using A

ale) and 5- to 10-ft-radius well tests (field-scale). Zhang et al. (2005)
 eservoir sandstones outcrop sandstones outcrop carbonates and carbonates
e high gradient magnetic resonance on post-drilled wireline plat
 roperties. This approach is demonstrated through stochastic synthesizin
 low profiles and fluid break-through. Production flow profiles are a

 ically depositional facies are simulated first using MPS then

es permeability by at least a factor of 2. The origin of th
ion rates during UBD depend on the format
mplications for reservoir characterization are discussed. R


 to the condensate relative permeability and this simplifies the measurements and model
 flow instead of the commonly used saturation. This would lower the numbe
 as being deposited in a ponded intraslope salt basin dominated b
potential for horizontal well placement. It was impossible to rea
d simulation and in combination with fracture corridor cl
a Bayesian inference has to be used to find th

 migration and entrapment reservoir connectivity
 asurements DFA and geochemistry for a reservoir-continuity assessment in a diverse
 migration and entrapment reservoir connectivity
 a given well; only after the well has reached final depth



 nd newly acquired DFA log data matched for the first produc
 nd newly acquired DFA log data matched for the first produc
 multi-rate deliverability measurements are obtained und
pected the remaining oil saturations lead to the suspicion
on-height functions proved a good method for modeling water saturati
   permeability varying from less than 1 mD to over 1000 mD
 ity restoration and a combination of steady-state and centrifuge experiments.

as observed from the low- to high-capillary-number flow regim

eabilities following significant volumes of high temperature fluid inje

perhaps hydraulic action during forced imbibition form the channels. Silica diss
siderable heterogeneity in this “hard well data and that distri
l 1994 owing to the high levels of complexity and geophysical unce
ility modeling procedure with application to the Surmont Lease in Nort
ility modeling procedure with application to the Surmont Lease in Nort

100m to 1700m. The block was awarded during the first round of deep offsh
etrophysical seismic cubes (Vclay Porosity). Reservoir connect

ll test analyses and a revised geological model over the entire fiel
e network was trained with effective porosity available at well loc

er at low saturation due to trapping.�In oil-wet media the wat
 uration due to fluid and mineral properties and pore structure variations. The
tion of the crude oil and the wetting state of the rock at an
raditional methods. It doesn’t use any chemical or even generat
y uncertainties of such reservoirs. The main challenges


he wireline dual packer and standard probe modules provided estimates o
y conditions deployed here which are unique to a supercharged

				
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