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Total SPE Papers - Reservoir Engineering - Reservoir Engineering

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Total SPE Papers - Reservoir Engineering - 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
TOTAL           IPTC    11737              CO2
TOTAL            SPE   113353              CO2
TOTAL            SPE   109739              CO2
TOTAL           IPTC    12545       Corporate Process
TOTAL           IPTC    12106       Corporate Process
TOTAL            SPE   112517       Corporate Process
TOTAL           IPTC    12658             Drilling
TOTAL            SPE   116672            EOR/IOR
TOTAL           IPTC    11800            EOR/IOR
TOTAL            SPE    99546            EOR/IOR
TOTAL           IPTC    12131            EOR/IOR
TOTAL            SPE   121182            EOR/IOR
TOTAL            SPE   121544        Flow Assurance
TOTAL           IPTC    11379        Flow Assurance
TOTAL            SPE   123111        Flow Assurance
TOTAL            SPE   121484        Fluid Description
TOTAL            SPE   107378        Fluid Description
TOTAL            SPE   121902        Fluid Description
TOTAL            SPE   110882           Giant Field
TOTAL            SPE   118892           Giant Field
TOTAL            SPE   109831            Heavy Oil
TOTAL            SPE   102094            Heavy Oil
TOTAL            SPE   103000            Heavy Oil
TOTAL            SPE   117479            Heavy Oil
TOTAL            SPE   110468            Heavy Oil
TOTAL            SPE   113409            Heavy Oil
TOTAL            SPE   117531            Heavy Oil
TOTAL            SPE   110479            Heavy Oil
TOTAL            SPE   117562            Heavy Oil
TOTAL            SPE   112708             HP/HT
TOTAL            SPE   123681             HP/HT
TOTAL            SPE   107745             HP/HT
TOTAL            SPE   124578             HP/HT
TOTAL            SPE   100182             HP/HT
TOTAL            SPE   112460   Low Permeability Reservoirs
TOTAL            SPE   115892   Low Permeability Reservoirs
TOTAL            SPE   103857   Low Permeability Reservoirs
TOTAL            SPE   121812   Low Permeability Reservoirs
TOTAL            SPE   105262   Low Permeability Reservoirs
TOTAL            SPE    90226      Reservoir Description
TOTAL            SPE   102659      Reservoir Description
TOTAL            SPE   111410      Reservoir description
TOTAL            SPE   118333      Reservoir Description
TOTAL           IPTC    12849      Reservoir Description
TOTAL            SPE   117908      Reservoir Description
TOTAL            SPE   105456      Reservoir Description
TOTAL            SPE   128339      Reservoir Description
TOTAL            SPE   110304      Reservoir Description
TOTAL            SPE   115822      Reservoir Description
TOTAL    SPE   116393    Reservoir description
TOTAL    SPE   102093    Reservoir Description
TOTAL    SPE    88756    Reservoir Description
TOTAL   IPTC    11813    Reservoir Description
TOTAL    SPE   123624    Reservoir description
TOTAL    SPE   103083    Reservoir Description
TOTAL    SPE   111912    Reservoir Description
TOTAL    SPE   101945    Reservoir description
TOTAL    SPE   105423    Reservoir Description
TOTAL    SPE    99389   Reservoir Development
TOTAL    SPE   128610   Reservoir Development
TOTAL    SPE   123964   Reservoir Development
TOTAL    SPE   123824   Reservoir Development
TOTAL    SPE   124596   Reservoir Management
TOTAL    SPE   106841   Reservoir Management
TOTAL   IPTC    11565   Reservoir Management
TOTAL    SPE   117172   Reservoir Management
TOTAL    SPE   110296   Reservoir Management
TOTAL    SPE   128894   Reservoir Management
TOTAL    SPE    90129   Reservoir Management
TOTAL    SPE   115963   Reservoir Management
TOTAL    SPE   108010   Reservoir Management
TOTAL    SPE   111973   Reservoir Management
TOTAL    SPE   109929     Reservoir Modelling
TOTAL    SPE   117434     Reservoir Modelling
TOTAL    SPE   102871     Reservoir Modelling
TOTAL    SPE   100946     Reservoir Modelling
TOTAL    SPE   105203     Reservoir Modelling
TOTAL    SPE    79698     Reservoir Modelling
TOTAL    SPE   106188     Reservoir Modelling
TOTAL    SPE   107077     Reservoir Modelling
TOTAL    SPE   113890     Reservoir Modelling
TOTAL    SPE   121244     Reservoir Modelling
TOTAL    SPE   122021     Reservoir Modelling
TOTAL    SPE    99575     Reservoir Modelling
TOTAL    SPE   121612     Reservoir Modelling
TOTAL    SPE   100206     Reservoir Modelling
TOTAL    SPE   102165     Reservoir Modelling
TOTAL    SPE   107525     Reservoir Modelling
TOTAL   IPTC    11320     Reservoir Modelling
TOTAL    SPE   109894     Reservoir Modelling
TOTAL    SPE   100233     Reservoir Modelling
TOTAL    SPE   116008     Reservoir Modelling
TOTAL    SPE   107556     Reservoir Modelling
TOTAL    SPE   101208     Reservoir Modelling
TOTAL    SPE   110422     Reservoir Modelling
TOTAL    SPE   103060     Reservoir Modelling
TOTAL   IPTC    11369   Reservoir Performance
TOTAL   IPTC    11763   Reservoir Performance
TOTAL    SPE   100229   Reservoir Preformance
TOTAL    SPE   100024        SPE Forum
TOTAL    SPE   107699     State of the Nation
TOTAL   IPTC    11640         Surveillence
TOTAL   IPTC    11376         Surveillence
TOTAL   IPTC    11686         Surveillence
TOTAL    SPE   117561   Unconventional Reservoirs
TOTAL   IPTC    11812   Unconventional Reservoirs
TOTAL    SPE   107760      Well Deliverability
TOTAL    SPE   102550      Well Deliverability
TOTAL    SPE   107392      Well Deliverability
TOTAL    SPE   102475      Well Deliverability
TOTAL    SPE    98164      Well Deliverability
TOTAL    SPE   112077      Well Deliverability
TOTAL    SPE   120508      Well Deliverability
TOTAL   IPTC    12388      Well Deliverability
TOTAL    SPE    98562      Well Deliverability
TOTAL    SPE   107341      Well Deliverability
TOTAL    SPE   107767      Well Deliverability
TOTAL    SPE   100023      Well Deliverability
TOTAL    SPE   104239      Well Deliverability
TOTAL    SPE   100627      Well Deliverability
TOTAL    SPE   105367      Well Deliverability
TOTAL    SPE   101420      Well Deliverability
TOTAL    SPE   102483         Well Testing
TOTAL    SPE   118148         Well Testing
TOTAL    SPE   128359         Well Testing
TOTAL    SPE   110820         Well testing
TOTAL    SPE   115820         Well testing
TOTAL    SPE   105685         Well Testing
TOTAL    SPE   103216         Well testing
           Section                                Subject
          Capture/Storage                         Case Study
 Mechanism - Capillary Alteration
               Storage                           Mineralization
        Total's Digital Field
 Total's Knowledge Management
 Total's Knowledge Management
      Light Well Architecture                     Tunu Field
         Polymer Injection                       Case Study
         Polymer Injection                 Offshore Implementation
            Technologies                    North Sea Experience
          Well Intervention                     Water Shut-off
          Well Intervention                     Water Shut-off
       Drag Reducing Agent                        Evaluation
       Production Modelling                Girassol Deepwater Field
       Production Modelling                Girassol Deepwater Field
            Correlations                         HP Acid gas
          Formation Water                         Modelling
       Insitu PVT Variations                Molecular simulations
          Integrated Study                       Handil Field
      Reservoir Development                       Deepwater
            Assisted HM
           Bitumen sands                      Reserves evaluation
           Bitumen sands                     Reservoir Description
         Depressuriziation                  Pore Network Modelling
            Porous Flow                 Lab testing - Bubble Nucleation
       Reservoir Description                 Anisotropic Rel. Perms
        Reservoir Modelling                     Foamy Oil Effect
         Thermal Recovery                 Progressive Cavity Pumps
            Well Testing                       Multiphase Meter
               Drilling                   Highly Depleted Reesrvoir
          Lesson's Learnt                     Elgin/Franklin Fields
           Scale Inhibition                   Elgin/Franklin Fields
            Surveillence               Static Bottomhole measurements
      Water Block Prevention
        Formation Damage                         SCAL Testing
        Fracture Stimulation                  High deviated well
  Naturally Fractured Reservoirs          Fracture Characterisation
           Water Blocking             Associated with Hydraulic fracturing
          Well Intervention                     Water Shut-off
    Anisotropic Permeabilities          Probe Formation test Analysis
    Anisotropic Permeabilities          Probe Formation test Analysis
       Carbonate reservoirs                 Stochastic simulations
       Carbonate reservoirs                      Subtle Faults
       Formation Evaluation                 Neutron Spectroscopy
       Formation Evaluation             Pressure Testing while Drilling
Fracture and Fault Characterisation      High-Resolution Image Logs
   Fracture Pressure Prediction                   Deepwater
  Near Wellbore Flow Properties              Integrated Well Data
        NMR Interpretation                Optimised WFT Sampling
  Petrophysical Property Determination       3D Core Scanner
    Porosity-Permeability Modelling          Statistical Pitalls
       Saturation Height function          Carbonate Reservoirs
        Shared Earth Modelling              Seismic Integration
         Static Reservoir Model                   Dunbar
         Static Reservoir Model             minimodels - SAG
         Static Reservoir Model                Seismic Data
         Static Reservoir Model             Seismic Upscaling
         Sweet Spot Detection               Seismic attributes
          Gas Coning Control                  Tyrihans Fied
              Heterogeneity                    Amenam R4
               Jura Project
             Stranded Fields               Laggan/Tormore Fields
               Alwyn Field                      Life of Field
       Development Optimisation                 ElginFranklin
              Gas Storage                       Case Study
               Gas storage                     Pecorade Field
            Integrated Asset                    Sendji Field
        Multi-layered Reservoir                 Life of Field
       Probablistic Performance              Multiple Reservoirs
                 Process                   Subsea Searation Unit
       Produced Water Injection            Permeability Reduction
     Produced Water Management                Total's Approach
               4D Seismic                      Girassol Field
            Analytical Model                        SAGD
              Assisted HM                        JACTATM
              Assisted HM                       Valhall Field
          Carbonate reservoirs                    Upscaling
         Compaction Modelling
Coupled Reservoir/Geomechanical Model
Coupled Reservoir/Geomechanical Model
      Dual Permeability Simulation           Transfer Functions
      Dual Permeability Simulation           Transfer Functions
           Fracture Modelling                      Clean-up
           Fracture Modelling                  Horizontal Wells
                 Gridding                        Optimisation
            History matching               Production Uncertainty
     Naturally Fractured Reservoirs      Discrete Fracture Modelling
     Naturally Fractured Reservoirs         Pragmatic Modelling
     Naturally Fractured Reservoirs            Respresentation
          Near Wellbore Flow                   Sand Production
           Petroelastic Model                      Upscaling
     Pore-Scale Network Modelling          Blowdown Rel. Perms.
     Pore-Scale Network Modelling           Gravitational Effects
        Shared Earth Modelling            Nat. Fractured Reservoirs
         Static Reservoir Model                   3D Seismic
   Thermal Adaptive Implicit Method             Stability Criteria
         Carbonate Reservoirs                  Integrated Study
     Naturally Fractured Reservoirs             Triple Porosity
     Naturally Fractured Reservoirs        Connectivity Prediction
             Smarter Fields                 Change Management
              Frac-Packing
                   4D Seismic                         Feasibility
                    Planning                        Total's Strategy
            Production Allocation                   ESP Challenge
Silica Inhibition and Blowdown Evaporation
                    Tar Mat                       Reservoir Description
                Acid Treatments                            ERW
          Completion Optimisation                    Big Bore Design
                Fracture Design                Influence ofHeterogeneity
                   Fracturing                 Acid - Challenging Conditions
                Horizontal Well                          Clean-up
                Horizontal Well                        OBM Effect
             Perforation Methods                        Orientation
                  Sand Control                         Gravel Pack
                  Sand Control                         Gravel Pack
                  Sand Control                 Microemulsion Technology
                  Sand Control
                 Sand Erosion                          Prediction
               Sand Production                        Case Study
                Scale Inhibitors                  Elgin/Franklin Fields
                Water Blocking                      Gas Reservoirs
                 Zonal Isolation                   CBL Interpretation
       Connected Volume Estimation
             Multiphase Metering                  Challenging Conditions
                      PTA                       Flow Regime Identification
           Real gas Flow Analysis            Average Pressure Approximation
       Testing by Production Logging
          Vertical Interference Test             Permeability Anisotropy
         Wellbore Storage Analysis                   Deconvolution
                                               Title
The CO2 Pilot at Lacq: An Integrated Oxycombustion CO2 Capture and Geological Storage Project in the South West of Franc
Capillary Alteration of Caprocks by Acid Gases
A Modeling Study of the Role of Selected Minerals in Enhancing CO2 Mineralization During CO2 Aquifer Storage
How To Handle Real-Life Well Production Instabilities and Uncertainties Within Digital Fields" A Practical Application From Con
Integrated Data and Information Management System From SubSurface to Surface to Enhance Production Activity and Busine
Transforming E&P Data Into Knowledge: Applications of an Integration Strategy
Tunu Field Light Architecture Wells
Polymer Injection in Deep Offshore Field: The Dalia Angola Case
Feasibility Study for EOR by Polymer Injection In Deep Offshore Fields
A Survey of North Sea Enhanced-Oil-Recovery Projects Initiated During the Years 1975 to 2005
Tackling Gas Field Decline With Efficient Chemical Water Shut-off: Successful Application on Peciko Field (East Kalimantan, In
Selective Water Shutoff in Gas Well Turns a Liability into an Asset: A Successful Case History From East Kalimantan, Indones
Experimental Methodology to Evaluate DRA: Effect of Water Content and Waxes on Their Efficiency
A Systematic Investigation of Girassol Deepwater Field Operational Data to Increase Confidence in Multiphase Simulation
A Systematic Investigation of Girassol Deepwater-Field Operational Data To Increase Confidence in Multiphase Simulation
High Pressure Acid Gas Viscosity Correlation
Static and Dynamic Models of Formation Water in Orinoco Belt, Venezuela
Understanding Compositional Grading in Petroleum Reservoirs thanks to Molecular Simulations
Reviving the Mature Handil Field: From Integrated Reservoir Study to Field Application
AKPO: A Giant Deep Offshore Development
More Rapid and Robust Multiple History Matching With Geological and Dynamic Uncertainties: Heavy-Oil Case Study
Quantifying Resources for the Surmont Lease with 2D Mapping and Multivariate Statistics
Facies Analysis and Architectural Elements Within a Fluvio-Estuarine Sedimentary System: The Lower Cretaceous Bituminous
Dynamic Pore Network Simulator for Modelling Buoyancy-Driven Migration during Depressurisation of Heavy-Oil Systems
Gas Bubble Nucleation of Extra-Heavy Oils in Porous Media: A New Computerized Tomography Technique and Physical Appro
Anisotropic Relative Permeabilities for Characterising Heavy-Oil Depletion Experiment
The Slender Bubble Model for Very Slow Degassing in Porous Media and Cold Production
World's First Metal PCP SAGD Field Test Shows Promising Artificial-Lift Technology for Heavy-Oil Hot Production: Joslyn Field
Methodology of Calibration for Nucleonic Multiphase Meter Technology for SAGD Extra Heavy Oil
Successful Development Drilling of an HP/HT Infill Well in a Highly Depleted Reservoir: Case Study
Elgin/Franklin: What Could We Have Done Differently?
Fighting Lead and Zinc Sulphide Scales on a North Sea HP/HT Field
Estimation of Static Bottom Hole Pressure from Well-Head Shut-in Pressure for a Supercritical Fluid in a Depleted HP/HT Rese
Wettability Alteration for Water-Block Prevention in High-Temperature Gas Wells
Fracturing in Tight-Gas Reservoirs: Application of SCAL Methods To Investigate Formation-Damage Mechanisms
Innovative Frac Stimulation of Low Perm Oil Zone in High Deviation Well Offshore Congo
Multiazimuth Seismic to Well Tie for Fracture Characterization
In Situ Water Blocking Measurements and Interpretation Related to Fracturing Operations in Tight Gas Reservoirs
Successful Innovative Water-Shutoff Operations in Low-Permeability Gas Wells
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
Nested Stochastic Simulations: A New Approach in Assessing Spatial Distribution of Carbonate Sedimentary Facies and Assoc
Subtle Faults in Carbonate Reservoirs
Comparison of Conventional Log Interpretation With Neutron Spectroscopy Log and X-Ray Diffraction Laboratory Analysis: A C
The Value of Formation Pressure Measurements While-Drilling a Case Study from Offshore Abu Dhabi
Characterization of Fractures and Faults From High-Resolution Image Logs To Optimize the Geological Model of a Fractured C
Deep Offshore Fracture Pressure Prediction in the Niger Delta – A New Approach
An Investigation of Near-Wellbore Flow Properties Using Sonic Scanner Measurements and Interval Pressure Transient Testin
Using the Continuous NMR Fluid Properties Scan to Optimize Sampling with Wireline Formation Testers
Petrophysical Properties Prediction Using 3D Core Scanner Imagery
Three Statistical Pitfalls of Phi-K Transforms
Modeling Original Water Saturation in the Transition Zone of a Carbonate Oil Reservoir
Incorporating Seismic Characterization Results into Bul Hanine Geological Model
Re-Evaluation of a Complex Mature Field (Dunbar, UKCS): A Geosciences Integrated Work
Permeability Modeling for the SAGD Process Using Minimodels
Akpo, Nigeria: From Seismic Interpretation to Geomodel
New Strategy for Seismic Facies Upscaling to the Reservoir Grid Scale
Identification of High-Porosity Reservoir Sands From 3D-Seismic Attributes Using Neural Network Technique in South Umm G
Tyrihans Field Development Overview
Vertical Flow Barrier Characterisation in Amenam R4 Reservoir (Nigeria) and Impact on Field Development and Reservoir Man
Jura Fast Track Project
Laggan & Tormore—Development of Two New Deepwater Gas Condensate Fields and Associated Gas Export Infrastructure
Maximising Recovery From Mature North Sea Assets by the Implementation of Production Optimisation Initiatives
Identifying the Optimum Development Plan for the Western Area of Elgin/Franklin in the North Sea
Converting the P�corade Oil Field Into an Underground Gas Storage
Converting the Pecorade Oil Field Into an Underground Gas Storage
Production Optimization by Real-Time Modeling and Alarming: The Sendji Field Case
Obagi – Present and Future Challenges of a Mature Oil Field
Partial Probabilistic Addition: A Practical Approach for Aggregating Gas Resources
Multiphase Loop Tests for Subsea Separation-Unit Development
Internal Formation Damage Properties and Oil-Deposition Profile Within Reservoirs During PWRI Operations
Emerging Issues in Produced Water Management: TOTAL E&P NORGE’s Approach
Matching of Production History and 4D Seismic Data--Application to the Girassol Field, Offshore Angola
A New Analytical Model for Conduction Heating during the SAGD Circulation Phase
A New Technique To Achieve History Match Using a Probabilistic Approach
History Matching of the Valhall Field Using a Global Optimization Method and Uncertainty Assessment
Innovative Methods To Improve Carbonate Reservoirs Modeling Accuracy and Reliability
Comparisons of Uncoupled and Various Coupling Techniques for Practical Field Examples
Practical Iterative Coupling of Geomechanics With Reservoir Simulation
A Practical Iterative Scheme for Coupling Geomechanics With Reservoir Simulation
Matrix-Fracture Transfer Function in Dual-Medium Flow Simulation: Review, Comparison, and Validation
SubFace Matrix-Fracture Transfer Function: Improved Model of Gravity Drainage/ Imbibition
Successful Modelling of Post-Fracture Cleanup in a Layered Tight Gas Reservoir
Explicit Simulation of Multiple Hydraulic Fractures in Horizontal Wells
Incorporation of Static and Dynamic Constraints in Optimum Upscaling: A Field Case Study
History Matching With Production Uncertainty Eases Transition Into Prediction
Characterisation and Modelling of a Fractured Reservoir Using a Novel DFN Approach
Fast and Efficient Modeling and Conditioning of Naturally Fractured Reservoir Models Using Static and Dynamic Data
Simulating Karstic Conduits as Wells in a Commercial Reservoir Simulator
Near-Wellbore Modeling: Sand Production Issues
From Logs Scale to Reservoir Scale: Upscaling of the Petroelastic Model
Relative Permeabilities for Blowdown of a Near-Critical Oil Reservoir: Issues and Solutions Emerging From Pore-Scale Networ
A Pore-Scale Network Modeling Study of Gravitational Effects During Solution Gas Drive: Results From Macroscale Simulation
The Challenges of Building-Up a Geological and Reservoir Model of a Late Ordovician Glacio-Marine Gas Reservoir Character
Construction of a Stochastic Geological Model Constrained by High-Resolution 3D Seismic Data - Application to the Girassol F
Stability Criteria for the Thermal Adaptive Implicit Method
Al Khalij: The Quest For Oil In A Highly Complex Carbonate Field
Characterization and Modelling Study of a Triple Porosity Fractured Reservoir
Connectivity Prediction in Fractured Reservoirs With Variable Fracture Size: Analysis and Validation
Making Our Mature Fields Smarter—An Industrywide Position Paper From the 2005 SPE Forum
Pushing the Limits of Frac-Pack Operating Envelope
Seismic Monitoring Feasibility on Bu-Hasa Field
Field Monitoring: Applications of Total Corporate Integration Strategy
Production Allocation Along Long Drains Activated by ESPs : Rising to the Challenge
A New Water Treatment Scheme for Thermal Development: The SIBE Process
Characterisation, Origin and Repartition of Tar Mat in the Bul Hanine Field in Qatar
Acid Stimulation of Extended Reach Wells: Lessons Learnt From N'Kossa Field
Big Bore Completion and Sand Control for High Rate Gas Wells
New Methodology of Effective Hydraulic Fracturing in High-Thickness Formation
Successful Acid-Fracturing in Adverse Conditions: Lessons Learnt and Integrated Evaluation in the Kharyaga Field
Delayed-Release Acid System for Cleanup of Al Khalij Horizontal Openhole Drains
A Case Study of Oil-Based Mud Effect on Horizontal-Well Productivity
Oriented Perforation in Dual Completion Wells: A Real Case in East Texas
Single Trip Multi-Zone Gravel Packing—Case Study at Handil, Bekapai & Sisi-Nubi Fields
Openhole Gravel Pack in the Roaring Forties for TOTAL AUSTRAL
First Application of Novel Microemulsion Technology for Sand Control Remediation Operations-A Successful Case History From
Sand Control Robustness in a Deepwater Development: Case Histories From Girassol Field (Angola)
Sand Erosion in Weakly Consolidated Reservoirs: Experiments and Numerical Modeling
Sanding—Not As It First Appeared
Development of Appropriate Test Methodologies for the Selection and Application of Lead and Zinc Sulfide Inhibitors for the El
Preventive Treatment for Enhancing Water Removal from Gas Reservoirs by Wettability Alteration
Reliability of Cement Bond Log Interpretations Compared to Physical Communication Tests Between Formations
The Use of Well Testing for Evaluation of Connected Reservoir Volume
Extending the Range of Multiphase Metering to Challenging High Water Cut Gas-Lifted Wells: TOTAL ABK Field Application
Statistical Diagnosis (VEMST) of Flow Regime: Alternative to Pressure Derivative Approach in Pressure Transient Analysis—P
Application of Convolution and Average Pressure Approximation for Solving Nonlinear Flow Problems--Constant Wellbore Pres
Method and Application of Cyclic Well Testing with Production Logging
A New Technique To Determine Horizontal and Vertical Permeabilities From the Time-Delayed Response of a Vertical Interfere
Explicit Deconvolution of Wellbore Storage Distorted Well Test Data
                                 Author                                       Abstract
                                                                             Abstract For decades to
Nicolas Aimard, Total; Marc Lescanne, Total; G�rard Mouronval, Total; Claude Pr�bende, Total come oil and gas will rem
                                                                             Abstract The safety of Mouronval, TOTAL storage
Virenkumar Shah, University of Pau and TOTAL SA; Daniel Broseta, University of Pau; and Gerard acid gas geological SA
                                                                             Abstract CO2 mineralization is a process whereby
S. Thibeau, Total; L.X. Nghiem, Computer Modelling Group; and H. Ohkuma, Japan Oil Engineering Company
                                                                             Abstract Digital fields involve the regular use of m
Jacques Danquigny and Marc Tison, TOTAL; Guennol� Ouay� and Emmanuel S�gui, TOTAL E&P Congo; and Michel
Tati Magdalena SAHEA, SPE, Nyoman SWATIKA, SPE, and Renaldy, SPE,Extended Abstract “Today knowledge has pow
                                                                              Total E&P Indonesie
Jean-Paul Couput, Alain Louis, and Jacques Danquigny, TOTAL S.A.             Abstract The full added value of a field performan
                                                                             Abstract Vervynck, challenges of the mature Tun
Ph. Jeannet, Ch. Longis, M. Caroline, F. Widiwibowo, G. Tarnaud, D. Dodiono, and L. One of the Total E&P Indonesie
                                                                             Abstract Whereas
D. Morel, M. Vert, Total E&P, S. Jouenne, Total Petrochemicals France, E. Nahas, Total E&P on-shore polymer injection may
                                                                              Nahas Total E&P
D.Morel, A.Labastie, Total E&P, S.Jouenne Total Petrochemicals France, E.Abstract Whereas on-shore polymer injection may
                                                                             Summary This paper provides
A.R. Awan, SPE, NTNU/Total E&P Norge; R. Teigland, SPE, Total E&P Norge; and J. Kleppe, SPE, NTNU a summary and a g
Armon Armon and Latief Riyanto, SPE, Total E&P Indonesie                     Abstract High water production in a gas well could
                                                                             Abstract This case Thouvenin, and a procedure
Chat Junesompitsiri, Antoine Berel, and Richard Curtice, Halliburton, and Latief Riyanto, Etiennehistory describesPascal Chene
                                                                             Abstract Drag reducing agents are used to reduce
I. Henaut, M. Darbouret, and T. Palermo, IFP, and P. Glenat and C. Hurtevent, TOTAL
Erich Zakarian and Dominique Larrey, Total                                   Abstract After over 5 years experience as operator
Erich Zakarian and Dominique Larrey, Total                                   Summary After more than 5 years of experience a
                                                                             Abstract Acid SPE, containing H2S are often enco
G. Galli�ro, C. Boned and A. Baylaucq, LFC with CNRS, Pau University; and F. Montel, gasesTOTAL
                                                                             Abstract Sincor is J. Ichbia and J. Bellorini, Total
J. Marcos, E. Pardo, J. Casas, D. Delgado, M. Rondon, M. Exposito, and L Zerpa, Sincor, and a strategic association between
G. Galliero, LFC with CNRS, Pau University; and F. Montel, SPE, Total        Abstract An accurate knowledge of the initial state
Henricus Herwin, Emmanuel Cassou, and Hotma Yusuf, Total E&P Indon�sie     Abstract The Handil field discovered in 1974 is a
F. Rafin, A. La�n�, and B. Ludot, TOTAL S.A. France                      Summary All deep water offshore projects are cha
J. Poncet, G. Vincent, M. Inizan, P. Henriquel and P. Jannes, Total          Abstract The generation of reservoir simulation mo
                                                                             Summary The McMurray formation consists of he
Weishan Ren, SPE, ConocoPhillips Canada; Clayton V. Deutsch, SPE, University of Alberta; David Garner, SPE, Chevron Can
                                                                              and O. In north-eastern Mines (Canada)
J. Bailleul, Ecole des Mines de Paris/Total E&P; V. Delhaye-Prat, Total E&P;AbstractParize, Ecole des Albertade Paris the flu
                                                                             Abstract number of vertically-oriented
C.C. Ezeuko and S.R. McDougall, Heriot-Watt University; I. Bondino, TOTAL E&P UKALtd; G. Hamon, TOTAL S.A heavy oil d
                                                                             Abstract The F. Franco, D. Mauduit, pore Monte
V. Meyer, J. Pilliez, P. Creux, and A. Graciaa, UMR 5150 Total-CNRS-UPPA, and F. Luck,study of multiphase flowand F.level p
                                                                             Abstract and G. years TOTAL S.A.
C.C. Ezeuko and S.R. McDougall, Heriot-Watt University; I. Bondino, TOTAL E&P UK;In recentHamon,the use of pore-scale net
                                                                             Abstract Cold production
Mehdi Chraibi, TOTAL, St�phane Zaleski, SPE, Univ-Paris 06, and Fabienne Franco, SPE, TOTALof oil leads to degassing
Jean-Louis Beauquin and Felix Ndinemenu, Total E&P; Gilles Chalier, Total Abstract Finding a reliable artificial lift pumping sys
                                                                             E&P Canada; Lionel Lemay and Laurent Seince, P
                                                                              Vincent ARENDO, Mark SHAFFER, Jose Steam-
Bruno PINGUET, Philippe PECHARD, Elsie GUERRA - SCHLUMBERGER, Abstract: Metering of bitumen produced byCONTR
L. Fambon, SPE, and G. Joffroy, SPE, TOTAL E&P UK Limited                    Abstract Drilling infill wells on HP/HT fields after a
Eric Festa, TOTAL E&P UK                                                     Abstract At the time of project sanction in 1997 E
K. Orski, B. Grimbert, C. Menezes, and E. Quin, Total E&P UK Ltd.            Abstract Lead and Zinc sulphides have recently be
Peyman R. Nurafza, SPE, and Jeremie Fernagu, SPE, Total E&P UK Ltd. Abstract A periodic measurement of static bottom
                                                                             Abstract This paper presents the development of
M.K.R. Panga and Y.S. Ooi, Schlumberger Well Services; P.L. Koh, U. Teknologi Petronas; K.S. Chan and�P. Enkababian,
                                                                             Abstract Gas well productivity in tight reservoirs is
B. Bazin, S. Bekri, O. Vizika and B. Herzhaft (Institut Fran�ais du P�trole) and E. Aubry (Total)
                                                                             Abstract Total Philippe Quero, Jean-Michel Ranje
Fabien Lemesnager, Patrick M’ Bouyou, and Jean Gavalda, Total, and B.W. McDaniel,operates an offshore oil field approx
Ramin Nawab, Sonja Maultzsch, Sung Yuh, and Benoit Mouly, Total E&P Abstract One of the ways to optimize the productio
                                                                             Abstract Invasion of aqueous drilling completion o
B. Bazin, Y. Peysson, F. Lamy, and F. Martin, IFP, and E. Aubry and C. Chapuis, Total
                                                                              SPE, Schlumberger, and Pascal Cheneviere, SPE
Hassan Chaabouni, SPE, Philippe Enkababian, SPE, and Keng Seng Chan, Abstract Water production from gas producing we
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 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
Andy Kristianto, Yulianto Jong, and Laurent Moinard, TOTAL E&P INDONESIE     Abstract The Elemental Capture Spectroscopy (EC
                                                                             Abstract Formation pore pressure and near-wellbo
Xavier POIRIER-COUTANSAIS, SPE; Emmanuelle BAUD, SPE, TOTAL ABK and Ettore MIRTO, SPE, Schlumberger
                                                                              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
                                                                             Abstract Drilling in deepwater is
Joseph Ajienka, SPE, Franck Egbon, SPE, and Uchechukwu Onwuemena, SPE, Total E&P Nigeria Limited becoming more a
                                                                             Abstract Total Indonesie
Cosan Ayan and Mario Petricola, Schlumberger, and Philip Knight and Bruno Lalanne,Wireline Formation Tester (WFT) pretest
                                                                             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 This paper
Soufiane JOUINI, Francois UMBHAUER, Jean-Pierre LEDUC, Noomane KESKES, TOTAL E&P deals with the use of core scan
Pierre Delfiner, SPE, Total S.A.                                               Summary Phi-k transforms are used widely to pre
                                                                               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 Bul Pellerin and Ga�l Lecante, Beicip-F
Nicolas Desgoutte, Beicip-Franlab; Abdulmalik Al Abdulmalik, Qatar Petroleum; Matthieu Hanine field is located offshore Qatar
                                                                               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 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 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
F.R. Munkvold and T. Knoff, Statoil                                            ABSTRACT Tyrihans is an oil and gas-condensa
Xavier Mathieu, Uche Onyema, Lionel Sabatier, S�bastien Blanchais, andAbstract In the Amenam–Kpono Field six of the
                                                                                Uche Eme, TOTAL E&P Nigeria
                                                                               Abstract This paper 7
J�r�me Lesgent, SPE, and Jimmy MacIntosh, Total E&P UK Ltd., and Phil Simons, Subsea focuses on Total E&P UK stra
Jeremy Cutler, TOTAL E&P UK Ltd.                                               Abstract The Laggan and Tormore gas condensat
Masud J. Akhtar, SPE, Total E&P UK Limited                                     Abstract Oil was first discovered in the North Sea
                                                                               Abstract The Western Area Development plc
P. Naylor, RPS Energy; J. Cutler, Total E&P U.K. plc; M.K. Denham, RPS Energy; and P.C.D. Ribeiro, Total E&P U.K. (WAD) in
Philippe Coffin and Genevi�ve Lebas / TOTAL                                  Abstract The need for additionnal Underground Ga
Philippe Coffin and Genevi�ve Lebas, TOTAL                                   Summary The need for additional underground ga
                                                                               Summary Digital technologies and Pierre Valette,
Jacques Danquigny, Renaud Da�an, Marc Tison, and Ronald Herrera, TOTAL; and Alain-Serge Ndombi can improve oil pro
                                                                               Abstract E&P Nigeria
N. Guillonneau, G. Fontaine, J.Y. Gory, S. Iwuoha, H. Ahmed, D. Ekpenyong, TOTAL OBAGI is an onshore oil field located on
Pierre Delfiner, SPE, and Robert Barrier, Total                                Summary The portfolio of gas sources to supply a
                                                                                TOTAL
P. Pagnier, C. No�k, and P. Maurel, IFP, and A. Ricordeau and J.L. Volle,Abstract As flow assurance is a critical point challe
                                                                                Total E&P
Jalel Ochi, Pascal Rivet, Jean-Claude Benquet, and Jean-Louis D�tienne,Abstract To predict correctly injectivity for Produce
                                                                               Abstract The E&P Norge AS
Pierre Goud, Stig Helland, Alexandre Goldszal, Ulf E. Moltu, and Laurence Pinturier, Total Norwegian Continental Shelf (NCS)
                                                                               Abstract This paper presents an advanced history
F. Roggero, SPE, and D.Y. Ding, SPE, IFP; P. Berthet, SPE, Total; and O. Lerat, J. Cap, and P.E. Schreiber, IFP
                                                                               Abstract The initial steam chamber
Anh N. Duong, SPE, ConocoPhillips Canada, Timothy A. Tomberlin, ConocoPhillips, Martin Cyrot, Total E&P that developed
L. den Boer, J. Poncet, P. Biver, P. Henriquel, and V. Marlot, Total S.A.      Summary The main objective of history matching
                                                                                Teigland, Total E&P Norge
B.R. Al-Shamma, SPE, Imperial Collegem, London/Total E&P Norge, and R.Abstract This paper provides a study of a history m
                                                                               Abstract While they already contain around half an
David Foulon, Total E&P Qatar; Louise den Boer, Total HQ France; Florence Vieban, Total E&P Qatar; and Rashed Noman, of
P. Samier, A. Onaisi, and G. Fontaine, Total SA                                Summary Generally in classical reservoir studies
P. Samier, Total SA,�and S. De Gennaro, Total UK                             Abstract The use of reservoir simulation coupled w
                                                                               Summary
Pierre Samier, SPE, and Atef Onaisi, Total SA, and Sergio de Gennaro, SPE, Total UK The use of reservoir simulation coupled
Ahmad S. A. Abushaikha1, SPE, and Olivier R. Gosselin, SPE, TOTAL S.A. Abstract Most of porous naturally fractured reservo
                                                                               Abstract Gravity
Ahmad S. A. Abushaikha, SPE, Qatar Petroleum, and Olivier R. Gosselin, SPE, TOTAL S.A. is a major recovery mechanism of
                                                                               Abstract The issue of filtrate cleanup in tight-gas w
Josef R. Shaoul, Johan de Koning, SPE, Pinnacle Technologies Delft; Christian Chapuis, Jean Rochon, SPE, Total E&P
                                                                               U.K. plc
H. Sadrpanah, SPE, Schlumberger, and T. Charles and J. Fulton, Total E&PAbstract This paper presents explicit simulation o
                                                                               Abstract SPE, Kelkar & Associates, Inc., Xavier B
Majid Mohammadpour Faskhoodi*, SPE, Harun Ates, SPE, and Tono Soeriawinata**,To predict future reservoir performance a
A.J. Little, SPE, H.A. Jutila, SPE, and A. Fincham, Energy Scitech Ltd.        Abstract The process of history-matching past res
F. Gouth and A. Toublanc, Total, and M. Mresah, CPTL                           Abstract Characterising and modelling of naturally
M. Garcia, FSS Intl., and F. Gouth and O. Gosselin, Total                      Abstract A large proportion of petroleum reservoirs
Monia Herriou and John W. Barker, SPE, Total SA                                Abstract Karst is a generic term for the effects of m
                                                                               Abstract Sand
Guillaume Servant, IFP; Philippe Marchina, SPE, Total; and Jean-Fran�ois Nauroy, IFP production in an oil or gas well can c
C. Menezes, SPE, Total E&P U.K. plc, and O. Gosselin, SPE, Total S.A.          Abstract Any quantitative workflow designed to c
                                                                               Abstract University; R. Ward, a practical attempt a
I. Bondino, SPE, TOTAL E&P UK Ltd; C.C. Ezeuko and S.R. McDougall, Heriot-Watt This work constitutesTOTAL E&P UK Ltd;
                                                                               U.; and Although experimental
I. Bondino, Total E&P U.K.; J. Long, Total S.A.; S.R. McDougall, Heriot-WattAbstract G. Hamon, Total S.A. work for solution g
                                                                             0           0
                                                                               Abstract This paper presents a specific J. Vittori, T
O. Lerat, P. Nivlet, B. Doligez, N. Lucet, and F. Roggero, IFP; P. Berthet, Total; F. Lefeuvre, Total E&P Borneo; and workflow d
                                                                               Abstract The fully implicit method (FIM) is widely u
A. Agarwal, SPE, Stanford U.; A. Moncorge, SPE, Total E&P U.S.A.; and H.A. Tchelepi, SPE, Stanford U.
                                                                               Abstract Noman, SPE, Qatar Petroleum, Bernard
David Foulon, SPE, Total E&P Qatar; Florence Vi�ban, Total E&P France, RashedAl Khalij could be viewed as the archetypa
                                                                               Abstract Adma-Opco
F. Gouth, L. Moen-Maurel, and F. Jeanjean, Total, and C. Soyeur and Sabah K. Aziz, An integrated multi-disciplinary fracture c
M. Masihi, SPE, Sharif University of Technology, and P.R. King, SPE            Summary Uncertainty in geometrical properties of
R. Murray, SPE, BP Exploration; C. Edwards, SPE, Shell; K. Gibbons, SPE, Abstract This paper summarizes the findings of th
                                                                               Helix-RDS; S. Jakeman, SPE, Shell;�G. de Jon
J.N. Furgier, F. Lavoix, and F. Lemesnager, Total                              Abstract Requirements for Frac-Packing long inter
                                                                             Abstract Summary A ADCO
Marvillet C., Hubans C., Thore P., Desegaulx P, TOTAL, Al-Mehairi Y.S., Shuaib M., Ali Al Shaikh 4D seismic feasibility study h
Aur�lien Treguier, Jacques Danquigny, and Alain Louis, Total S.A.          Abstract Important progress of digital technologies
                                                                             Abstract Production allocation is of utmost importa
S.A. Constant, D.J. Foulon, SPE, Total E&P Qatar; J.A. Danquigny, SPE, Total�; M.D. Labiadh, R. Narayanan and R. Noma
Pierre Pedenaud, Fabrice Dang, TOTAL                                         Abstract The production of extra heavy oil or bitum
                                                                             Abstract Beicip-Franlab; C.J. and the log detectio
N.M. Jedaan, A. Al Abdulmalik, Qatar Petroleum; D. Dessort, Total; V.L.N. de Groen, Both core descriptionFraisse, Total; E. Plu
                                                                             Abstract
J.M. Mazel and H. Poitrenaud, Total E&P, and P. M’Bouyou, Total E&P Congo N’Kossa is an offshore field located 6
Alain BOURGEOIS, Sebastien BOURGOIN, and Pierre PUYO, TOTAL AUSTRAL          Abstract This paper outlines and discusses the iss
                                                                             Abstract BJ Aguada
Raul Sanchez, Regis Agut, and David Coulon, Total Australia, and Roberto Sentinelli,The Services Pichana field is located in the
                                                                             Abstract The Kharyaga
H. Poitrenaud, P. Ferrand, and P. Pouget, SPE, Total E&P, and J. Mani�re, SPE, Schlumberger field is located in Timan-P
                                                                             Abstract Halliburton
P. Leschi, SPE, and G. Demarthon, Total E&P, and E. Davidson, SPE, and D. Clinch, It is well known that the use of hydrochlo
                                                                             Abstract Completing horizontal wells with openhole
Hassan Chaabouni, Schlumberger, Pierre Baux, Dasa Manalu, Muhammad Sobirin, Total E&P Indonesie, Philippe Enkababian
                                                                             Abstract Fracturing Total E&P USA, Inc.
Cesar Gama, David Gerez, and Paul A. Babasick, SPE, Schlumberger, and Jose Piedras, SPE, is an important technique for s
                                                                             Abstract Indonesia
Mark Banman, Eric Delattre, Muhammad Sofyan, and Siswara Suryadana, Total E&P Stacked gravel-packs involve limited tech
                                                                             Abstract TOTAL AUSTRAL
P. Puyo and A. Bourgeois, Total Austral, and A. Penno and A. Oliveira, Halliburton Energy Services Inc. operates the Carina a
                                                                             Abstract This paper documents a novel engineerin
F. Lavoix, P. Leschi, and E. Aubry, Total E&P, and L. Quintero, X. Le Prat, and T. Jones, Baker Hughes Drilling Fluids
G. Petit, H. Foucault, and A. Iqbal, Total E&P                               Abstract Wells in the Girassol field offshore Angol
                                                                              J.-F. Nauroy, IFP
G. Servant, IFP; P. Marchina, Total S.A.; and Y. Peysson, E.�Bemer, and Abstract Allowing sand to be produced is widely k
                                                                             Abstract This paper Alexander, case study involve
Ahmed Abulsayen and Abdulwahab Enneamy, VEBA (Libya), and Kaibin Qiu, Rob Marsden, Joe described a and Muhammad S
                                                                               Heath and C. zinc and iron sulphide scales Simp
S. Dyer, Scaled Solutions; K. Orski and C. Menezes, Total E&P U.K. Ltd.; S.Abstract LeadMacPherson, Clariant; and C. are k
                                                                             Abstract Cheneviere, and condensate drop Samu
Mohan K.R. Panga and�Suzylawati Ismail, Schlumberger Well Services;�Pascal Water blocks Total;�and Mathew out n
                                                                             Abstract Two classes (sonic and ultrasonic) of cem
Douglas Boyd, Salah Al-Kubti, Osama Hamdy Khedr, Naeem Khan, and Kholoud Al-Nayadi, ZADCO; Didier Degouy, ADMA-OP
                                                                             Abstract In its search M.R. Wilson, gas reserves
M.M. Levitan, SPE, and M.J. Ward, SPE, BP plc.; J.-L. Boutaud de la Combe, SPE, Total S.A.; andfor new oil andWell-Test Sol
                                                                              Pinguet and metering using conventional separat
David Costa; Total ABK, Jean-Paul Couput, Total; Florian Hollaender, BrunoAbstract FlowThomas Koshy; Schlumberger
                                                                             Abstract Before the early eighties Engineering of
Victor T. Biu, Total E&P Nigeria, Emmanuel O. Biu, University of Port Harcourt, and Mike O. Onyekonwu, Laser identification Co
                                                                             Abstract Real
M. Zhakupov, SPE, Total S.A., and D. Ilk, SPE, and T.A. Blasingame, SPE, Texas A&M U. gas" flow problems (i.e. problems w
                                                                             Abstract One of & predicaments Azari, SPE , S.
J. Rochon, SPE, V. Jaffrezic, SPE, and J.L. Boutaud de La Combe, SPE, TOTAL ExplorationtheProduction; M. of traditional we
James J. Sheng, Baker Hughes                                                 Abstract Vertical and horizontal permeabilities are
O. Bahabanian, D. Ilk, N. Hosseinpour-Zonoozi, and T.A. Blasingame, SPE, Abstract The analysis/interpretation of wellbore sto
                                                                             Texas A&M U.
   to come oil and gas will remain an energy source of choice to meet increasing demand. But oil and gas operators have to develop fields re
of acid gas geological storage is to a large extent controlled by the capillary properties of the caprock. This low-permeable (e.g. clayey) poro
 lization is a process whereby the CO2 that is injected into a geological formation dissolves into the formation water reacts with the in situ min
s involve the regular use of modeling tools to model and optimize production systems. Modeling is a challenge given the transient and instabl
  €œToday knowledge has power. It controls access to opportunity and advancement. -- Peter F. Drucker Today it is so often we heard the
  ed value of a field performance strategy is only achieved when every effort is treated as an integral part of the complete and larger productio
challenges of the mature Tunu giant gas and condensate field development is the size reduction of new reserves associated to each new tar
 -shore polymer injection may be qualified as a mature EOR technique considering the hundreds of operations that have been conducted all
 -shore polymer injection may be qualified as a mature EOR technique considering the hundreds of operations that have been conducted all
r provides a summary and a guide of the enhanced-oil-recovery (EOR) technologies initiated in the North Sea in the period from 1975 until be
 production in a gas well could significantly reduce gas production due to high friction losses in the tubing the effect of water blocking in front
 istory describes a procedure in which a polymer sealant and a bridge plug were used to shut off water production from upper zones to enable
 ng agents are used to reduce significantly the frictional pressure loss under turbulent flow conditions allowing a substantial increase in pipeli
 years experience as operator of Girassol the earliest deepwater field put in production offshore West Africa Total has recorded a large amo
    than 5 years of experience as operator of Girassol the earliest deepwater field put in production offshore West Africa Total has recorded a
containing H2S are often encountered in the petroleum industry. However reliable experiments on their thermophysical properties in reservo
 trategic association between PDVSA Total and Statoil committed to the production upgrading and commercialization of extra heavy oil from
e knowledge of the initial state of a petroleum reservoir is crucial in order to optimize its development plan. Such knowledge relies on a correc
 field discovered in 1974 is a giant mature oilfield located in the Mahakam Delta Indonesia. The field consists of 555 accumulations and wa
 ater offshore projects are challenging. They are large developments difficult to implement and often beyond the limits of proven technologie
 ion of reservoir simulation models that match field production data has been and is still a long-time industry challenge not only for the time s
urray formation consists of heterogeneous Cretaceous-bitumen-saturated sands. The reservoirs are thick and laterally extensive in the main
  tern Alberta (Canada) the fluvio-estuarine McMurray Formation constitutes the main bitumen accumulation of the Athabasca Heavy Oil Prov
   vertically-oriented heavy oil depletion experiments have been conducted in recent years in an attempt to investigate the impact of gravitation
 f multiphase flow pore level physic has scientific appeal as well as many applications mainly in oil reservoir engineering. In this work we sho
 ars the use of pore-scale network models has greatly advanced our understanding of solution gas drive processes by accounting for the com
 tion of oil leads to degassing of the light species and the formation of a bubbly phase sometimes called the “foamy oil effect. This bubbly
  liable artificial lift pumping system for heavy oil thermal recovery has been a challenge mainly due to the high operating temperatures (>150Ë
  bitumen produced by Steam-Assisted Gravity Drainage (SAGD) induces many issues arising from high operating temperatures (150-200 C)
wells on HP/HT fields after a significant depletion has occurred represents a real challenge. It requires drilling from a cap rock remaining at o
 of project sanction in 1997 Elgin/Franklin was the largest High-Pressure High-Temperature (HP/HT) development in the world.� It require
nc sulphides have recently become a concern in some HP/HT gas fields. The Elgin/Franklin Field (Central Graben North Sea) started produ
measurement of static bottom-hole pressure to monitor the reservoir depletion is an essential reservoir management practice. In an HP/HT o
  presents the development of a chemical system for water-block prevention in gas/condensate wells. The chemical system alters the format
  ductivity in tight reservoirs is greatly impeded by the fracturing fluid interactions with the formation. New simulators introduce formation dama
 es an offshore oil field approximately 60 Km West of Pointe-Noire Republic of Congo. To date the Albian reservoir has contributed most of
ways to optimize the production of tight sand reservoirs is to take advantage of the geometry and density of the existing natural fractures in or
aqueous drilling completion or fracturing fluids can reduce the relative permeability to gas and thereby causes a waterblock. In the case of lo
uction from gas producing wells characterized by low productivity and low reservoir pressure zones can prematurely kill wells leading to a co
 -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
  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
 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
 ore pressure and near-wellbore mobility are key parameters for reservoir description. Traditionally these data are acquired with wireline form
ring Upper Jurassic Arab reservoirs of an offshore Abu Dhabi fractured carbonate field (Abu Al Bukhoosh) have been producing for more tha
eepwater is becoming more and more expensive. There is need to know before hand for well planning purposes the values of the fracture p
 rmation Tester (WFT) pretest success ratio (good versus tight pressure points) has been traditionally low in East Kalimantan-Indonesia over
most important objectives of fluid sampling using wireline formation testers (WFT) is to ensure that representative samples of the different flu
  eals with the use of core scanner imagery for discriminating main representative rock textures to improve core high resolution petrophysical
sforms are used widely to predict permeability. Some of the difficulties of this exercise are well identified such as the homogeneity of the pop
   modeling water-saturation variation in transition zones is important to reservoir simulation for predicting recoverable oil and guiding field-dev
 ield is located offshore Qatar with primary oil production from the Reservoir-X carbonates. In 2005 and 2006 Qatar Petroleum recognized th
 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
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
Umm Gudair Field is a multi-accumulation structure with the most prolific production of oil from a Ratawi Oolite reservoir (Neocomian). The h
  s is an oil and gas-condensate field offshore Mid-Norway. Oil reserves are 29 million Sm3 and gas reserves are 35 billion Sm3. The field wi
nam–Kpono Field six of the hydrocarbon bearing reservoirs encountered are currently developed. The Main Reservoir (R4) is characterize
  ocuses on Total E&P UK strategy for the fast track development of the Jura Project and resultant challenges encompassing: � Contract
n and Tormore gas condensate fields are situated in 600m water depth some 140km north-west of the Shetland Islands. The region is served
   discovered in the North Sea in the 1970’s and some of platforms that were erected during that era are still producing albeit the productio
n Area Development (WAD) involves the Glenelg and West Franklin undeveloped discoveries which are located in the UKCS Central Graben
 r additionnal Underground Gas Storage (UGS) in Europe and in France is increasing. TOTAL has therefore undertaken feasibility studies to
 for additional underground gas storage (UGS) in Europe and in France is increasing. TOTAL has therefore undertaken feasibility studies to c
hnologies can improve oil production and reduce operating costs. In this prospect TOTAL launched a corporate program called Field Monito
n onshore oil field located on OML58 85 km north-west of Port-Harcourt Nigeria. It is composed of 26 stacked reservoir levels with an estim
 lio of gas sources to supply a liquefied-natural-gas (LNG) project may involve many diverse fields each with its range of uncertainty and deg
urance is a critical point challenging offshore field development led TOTAL and IFP to manage a large R&D program on multiphase flow beh
  orrectly injectivity for Produced Water Re-Injection (PWRI) a good description of the formation damage by oil and solid particles have to be
gian Continental Shelf (NCS) is subject to stringent requirements regarding offshore discharges. Focus has previously been on dispersed oil
presents an advanced history matching methodology for constraining 3D stochastic reservoir models to both production history and 4D seism
eam chamber that developed during the circulation phase of a Steam Assisted Gravity Drainage (SAGD) process impacts the efficiency of bi
 objective of history matching is to improve reservoir representation in order to obtain reliable predictions of production rate and thus optimise
provides a study of a history match on a complex reservoir model using a global optimization method. This is done by applying Evolutionary A
already contain around half of the world’s hydrocarbon reserves carbonate fields still exhibit lower recovery factors than clastic fields. A
  in classical reservoir studies the geomechanical behavior of the porous medium is taken into account by the rock compressibility. Inside the
 eservoir simulation coupled with geomechanics to model physical phenomena such as compaction subsidence induced fracturing enhance
 f reservoir simulation coupled with geomechanics has been increasing in recent years as its utility in modeling physical phenomena such as
  us naturally fractured reservoirs present a two-timescale flow-system due to a two-scale heterogeneity which cannot be modelled explicitly
major recovery mechanism of naturally fractured reservoirs where fracture gas drains matrix oil until equilibrium is reached with the capillary
 f filtrate cleanup in tight-gas wells following a hydraulic fracture treatment has long been a topic of discussion in the industry. At one extreme
   presents explicit simulation of hydraulic fractures in horizontal wells to predict the fracture behaviour and post-fracture production profile le
  ture reservoir performance and uncertainties associated a series of reservoir simulation runs are required. It is now a common practice to g
  s of history-matching past reservoir performance involves making reasonable adjustments to key properties in a base geological model eith
 ng and modelling of naturally fractured reservoirs (NFR) with fracturing at different scales is usually a challenging task as the specific respon
 ortion of petroleum reservoirs is known to be naturally fractured with consequences on their flow behavior hence on reservoir performance. T
  neric term for the effects of meteoric (rain) water on carbonate rocks. Resulting features include rock dissolution conduits sink-holes etc w
ction in an oil or gas well can cause additional operational difficulties but contributes to production enhancement by improving the well inflow
  ative workflow designed to constrain reservoir models to 3D/4D seismic data must rely on petro-elastic modelling (or PEM) which relates
onstitutes a practical attempt at addressing issues surrounding depletion gas-oil relative permeabilities in the case of a near-critical oil by usin
perimental work for solution gas drive processes is routinely carried out and interpreted for the purpose of defining critical gas saturations an

 resents a specific workflow developed to build a detailed geological model constrained by high-resolution 3D seismic data. The objective of t
plicit method (FIM) is widely used due to its unconditional stability (even with possibly large time steps). However FIM is computationally expe
 ld be viewed as the archetypal complex carbonate field. Laterally sealed by a stratigraphic closure the reservoir monocline consists in a laye
d multi-disciplinary fracture characterization & modeling study has been performed on a large oil reservoir in offshore Abu Dhabi. This pape
 y in geometrical properties of fractures when they are considered as the conductive paths for flow movement affects all aspects of flow in fr
 summarizes the findings of the SPE Forum held in September 2005 on “Making our Mature Fields Smarter.�Participants in the Forum
 ts for Frac-Packing long intervals in highly deviated wells are more and more frequent in many new projects. Although frac packing is a matu
 4D seismic feasibility study has been performed on carbonate reservoirs of the Bu Hasa field onshore Abu Dhabi. It concludes to the feasibi
 ogress of digital technologies over the past few years radically changes the way Total acquires processes and spreads the data coming from
 llocation is of utmost importance for optimum reservoir development and production optimization. It is becoming all the more critical as fields
 on of extra heavy oil or bitumen through Thermal methods (e.g. SAGD - Steam Assisted Gravity Drainage) requires the generation and injec
escription and the log detection have evidenced the presence of bitumen inside the Bul Hanine Field (figure 1) which can be particularly abun
a is an offshore field located 60 km west of the coasts of Congo in water depths of 170 m. The field is producing light sweet oil from an Albian
outlines and discusses the issues surrounding the TOTAL AUSTRAL Carina and Aries field development project and the engineering issues
  Pichana field is located in the center of the Neuqu�n Basin in the province of Neuqu�n being at present one of the main gas producer
 ga field is located in Timan-Petchora region of Northern Russia 60 km North of the Arctic Polar Circle. The field is producing principally from
 own that the use of hydrochloric acid to clean up and restore permeability of open holes drilled in limestone formations is a questionable pro
 horizontal wells with openhole sections or non-cemented liners is a common practice. This type of openhole wells is preferred to maximize re
  an important technique for stimulating production in low-permeability formations and requires special consideration in designing the preced
avel-packs involve limited technical risk but require considerable rig time when completing deep multi-zone sand control wells. Four field dev
 STRAL operates the Carina and Aries fields which are located in offshore Tierra del Fuego in the most southern region of Argentina. These
 ocuments a novel engineering approach and the operational methodology used to achieve high efficiency remediation on two offshore applic
 Girassol field offshore Angola are situated in very deep water and have being completed in unconsolidated sandy turbiditic reservoirs. Toda
 nd to be produced is widely known to enhance oil production rates particularly for heavy-oils fields. However in such a situation it is very im
 escribed a case study involved an investigation in a field in Libya where massive unexplained fill had been reported accompanying obstructi
and iron sulphide scales are known to be particular issues with gas production fields particularly those producing from HP/HT reservoirs.�
  s and condensate drop out near the wellbore in a gas reservoir can cause rapid production decline. The liquid (water/condensate) is trapped
  (sonic and ultrasonic) of cement bond log tools are run in tandem as part of ZADCO’s standard cement evaluation program. The effecti
h for new oil and gas reserves the oil industry moves to more and more remote areas of the world and to technically challenging areas of dee
ng using conventional separation-based technologies in low-pressure high gas rate environments typical of gas-lifted wells is a very difficult o
early eighties identification of flow regime has been a difficult task for reservoir engineer and welltest analyst until the emergence of the deriv
 ow problems (i.e. problems where the gas properties are specifically taken as implicit functions of pressure temperature and composition)
 redicaments of traditional well testing is the requirement of shutting-in a well to conduct a pressure buildup test for the purpose of obtaining w
  horizontal permeabilities are important parameters for designing well completion and predicting well performance. In the past to determine
 s/interpretation of wellbore storage distorted pressure transient test data remains one of the most significant challenges in well test analysis.ï
                                                                                        OnePetro gases or
 s operators have to develop fields requiring much more processing and energy - i.e. very sour OnePetro extra heavy oils - while reducing the
his low-permeable (e.g. clayey) porous media usually saturated with water acts as a capillary barrier to the underlying stored acid gas � pr
ation water reacts with the in situ minerals and ions and precipitates as carbonate minerals. This process governs the long-term fate of the
  lenge given the transient and instable flow regimes encountered in Oil & Gas facilities. Optimization requires a further level of accuracy: it im
er Today it is so often we heard the words of “data or information.Furthermore it becomesthe data or information management process
  of the complete and larger production system which ranges from reservoir to export. By combining data gathering integrated modelling and
                                                                                        OnePetro
 reserves associated to each new target which tends to reduce the economical value of future drilling projects especially in a context of incre
 rations that have been conducted all over the world only one polymer pilot has been implemented offshore and none in deep offshore condi
 rations that have been conducted all over the world only one polymer pilot has been implemented offshore and none in deep offshore condi
h Sea in the period from 1975 until beginning of 2005. The five EOR technologies that have been initiated in this region are hydrocarbon (HC
    the effect of water blocking in front of perforations and formation damage due to water which eventually could lead to a significant loss of
                                                      OnePetro
 roduction from upper zones to enable gas production from productive lower zones. Offshore gas fields operated in East Kalimantan were pro
 owing a substantial increase in pipeline capacity. Their performance is known to depend on their own characteristics (molecular weight struc
                                                                                        OnePetro
 frica Total has recorded a large amount of operational data. The production system includes several conventional subsea loops connected t
  re West Africa Total has recorded a large amount of operational data. The production system includes several conventional subsea loops c
                                                      OnePetro
 thermophysical properties in reservoir conditions in particular viscosity are very scarce. From a modeling point of view H2S (and CO2) are p
mmercialization of extra heavy oil from an area covering over 325 Km2 in the Orinoco Belt (Figure 1). The Sincor area is composed of a serie
 n. Such knowledge relies on a correct description of the spatial distribution of the fluid components. The compositional variations are mainly
onsists of 555 accumulations and was developed by more than 350 wells with conventional oil recovery methods: natural depletion and periph
yond the limits of proven technologies at their inception. AKPO field is located in block Offshore Mining License (OML) 130 200 km offshore
                                                                                        OnePetro
stry challenge not only for the time spent on history matching studies but also because of the non-uniqueness of the solution. This paper pre
 k and laterally extensive in the main fairways. Many commercial projects are in the early stages of development. Resources too deep to mine
ation of the Athabasca Heavy Oil Province. Deposited within the fluvial-to-marine transition zone the McMurray clastic succession is characte
                                                                                         drive. Although some experimental result indirectly sugge
 o investigate the impact of gravitational forces on gas evolution during solution gasOnePetro
 voir engineering. In this work we show that micro-tomography is an effective tool to extract the structure of many solid systems in a non-des
e processes by accounting for the complex dynamics operating at the microscopic scale. Moreover it has also been demonstrated that a por
  the “foamy oil effect. This bubbly phase is particularly observed with heavy oils combining high viscosity and asphaltenes. Presence an
e high operating temperatures (>150ËšC). Available options such as Rod Pumps and Electrical Submersible Pumps (ESP) which are well pr
                                                                                        OnePetro
  operating temperatures (150-200 C) steam presence in the gas phase foaming emulsion and small density differences between bitumen a
                                                                                        OnePetro OnePetro
 rilling from a cap rock remaining at or close to virgin pressure into a reservoir in which pore and fracture pressures have largely decreased d
 velopment in the world.� It required innovation across the full range of operator activities from fluid modeling through development conce
  ral Graben North Sea) started production early 2001. The wells produce a condensate-rich gas from the Fulmar and Pentland reservoirs wi
management practice. In an HP/HT offshore environment the unavailability of qualified permanent down-hole monitoring technologies and the
he chemical system alters the formation wettability to intermediate gas wet conditions thereby decreasing the capillary forces and enhancing
  simulators introduce formation damage mechanisms to calculate gas well productivity. However equations describing formation damage mu
an reservoir has contributed most of the oil produced. However a significant part of the oil in place is in the Cenomanian a low permeability s
   of the existing natural fractures in order to optimally design and locate the production wells. The detailed mapping of the reservoir fracture n
 auses a waterblock. In the case of low permeability formations the capillary pressure tends to be high because of the small pore size. Clean
                                                                                        OnePetro OnePetro
 prematurely kill wells leading to a considerable loss in recoverable reserves. In some cases mechanical techniques provide a viable solutio
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
  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
 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
                                                                                         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
 h) have been producing for more than thirty years. All the available informations indicate that the producing layers subdivided into Upper and
purposes the values of the fracture pressure. The Fracture pressure could be determined by predictive or verificative methods. Many correla
w in East Kalimantan-Indonesia over decades despite technological advances.� One possible reason has been postulated as alteration of
 sentative samples of the different fluids encountered in the formation are obtained. Usually the wireline or LWD petrophysical logs will guide
 ve core high resolution petrophysical log quality and to propose a better strategy for plugs sampling. The idea of using tomography images h
    such as the homogeneity of the population (rock typing) the matching of cores and logs (especially depth matching) and the problem of pe
   recoverable oil and guiding field-development plans. The large transition zone of a heterogeneous Middle East reservoir was challenging to
                                                                                          OnePetro modern
2006 Qatar Petroleum recognized that future development of this mature field would require aOnePetrostate of the art reservoir model and
 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
 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
   Oolite reservoir (Neocomian). The historic ultimate seal held by the thick Ratawi Shale Member displays embedded multilayered oil bearing
erves are 35 billion Sm3. The field will be developed as a subsea project with 5 templates having 9 producers and 3 injectors. Production st
e Main Reservoir (R4) is characterized by vertically stacked sand bodies with intercalated shale layers laterally well extended. In the initial re
  nges encompassing: � Contract strategy to maximise schedule efficiency and flexibility. � Innovative design engineering for subsea a
 hetland Islands. The region is served by limited oil and gas infrastructure and so called stranded gas" fields have been left undeveloped to d
 are still producing albeit the production has dwindled significantly. With the technical costs on the rise oil & gas operators are constantly on th
   located in the UKCS Central Graben to the west of the Elgin/Franklin (E/F) asset. E/F is one of the largest high pressure high temperature
 ore undertaken feasibility studies to convert the P�corade depleted oil field situated in South West France into an UGS. The P�corad
ore undertaken feasibility studies to convert the depleted P�corade oil field situated in South West France into an UGS. The P�corade
                                                                                          OnePetro OnePetro
orporate program called Field Monitoring" to capitalize affiliate previous experiences. For gas-lifted wells it resulted in the development of the
  tacked reservoir levels with an estimated total OOIP of 1.2 Gbbls. It was discovered in 1964 and has been producing since 1966 through 12
  with its range of uncertainty and degree of maturity. For project approval it is necessary to aggregate the reserves/resources of all these fie
R&D program on multiphase flow behaviour. One of the objectives is to improve the understanding of the behaviour of gas/oil/water mixtures
   by oil and solid particles have to be introduced in simulators for both fractured and non fractured flows. It is well known that the complex me
has previously been on dispersed oil concentration (OIW) in produced water (PW) discharge but management tools like the calculation of th
 both production history and 4D seismic attributes. The proposed approach is based on an optimization loop which integrates geostatistical m
 ) process impacts the efficiency of bitumen recovery tremendously. The circulation phase during which both horizontal injector and producer
   of production rate and thus optimise future field developments. Standard history matching techniques are composed of a fixed geological m
his is done by applying Evolutionary Algorithms to the problem of history matching. The results of the history match are then used to carry ou
ecovery factors than clastic fields. A major explanation lies in the more complex intrinsic structure and higher chemical reactivity of carbonate
by the rock compressibility. Inside the reservoir simulator the rock compressibility is assumed to be constant or to vary with the pressure of t
 sidence induced fracturing enhancement of natural fractures and/or fault activation SAGD recovery etc.. has been increasing. Different me
 deling physical phenomena such as compaction subsidence induced fracturing enhancement of natural fractures and/or fault activation an
 which cannot be modelled explicitly nor homogenised in reservoir simulation models. When the only flowing domain is the fracture network
                                                      fluid densities matrix gas capillary pressure and block height). The challenge of modelling g
uilibrium is reached with the capillary forces (wrt OnePetro
 ssion in the industry. At one extreme there is the possibility of a “water block in which filtrate fluid prevents gas production completely. In
                                                     OnePetro
nd post-fracture production profile leading to an optimum design and maximum production enhancement. The paper demonstrates the adva
  ed. It is now a common practice to generate multi million-cell geological model to capture the heterogeneity details in the reservoir. However
erties in a base geological model either by ‘trial-and-error’ or using some computer-assisted approach until observed data are adeq
                                                                                          OnePetro
 allenging task as the specific response from each scale is difficult to isolate. We focus on a carbonate reservoir in North Africa in productio
 or hence on reservoir performance. Though the modeling of such reservoirs has been the purpose of many research works it remains a cha
 ssolution conduits sink-holes etc which may have extremely high permeability. Fluid flow simulations in such environments are therefore v
ncement by improving the well inflow performance. In order to be able to assess the relatve magnitude of those two effects and to optimize th
 c modelling (or PEM) which relates fluid and rock properties to elastic ones. Various scales must be accounted for: laboratory cores and w
    the case of a near-critical oil by using pore-scale network modelling techniques. Firstly a new model for gas buoyancy is presented that is a
                                                                                          OnePetro
of defining critical gas saturations and relative permeability data developing a thorough understanding of the results to facilitate confident ap
                                                                                          OnePetro OnePetro
                                                                                          OnePetro
  n 3D seismic data. The objective of the proposed approach was 1/ to integrate both geological and seismic information in a coherent fine-gri
However FIM is computationally expensive per time step especially for large number of components. IMPES (Implicit Pressure Explicit Satu
 eservoir monocline consists in a layercake of alternating good and poor quality rock whose fabric has been intensively reworked during multi
voir in offshore Abu Dhabi. This paper describes the methodology used for analyzing and integrating the geophysical geomechanical geolog
ement affects all aspects of flow in fractured reservoirs. The connectivity of fractures embedded in low-permeability zones can control fluid
 Smarter.�Participants in the Forum have granted permission to present this paper on the basis that the authors are neither representing
 ects. Although frac packing is a mature technology its limits of applicability are not well known and are progressively extended by operationa
  bu Dhabi. It concludes to the feasibility of the method as a reservoir injection monitoring tool an interesting result when several recent paper
 es and spreads the data coming from its upstream assets. The rising generation of oilfields already reaps the benefits from the use of these
 ecoming all the more critical as fields are increasingly developed through long often multilayer commingled horizontal drains either to reduc
 ge) requires the generation and injection into the reservoir of significant quantities of steam which is finally recirculed with the produced bitum
                                                                                          OnePetro
ure 1) which can be particularly abundant in some wells. This tar mat severely impacts reservoir production behaviour because it acts as a p
oducing light sweet oil from an Albian age reservoir buried between 3100m and 3400m TVD. In order to access reserves located in the south
nt project and the engineering issues addressed to facilitate achieving the project goals of producing gas at high rates from the shallow uncon
 resent one of the main gas producers in Argentina. The completion programs of Aguada Pichana wells imply the stimulation of Middle Mulic
The field is producing principally from a Devonian age carbonate reservoir this limestone formation having an average porosity of 8 to 12% a
 one formations is a questionable procedure. It is necessary to remove not only the filter cake at the well bore face but more importantly th
hole wells is preferred to maximize reservoir productivity. Some questions that always come up for this type of wells are: will it be necessary
 onsideration in designing the preceding perforating job. Aligning the perforations along the direction of maximum geological stress known as
one sand control wells. Four field developments are challenging the conventional approach to completing long sand control zones by using ne
  southern region of Argentina. These fields are prolific gas producers and are being developed with a reduced number of wells with departu
cy remediation on two offshore applications. Results are presented detailing specific placement procedures in-situ treatment design and pro
 ated sandy turbiditic reservoirs. Today in Girassol which includes also Jasmin reservoir 29 wells have been completed and connected to pro
wever in such a situation it is very important to be able to determine the expected sand rate as well as the amount of sand produced during
een reported accompanying obstruction of production for majority of production wells since the onset of production indicating possible sandin
producing from HP/HT reservoirs.� The Elgin/Franklin Field is located 240 kilometres east of Aberdeen in the Central Graben Area of the
                                                                                          OnePetro
e liquid (water/condensate) is trapped near the wellbore due to strong capillary forces and/or viscous fingering of gas through the liquid. To re
ment evaluation program. The effectiveness of these tools and their evaluations are often challenged and are not regarded as a replacement
  technically challenging areas of deep water.� Development of hydrocarbon resources in these environments is extremely expensive.�
  of gas-lifted wells is a very difficult operation. Owing to low retention times of the gas the quality of separation and existing instrumentation i
 alyst until the emergence of the derivative approach. This approach has helped to reduce the uncertainties of the interpretation of welltest re
  ure temperature and composition) are particularly challenging because the diffusivity equation for the "real gas" flow case is strongly non-lin
  up test for the purpose of obtaining well and reservoir properties. This deterrent factor is more prominent in prolific wells due to loss of reven
 rformance. In the past to determine the permeabilities from a vertical interference test some investigators proposed correlations or type cur
 cant challenges in well test analysis.� Deconvolution (i.e. the conversion" of a variable-rate distorted pressure profile into the pressure pro
he underlying stored acid gas � provided its water-wettability is preserved and water/acid gas interfacial tension (IFT) is high enough. The
ss governs the long-term fate of the injected CO2 and ensures a safe storage once CO2 has been converted into minerals. In a previous stu
uires a further level of accuracy: it implies the modeling of an envelope of production operating-points. This paper presents the solutions wh
 or information management process where three important parts should be involved: input – process – output. From those three data be
a gathering integrated modelling and control elements in so-called “value loops optimization opportunities of the field efficiency are achi

ore and none in deep offshore conditions. A very thorough feasibility study of polymer injection has been made on the Dalia field in Angola
ore and none in deep offshore conditions. A very thorough feasibility study of polymer injection has been made on a typical deep-offshore h
 d in this region are hydrocarbon (HC) miscible gas injection water-alternating-gas (WAG) injection injection simultaneous water-and-gas (S
ally could lead to a significant loss of recoverable reserves. Selective mechanical water shut-off (i.e. casing patch) the main technique used

haracteristics (molecular weight structure chemical composition) and on external parameters such as turbulence intensity oil viscosity etc.

several conventional subsea loops connected to a floating-production storage and offloading vessel (FPSO) at 1 350-m water depth with ga

he Sincor area is composed of a series of stacked unconsolidated sand-shale reservoirs with good petrophysical properties. The depositiona
 compositional variations are mainly due to gravitational segregation and thermo-diffusion phenomena. Usually a good estimation of the stea
methods: natural depletion and peripheral water injection. After many reservoirs have been water-flooded in order to recover the tertiary oil E
License (OML) 130 200 km offshore Nigeria in 1400 m of water. At plateau production AKPO will produce and export 175 000 B/D of conde

opment. Resources too deep to mine are considering steam assisted gravity drainage (SAGD) (Butler 1991). Detailed high-resolution 3D geo
Murray clastic succession is characterized by the lateral and vertical juxtaposition of a wide variety of depositional processes. This led to com

e of many solid systems in a non-destructive and classical manner. Recently X-ray computed tomography tools have been extended to the a
 s also been demonstrated that a pore-network model when suitably anchored to core material is able to provide both qualitative and quantita
 osity and asphaltenes. Presence and behavior of a foamy-oil effect appears to be critical to the cold production process. This process is not
sible Pumps (ESP) which are well proven in the industry are not particularly well suited to thermal production. While Rod Pumps offer high t


 odeling through development concept definition HP/HT drilling and platform design to commercial framework.� Eight years after produc
e Fulmar and Pentland reservoirs with initial temperature of 200 degC and pressure of 1100 bar. Mid-2002 the first Calcium Carbonate obs
-hole monitoring technologies and the risks and costs of occasional operations make gradient surveys very difficult to acquire on a routine ba
 g the capillary forces and enhancing the clean up of trapped water at low drawdown pressures. Five different chemicals (A1-A5) are evalua
ons describing formation damage must be supported by experimental data obtained in conditions representative of fracturing operations. Th
 he Cenomanian a low permeability sandstone formation with poor quality. As of early 2007 only two of the initial 50 wells in the field had be
d mapping of the reservoir fracture network is therefore essential. To achieve such a detailed fracture mapping a wide azimuth 3D surface s
ecause of the small pore size. Clean up of water blocks requires high draw down unless water vaporization by the flowing gas is improved by

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
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


ing layers subdivided into Upper and Lower Arab are fractured to varying extents. As a result a better understanding of the fracture networ
or verificative methods. Many correlations exists that can be used to predict the fracture pressure. However they are mostly limited to onsho
 has been postulated as alteration of near-wellbore formation properties during drilling operations.� The relatively tight gas sands are drille
or LWD petrophysical logs will guide the sample acquisition program. This typically means that resistivity and nuclear logs are used to infer b
e idea of using tomography images has physical bases. In fact scanned data is representative for rock bulk density changes; the perceptual
pth matching) and the problem of permeability upscaling. Not so well-known however are the pitfalls of a statistical and geostatistical nature
dle East reservoir was challenging to model. Core-calibrated log-derived water saturations were used to generate saturation-height-function

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
  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
ys embedded multilayered oil bearing reservoir sands. Sands were sedimented as thin tidal bars anastomosed with distributary and tidal chan
  ucers and 3 injectors. Production start-up is July 2009. The field development is innovative in the following aspects: Cost effective devel
aterally well extended. In the initial reservoir study a low vertical reservoir permeability (Kv/Kh=0.01) and maps of vertical transmissibility with
  tive design engineering for subsea application: -����� First use worldwide of subsea chemical injection metering. -��ï¿
elds have been left undeveloped to date; primarily due to the significant investment required to establish an export route to market in this rem
   & gas operators are constantly on the lookout for cheap and simple solutions. These help not only to increase the hydrocarbon production f
  est high pressure high temperature producing asset in the world and involves gas condensate reservoirs at 1 100bara and 190degC. The W
 rance into an UGS. The P�corade field offers some good characteristics to become an UGS but is also deep (2500 m) and countains hy
 ance into an UGS. The P�corade field offers a number of positive characteristics which make it a good candidate for UGS but it is also

 en producing since 1966 through 123 wells and 257 completions. 21 layers have been developed. With a global recovery to-date of 50% an
he reserves/resources of all these fields into project-level representative numbers either deterministic or probabilistic. Arithmetic addition of
  behaviour of gas/oil/water mixtures in separation tanks. In the framework of a joint project a new test facility platform GOwSP (Gas Oil wate
 It is well known that the complex mechanisms of the formation of an external filter cake and of a deep internal damage should be better und
gement tools like the calculation of the Environmental Impact Factor (EIF) have also shown the important contributions of naturally occurring
 oop which integrates geostatistical modeling upscaling fluid flow simulation and petro-elastic modeling in the same workflow.� Simulated
 both horizontal injector and producer in a SAGD well pair are put under circulation is designed to establish inter-well communication and cre
are composed of a fixed geological model with global modifications and local adjustments. The limitations with this methodology are clear: loc
 tory match are then used to carry out an uncertainty assessment on variables of interest. The main parameters used in the history match inc
 gher chemical reactivity of carbonate rocks. Because it is linked to both the depositional and the biological environment the genetic pore ne
stant or to vary with the pressure of the oil phase. It induces some changes in the porosity field. During the depletion phase or the cold-wate
c.. has been increasing. Different methods of coupling have been investigated by numerous researchers: fully implicit coupling iterative cou
al fractures and/or fault activation and steam-assisted gravity drainage (SAGD) recovery has become apparent. Among different methods in
 wing domain is the fracture network and when the accumulation lies in porous and low permeable matrix blocks the rate of exchanges betw


nt. The paper demonstrates the advantages of using explicit numerical simulation in contrast to analytical modeling.� Conventionally an
 eity details in the reservoir. However computational cost of such models is prohibitive for reservoir simulation studies and they need to be u

 eservoir in North Africa in production for two years. There is evidence of fracturing at different scales (from diffuse fractures to conductive fa
 any research works it remains a challenging task. Too simplistic reservoir models do not allow capturing essential features like large-scale f
 n such environments are therefore very challenging – conventional reservoir simulators often experience convergence problems and run t
 f those two effects and to optimize the well completion and operation philosophy a quantitative forecast of the expected amount and rate of
accounted for: laboratory cores and well logs geological and seismic grids fluid flow simulator models. The petro-elastic model is generally
  gas buoyancy is presented that is able to track dynamically the movement of buoyant gas in the pore network; this framework is successful



MPES (Implicit Pressure Explicit Saturations) on the other hand is computationally inexpensive but only conditionally stable. For large-scale
een intensively reworked during multiple phases of diagenesis. Additionally the oil column is relatively thin and average water saturation abo
  geophysical geomechanical geological and reservoir data in order to achieve a comprehensive understanding of the fracture network and
 permeability zones can control fluid movement and influence field performance. This can be analyzed using percolation theory. This approa
 he authors are neither representing the views of the SPE nor of the participants’ companies. We are delivering smarter fields in order t
progressively extended by operational experience. Today it is a common practice to perform Frac-Pack in 65� deviated well over length o
ting result when several recent papers [1] have suggested that 4D seismic may not be applicable to Middle East carbonate reservoirs due to
ps the benefits from the use of these technologies through a patchwork of customized applications ranging from measurement up to visualiza
 gled horizontal drains either to reduce costs in offshore environments to ensure productivity in low permeability reservoirs or as an improve
 lly recirculed with the produced bitumen. Considering the need to minimize fresh water consumption and the possibility of increasingly string

 access reserves located in the southernmost compartments of the reservoir Extended Reach Drilling (ERD) was implemented. Six ERD we
  at high rates from the shallow unconsolidated sand stone reservoirs. The main challenge in terms of completion architecture was to maxim
 imply the stimulation of Middle Mulichinco Formation (primary target) through hydraulic fractures. Mulichinco Formation is 30 to 80 meters th
ng an average porosity of 8 to 12% and permeabilities ranging from 1 to 200 mD. The wells are completed as cased-hole with a 7inch liner
 ll bore face but more importantly the low permeability crushed zone created during the drilling operation. To achieve uniform treatment of
ype of wells are: will it be necessary to cleanup the mud and filtercake from the openhole section before or while starting production? Will the
maximum geological stress known as the preferred fracture plane (PFP) provides significant opportunities to improve the efficiency of the fra
g long sand control zones by using newer technologies. A typical well in the Mahakham Delta has five zones and installing conventional grav
educed number of wells with departures of up to 3.5 km at approximately 1000 m TVD. This paper discusses the issues surrounding the T
ures in-situ treatment design and productivity improvements. Two wells were recently drilled and completed for the Rosa deepwater project
 een completed and connected to production facilities and pressure maintenance is coming from 13 water injectors and 2 gas injectors. The c
the amount of sand produced during the life of the well. To address this problem an oedometric cell specially designed to simulate a radia
production indicating possible sanding issues for this field. To investigate this problem relevant data from different sources and different do
en in the Central Graben Area of the North Sea blocks 22/30b 22/30c and 29/5b. With initial temperatures of 200�C and pressures of 16

 d are not regarded as a replacement for reservoir inter-zonal communication tests performed between producing reservoirs on every well. C
onments is extremely expensive.� To be economically viable the newly discovered fields must be developed and effectively exploited with
aration and existing instrumentation is often doubtful leading to an under-estimate of liquid rates. An aggravating factor is that such wells are
ies of the interpretation of welltest result because key regions of radial flow and boundary features required for reservoir characterization des
 real gas" flow case is strongly non-linear.� Whereas different methods exist which allow us to approximate the solution of the real gas diff
nt in prolific wells due to loss of revenue and problems associated with crossflow or when bringing a well back on production. Moreover in ca
ors proposed correlations or type curves based on simplified point source solutions. However it is impossible for these correlations or type c
 pressure profile into the pressure profile for an equivalent constant rate production sequence) has been in limited use as a "conversion" mec
ial tension (IFT) is high enough. The displacement or capillary breakthrough pressure above which the stored acid gas intrudes into the cap
 erted into minerals. In a previous study involving the modelling of the long-term fate of CO2 in the Utsira aquifer storage the authors observ
This paper presents the solutions which are being implemented in two affiliates of West Africa within TOTAL Digital Field corporate program
– output. From those three data become the “input and running systems or applications are the “processes which will deliver infor
 unities of the field efficiency are achieved in every phase of the asset lifecycle. The Field Monitoring solutions of TOTAL aim at improving th

 n made on the Dalia field in Angola a typical deep-offshore high permeability (>1D as an average) sandstone reservoir containing medium v
 n made on a typical deep-offshore high permeability (>1D as an average) sandstone reservoir containing medium viscosity oil (3 to 7cP und
 tion simultaneous water-and-gas (SWAG) injection foam-assisted WAG (FAWAG) injection and microbial EOR (MEOR). Each EOR techn
 sing patch) the main technique used to solve this problem so far has some disadvantages mainly reducing the inside diameter of the produ

urbulence intensity oil viscosity etc. The mechanism by which DRAs interfere with turbulence is not fully understood and drag reduction is no

PSO) at 1 350-m water depth with gas lift injected at the bottom of the risers for activation and flow stabilization. A systematic review of the o

 physical properties. The depositional system can be divided in two main parts Deltaic and Fluvial. Fluvial sands mainly stacked braided cha
Usually a good estimation of the steady state spatial distribution of the components is obtained by thermodynamic modeling based on an Eq
d in order to recover the tertiary oil EOR lean gas injection project was started in November 1995 on five reservoirs. The project was succes
uce and export 175 000 B/D of condensate and will export at startup 320 MMscf/D of gas to Bonny NLNG plant onshore Nigeria. AKPO res

 991). Detailed high-resolution 3D geostatistical modeling is useful for individual well-pair or pad flow simulation but is neither practical nor ne
 positional processes. This led to complex lithofacies variations responsible for uncertainties in predicting reservoir heterogeneities. In this co

hy tools have been extended to the ability to contrast fluids in the pore space of core samples. As time required for collecting a CT image is
o provide both qualitative and quantitative descriptions of relative permeability and hydrocarbon recovery. In contrast many so-called “exp
oduction process. This process is not a well-understood production mechanism because a wide range of different petrophysical parameters a
uction. While Rod Pumps offer high temperature service they are limited in the flowrate they can deliver. ESPs on the other hand can handle


mework.� Eight years after production first began it is fair to say that Elgin/Franklin has not only achieved the aims of the initial project it h
 002 the first Calcium Carbonate obstructions appeared downhole on several wells and resulted in a progressive production decrease. More
 ery difficult to acquire on a routine basis. On Elgin-Franklin (HP/HT gas condensate fields North Sea UKCS) the typical approach is to use
 fferent chemicals (A1-A5) are evaluated in this study for their ability to prevent water block formation at high temperature. Adsorption/desor
sentative of fracturing operations. The purpose of this work is to derive the absolute permeability damage and multiphase flow upon return g
 the initial 50 wells in the field had been completed in the Cenomanian. It was desired to evaluate the potential of hydraulic fracturing stimulat
mapping a wide azimuth 3D surface seismic acquisition has been acquired and is being processed for azimuthal anisotropy estimation. The a
 ion by the flowing gas is improved by using specific additives like alcohols. The purpose of this work is to investigate fracture face damage b

 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
 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


understanding of the fracture networks and their relationship with major and sub-seismic faults in this field is now critical to optimize infill drill
 ver they are mostly limited to onshore and shallow water fields. There is therefore the need to develop correlations that can reliably predict t
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
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
bulk density changes; the perceptual texture of these images reveals features like granularity mineralogy both tied to porosity distribution. In
 a statistical and geostatistical nature that may create significant biases—always in the same direction—an underestimation of permeability
 generate saturation-height-function groups for nine reservoir-rock types. To match the large span of log water saturation (Sw ) in the transiti

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
 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
mosed with distributary and tidal channels deposited under pro-deltaic to delta front environment. To delineate this complex reservoir a neur
 wing aspects: Cost effective development with a 43 km tie-back to the Kristin platform through an 18 pipeline. Tie-back is possible becau
d maps of vertical transmissibility within these shale layers were implemented in the dynamic model. In fall 2007 Amenam East well confirm
 mical injection metering. -����� Subsea hard HIPPS IL 3 rated with fibre optic control first Subsea HIPPS in the Total Group.
 an export route to market in this remote and harsh environment. After several years of extensive development engineering studies and com
 crease the hydrocarbon production from a well but also helps in improving the overall field recovery factor. However sometimes expensive w
rs at 1 100bara and 190degC. The WAD is at similar conditions and two drilling strategies involving up to five new wells were proposed: Stra
also deep (2500 m) and countains hydrogen sulphide. This paper describes the different challenges faced by the project: the sizing of the
ood candidate for UGS but it is also deep at 2500 m and contains hydrogen sulphide. This paper describes some of the challenges faced by

  a global recovery to-date of 50% and an average producing water-cut of 75% OBAGI can be considered as a mature oil field. Current activ
  probabilistic. Arithmetic addition of all low estimates (1P or P90) and all high estimates (3P or P10) is known to overstate the range of unce
acility platform GOwSP (Gas Oil water Separation Platform) was implemented in 2006 on the IFP-Lyon site. The issue consists in improving
nternal damage should be better understood. In a previous published work1 we attempted to quantify the petro-physical external filter cake p
 t contributions of naturally occurring dissolved components and production chemicals. Even if the legislation seeks a balance between techn
 in the same workflow.� Simulated production history and 4D seismic attributes are compared to real data using a single objective function
 ish inter-well communication and create an initial steam chamber. It is desirable to know the mid-point temperatures between and along the
 s with this methodology are clear: local adjustments are not always geologically realistic static uncertainties are not taken into account and o
ameters used in the history match included: horizontal permeabilities porosities and vertical transmissibilities. �This study also made use
cal environment the genetic pore network is more complicated than in classical sandstones. Moreover; it is usually strongly reworked after d
the depletion phase or the cold-water injection of high-pressure/high-temperature (HP/HT) reservoirs the stress state in and around a reserv
s: fully implicit coupling iterative coupling and one way coupling. So far the iterative explicit method appears to be the prefered method for fi
pparent. Among different methods investigated by researchers the iterative explicit method appears to be the preferred method for field-sca
ix blocks the rate of exchanges between the two domains drives the recovery of such reservoirs. So called dual-porosity simulation models


cal modeling.� Conventionally analytical methods and software are used to forecast post-fracture production rates to evaluate the profita
ulation studies and they need to be upscaled. Upgridding is an upscaling design technique that provides optimal geologic layer grouping sch

rom diffuse fractures to conductive faults) �with significant implications for oil production. We first present the way fractures have been fu
g essential features like large-scale fracturing trends or non-linear multivariate relationships between the equivalent (generally anisotropic) p
nce convergence problems and run times of several days are not uncommon even for models with a modest number of grid cells. We propo
 of the expected amount and rate of sand production must be established. It requires a correct description of all the mechanisms involved in
The petro-elastic model is generally a fine-scale model (“pem) defined and calibrated for each specific case against core and logs data
etwork; this framework is successfully used to model experimental visual observations of “coherent channelized gas flow and dispersed



 y conditionally stable. For large-scale heterogeneous models the allowable stable time step of IMPES may be extremely small. In the Adapti
 in and average water saturation above free water level exceeds 85%. Al Khalij development challenge can thus be formulated as: How to ef
standing of the fracture network and its effect on fluid flow. The study has highlighted the existence of two scales of fractures developing in t
using percolation theory. This approach uses the hypothesis that the permeability map can be split into either permeable (i.e. fracture) or imp
are delivering smarter fields in order to add value to our business – there are many facets to this value beyond reservoir well process and
  in 65� deviated well over length of less than 100 ft and to achieve good completion efficiency (mechanical skin less than 5). This is possi
dle East carbonate reservoirs due to their rock physics characteristics. 2D full wave equation and 3D convolutional modelling approaches ha
ng from measurement up to visualization. This combination of both existing and leading-edge technologies ensures to constantly reach the f
meability reservoirs or as an improved oil recovery method tapping unswept areas. Conventional Production Logging Tools (PLTs) have bee
d the possibility of increasingly stringent environmental regulations it is likely that maximization of the recycling of the produced water into ste

ERD) was implemented. Six ERD wells have been drilled to date with lateral extensions close to 6500 m leading to total depths sometimes in
ompletion architecture was to maximize the well head flowing pressure while insuring “long term integrity of wells.� This was addresse
hinco Formation is 30 to 80 meters thick and has a variable permeability throughout the pay zone. The gas drainage from the best permeabi
ted as cased-hole with a 7inch liner through the reservoir section. The perforated intervals range from 30 to 80 m in length and the wells we
on. To achieve uniform treatment of the entire openhole section with hydrochloric acid is difficult: the rapid reaction of the acid in downhole
 or while starting production? Will the filtercake disperse and get removed while producing the well and applying drawdown to the formation?
es to improve the efficiency of the fracture job maximizing ultimate production from the well. Wells are frequently completed with multiple tu
ones and installing conventional gravel pack completions would consume up to 30 rig days. This represents a significant capital cost. To redu
 cusses the issues surrounding the TOTAL AUSTRAL Carina field development project and the innovative processes that were used to add
 eted for the Rosa deepwater project Block 17 offshore Angola using a Non-Aromatic Oil-Based Mud (NAOBM) weighted with sized calcium
er injectors and 2 gas injectors. The completion strategies employed have included mainly stand alone screens in open hole and cased hole
pecially designed to simulate a radial flow towards a well has been developed at IFP. Tests performed under CT-scan on cohesionless san
om different sources and different domains (i.e. wireline logs laboratory test data drilling data well data and field data) were integrated to g
ures of 200�C and pressures of 16 000psi this is one of the highest pressure and temperature developments ever undertaken. The fields

producing reservoirs on every well. Consequently the value of continuing to run these tools was raised by management. In response the relia
veloped and effectively exploited with very few wells. This forces the oil companies to concentrate on high quality reservoirs that yield highly p
gravating factor is that such wells are often producing at high water-cuts thus leading to significant uncertainty on oil rates. To solve such me
red for reservoir characterization description and evaluation have been adequately diagnose. However the approach is complex for non-mat
 imate the solution of the real gas diffusivity equation all of these approximate methods have limitations (including numerical models). The p
  back on production. Moreover in case of commingled reservoirs conventional buildup provides only average values of permeability skin a
ssible for these correlations or type curves to cover the variety of scenarios found in the real world. In the recent years people start to use re
  in limited use as a "conversion" mechanism for the last 25 years.� Unfortunately standard deconvolution techniques require accu-rate m
 stored acid gas intrudes into the caprock is directly related to those two interfacial properties. Water/acid gas IFTs have recently been thoro
 a aquifer storage the authors observed that CO2 mineralization was not possible if mineral reactions were limited to Calcite and Dolomite pr
 TAL Digital Field corporate program called Field Monitoring to address this issue. The instabilities of production parameters observed durin
 €œprocesses which will deliver information as the “output. Those three basic parts are essential for running continuously and simultaneo
 utions of TOTAL aim at improving this field performance through the execution of pertinent analyses that help take strategic decisions; thes

dstone reservoir containing medium viscosity oil (3 to 7cP under reservoir conditions). The study has demonstrated that high molecular weig
 g medium viscosity oil (3 to 7cP under reservoir conditions). The study has demonstrated that high molecular weight hydrolyzed polyacrylam
obial EOR (MEOR). Each EOR technology that has been initiated in the North Sea was identified with its respective maturity level and/or mat
ucing the inside diameter of the production tubing which makes future mechanical water shut-off of the deeper reservoirs more difficult. Chem

  understood and drag reduction is not easy to predict. Laboratory tests are still required to quantify the potential efficiency of these additives.

 ilization. A systematic review of the operating parameters of the subsea production loops over the past years gave the opportunity to extract

 al sands mainly stacked braided channels represent the bottom part of the reservoir. Deltaic sands go from distributary channel and mouth
modynamic modeling based on an Equation of State (EoS). This heuristic approach is unable to yield any knowledge on the time required to e
 e reservoirs. The project was successful and extended to the other six reservoirs in 2000. However the field production continued to decline
NG plant onshore Nigeria. AKPO reservoirs characteristics have greatly influenced the development scheme while still making it technically

 ulation but is neither practical nor necessary for resource assessment across large areas. A methodology for resource assessment is deve
g reservoir heterogeneities. In this context a realistic paleogeographic reconstitution is necessary to localize sandy reservoirs and optimize th

  equired for collecting a CT image is much longer than almost flow time scales CT imaging must occur at static flow conditions to accurate g
 . In contrast many so-called “experimental depletion drive relative permeabilities are not measured directly but are generally obtained by
   different petrophysical parameters and experimental factors interact in a rather complex way. Over the past few years a number of efforts h
 . ESPs on the other hand can handle high volumes of low viscosity fluids but are still limited in terms of maximum operating temperature. P


eved the aims of the initial project it has clearly surpassed them.� The increased gas export capacity compared to initial design the succe
  gressive production decrease. Moreover lead and zinc sulphides were identified on well G6. The heavy scaling from its surface-controlled s
UKCS) the typical approach is to use an average fluid density to estimate the static bottom-hole pressure from the well-head shut-in pressure
  high temperature. Adsorption/desorption characteristics of these chemicals and temperature stability are also investigated for long-term pre
  e and multiphase flow upon return gas permeability after core invasion by a fracturing fluid by methods used in Special Core Analysis Labora
 tential of hydraulic fracturing stimulation treatments to more fully comprehend the production capability of this reservoir. In early 2007 a third
 zimuthal anisotropy estimation. The azimuthal variations of P-wave AVO and velocity are analyzed in terms of TIH anisotropy. In order to inte
 to investigate fracture face damage by measuring relevant petrophysical parameters: absolute permeability damage and gas return permeab

 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
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


 ld is now critical to optimize infill drilling and produce the remaining reserves. The present paper focuses on the characterization of different
correlations that can reliably predict the fracture pressure for deep water fields. This paper explores the concept of developing and possibly
one layers using oil based mud systems. To further investigate possible near formation alteration an extensive evaluation program was unde
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
 y both tied to porosity distribution. In this paper we demonstrate that core scanner images contain information that can be related to petroph
—an underestimation of permeability. The passage from Phi to k is performed in three steps: (1) in cored wells an exponential regression e
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

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
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
  ineate this complex reservoir a neural network technique was applied to estimate effective porosity integrating well information and 3D mult
  pipeline. Tie-back is possible because the pipeline will have direct electrical heating to prevent formation of hydrates and to preserve temp
 fall 2007 Amenam East well confirmed an excellent lateral communication with Amenam Main Field through the aquifer and highlighted the
st Subsea HIPPS in the Total Group. � Bundle construction utilising controlled depth tow method with the heaviest ever installed lead tow
opment engineering studies and commercial negotiations the Laggan and Tormore partners led by TOTAL�E&P�UK�Ltd (TEP�U
 or. However sometimes expensive well interventions are necessary in order to better understand the problems faced and then use the data
o five new wells were proposed: Strategy-A: Drilling from the existing E/F platforms Strategy-B: Drilling from a new wellhead platform (WHP)
ced by the project: the sizing of the working volume (volume of gas which can be stored and cycled each year) which required the acquisitio
  bes some of the challenges faced by the project including: The sizing of the working volume (volume of gas which can be stored and cycle

ed as a mature oil field. Current activities are driven by two main objectives: to sustain short term production level and to identify potential r
 nown to overstate the range of uncertainty. On the other hand independent probabilistic addition tends to produce unrealistically narrow ran
site. The issue consists in improving the design of separator as operators are now faced with more difficult operating conditions related to de
e petro-physical external filter cake properties. In this paper results from core flood experiments (CFE) aimed to quantify the internal damage
ation seeks a balance between technical feasibility and economic cost it is believed that regulators may wish to move to requirements where
data using a single objective function which is minimized using a new optimization algorithm based on response surface fitting. Inversion pa
emperatures between and along the horizontal well pair so that any development of the steam chamber can be predicted. This paper propos
nties are not taken into account and only a limited number of models are used for prediction. In order to solve this problem a probabilistic ap
 lities. �This study also made use of methods for improving the convergence of the optimization cycle which included using correlations a
it is usually strongly reworked after deposition by superimposed diagenetic processes as well as fracturing phases. This creates levels of het
 e stress state in and around a reservoir can change dramatically. This process might result in rock movements such as compaction induced
 ears to be the prefered method for field-scale simulation. This method is a loose coupled approach between a reservoir simulator (finite volu
be the preferred method for field-scale simulation. This method is a loose coupled approach between a reservoir simulator and a geomecha
 led dual-porosity simulation models must incorporate an adequate transfer function between fracture and matrix in order to predict the recov


 roduction rates to evaluate the profitability of fracturing. The availability of analytical software that is simple and fast has been the rationale f
  optimal geologic layer grouping scheme for simulation model construction. In this study we defined the optimum vertical layering scheme u

esent the way fractures have been fully characterised using an extensive integration of static (FMI) and dynamic (Well test Pressure Build Up
e equivalent (generally anisotropic) permeability of the fracture system and fracture densities and properties to be characterized on a directio
 dest number of grid cells. We propose a method in which the conduits are represented as long horizontal wells with no net production to the
on of all the mechanisms involved in the phenomenon of sand production sand transport in particular. The proposed numerical method con
 cific case against core and logs data. Aiming a 4D history matching workflow at the flow model scale we then need to validate the use of t
 channelized gas flow and dispersed “incoherent gas flow that are seen to take place in porous media as permeability increases. We then



may be extremely small. In the Adaptive Implicit Method (AIM) only a subset of the primary variables is treated implicitly. AIM offers a balance
can thus be formulated as: How to efficiently recover a large oil accumulation trapped with much larger amounts of water in the capillary tran
wo scales of fractures developing in this reservoir and forming a triple porosity system in regions where they are interconnected: Diffuse frac
 ither permeable (i.e. fracture) or impermeable (i.e. matrix) portions and assumes that the connectivity of fractures controls the flow. The an
e beyond reservoir well process and production management.�What may not be so clear is how to apply these smart technologies to m
anical skin less than 5). This is possible with thorough engineering and QA/QC and when accurate well data are available. Over the last five
 nvolutional modelling approaches have been combined in this study in order to maximize the reliability of the predictions while optimizing the
ies ensures to constantly reach the field optimal efficiency. This result is achieved by a close follow-up of the field behaviour from reservoir t
ction Logging Tools (PLTs) have been adapted to this more complex situation through optimized acquisition methodologies and propulsion
cycling of the produced water into steam will be mandatory. The SAGD water treatment scheme is complex because it depends on the wate

  leading to total depths sometimes in excess of 8600m. In addition to the challenges pertaining to the drilling itself the completion also carrie
 grity of wells.� This was addressed through implementation of limited - or even not - proven technologies. Introduction TOTAL AUSTRAL
gas drainage from the best permeability zones causes a differential depletion in reservoir pore pressure affecting by consequence the mecha
30 to 80 m in length and the wells were traditionally matrix-acid stimulated following perforation. The wells produced initially unassisted then l
pid reaction of the acid in downhole conditions often creates a localized loss zone through which most of the treating fluid is lost so that trea
applying drawdown to the formation? Will the remaining filtercake impair well productivity? The paper presents the case of a gas producing h
 frequently completed with multiple tubing strings (up to four in some cases) sensor lines control lines or other hardware that can be damag
ents a significant capital cost. To reduce costs the Operator has completed 19 wells with Single Trip Multi-zone (STMZ) technology. Two diff
 ive processes that were used to address these situations.�Through careful planning the processes selected to facilitate the completions
NAOBM) weighted with sized calcium carbonate. After installing the Stand-Alone-Screens (SAS) across the production intervals and allowing
 creens in open hole and cased hole frac-packs. A review of the design for both producers and injectors along with the criteria related to the
under CT-scan on cohesionless sand samples allow to monitor in real time the initiation of the sand production and to follow the developme
a and field data) were integrated to generate a Mechanical Earth Model (MEM). This model provided the descriptions of the rock strengths an
opments ever undertaken. The fields began production in Q1 2001.�Preliminary scaling studies identified a risk for calcium carbonate sc

y management. In response the reliability of these tools and their interpretations for determining the existence of poor behind casing cement
 h quality reservoirs that yield highly productive wells with large reserves per well.� High costs prohibit extensive appraisal activity and drive
rtainty on oil rates. To solve such metering challenges with a large majority of their wells operating above 95% gas fraction under metering c
 he approach is complex for non-mathematician and an alternative method for improving its interpretation and reducing the difficulty of its pra
 (including numerical models). The purpose of this work is to provide a direct solution mechanism for the case of time-dependent real gas flo
 erage values of permeability skin and pressure. An innovative periodic well testing technique named WTPL (Well Testing by Production Lo
e recent years people start to use regression analysis to match the responses at the source interval and the observation point. With regressi
ution techniques require accu-rate measurements of flowrate and pressure — at downhole (or sandface) conditions.� While accurate pre
 d gas IFTs have recently been thoroughly characterized. However little is known on the effect of acid gases (CO2 H2S and their mixtures) o
ere limited to Calcite and Dolomite precipitation and dissolution. Indeed to mineralize CO2 non carbonate minerals that are present in the fo
 oduction parameters observed during production tests are assessed for gas-lifted wells in Total Congo and Gabon affiliates. These tests are
 running continuously and simultaneously in a daily operation by implementing the data or information management system practices within t
hat help take strategic decisions; these decisions are based on a common single and widely shared view of the information that provides a b

monstrated that high molecular weight hydrolyzed polyacrylamides could be used under a wide range of salinities covering sea water and a m
ecular weight hydrolyzed polyacrylamides could be used under a wide range of salinities covering sea water and a mixture of sea water and
respective maturity level and/or maturation time frame technology use restrictions and process efficiency on the basis of incremental oil. A
eeper reservoirs more difficult. Chemical water shut-off is the preferred solution to this problem. Peciko is a giant multilayer gas field located

 otential efficiency of these additives. This paper reports on an original experimental methodology based on the combined use of a classical r

years gave the opportunity to extract series of measurements representative of a wide range of flow rates watercuts and gas-lift rates inclu

from distributary channel and mouth bar to point bar and crevasse splay. Drilling of vertical observation wells and a testing campaign started
y knowledge on the time required to establish a segregated profile and it needs correlation for the thermodiffusion coefficients which is not re
  field production continued to decline from 200 000 BOPD in the late seventies to 12 500 BOPD in 2003. An integrated study on the largest
heme while still making it technically and economically viable. AKPO reservoirs consist in a 620-million-recoverable-barrels accumulation of a

ogy for resource assessment is developed from a geostatistical study on the Surmont lease. The uncertainty in more than 30 correlated varia
alize sandy reservoirs and optimize the exploitation of bituminous sandstones. The sedimentological study of the McMurray reservoir based

at static flow conditions to accurate geometrical information on fluid- fluid and solid – fluid interaction. Considering new decisive developm
directly but are generally obtained by history-matching laboratory production data with reservoir simulators often resulting in very low gas rel
past few years a number of efforts have been made in many institutions in order to understand and model the solution gas drive mechanism
 maximum operating temperature. Progressing Cavity Pumps (PCP) with elastomeric stator is economic to run and have done well in heav


 compared to initial design the successful development of Glenelg (2006) and West Franklin (2007) satellites using extended reach drilling te
y scaling from its surface-controlled subsurface safety valve (SCSSV) to the Christmas Tree caused the well to be shut-in from end 2004 unt
e from the well-head shut-in pressure. This estimation is valid as long as there is only one phase present inside the well-bore. As soon as the
 re also investigated for long-term prevention of water blocks. Contact angle and air-brine imbibition tests are conducted to determine wetta
used in Special Core Analysis Laboratory (SCAL). The core permeability is in the microDarcy range. Experimental data of absolute permeab
of this reservoir. In early 2007 a third well was drilled and completed in this structure penetrating the Cenomanian at a 60 degree inclination
 ms of TIH anisotropy. In order to interpret the resulting anomaly maps in terms of fracture orientation and density it is necessary to tie the m
 ility damage and gas return permeabilities. Measurements are performed in representative conditions of a fracturing operation in a tight gas

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
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


es on the characterization of different types of fractures and faults identified on high-resolution image logs recorded in this field. The objective
  concept of developing and possibly modifying some existing correlations to suit deep offshore needs as well as develop an Excel Spreadshe
 tensive evaluation program was undertaken using new generation sonic logs WFT-multi-probe interval pressure transient testing (IPTT) an
  However these logs are not able to capture variations in the hydrocarbon column to allow the operator to ensure that all representative fluids
 mation that can be related to petrophysical properties. This paper presents a fully automated method based on a stochastic approach for tex
 ed wells an exponential regression equation is established between core porosity and core permeability k; (2) in uncored wells log porosity
e oil column three saturation-height functions per rock type (RT) were developed one each for the low- medium- and high-porosity range. T

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
 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
 grating well information and 3D multi-attributes between seismically mapped sequences. This method is more efficient than conventional es
on of hydrates and to preserve temperature. Pressure support with both gas injection and raw sea water injection. This is feasible by insta
ough the aquifer and highlighted the presence of multi disconnected hydrocarbon bearing flow units within R4 reservoir of the Amenam-East
h the heaviest ever installed lead towhead. � Towhead design with multiple diver/ROV retrievable components (including complete piping
TAL�E&P�UK�Ltd (TEP�UK) are moving towards sanction of a major project that could lead to first production of gas from this ch
 oblems faced and then use the data acquired to study and then implement a more long-term/ permanent solution. The purpose of this pape
 rom a new wellhead platform (WHP) which would be constructed over West Franklin Strategy-A involved high step-outs of more than 4 000
ch year) which required the acquisition and processing of a new 3D seismic program and the construction of specific geological and reservo
of gas which can be stored and cycled each year) which required the acquisition and processing of a new 3D seismic program and the cons

 ction level and to identify potential remaining resources for additional developments Appropriate monitoring and global static/dynamic revi
 to produce unrealistically narrow ranges. The correct answer would be obtained by using correlated addition but this requires the estimation
 ult operating conditions related to deep offshore or difficult crudes. The GOwSP is an industrial closed loop test facility designed for R&D pro
aimed to quantify the internal damage are presented. In recent published works CFE were performed to examine along rock samples the d
 wish to move to requirements where dispersed oil concentration is not the only parameter to be considered. Furthermore recently develope
 esponse surface fitting. Inversion parameters can be selected throughout the entire modeling workflow to update the facies spatial distribut
 can be predicted. This paper proposes a new analytical model to predict the temperature fronts and heating efficiency between and along th
  solve this problem a probabilistic approach is presented using uncertainty quantification throughout the history matching process. This pap
e which included using correlations adopting a Bayesian approach and exploring the search space. The results obtained over the optimizatio
 ng phases. This creates levels of heterogeneity orders of magnitude higher than in clastic environments. As a result small scale heterogene
ements such as compaction induced fracturing and enhancement of natural fractures and/or fault activation which continuously modify the
 ween a reservoir simulator (finite volumes) and a geomechanical simulator (finite elements). At user-defined steps the fluid pressures calcu
 reservoir simulator and a geomechanical simulator. At user-defined steps the fluid pressures are transmitted to the geomechanical tool wh
 d matrix in order to predict the recovery mechanisms for an optimal reservoir management. This is still true for dual-porosity / dual-permeab


ple and fast has been the rationale for using analytical methods in the past. However computer technology has enabled us to run numerica
 optimum vertical layering scheme utilizing two different methodologies: analytical approach proposed by King et al1 and streamline simulatio

dynamic (Well test Pressure Build Up Mud losses) data. The advanced use of well test signatures in understanding the main flow mechanis
 rties to be characterized on a directional fracture-set basis. Conversely too complex reservoir models intended to be more realistic require
tal wells with no net production to the surface but in which cross-flow can occur. We present tests that demonstrate the efficiency of the met
The proposed numerical method considers that the geomechanical problem (rock failure) interplays with the transport of sand. Equilibrium eq
we then need to validate the use of the logs-scale calibrated “pem at a larger scale vertically and laterally. In this paper we proposed a
a as permeability increases. We then apply the pore-scale network model to study the dynamics of gas flow during reservoir depressurization



 eated implicitly. AIM offers a balance between FIM and IMPES by employing implicit treatment only where necessary. The challenge with AI
amounts of water in the capillary transition zone of a highly heterogeneous reservoir of uncertain boundaries overlying an active aquifer?" To
 hey are interconnected: Diffuse fractures which strike N20 to N40. This scale develops mostly in the denser reservoir units. Its spacing is c
of fractures controls the flow. The analysis of the connectivity based on finite-size scaling assumes that fractures all have the same sizes. Ho
apply these smart technologies to mature fields with a legacy infrastructure and long production history.� Participants felt that maturity in i
 data are available. Over the last five years Frac-Pack operating envelop has been pushed to 70 - 75� deviated wells and to lengths rang
of the predictions while optimizing the cost effectiveness of the study. Because the assessment of repeatability noise indicated a realistically
of the field behaviour from reservoir to point of sale. This paper: presents examples of early successful achievements fit for the purpose of
 ition methodologies and propulsion equipment using either coiled tubing or tractors. However these tools face their limits when it comes to
 plex because it depends on the water characteristics the steam generator type selected (OTSG or conventional boiler) and the decision to c

illing itself the completion also carried its own ones as the formation would require effective acid-stimulation (not only an acid wash) to reach
gies. Introduction TOTAL AUSTRAL operates the Carina and Aries fields located in offshore Tierra del Fuego in the most southern region
 affecting by consequence the mechanical properties of the rock in its whole thickness. This petrophysical and mechanical behavior of the re
 s produced initially unassisted then later on a work-over campaign was launched in order to equip the well with electrical submersible pump
 of the treating fluid is lost so that treatment of the entire section is inefficient. Traditional completion practice on Al Khalij field (Qatar) involv
 esents the case of a gas producing horizontal well in Indonesia completed with a perforated liner. The target reservoir is a clean sandstone r
or other hardware that can be damaged during perforation. The traditional approach of hiring a workover rig to remove the completion prior to
 lti-zone (STMZ) technology. Two different STMZ techniques have been applied because of differing well characteristics and objectives. To d
selected to facilitate the completions were successful in achieving the project goals of the operator.�These goals included not only the pr
the production intervals and allowing the wells to cleanup the Productivity Index (PI) measured on each well was very disappointing. A diagn
   along with the criteria related to the sand characteristics and off-shore implementation of the completions will be described. Production str
 duction and to follow the development of the sand producing zone. In parallel a numerical approach is proposed to simulate the dominant
  descriptions of the rock strengths and in-situ stresses in the reservoir formation. Somewhat surprisingly the model backed up by the core la
ified a risk for calcium carbonate scaling with an increased scaling risk as the wells mature.� In May 2002 the first obstruction occurred a

stence of poor behind casing cement quality and possibly hydraulically communicating layers was critically and systematically examined by a
 extensive appraisal activity and drive development decisions based on very few wells.� Whilst these limited penetrations are often logged
 e 95% gas fraction under metering conditions and water cuts often higher than 90 % TOTAL ABK has evaluated different well testing & mon
 n and reducing the difficulty of its practical application haven’t been discovered most especially where there is inconsistency in data sam
e case of time-dependent real gas flow which uses an approach that combines the so-called average pressure approximation (a convolution
WTPL (Well Testing by Production Logging) has been developed in which a cyclic wave function is imposed in the wellbore by modulating the
  the observation point. With regression analysis we face the problem of non-unique solutions. Sometimes an estimated permeability is outs
e) conditions.� While accurate pressure measurements are commonplace the measurement of sandface flowrates is rare essentially non
ases (CO2 H2S and their mixtures) on the water-wettability of caprocks. We present an experimental setup and procedure for measuring co
 te minerals that are present in the formation have to: dissolve in order to buffer the pH decrease resulting from the CO2 injection; provide
and Gabon affiliates. These tests are systematically modeled with nodal well flow models. The impact of well instabilities or metering and res
 anagement system practices within the company. For Total E&P Indonesie the beginning of “Data/Information Management project (de
w of the information that provides a better understanding of ongoing events on each asset. This paper presents TOTAL field examples of D

 salinities covering sea water and a mixture of sea water and produced water. Additional recoveries in the range of 3 to 7 % can be expecte
 ater and a mixture of sea water and produced water. Additional recoveries in the range of 5% can be achieved in this particular context of la
ncy on the basis of incremental oil. Apart from WAG at Ekofisk and FAWAG at Snorre central fault block (CFB) all technologies have been a
  is a giant multilayer gas field located in the Mahakam delta of East Kalimantan with water depths of around 30 – 40 meters. There are mo

 on the combined use of a classical rheometer and a laboratory loop offering a large range of experimental conditions in terms of temperatur

es watercuts and gas-lift rates including flow-stability tests performed both on upward- and downward-sloping flowlines. These data were co

 wells and a testing campaign started at the end of 1999. In well tests anomalies in water salinity values were observed: an aquifer salinity o
odiffusion coefficients which is not readily available. One way to provide further information both on the dynamic of the segregation and on th
 . An integrated study on the largest EOR reservoir was performed to assess the projects’ performance including 3D geo-modeling res
ecoverable-barrels accumulation of a critical fluid made of very light oils up to 53�API and classified as condensate with well head shut-in

ainty in more than 30 correlated variables is calculated on a dense 2D grid using all available information including wells seismic and geolog
dy of the McMurray reservoir based on outcrops and subsurface data (cores well logs seismic profiles) has been undertaken along a 150

 Considering new decisive developments of the visualization cell we claim to have developed a new petrophysical tool which might permit to
ors often resulting in very low gas relative permeabilities that are difficult to explain from a physical viewpoint. Although pore-scale network m
odel the solution gas drive mechanism in primary heavy oil recovery. Conventional simulations are not reliable for prediction forecast purpose
mic to run and have done well in heavy oil cold production. These elastomers are however limited in temperature (<150ËšC). Through resear


ellites using extended reach drilling techniques and the recent drilling of an infill well in highly depleted reservoir are some of the key contribu
  well to be shut-in from end 2004 until an appropriate programme of remediation and prevention was implemented. Lead and zinc sulphides
 t inside the well-bore. As soon as the pressure drops below dew point in the tubing the vertical phase distribution changes and the bottom-h
 s are conducted to determine wettability alteration before and after treatment with the chemicals. The results show that chemical A5 gives t
perimental data of absolute permeability damage due to the fracturing fluid filtration and water sensitivity of this illitic sandstone as well as wa
 nomanian at a 60 degree inclination for this purpose. Proppant fracturing from a wellbore with a 60 degree inclination in a hard-rock formatio
 d density it is necessary to tie the measurements of anisotropy derived from the 3D surface seismic analysis to existing well data such as w
  a fracturing operation in a tight gas formation: cores with an absolute permeability of 10 microDarcy set at Swi experimental pressure of 20

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
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


 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
  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
 pressure transient testing (IPTT) and coring. A Sonic Scanner* survey was conducted in Tunu field to investigate possible nearby formation
 o ensure that all representative fluids are sampled. The most important information a continuous fluids type and property log is still not wide
ased on a stochastic approach for textural analysis and segmentation of core scanner images. The technique used to obtain image models is
 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
 medium- and high-porosity range. Though developed on a different scale from the simulation-model cells the saturation profiles generated

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
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
s more efficient than conventional estimation with the ability to build a non-linear relationship between seismic traces and target porosity logs
 ter injection. This is feasible by installing two water injection pumps subsea and using available power and compressor capacity at neighbo
 in R4 reservoir of the Amenam-East structure. It was assumed in the initial Field Development Plan that these shale layers would play a cru
mponents (including complete piping and control modules). � Adapting design and strategy to capture base parameter changes – additi
   to first production of gas from this challenging region by 2014. The proposed project facilities consist of a subsea template-manifold above e
  t solution. The purpose of this paper is to present details on what kind of solutions that have been implemented within the Alwyn field (produ
ed high step-outs of more than 4 000m which have not previously been attempted under the extreme WAD conditions. The drilling risk asso
  on of specific geological and reservoir models the safety and environmental issues such as caprock integrity and sour gas production the
  w 3D seismic program and the construction of specific geological and reservoir models. The safety and environmental issues related to ca

itoring and global static/dynamic review are the key factors to achieve these objectives. The short term objective is to maintain production b
ition but this requires the estimation of all correlations between field-resource estimates. This paper presents a simplified and pragmatic ap
oop test facility designed for R&D program and for testing multiphase equipment such as separators pumps or flow-meters. The loop includ
 examine along rock samples the deposition profile of only solid particles. The present work focuses on the oil droplets deposition profile. T
red. Furthermore recently developed water treatment technologies are currently being installed on the NCS. In relation with the various wat
  to update the facies spatial distribution the petrophysical properties and fluid flow parameters.� Advanced parameterization techniques a
ating efficiency between and along the horizontal well pair during the SAGD circulation phase. By using the exponential integral solution for r
  history matching process. This paper describes the process of geological and reservoir uncertainty quantification and ranking and focuses
  results obtained over the optimization cycle are used to identify sensitivity parameters correlations and parameter trends in a global search
. As a result small scale heterogeneity is often a key driver of fluid flow in carbonates. Proper reliable modeling of this critical heterogeneity
ation which continuously modify the reservoir properties such as the permeabilities and the fault transmissibilities. Modifications of such par
ined steps the fluid pressures calculated by the reservoir simulator are transmitted to the geomechanical tool which computes the actual str
mitted to the geomechanical tool which computes the actual stresses and reports the modifications of porosities and permeabilities back to t
 rue for dual-porosity / dual-permeability models where the matrix domain is also flowing but at lower velocity. During the past 40 years until


ology has enabled us to run numerical models with nearly the same speed. Although analytical methods have been continuously improving
 y King et al1 and streamline simulation approach by Ates et al2. New upscaled layering scheme was further validated by running composition

 derstanding the main flow mechanisms occurring within the reservoir is emphasized. Then we detail the way the dynamic model was build
ntended to be more realistic require computationally intensive and memory consuming algorithms. They also involve numerous parameters
demonstrate the efficiency of the method first on a conceptual model then on a full field model of a particular carbonate reservoir. The result
  the transport of sand. Equilibrium equations which control rock failure (solid mechanics) and sand transport (fluid mechanics) are solved sim
aterally. In this paper we proposed a methodology to define an upscaled “PEM (new set of relationships valid at reservoir-scale) by tunin
 low during reservoir depressurization in virgin and waterflooded conditions with the dual purpose of understanding the microscopic flow beha



ere necessary. The challenge with AIM is to find a robust and sharp stability criteria that can be used to choose an optimal time step size. The
 ries overlying an active aquifer?" To meet a challenge of such magnitude a phased development was undertaken and completed recently n
enser reservoir units. Its spacing is controlled by the mean curvature of the seismic Top-Reservoir surface and by the structural depth. On th
 ractures all have the same sizes. However natural fracture networks involve a relatively wide range of fracture lengths modeled by either sc
� Participants felt that maturity in itself made a challenge for deployment and enforces the need for effective Change Management. Deplo
½ deviated wells and to lengths ranging from 100 to 322 ft. The success of such operations depends obviously on some specific precautions
atability noise indicated a realistically irreducible threshold for high resolution 4D surface seismic and a possible limitation for WAG monitoring
 l achievements fit for the purpose of local assets dealing with the monitoring of reservoirs (4D tracers ..) wells pipeline flow assurance ro
ols face their limits when it comes to logging long horizontal drains produced by downhole electrical submersible pumps (ESP): the presence
ventional boiler) and the decision to completely eliminate waste water disposal (zero liquid reject) or use other waste handling and disposal m

ation (not only an acid wash) to reach the desired levels of productivity. Stimulation of long intervals and how to ensure full coverage of treat
l Fuego in the most southern region of Argentina (Figure 1).� These fields are prolific gas fields and are being developed with a reduced n
al and mechanical behavior of the reservoir added to the possibility of finding free water in the lowest part makes it difficult to reach the bes
well with electrical submersible pumps (ESP). Work-over operations were taken as an opportunity to re-stimulate lower-performing wells of t
 actice on Al Khalij field (Qatar) involved cemented casing perforations and subsequent stimulation of the limestone with retarded emulsifie
arget reservoir is a clean sandstone reservoir. The horizontal drain is 1155 feet (ft) long. The reservoir permeability is ranging between 0.1 an
  rig to remove the completion prior to perforating is in many cases not cost effective leading to foregone opportunities to extend production
l characteristics and objectives. To date 14 wells have been equipped with Dual Sting - STMZ completions and five wells have the new Sing
 These goals included not only the production of gas at relatively high rates from the shallow unconsolidated sand-stone reservoir at approx
 well was very disappointing. A diagnosis study concluded that the severe productivity impairment on these wells was related to either screen
ons will be described. Production strategy recommendations to minimize the sand risk during well start-up and ramp-up and also well steady
s proposed to simulate the dominant sanding mechanism. The theoretical model is based on the resolution of the equations of equilibrium a
   the model backed up by the core laboratory test data observations from core inspection and thin section analyses revealed the rocks to b
 2002 the first obstruction occurred and was identified as CaCO3 resulting in a programme of remediation and treatment as discussed previ

lly and systematically examined by a dedicated team of ZADCO and Schlumberger technical professionals. The criteria used to judge the us
 limited penetrations are often logged extensively using modern formation evaluation tools the acquired static data cannot confirm that the w
evaluated different well testing & monitoring strategies based on multiphase metering use. A compact dual-energy gamma-ray Venturi multi
 re there is inconsistency in data sampling. The statistical approach (VEMST) utilized simple statistical tools such as StatDiff StatDev and S
essure approximation (a convolution for the right-hand-side non�linearity) and the Laplace transformation.� For reference Mireles and
sed in the wellbore by modulating the flowrate. The analysis of the acquired rate function and the resulting pressure wave then provides form
 es an estimated permeability is outside a reasonable range when analyzing noisy data from real tests. In a wireline vertical interference tes
face flowrates is rare essentially non-existent in practice. As such the "deconvolution" of wellbore storage distorted pressure test data is pr
etup and procedure for measuring contact angles on mineral substrates in the conditions of geological storage. Measurements have been ca
ing from the CO2 injection; provide cations such as Ca2+ Mg2+ Fe2+ to the formation water; not release bicarbonate (HCO3–) to the f
 well instabilities or metering and reservoir uncertainties on modeled outputs such as gross production rates is assessed. This enables to be
Information Management project (dedicated for Geoscience and Reservoir division) had been carried out in the year 2000 and was successf
presents TOTAL field examples of Data Validation and Reconciliation (DVR) applied to flow measurement (metering) systems; and the resul

he range of 3 to 7 % can be expected in this particular context of large well-spacing development of a medium viscosity field. Powder polym
chieved in this particular context of large well-spacing development of a medium viscosity field. Powder polymer supply is achievable for dee
k (CFB) all technologies have been applied successfully (i.e. positive in economic terms) to the associated fields. HC miscible gas injection
ound 30 – 40 meters. There are more than 100 reservoirs per well with average thicknesses of less than 1 m. Most of these reservoirs we

ntal conditions in terms of temperature pressure flow rates and cooling rates. Different commercial oil soluble DRAs have been tested on va

sloping flowlines. These data were compared to the results obtained from dynamic simulations performed with the simulation code OLGA or

 were observed: an aquifer salinity of 2300 ppm while some wells produced water at 15000 ppm. At that time high values were considered
dynamic of the segregation and on the thermodiffusion process is to use Molecular Dynamics (MD) simulations. In this paper Both EoS and
 nce including 3D geo-modeling reservoir simulation and chemical tracer injection. The study permitted to track the main effects of the gas i
as condensate with well head shut-in pressures up to 400 bars fluid temperature up to 116�C at wellhead and very high gas liquid ratio (

n including wells seismic and geologic trends. The correlation structure between the variables is modeled under a multivariate Gaussian mo
) has been undertaken along a 150 km north (distal) - south (proximal) transect. Facies analysis permits to constrain depositional environm

ophysical tool which might permit to access experimentally to the visualization in quasi-static flow of the capillary phenomena and multiphase
point. Although pore-scale network models have been successfully used in the past to match raw production data the steady-state relative p
 liable for prediction forecast purposes. The reason is often that conventional modeling requires relative permeabilities tables that are not uni
perature (<150ËšC). Through research work conducted by PCM and TOTAL Metal PCP technology has been developed to meet the high te


 servoir are some of the key contributors to the success of Elgin/Franklin.� The high level of technical innovation from project conception
plemented. Lead and zinc sulphides had not been predicted during the initial scaling studies. While several publications mention these on H
istribution changes and the bottom-hole pressure can not be accurately estimated using one single average density. Fluid segregation mech
results show that chemical A5 gives the best wettability alteration at high temperature with minimum formation damage. The improvement in
  of this illitic sandstone as well as water saturation profiles measured by X-Ray in two phase flow experiments are interpreted. The methodol
 ree inclination in a hard-rock formation has always been difficult. Also adding another level of uncertainty was the fact that the Cenomanian h
alysis to existing well data such as well bore electric imaging and dipolar sonic logging. The multi-azimuth VSP technique is used to link thes
t at Swi experimental pressure of 200 bars for the fracturing fluid invasion. Water and gas saturations during the invasion of the fracturing flu

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
 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


ain the present-day reservoir behavior. A uniform classification scheme of fracture types was devised and specific properties namely density
 sure for deep offshore fields both in the Niger Delta region and the Gulf of Mexico. Furthermore the predicted fracture gradient (LOT) values
 nvestigate possible nearby formation alteration followed by MDT*-multi-probe IPTT. �The Sonic Scanner dipole radial profiling showed so
 type and property log is still not widely used in the industry. Modern NMR logging tools can deliver – in addition to conventional porosity 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
quation is sometimes used again to populate the cells of a dynamic reservoir model in 3D where input porosity values are obtained by interp
ells the saturation profiles generated are a good statistical match to the wireline-log-interpreted Sw and bulk volume of water (BVW) and flu

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
 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
 ismic traces and target porosity logs for interpolation. The combination of 20 seismic attributes including impedance derived by model based
 and compressor capacity at neighbouring fields. Extensive use of advanced wells. The oil producers are dual-lateral with approx. 1.5 km
t these shale layers would play a crucial role in fluid dynamics and hydrocarbons recovery. The initial dynamic model was used to optimise w
e base parameter changes – addition of second well to project during main contract Tender negotiations. Results/Conclusions Dissertatio
  a subsea template-manifold above each of the Laggan and Tormore reservoirs with production from up to eight subsea wells commingled a
emented within the Alwyn field (producing since 1987) in the Northern North Sea. These production enhancement measures relate to a numb
 AD conditions. The drilling risk associated with Strategy-A was greater than with Strategy-B but to compensate Strategy-A offered the pros
 tegrity and sour gas production the conversion of existing oil&gas well producers into gas injectors and producers the processing of cycled
d environmental issues related to caprock integrity and sour-gas production. The conversion of existing oil and gas wells into gas injection a

 objective is to maintain production by optimizing the injection capacity. Difficulties to model reservoir performance have resulted in implemen
 esents a simplified and pragmatic approach partial probabilistic addition. A hierarchy of “resource containers is defined from individual re
umps or flow-meters. The loop includes a large three-phase storage tank (10m3). Gas and liquids are flowing separately towards a mixing po
n the oil droplets deposition profile. The mechanisms and laws governing the internal damage with oil are different from those concerning sol
 NCS. In relation with the various water management actors (operators manufacturers researchers authorities) Total E&P Norge’s R&D
 anced parameterization techniques are used to constrain the fine scale geostatistical model. The gradual deformation method allows smooth
 the exponential integral solution for radial heating in a long cylinder and superposition in space for multi-heating sources the proposed mode
antification and ranking and focuses on specific examples. The result of implementing such a workflow leads to reservoir models which hono
d parameter trends in a global search space. In addition the original manual history match was further improved by adopting a pressure matc
modeling of this critical heterogeneity remains a pitfall often preventing efficient reservoir simulation and development.� This paper recaps
 issibilities. Modifications of such parameters strongly affect the flow pattern in the reservoir and ultimately the recovery factor. To capture th
 al tool which computes the actual stresses and reports the modifications of the petrophysical properties (porosities and permeabilities) back
 orosities and permeabilities back to the reservoir simulator. This paper presents a new iterative scheme that allows any reservoir simulator t
 locity. During the past 40 years until recently several formulations have been proposed. In order to review compare and validate some of th


  have been continuously improving there are a number of parameters and effects which are not fully taken into consideration by these met
 ther validated by running compositional simulations in different sectors of the reservoir. We used the analytical method of King et al1 both in

 e way the dynamic model was build using a novel discrete fracture network (DFN) approach developed internally. The method populates the
y also involve numerous parameters a large part of which cannot be estimated from available data. In-between there is a need for reasona
cular carbonate reservoir. The results obtained with the conceptual model confirm that a substantial (3-fold) reduction in CPU time could be
sport (fluid mechanics) are solved simultaneously by an iterative coupled scheme at the wellbore scale. Sand production experiments in the
 hips valid at reservoir-scale) by tuning a fine-scale existing “pem adjusting the most sensitive and relevant parameters by an optimisat
 erstanding the microscopic flow behavior and producing predicted estimates for the variation of multi-phase flow properties: this is undertake



choose an optimal time step size. The objective here is to derive and verify the stability criteria for a given time step selection in simulations b
undertaken and completed recently nine years after kick-off. Even so the expected recovery factor remained low and the reservoir model un
ce and by the structural depth. On the crest it forms a connected network of a few tens of mD of equivalent permeability i.e. about 10 times t
 racture lengths modeled by either scale-limited laws (e.g. log normal) or power laws. In this paper we extend the applicability of the percola
 ffective Change Management. Deployment and Change Management are seen as the major challenges facing the creation of Smart Fields
 viously on some specific precautions: Enough information about reservoir conditions geology and rock properties must be available to allow
 ossible limitation for WAG monitoring a 4D well seismic exercise was simulated which overcame those limitations. Introduction The Bu Has
..) wells pipeline flow assurance rotating equipments emphasizes recent applications of the Total corporate integration strategy dedicated
mersible pumps (ESP): the presence of a by-pass tubing at pump level makes it extremely challenging to perform a “classical PLT in prod
 other waste handling and disposal methods. SAGD water treatment also faces some additional specific challenges compared with oil fields

  how to ensure full coverage of treatments is a recurrent topic of debate several approaches have been discussed in the literature. In the pa
are being developed with a reduced number of wells with departures of up to 4 Km @ 1500 m TVD/RKB. The drilling scenario for Carina/Ari
art makes it difficult to reach the best results by means of a unique fracture. Within the optimization process that is followed in the developm
 stimulate lower-performing wells of the field. Several options were considered for this purpose from mechanically-diverted acid squeeze to p
 he limestone with retarded emulsified hydrochloric acid and ball sealers. This paper describes a new and different approach which involves
ermeability is ranging between 0.1 and 5 millidarcies (mD) An engineered oil-based mud was used as drill-in fluid to prevent any damage to
ne opportunities to extend production by perforating new intervals or reperforating existing producing zones. With casingless completions ev
ons and five wells have the new Single String-STMZ technology. These 19 wells embody 77 frac packs / gravel packs. The average comple
 ated sand-stone reservoir at approximately 1000 m TVD but also minimization of impact to the environment. To minimize cost and still acc
ese wells was related to either screen plugging by mud particles while running the screens to bottom in the NAOBM and/or the plugging induc
 up and ramp-up and also well steady-state production will be given. This paper will provide an overview of the behavior of both sand control
 tion of the equations of equilibrium at the interface between the intact zone and the slurry made of eroded sand and oil. An algorithm in 2-D
 ion analyses revealed the rocks to be extremely hard and strong and therefore highly unlikely to sand. These findings contradicted with initi
 on and treatment as discussed previously in SPE 94865.�In late 2004 however zinc and lead sulphide scale deposits were also identified

 als. The criteria used to judge the usefulness of these logs was the present or not of communication behind casing as determined by the phy
 static data cannot confirm that the wells will drain sufficient reserves. Evaluation of reservoir connectivity over large distances from the well r
 ual-energy gamma-ray Venturi multiphase flow meter (MPFM) was selected and placed under field trial to assess whether this technology co
 ools such as StatDiff StatDev and StatExp derived from time series analysis to identify possible unseen features diagnose key flow regime
ation.� For reference Mireles and Blasingame used a similar scheme to solve the real gas flow problem conditioned by the constant rate in
ng pressure wave then provides formation characteristics such as permeability and skin in the vicinity of the well. This technique eliminates t
 In a wireline vertical interference test we perform a drawdown test followed by a buildup test. Because of the delay of response the pressur
age distorted pressure test data is problematic — in theory this process is possible but in practice without accurate measurements of flow
 torage. Measurements have been carried out in a range of pressures extending up to 150 bar both with CO2 and H2S and with mineral sub
ease bicarbonate (HCO3–) to the formation water. Then the released cations react with HCO3– resulting from the dissolution of the inj
ates is assessed. This enables to better check the quality of production tests or the need to question or update the model of a well. This stud
ut in the year 2000 and was successfully completed in 2003. Today its Geoscience and Reservoir division has applied an integrated data and
 nt (metering) systems; and the resulting added value : in improving production allocation along with reservoir and surface material balance

 edium viscosity field. Powder polymer supply is achievable for deep offshore fields either with a specific bulk carrier or using standard intern
 polymer supply is achievable for deep offshore fields either with a specific bulk carrier or using standard international containers to transport
ated fields. HC miscible gas injection and WAG injection can be considered mature technologies in the North Sea. The most commonly used
han 1 m. Most of these reservoirs were perforated and produced commingled throughout the lifetime of a well. Efficient water shut-off is very

 oluble DRAs have been tested on various fluids including a paraffinic crude oil. The experimental results have shown that either the presenc

ed with the simulation code OLGA originally used for the design of the subsea production system. The comparison focused on the overall pre

 t time high values were considered measurement problems. In 2001 the first horizontal producers started to cut water with similar high valu
ulations. In this paper Both EoS and MD simulations were applied for the calculation of the fluid distribution in reservoirs. MD results provide
 to track the main effects of the gas injection and define reservoir management guidelines for the other lean gas injection reservoirs. In the s
head and very high gas liquid ratio (GLR). AKPO is not only a giant condensate field but also a gas field with 1 Tcf planned gas export. Wit

ed under a multivariate Gaussian model. The local distributions of uncertainty have been checked with cross validation and with more than 1
 s to constrain depositional environments within the McMurray Formation. We document in detail facies associations corresponding to contin

 capillary phenomena and multiphase flows analysis in 3D form or in dynamic flow in 2D form. The in-situ measurements are realized in rese
ction data the steady-state relative permeabilities calculated from such models commonly predict much slower gas saturation build-up than t
 permeabilities tables that are not universal but depend at least on the depletion rate and possibly on other parameters. In this paper we kee
s been developed to meet the high temperature requirement of SAGD and other thermal recovery processes. Three models of the Metal PCP


 l innovation from project conception right through to recent drilling achievements has provided valuable experience not only for the Total gro
eral publications mention these on HP/HT fields little information is available on downhole inhibitor squeeze. Scale removal lab studies inclu
 age density. Fluid segregation mechanisms involve complex thermo-convective phenomenon in association to gravity which are strongly re
mation damage. The improvement in water block removal after treatment with A5 is tested by injecting gas into brine-saturated cores at diff
ments are interpreted. The methodology of interpretation provides the petrophysical data specific to the rock-fluid system: the absolute perme
 y was the fact that the Cenomanian has never been fracture stimulated. This paper will detail the planning process from both the operator a
uth VSP technique is used to link these measurements with the surface seismic data. Initial logging measurements carried out over the field
 uring the invasion of the fracturing fluid as well as during the gas back flow are monitored thanks to a XRay equipment. Adding alcohol in the

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
 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


d specific properties namely density orientation apertures and porosity of each fracture type wherever applicable were generated. These
dicted fracture gradient (LOT) values yielded by the various correlations were compared with actual LOT from a particular deep offshore field
nner dipole radial profiling showed some radial property change at several zones.� The altered zone radial extent was quantified. �The
n addition to conventional porosity and permeability information – a continuous fluid log of oil gas water and OBM filtrate (OBMF) at multi
dels. The accuracy of the model is a key point for confidently linking images and physical or geological properties. This approach is demonstr
orosity values are obtained by interpolation. The core-scale regression equation generally underestimates permeability by at least a factor o
 bulk volume of water (BVW) and fluid volumetrics agree with the geological model. RT-guided saturation-height functions proved a good me

 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
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
g impedance derived by model based inversion was selected on the basis of ranking of error factors. The network was trained with effective
are dual-lateral with approx. 1.5 km horizontal reservoir sections equipped with down-hole ICVs (Inflow Control Valves) and gas lift. Both m
namic model was used to optimise well location and perforation strategy. With 35 development wells drilled and almost five years of product
ns. Results/Conclusions Dissertation on the challenges faced and overcome to deliver the Jura project: � Multiple contractors / vendors
  to eight subsea wells commingled and exported multiphase to the Shetland Islands via two 18" 140km rigid steel flowlines. A new gas proce
ancement measures relate to a number of different disciplines ranging from topsides modifications to well interventions to sub-surface. As th
 pensate Strategy-A offered the prospect of lower capex and earlier production. This development decision involved complex interactions be
  producers the processing of cycled gas (including sour gas treatment) the cost of the project compared to more conventional UGSs. Th
  oil and gas wells into gas injection and production wells. The processing of cycled gas (including sour-gas treatment). The cost of the proje

rformance have resulted in implementation of an intensive monitoring program. This is to limit water production and to maintain/increase wat
ontainers is defined from individual reservoirs to total project level and resources are aggregated from bottom upward using either arithmetic
owing separately towards a mixing point by the way of a compressor and centrifugal pumps. The mixture is sent to the multiphase equipment
 e different from those concerning solid particles. Like solid particles oil tends to deposit preferentially at the core entrance but quickly a movi
 horities) Total E&P Norge’s R&D department is strongly involved in the issues related to installation and operation of these technologies
al deformation method allows smooth transformations of the facies model realization while conserving the overall statistical characteristics. In
  heating sources the proposed model can be used to predict these temperature profiles provided that the steam temperatures or pressures
 leads to reservoir models which honour the production history of the modelled field. To achieve a history match the workflow should consist
mproved by adopting a pressure match using an Evolutionary Strategy. Best matched cases were selected based on the global and partial ob
development.� This paper recaps the traditional upscaling methods used for heterogeneity modeling and highlights their limitations when
ely the recovery factor. To capture the link between flow and in-situ stresses it becomes essential to conduct coupled reservoir-geomechani
 (porosities and permeabilities) back to the reservoir simulator. In the classical iterative scheme at each stress equilibration step the reservo
e that allows any reservoir simulator to be coupled with any nonlinear finite-element-method (FEM) package for the stress analysis without an
ew compare and validate some of them this work first analyse the main recovery drivers in two-phase systems like drainage and imbibition


 ken into consideration by these methods and therefore result in unrealistic production forecasts. These factors include non-Darcy effects
nalytical method of King et al1 both in its original form and in a modified version. We refer to the original form as map-based approach and th

 internally. The method populates the static parameters at the full field scale using a geo-statistical process guided by a geological driver. Usi
between there is a need for reasonably complex models and methods to generate them in a consistent way with various fracturing and dyna
  old) reduction in CPU time could be achieved compared to a conventional approach using high permeability values to represent the conduit
 Sand production experiments in the laboratory on cohesionless sand samples carried out under CT-scan are used to calibrate the model an
 relevant parameters by an optimisation procedure. Some previous studies already addressed downscaling problems (from reservoir to ge
ase flow properties: this is undertaken at two PVT extremes (fluid samples separated by a depth interval of 200m from the top and bottom o



n time step selection in simulations based on a Thermal Adaptive Implicit Method (TAIM). Our linear stability analysis accounts for mass and
ained low and the reservoir model unmatched. This paper describes the extensive work program implemented to better understand early-tim
lent permeability i.e. about 10 times the matrix permeability. Large scale fractures forming a connected network on the crest of the structure
 extend the applicability of the percolation approach to a system with a distribution of size. For scale-limited distributions we use the hypothe
s facing the creation of Smart Fields. During the Forum it became apparent that companies do not have a common vision of what a truly S
 properties must be available to allow detailed fracture planning. In particular time must be spent to obtain a representative mini frac and a c
 limitations. Introduction The Bu Hasa Field onshore Abu Dhabi is a super giant carbonate oil field. The Lower Cretaceous Shu’aiba m
porate integration strategy dedicated to improve overall field performance. This activity is implemented in a single program named Field Mon
o perform a “classical PLT in production mode. This paper describes the various attempts to rise to this production allocation challenge in
 challenges compared with oil fields worldwide such as the high silica content in the produced water. An overview of the current water treatm

n discussed in the literature. In the particular case of N’Kossa this issue was not only rendered difficult by the length of the perforated int
B. The drilling scenario for Carina/Aries phase 1 included two horizontal wells to be drilled from the platform CARINA-1 (85 m water depth) an
 cess that is followed in the development of this field the implementation of a strategy of selective stimulation through the pumping of two hy
chanically-diverted acid squeeze to propped hydraulic-fracturing or acid-fracturing this later option being ultimately selected. However the rat
nd different approach which involves leaving drains in openhole condition and using a slow acting stimulation treatment for damage remova
 rill-in fluid to prevent any damage to the reservoir. A carbonate particle-based filtercake was used to create a thin and reliable filter cake. Wh
nes. With casingless completions even this option is not available. A downhole orienting and imaging platform has the unique capability to o
  gravel packs. The average completion time has been 11.3 rig days/well for DS-STMZ wells. SS-STMZ completions have averaged of 22.2
ment. To minimize cost and still accomplish the project goals the wells were drilled from a single platform. Introduction Project Challeng
 he NAOBM and/or the plugging induced by a mixture of formation sand mud and filter cake when draw-down was applied during cleanups.
  of the behavior of both sand control techniques after 5 years of production and injection. An in depth analysis of the different productivity/inje
ded sand and oil. An algorithm in 2-D was developed and implemented in a finite element code. Two calculations are alternatively performed
 These findings contradicted with initial impression and previous expectation on this sandstone that it should have been sand-prone formation
 e scale deposits were also identified.�These had not been predicted during the initial scaling studies.�This resulted in the well being s

hind casing as determined by the physical test. For the twenty-eight wells examined twenty-five of the cement log interpretations matched th
 y over large distances from the well requires relatively long and expensive well tests. In this paper we review a number of critical points asso
 to assess whether this technology could reduce the uncertainty on oil production by removing any impact of imperfect separation. 20 tests w
  features diagnose key flow regime for reservoir description and act as checkmate/alternative to the derivative approach to interpret comple
em conditioned by the constant rate inner boundary condition. In this work we provide a direct solution scheme to solve the constant pressur
  the well. This technique eliminates the disadvantage of shutting-in a well and maintains the production with a modulating periodic pattern. In
of the delay of response the pressure at the observation probe continues to drop for some time during the buildup period at the source interv
hout accurate measurements of flowrates this process can not be employed.� In this work we provide explicit (direct) deconvolution of we
h CO2 and H2S and with mineral substrates representative of c
 sulting from the dissolution of the injected CO2 and precipitate ne
 update the model of a well. This study highlights the pa
 n has applied an integrated data and information management practices starting from subsurface ac
servoir and surface material balance in reconciling surface and su

c bulk carrier or using standard international containers to transport big
d international containers to transport big bags (250 kg). Even in the case
North Sea. The most commonly used EOR technology in the North Sea has been WAG and
a well. Efficient water shut-off is very critical when water

s have shown that either the presence of waxy crystals or

 omparison focused on the overall pressure drop between manifolds and to

 ted to cut water with similar high values to those observed in some we
 ion in reservoirs. MD results provide insights on time evolu
 ean gas injection reservoirs. In the same time dynamic synthesis has be
 d with 1 Tcf planned gas export. With such particular reservoir condit

 ross validation and with more than 100 new wells drilled during the last two
 associations corresponding to continental (fluvial/palustral/p

u measurements are realized in reservoir conditions of extr
 slower gas saturation build-up than that found experimentally. Some pr
her parameters. In this paper we keep the conventional Darcy scale
sses. Three models of the Metal PCP are now available to cover a wide range of flow rat


 experience not only for the Total group and Elgin/Fra
eeze. Scale removal lab studies included dissolution of the recovered scales and c
 ation to gravity which are strongly related to the temperature gradient in t
gas into brine-saturated cores at different pressure gradient
 ock-fluid system: the absolute permeability the relative perme
 ng process from both the operator and the service
asurements carried out over the field show a very clear correlat
Ray equipment. Adding alcohol in the fracturing fluid has a str

sent the true spherical permeability. In contrast the spherical permeability can be
 s set vertically against the borehol
mentological and diagenetic processes and each with t
are occasions identified as individual reflectors on


er applicable were generated. These fracture pr
T from a particular deep offshore field in the Niger Delta and the res
 adial extent was quantified. �The MDT-IPTT tests quantified the virgin zon
 ter and OBM filtrate (OBMF) at multiple depths
 roperties. This approach is demonstrated through stochastic synthesizin
 es permeability by at least a factor of 2. The origin of th
on-height functions proved a good method for modeling water saturati

 l 1994 owing to the high levels of complexity and geophysical unce
  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
 e network was trained with effective porosity available at well loc
w Control Valves) and gas lift. Both main bore and laterals
 illed and almost five years of production (1st oil in July 2003) the
 t: � Multiple contractors / vendors directly managed by Total E&P UK at diverse
 rigid steel flowlines. A new gas processing facility sized for 500 MMscfd and operated by
ell interventions to sub-surface. As these disciplines originate from di
sion involved complex interactions between conflicting issues and the best way forward
red to more conventional UGSs. The main benefits expected from the project ar
gas treatment). The cost of the project compared to more conventional UGSs.

duction and to maintain/increase water injection capacity. For the
bottom upward using either arithmetic or probabilisti
  is sent to the multiphase equipment to be tested before coming back to the s
 the core entrance but quickly a moving front of oil drople
n and operation of these technologies. The work described in this study was perf
 e overall statistical characteristics. In addition a new history matching
he steam temperatures or pressures are known during the circulation peri
 y match the workflow should consist of the following steps:
ed based on the global and partial objective values of each match. Predi
  and highlights their limitations when applied to carb
 nduct coupled reservoir-geomechanical simulations. This p
 stress equilibration step the reservoir simulation needs to be rest
age for the stress analysis without any limitation on the functionality of either
 ystems like drainage and imbibition under capillary and gravity forces


se factors include non-Darcy effects along the fracture mult
 form as map-based approach and the modified form as average

ess guided by a geological driver. Using an innovative
 way with various fracturing and dynamic data in order to produce conditio
ability values to represent the conduits. The full field model was built
 n are used to calibrate the model and show its ability to reproduce the
caling problems (from reservoir to geological/seismic scale) but
 l of 200m from the top and bottom of the oil bearing column) and for two



bility analysis accounts for mass and heat convection hea
mented to better understand early-time reservoir behavior and find ways to
  network on the crest of the structure. They are associated
 ted distributions we use the hypothesis seen in the li
ve a common vision of what a truly Smart Field will look like and this contributes to th
ain a representative mini frac and a correct interpretation; Requirements
e Lower Cretaceous Shu’aiba member of the Thamama formation is
in a single program named Field Monitoring and focused on
his production allocation challenge in a complex carbonate field located o
n overview of the current water treatment process options for SAGD will

 ult by the length of the perforated intervals (up to 1200m) but also
orm CARINA-1 (85 m water depth) and two horizontal wells from the platform ARIES
 ation through the pumping of two hydraulic fractures directed
 ultimately selected. However the rather adverse conditions exi
ulation treatment for damage removal an
 ate a thin and reliable filter cake. While drilling this well
  atform has the unique capability to orient guns along
  completions have averaged of 22.2 rig days/well inclusive of NPT and the upper completi
 orm. Introduction Project Challenges.�The Carina field contains a cons
-down was applied during cleanups. Based on collaborative laboratory work between the
nalysis of the different productivity/injectivity characteristics suc
 lculations are alternatively performed: one on the intact zone (
ould have been sand-prone formation. Facing these appa
s.�This resulted in the well being shut in and the squeeze treatments de

ement log interpretations matched the communication test results. One well which c
eview a number of critical points associated with design and e
ct of imperfect separation. 20 tests were performed considering 15
rivative approach to interpret complex features. Result fr
cheme to solve the constant pressure inner boundary condition prob
with a modulating periodic pattern. In addition the WTPL can b
he buildup period at the source interval. The maximum press
e explicit (direct) deconvolution of wellbore storage distorted pressu

				
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