Spe Papers_well Deliverability

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;

BP Shell Chevron ConocoPhillips Marathon Total Schlumberger Imperial College, London Heriot Watt University, Edinburgh (Anywhere in Article) Total

Total No Papers 551 575 482 191 55 255 1130 95 235

Reservoir Engineering Related 175 279 238 68 37 129 563 53 175

3569

1717

Total number of papers published post 2005 =

10,000

35% of papers published categorised

Organisation

Paper Source No.

Chapter

Section

SHELL TOTAL SCHLUMBERGER SCHLUMBERGER CONOCO

SPE SPE IPTC SPE SPE

101038 107760 12368 126066 114912

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Acid Treatments Acid Treatments Acid Treatments Artificial Lift Artificial Lift

CHEVRON BP CONOCO SCHLUMBERGER SCHLUMBERGER Heriot Watt University Heriot Watt University CONOCO TOTAL

SPE SPE SPE SPE SPE SPE IPTC SPE SPE

128337 115950 117489 110103 106094 122231 12145 114011 102550

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Artificial Lift Artificial Lift Artificial Lift Artificial Lift Artificial Lift Clean-up Compex Wells Completion Optimisation Completion Optimisation

CHEVRON BP SCHLUMBERGER SCHLUMBERGER Heriot Watt University SCHLUMBERGER SCHLUMBERGER SHELL SHELL SCHLUMBERGER SCHLUMBERGER

SPE SPE SPE IPTC SPE SPE SPE SPE SPE SPE SPE

89753 106854 102544 12364 108173 112476 112862 99921 100495 101720 102583

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Completion Optimisation Completion Optimisation Completion Optimisation Completion Optimisation Completion Optimisation Completion Optimisation Completion Optimisation Completion Optimisation Completion Optimisation Completion Optimisation Completion Optimisation

CHEVRON SCHLUMBERGER SCHLUMBERGER Heriot Watt University SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SHELL SCHLUMBERGER SCHLUMBERGER BP SHELL MARATHON BP Heriot Watt University BP SCHLUMBERGER

SPE SPE SPE SPE IPTC SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE

100834 100834 110240 123682 11630 84219 120744 90959 126070 126061 98359 102831 99718 99878 99878 115546 102653

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Complex Wells Complex Wells Complex Wells Complex Wells Complex Wells Complex Wells Complex Wells Complex Wells Complex Wells Complex Wells Condensate Banking Controlled injection Downhole Control Valves Dual ESP Dual ESP Erosion ESP

Imperial College SCHLUMBERGER SHELL

SPE SPE SPE

96722 96722 105583

Well Deliverability Well Deliverability Well Deliverability

ESP ESP Foam flow

CHEVRON SCHLUMBERGER CONOCO SCHLUMBERGER Heriot Watt University Heriot Watt University SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SHELL SCHLUMBERGER SCHLUMBERGER

SPE IPTC SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE

101987 12668 106050 106050 86485 100417 107979 112438 117061 119825 108011 122307 103822

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Formation Damage/High Velocity Flow Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design

CHEVRON SCHLUMBERGER SCHLUMBERGER Heriot Watt University SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER BP SCHLUMBERGER TOTAL SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER BP

SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE

112531 112435 125336 123466 122514 108126 107604 102616 112171 107392 99419 118292 112442 114768 121204 121415 101821

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design

CHEVRON Heriot Watt University SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER

SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE

101821 101821 113562 101722 119300 115556 119635 107730 100572 105657 98338 100524 102677

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design Fracture Design

SCHLUMBERGER

SPE

119586

Well Deliverability

Fracture Design

CHEVRON BP Heriot Watt University SCHLUMBERGER Heriot Watt University SCHLUMBERGER SCHLUMBERGER SHELL Heriot Watt University

SPE SPE SPE IPTC SPE IPTC SPE SPE SPE

101019 102227 107338 11150 107432 11347 102326 102326 121916

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Fracture Design Fracture Design Fracture Design Fracture Design Fracture Diagnosis Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics

CHEVRON SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER BP SCHLUMBERGER BP SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER

SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE

102326 110068 107662 102788 102528 100556 106301 102167 109909 109969 121888 98188 100321 106225 102469 106317

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics

CHEVRON SCHLUMBERGER CHEVRON SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER Heriot Watt University SCHLUMBERGER SCHLUMBERGER SHELL

SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE

108142 110696 109247 106264 106043 102570 107634 102405 98746 98746

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics

CHEVRON SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER CONOCO Heriot Watt University TOTAL CONOCO CHEVRON

SPE SPE IPTC SPE SPE SPE SPE SPE SPE

102990 122018 12183 119351 107793 115726 102475 114804 103433

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Fracture Diagnostics Fracture Diagnostics Fracture Diagnostics Fracture Dignostics Fracture Performance Fracture Performance Fracturing Fracturing Gas Condensate Deliverability

SHELL SCHLUMBERGER SCHLUMBERGER SHELL

SPE SPE SPE SPE

112234 104202 106854 110754

Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Gas Coning Control Gas Lift Systems Gas Production Heavy Oil-in-Water Emulsion

CHEVRON TOTAL Heriot Watt University BP SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER TOTAL CONOCO SHELL BP Heriot Watt University SHELL

SPE SPE SPE IPTC SPE SPE SPE SPE SPE SPE SPE SPE SPE

102773 98164 104183 11508 113553 114961 112077 112077 97121 102678 100796 107138 102077

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

High Velocity Coefficient Horizontal Well Horizontal Well Horizontal Well Horizontal Well Horizontal Well Horizontal Well Horizontal Well Horizontal Well Horizontal Well Hydrate Control Inflow Performance Inflow Performance

CHEVRON CHEVRON

SPE SPE

84399 90541

Well Deliverability Well Deliverability

Inflow Performance Inflow Profiling

Imperial College SCHLUMBERGER BP Heriot Watt University SCHLUMBERGER Heriot Watt University SCHLUMBERGER Heriot Watt University

SPE SPE IPTC SPE SPE SPE SPE SPE

95843 120800 11784 108700 123008 100191 120799 99929

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Intelligent WAG Injector Intelligent Well Intelligent Well Intelligent Well Intelligent Well Intelligent Well Intelligent Well Intelligent Well

CHEVRON SCHLUMBERGER SCHLUMBERGER CONOCO SCHLUMBERGER SHELL SHELL SHELL MARATHON

SPE SPE SPE SPE SPE SPE SPE SPE SPE

103308 110960 113918 103617 103617 122133 107790 107795 120625

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Intelligent Well Intelligent Well Intelligent Well Lab Testing - Fracturing Lab Testing - Fracturing Lab Testing - Stimulation Lab Testing - Stimulation Lab Testing - Stimulation Liquid Loading

CHEVRON SHELL SHELL BP SHELL BP BP BP

IPTC SPE SPE SPE SPE IPTC SPE SPE

11332 104605 107980 107467 115567 11651 108380 110357

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Liquid Loading Liquid Loading Liquid Loading Liquid Loading Liquid Loading Liquid Loading Liquid Loading Liquid Loading

CHEVRON

SPE

103266

Well Deliverability

Liquid Loading

CHEVRON MARATHON CONOCO

SPE SPE SPE

116764 103151 107780

Well Deliverability Well Deliverability Well Deliverability

Liquid Loading Liquid Loading Modelling - Acid treatment

CHEVRON SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SHELL SCHLUMBERGER SHELL SCHLUMBERGER TOTAL SCHLUMBERGER

SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE

109588 104629 116370 120049 105022 106400 102241 112488 102656 104099 101082 120508 120508 101278

Well DeliverabilityModelling - Coupled Reservoir/Geomechanical Well Deliverability Modelling - Flow Assurance Well Deliverability Modelling - Well Productivity Well Deliverability Modellling - Sanding Prediction Well Deliverability Perforation Methods Well Deliverability Perforation Methods Well Deliverability Perforation Methods Well Deliverability Perforation Methods Well Deliverability Perforation Methods Well Deliverability Perforation Methods Well Deliverability Perforation Methods Well Deliverability Perforation Methods Well Deliverability Perforation Methods Well Deliverability Perforation Methods

CHEVRON MARATHON SHELL SCHLUMBERGER SCHLUMBERGER

SPE IPTC IPTC SPE SPE

108088 12334 12334 112432 113698

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Perforation Methods Perforation Methods Perforation Methods Perforation Methods Perforation Methods

CHEVRON SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER Heriot Watt University Heriot Watt University BP Heriot Watt University SCHLUMBERGER SCHLUMBERGER SHELL SHELL CONOCO SCHLUMBERGER SCHLUMBERGER CHEVRON

SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE

128334 111538 119639 121931 121964 107864 100512 98351 122266 110978 112491 101187 101181 105541 105541 117518 98563

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Perforation Methods Perforation Methods Perforation Methods Perforation Methods Perforation Methods Performance Decline Performance Decline Produced Water Injection Production Capacity Production Optimisation Sand Control Sand Control Sand Control Sand Control Sand Control Sand Control Sand Control

CHEVRON SHELL

SPE SPE

112394 116091

Well Deliverability Well Deliverability

Sand Control Sand Control

SHELL CONOCO SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER BP BP

SPE SPE SPE SPE SPE SPE SPE

111635 105542 105542 128606 112456 104532 107297

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Sand Control Sand Control Sand Control Sand Control Sand Control Sand control Sand Control

CHEVRON Heriot Watt University Heriot Watt University SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER TOTAL TOTAL SCHLUMBERGER SCHLUMBERGER

SPE SPE SPE SPE SPE SPE SPE SPE IPTC SPE IPTC SPE

110395 122054 122064 105758 107297 121093 121834 121912 12388 98562 12448 98151

Well deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Sand Control Sand Control Sand Control Sand Control Sand Control Sand Control Sand Control Sand Control Sand Control Sand Control Sand Control Sand Control

CHEVRON TOTAL SCHLUMBERGER SCHLUMBERGER BP SCHLUMBERGER

SPE SPE IPTC SPE SPE SPE

106707 107341 12581 123495 98252 112050

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Sand Control Sand Control Sand Control Sand Control Sand control Sand Control

CHEVRON SCHLUMBERGER

SPE IPTC

112084 12385

Well Deliverability Well Deliverability

Sand Control Sand Control

CHEVRON SCHLUMBERGER SCHLUMBERGER

SPE SPE SPE

107440 107440 102185

Well Deliverability Well Deliverability Well Deliverability

Sand Control Sand Control Sand Control

CHEVRON Heriot Watt University SHELL TOTAL TOTAL CONOCO CONOCO SHELL SCHLUMBERGER CONOCO Imperial College SCHLUMBERGER SCHLUMBERGER TOTAL Imperial College SCHLUMBERGER

SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE

103821 101994 116713 107767 100023 121498 102802 112099 112904 103244 100944 100944 104239 104239 92715 92715

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Sand Control Sand Control Sand Control Sand Control Sand Erosion Sand Management Sand Management Sand Management Sand Management Sand Management Sand Production Sand Production Sand Production Sand Production Sand Production Sand Production

BP Heriot Watt University

SPE SPE

89895 89895

Well Deliverability Well Deliverability

Sand production Sand production

Imperial College BP Imperial College SCHLUMBERGER BP BP

SPE SPE SPE SPE SPE SPE

89895 84500 84500 102242 115058 90273

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Sand production Sand production Sand production Sand Production Sand Production Sand Production

Imperial College SHELL SCHLUMBERGER SCHLUMBERGER TOTAL Imperial College Imperial College CONOCO SCHLUMBERGER CONOCO SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER BP BP

SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE

90273 102305 98315 101087 100627 100371 82249 77363 90383 107978 106272 107978 115525 115528 90062 121483

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Sand Production Sand Production Sand Production Sand Production Scale Inhibitors Scale Management Skin Factor Skin Factor Model State of the Nation Stimulation Stimulation Stimulation Stimulation Stimulation Stimulation Stimulation

CHEVRON

SPE

86504

Well Deliverability

Stimulation

CHEVRON

SPE

98221

Well Deliverability

Stimulation

CHEVRON Heriot Watt University SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SHELL SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER

SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE

122630 110895 98221 98357 105127 106321 106442 112419 116601 116775 106321 109911 104610 106444 115558

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Stimulation Stimulation Stimulation Stimulation Stimulation Stimulation Stimulation Stimulation Stimulation Stimulation Stimulation Stimulation Stimulation Stimulation Stimulation

CHEVRON SCHLUMBERGER SHELL

SPE SPE SPE

102669 104627 107749

Well Deliverability Well Deliverability Well Deliverability

Stimulation Stimulation Stimulation

Heriot Watt University SCHLUMBERGER

SPE SPE

106012 102681

Well Deliverability Well Deliverability

Stimulation Stimulation

CHEVRON SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER CONOCO

SPE SPE SPE SPE SPE

111431 107966 111431 98055 116711

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Stimulation Stimulation Stimulation Stimulation Optimisation Water and Condensate Blocks

CHEVRON SCHLUMBERGER TOTAL SCHLUMBERGER Heriot Watt University BP Heriot Watt University BP Heriot Watt University BP SCHLUMBERGER TOTAL

SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE SPE

98375 105367 105367 112176 113889 112143 112143 112282 107168 120708 101420 101420

Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability Well Deliverability

Water Blocking Water Blocking Water Blocking Water Control/Stimulation Water Entry Detection Water Injection Water Injection Water Injection Well Comparison Well Optimisation Zonal Isolation Zonal Isolation

Subject Case Study ERW Production Optimisation ESP's Formation Powered Jet Pump

Gas Lift Gas Well SAGD SAGD ESP Staircase Lifting Intelligent Wells Downhole control Valves Big Bore Design Big Bore Design

Gas Condensate High Rate Gas Wells Horizontal Wells Manati Gas Filed Marginal Wells Multilayered Reservoirs Near Wellbore Stress Openhole Openhole

Carbonate Reservoir Carbonate Reservoir Complex Reservoirs Downhole Control Valves Downhole Control Valves Downhole Control Valves Downhole Control Valves Downhole Control Valves Intervention Production Performance Removal Reservoir Damage Prevention West Brae Field Appications Appications Gas Well Perforation Methods

Performance Analysis Performance Analysis Prediction Productivity Impairment Acid Fracturing Candidate selection Candidate selection Chalk Reservoirs Damage prevention Fiber Assisted Fiber Assisted Fiber Assisted Fiber Assisted Fiber Assisted Flowback Aids Formation Modulus Contrast Frac Fluids Fracture Fluid Fracture Fluids Optimisation Fracture Geometry Fracture Geometry Fracture Propagation Height Control Horizontal well Horizontal Well Application Influence ofHeterogeneity Mature Fields Multifrac Horizontal Wells Multistage Multistage Horizontal Wells Multistage Horizontal Wells Multistage Horizontal Wells Non-Darcy/Multiphase

Non-Darcy/Multiphase Non-Darcy/Multiphase Optimisation Performance Criteria Proppant Transport Samara Area Reservoirs Simultaneous Fracturing Sliding Sleeve Application Sliding Sleeve Applocation Soft Formations Surfactant Fracturing Surfactant Fracturing Surfactant Fracturing

Surfactant Fracturing Water Control Water-Fracs Waxy-Oil Reservoir Clean-up Gas Condensate Acid Fracturing Clean-up Clean-up Clean-up Gas Condensate

Clean-up/Damage Mitigation Completion Optimisation Damage Analysis Deviation Surveys Diagnostics Fiber Assisted Fracture Conductivity Fracture Conductivity Fracture Geometry Fracture Geometry Fracture Geometry Gas Condensate Gas Condensate High Permeability Formations Long-Term Rate Effects Low-Conductivity Microseismic Monitoring Microseismic Monitoring Non-Darcy Effects Proppant Flowback Refracture Reseridual Saturation Skin Factor Sonic Anisotropy State of the Nation State of the Nation Water Injector Fracturing Water Injector Fracturing Fracture Geometry Chalk reservoirs Gas-Condensate Mobility Acid - Challenging Conditions Massive Annular Fracturing Distinguished Lecture

Modelling Theory High rate wells Gas shut-off Two Phase Flow Clean-up Impact of Trajectory Injectivity Novel Open hole Novel Open hole OBM Effect OBM Effect Openhole Under Performance GOM Gas Condensate Horizontal wells Profiling Temperature Data Statoil Veslefrikk Complex Wells Development Optimisation Downhole Control Valves Downhole Control Valves Downhole Control Valves - Placement ESP's Proactive and Reactive Control

Production Optimisation Production Optimisation Uncertainty Management Heterogeneity Heterogeneity Behaviour of CO2 and N2 Foams Modelling Modelling Critical Velocity Calculations Dual Lateral Mitigation Mitigation North Sea Experience Prediction

Horizontal Well Cavity Completion Productivity Improvement Heterogeneity Carboate Reservoir Case study Coiled Tubing Dynamic UB Limited Entry Negative Skin Factors Optimisation Orientation Orientation Productivity Improvement

Propellant assisted Propellant assisted Propellant assisted Skin Variation Quantified UnderBalanced

Scale Formation Scale Formation Fracture Propagation UBD - Vietnam SMART Completions Albacora Field Associated with Hydraulic fracturing Challenging Conditions Completion Optimisation Completion Optimisation Complex Wells Deepwater Deepwater Deepwater

Expandable Screen Failure Failure Failure Mitigation Failures Gravel Pack Gravel Pack Gravel Pack Gravel Pack Gravel Pack Gravel Pack Gravel Pack Gravel Pack Gravel Pack Gravel Pack Gravel Pack Gravel Pack Gravel Pack Modelling Gravel Packing

Horizontal Wells Microemulsion Technology Optimisation Perforate/Gravel Pack Perforating Policy Perforation Method Screen Failure Screen Technology Screenless Completions Screenless Completions Screens Steamflood Tapti Field

Prediction Clean-out Observations Post-Failure Risk Assessment Sarir Field Accurate Pediction Accurate Pediction Case Study Case Study Effect of water-Cut Effect of water-Cut

Flowing conditions Flowing conditions Flowing conditions Horizontal wells Horizontal wells Mature Fields Mitigation Prediction Prediction Prediction Wellbore Stability Wellbore Stability Elgin/Franklin Fields Assessment Horizontal wells Acid treatment Acid Fracturing Acid Fracturing Acid Fracturing Acid Fracturing Acid Fracturing Acid Treatment Acid Treatment

Acid treatment Acid treatment Acid treatment Acid Treatment Acid treatment Acid Treatment Acid Treatment Acid Treatment Acid Treatment Acid Treatment Acid Treatment Acid Treatment Acid Treatment Chelating Agent Application Combined Treatments Diversion Techniques Foam Fracturing

Gas Condensate Heterogeneity Horizontal wells

Relative Permeability Modifier Restimulation Surfactant Fracturing Surfactant Fracturing Surfactant Fracturing Mature Fields Chemical Treatment Gas Condensate Gas Reservoirs Gas Reservoirs Sufactant Treatment Intelligent Wells Flow Control Flow Control Hammer effects Gas Condensate - Layered LWD CBL Interpretation CBL Interpretation

Title A High-Success-Rate Acid Stimulation Campaign—A Case History Acid Stimulation of Extended Reach Wells: Lessons Learnt From N'Kossa Field Optimizing Well Productivity by Controlling Acid Dissolution Pattern During Matrix Acidizing of Carbonate Reservoirs Case Study: First Successful Offshore ESP Project in Saudi Arabia Formation Powered Jet Pump Use at Kuparuk Field in Alaska

A Simple Operational Approach To Ascertain the Viability of Your Offshore Gas Lift Project Before Fully Committing: The Meji Jacket X and Y Pilot Case Artificial Lift Selection Strategy for the Life of a Gas Well with some Liquid Production SAGD Gas Lift Completions and Optimization: A Field Case Study at Surmont Pushing the Boundaries of Artificial Lift Applications: SAGD ESP Installations at Suncor Energy, Canada Staircase Lifting of Oil Using Venturi Principle: A New Artificial-Lift Technique Efficient Intelligent Well Cleanup using Downhole Monitoring Advanced Wells: A Comprehensive Approach to the Selection Between Passive and Active Inflow Control Completions Revised Big Bore Well Design Recovers Original Bayu-Undan Production Targets Big Bore Completion and Sand Control for High Rate Gas Wells

Exploring Reservoir Engineering Aspects of Completion in Gas/Condensate Reservoirs: West African Examples A Critical Review of Completion Techniques for High-Rate Gas Wells Offshore Trinidad Selection of an Adequate Completion Type is the Key to Successful Reserves Recovery. Case History of Horizontal Drilling in t The Challenges and Advantages of Openhole Completions in the Manati Gas Field Multiple-Zone Completion in Marginal Production Wells Multiple-Layer Completions for Efficient Treatment of Multilayer Reservoirs Dipole Radial Profiling and Geomechanics for Near Wellbore Alteration Detection to Improve Productivity in a Matured Field Openhole Completion Options: The Niger Delta Experience Mechanistic Understanding of Rock/Phosphonate Interactions and the Effect of Metal Ions on Inhibitor Retention Production Tubing String Design for Optimum Gas Recovery Optimized Tubing-String Design Modeling for Improved Recovery

Application of a Maximum Reservoir Contact (MRC) Well in a Thin, Carbonate Reservoir in Kuwait Application of a Maximum Reservoir Contact (MRC) Well in a Thin, Carbonate Reservoir in Kuwait Succeeding With Multilateral Wells in Complex Channel Sands A Generalized Predictive Control for Management of an Intelligent Well’s Downhole, Interval Control Valves—Design and Using Down-Hole Control Valves to Sustain Oil Production From the First Maximum Reservoir Contact, Multilateral and Smart W On Reservoir Fluid-Flow Control With Smart Completions Case Study: The Use of Downhole Control Valves to Sustain Oil Production from the First Maximum Reservoir Contact, Multila Optimization of Commingled Production Using Infinitely Variable Inflow Control Valves Horizontal Open Hole, Dual-Lateral Stimulation, Using a Multilateral Entry with High Jetting Tool Experimental and Numerical Study on Production Performance: Case of Horizontal and Dual-Lateral Wells Evaluation of Alcohol-Based Treatments for Condensate Banking Removal Online Water-Injection Optimization and Prevention of Reservoir Damage Increasing Oil Recovery by Preventing Early Water and Gas Breakthrough in a West Brae Horizontal Well:�A Case History Analysis of Possible Applications of Dual ESPs—A Reservoir-Engineering Perspective Analysis of Possible Applications of Dual ESPs—A Reservoir-Engineering Perspective Erosion Study for a 400 MMcf/D Completion: Cannonball Field, Offshore Trinidad Development of an Integrated Solution for Perforation, Production and Reservoir Evaluation

Survival Analysis: The Statistically Rigorous Method for Analyzing Electrical Submersible Pump System Performance Survival Analysis: The Statistically Rigorous Method for Analyzing Electrical Submersible Pump System Performance Hydraulic Predictions for Polymer-Thickened Foam Flow in Horizontal and Directional Wells Effects of Formation Damage and High-Velocity Flow on the Productivity of Slotted-Liner Completed Horizontal Wells Long Term Evaluation of an Innovative Acid System for Fracture Stimulation of Carbonate Reservoirs in Saudi Arabia Horizontal Fracture Stimulation Success in the Alpine Formation, North Slope, Alaska Horizontal Fracture Stimulation Success in the Alpine Formation, North Slope, Alaska Fracture Treatment Design and Execution in Low-Porosity Chalk Reservoirs Field Case Studies: Damage Preventions Through Leakoff Control of Fracturing Fluids in Marginal/Low-Pressure Gas Reservo Fiber-Laden Fracturing Fluid Improves Production in the Bakken Shale Multi-Lateral Play Fiber-Based Fracture Fluid Technology a First for Oil Reservoirs in Western Siberia Field Trials of Fiber Assisted Stimulation in Saudi Arabia: An Innovative Non-Damaging Technique for Achieving Effective Zona Fiber-Laden Fluid: Applied Solution for Addressing Multiple Challenges of Hydraulic Fracturing in Western Siberia An Engineered Fiber for the Fracturing of Unconsolidated Sand in Highly Deviated Wells in the Tali Field of Brunei Comparison of Flowback Aids: Understanding Their Capillary Pressure and Wetting Properties Effect of Formation Modulus Contrast on Hydraulic Fracture Height Containment

Weighted Frac Fluids for Lower-Surface Treating Pressures A Faster Cleanup, Produced Water-Compatible Fracturing Fluid: Fluid Designs and Field Case Studies Optimizing Fracturing Fluids From Flowback Water Optimization of Hydraulic Fracture Geometry Maximizing Effective Fracture Half-Length to Influence Well Spacing Novel Frac-and-Pack Technique for Selective Fracture Propagation A Novel Approach to Fracturing Height Control Enlarges the Candidate Pool in the Ryabchyk Formation of West Siberia’s M Fracture Treatment Optimization for Horizontal Well Completion Application of a Highly Efficient Multistage Stimulation Technique for Horizontal Wells New Methodology of Effective Hydraulic Fracturing in High-Thickness Formation Stimulating High-Water-Cut Wells: Results From Field Applications Efficient Multifractured Horizontal Completions Change the Economic Equation in Latin America Through Improved Reservoir C Continuous Pumping, Multistage, Hydraulic Fracturing in Kitina Field, Offshore Congo, West Africa Successful Multistage Horizontal Well Fracturing in the Deep Gas Reservoirs of Saudi Arabia: Field Testing of a Promising Inno Successful Multistage Hydraulic Fracturing Treatments Using a Seawater-Based Polymer-Free Fluid System Executed From a Successful Continuous, Multi-Stage, Hydraulic Fracturing Using a Seawater-Based Polymer-Free Fluid System, Executed from Designing Hydraulic Fractures in Russian Oil and Gas Fields to Accommodate Non-Darcy and Multiphase Flow

Designing Hydraulic Fractures in Russian Oil and Gas Fields to Accommodate Non-Darcy and Multiphase Flow Designing Hydraulic Fractures in Russian Oil and Gas Fields to Accommodate Non-Darcy and Multiphase Flow Optimized Hydrualic Fracturing for the Gandhar Field Production Performance Design Criteria for Hydraulic Fractures Quantifying Proppant Transport for Complex Fractures in Unconventional Formations Particularities of Hydraulic Fracturing in Dome-Type Reservoirs of Samara Area in the Volga-Urals Basin Simultaneous Hydraulic Fracturing of Adjacent Horizontal Wells in the Woodford Shale Novel Technology Replaces Perforating and Improves Efficiency During Multiple Layer Fracturing Operations A Study of Fracture Initiation Pressures in Cemented Cased-Hole Wells Without Perforations Semiphenomenological Model of Hydraulic Fracturing in Granular Media Optimization of a Visco-Elastic Surfactant (VES) Fracturing Fluid for Application in High-Permeability Formations Novel CO2-Emulsified Viscoelastic Surfactant Fracturing Fluid System Enables Commercial Production From Bypassed Pay in Fracture Stimulation Utilizing a Viscoelastic-Surfactant-Based System in the Morrow Sands in Southeast New Mexico

Overcoming Excessive Fluid Loss in Tip-Screen-Out Stimulations of Depleted, High-Permeability Reservoirs Using a New-Gen

Water Control and Fracturing: A Reality Water-Fracs: We Do Need Proppant After All Hydraulic Fracturing With Heated Fluids Brings Success in High-Pour-Point Waxy-Oil Reservoir in India Fracturing Technology for 4% Porosity Libya’s Reservoir: Application of Correct Diagnostic and Methodology to Optimize th The Effects of Fracture Cleanup on the Productivity of Gas Condensate Systems An Integrated Evaluation of Successful Acid Fracturing Treatment in a Deep Carbonate Reservoir Having High Asphaltene Con New Results Improve Fracture Cleanup Characterization and Damage Mitigation New Results Improve Fracture Cleanup Characterization and Damage Mitigation Investigation of Cleanup Efficiency of Hydraulically Fractured Wells in Gas Condensate Reservoirs

New Results Improve Fracture Cleanup Characterization and Damage Mitigation Optimizing the Completion of a Multilayer Cotton Valley Sand Using Hydraulic-Fracture Monitoring and Integrated Engineering Comparative Analysis of Damage Mechanisms in Fractured Gas Wells Borehole Deviation Surveys are Necessary for Hydraulic Fracture Monitoring Hydraulic Fracture Diagnostics Used To Optimize Development in the Jonah Field Evaluation of the Proppant-Pack Permeability in Fiber-Assisted Hydraulic Fracturing Treatments for Low-Permeability Formatio Determining Realistic Fracture Conductivity and Understanding Its Impact on Well Performance—Theory and Field Examples The Texture of Acidized Fracture Surfaces: Implications for Acid Fracture Conductivity Complex Fracture Geometry Investigations Conducted on Western-Siberian Oilfields at Rosneft Company A New Environmentally Acceptable Technique for Determination of Fracture Height and Width Hydraulic Fracture Geometry Investigation for Successful Optimization of Fracture Modeling and Overall Development of Juras Production Forecasting in a Limited-Data Environment: Evolving the Methodology in the Yamburgskoe Arctic Gas/Condensate Correcting Underestimation of Optimal Fracture Length by Modeling Proppant Conductivity Variations in Hydraulically Fracture Fracture Propagation in High-Permeability Rocks: The Key Influence of Fracture Tip Behavior Acid Fracturing of Deep Gas Wells Using a Surfactant-Based Acid: Long-Term Effects on Gas Production Rate Evaluation and Optimization of Low-Conductivity Fractures Hydraulic Fracture Diagnostics In The Williams Fork Formation, Piceance Basin, Colorado Using Surface Microseismic Monitoring Technology Evidence of a Horizontal Hydraulic Fracture From Stress Rotations Across a Thrust Fault Quantifying Non-Darcy Effects on the Productivity of a Cased-Hole Frac Pack (CHFP) Well Prediction of Long-Term Proppant Flowback in Weak Rocks Effect of Production Induced Stress Field on Refracture Propagation and Pressure Response Hydraulic Fracturing and Filtration in Porous Medium New Mechanical and Damage Skin Factor Correlations for Hydraulically Fractured Wells Differential Cased Hole Sonic Anisotropy for Evaluation of Propped Fracture Geometry in Western Siberia, Russia New Findings in Fracture Cleanup Change Common Industry Perceptions New Findings in Fracture Cleanup Change Common Industry Perceptions

The Resiliency of�Frac-Packed Subsea Injection Wells Eliminating the Poroelastic Problems Associated with Water Injection in the Kikeh Deep Water Development Using Open and Cased Hole Sonic Anisotropy and Geomechanics Modeling for Hydraulic Fracturing Evaluation: A Case Study Hydraulic Fracture Offsetting in Naturally Fractured Reservoirs: Quantifying a Long-Recognized Process Well Productivity In North Sea Chalks Related To Completion And Hydraulic Fracture Stimulation Practices Gas Condensate Relative Permeabilities in Propped Fracture Porous Media: Coupling Versus Inertia Successful Acid-Fracturing in Adverse Conditions: Lessons Learnt and Integrated Evaluation in the Kharyaga Field Massive Annular Fracturing Practices in BJC Gas Field, Sichuan, China Deliverability of Gas-Condensate Reservoirs—Field Experiences and Prediction Techniques

Gas Coning Control for Smart Wells Using a Dynamic Coupled Well-Reservoir Simulator Auto, Natural, or In-Situ Gas-Lift Systems Explained A Critical Review of Completion Techniques for High-Rate Gas Wells Offshore Trinidad Innovative Gas Shutoff Method Using Heavy Oil-in-Water Emulsion

Effect of Wettability on High-Velocity Coefficient in Two-Phase Gas/Liquid Flow Delayed-Release Acid System for Cleanup of Al Khalij Horizontal Openhole Drains The Effect of Well Trajectory on Horizontal Well Performance Prudhoe Bay Study Of Horizontal Well Injectivity And Recommended Approach To Achieving Long Term Efficient Waterfloodin Application of a Novel Open-Hole Horizontal Well Completion in Saudi Arabia Successful Case History of a Novel Open-Hole Horizontal Well Completion in Saudi Arabia A Case Study of Oil-Based Mud Effect on Horizontal-Well Productivity A Case Study of Oil-Based Mud Effect on Horizontal-Well Productivity Predicting Horizontal-Openhole-Completion Success on the North Slope of Alaska Analyzing Underperformance of Tortuous Horizontal Wells: Validation With Field Data Experience in AA-LDHI Usage for a Deepwater Gulf of Mexico Dry-Tree Oil Well: Pushing the Technology Limit The Effect of Positive Coupling and Negative Inertia on Deliverability of Gas Condensate Wells Cost-Effective Life-Cycle Profile Control Completion System for Horizontal and Multilateral Wells Production and Injection Profiling Through Permanent-Downhole-Pressure-Gauge Recording During a Coiled-Tubing-Conveyed Workover Operation Flow Profiling by Distributed Temperature Sensor (DTS) System—Expectation and Reality Improved Reservoir Management With Intelligent Multizone Water-Alternating-Gas (WAG) Injectors and Downhole Optical Flow Monitoring Slim Intelligent Completions Technology Optimize Production in Maximum Contact, Expandable Liner and Quad Laterals Comp Na Kika Field Experiences in the Use of Intelligent Well Technology to Improve Reservoir Management Inflow Control Devices: Application and Value Quantification of a Developing Technology First Applications of Inflow Control Devices (ICD) in Open Hole Horizontal Wells in Block 15, Ecuador Techniques for Optimum Placement of Interval Control Valve(s) in an Intelligent Well Integrating ESPs with Intelligent Completions: Options, Benefits and Risks Should “Proactive or “Reactive Control Be Chosen for Intelligent Well Management?

Maximizing Production Capacity Using Intelligent-Well Systems in a Deepwater, West-Africa Field Intelligent Completions Technology Offers Solutions to Optimize Production and Improve Recovery in Quad–Lateral Wells in Insurance Value of Intelligent Well Technology Against Reservoir Uncertainty Laboratory Hydraulic Fracturing Test on a Rock With Artificial Discontinuities Laboratory Hydraulic Fracturing Test on a Rock With Artificial Discontinuities New Insights into Application of Foam for Acid Diversion Modeling and CT-Scan Study of the Effect of Core Heterogeneity on Foam Flow for Acid Diversion Modeling and CT-Scan Study of Foams for Acid Diversion Guidelines for the Proper Application of Critical Velocity Calculations A Combined Well Completion and Flow Dynamic Modeling for a Dual-Lateral Well Load-up Investigation On the Flow Performance of Velocity Strings To Unload Wet Gas Wells A Novel Foamer for Deliquification of Condensate-Loaded Wells Securing The Future In Mature Gas Fields Prediction Onset and Dynamic Behaviour of Liquid Loading Gas Wells Getting the Last Gasp: Deliquification of Challenging Gas Wells Highly Successful Batch Application of Surfactant in North Sea Gas Wells Gas-Well Liquid Loading From the Power Perspective

Automatic Concurrent Water Collection (CWC) System for Unloading Gas Wells

A New Method of Plunger Lift Dynamic Analysis and Optimal Design for Gas Well Deliquification Investigation of Gas Carryover With a Downward Liquid Flow An Acid-Placement Model for Long Horizontal Wells in Carbonate Reservoirs The Use of a Fully Coupled Geomechanics-Reservoir Simulator To Evaluate the Feasibility of a Cavity Completion Managing Production in Maturing Assets: Increasing Intervention Success by Combining Production Logging With Nodal Analy Forecasting the Productivity of Thinly Laminated Sands with a Single Well Predictive Model Geomechanical Characterization of a Sandstone Reservoir in Middle East—Analysis of Sanding Prediction and Completion St Effective Matrix Acidizing in Carbonate Reservoir—Does Perforating Matter? Productivity Increase Using the Combination of Formation Isolation Valve and Dynamic Underbalanced Perforation Coiled-Tubing Perforation and Zonal Isolation in Harsh Wellbore Conditions Dynamic Underbalanced Perforating Application Increases Productivity in the Mature High-Permeability Gas Reservoirs of San Limited Entry Perforations in HVO Recovery: Injection and Production in Horizontal Wells Overbalanced Perforating Yields Negative Skins in Layered Reservoir Optimized Perforation—From Black Art to Engineering Software Tool Oriented Perforation in Dual Completion Wells: A Real Case in East Texas Oriented Perforation in Dual Completion Wells: A Real Case in East Texas New Perforating Technique Improves Well Productivity and Operational Efficiency New Solution To Improve Perforation Penetration and Breakdown: San Jorge Field, Argentina Case Histories Propellant-Assisted Perforating—An Alternative Stimulation Solution in Heavily Karstified Carbonate Reservoirs Propellant-Assisted Perforating—An Alternative Stimulation Solution in Heavily Karstified Carbonate Reservoirs Quantifying Skin Variation for Underbalanced Perforating Improved Method for Underbalanced Perforating With Coiled Tubing in the South China Sea

A Novel Technology for Through Tubing Perforation in Highly Deviated Wells Where Electric Line Is Limited Modeling Air and Water Perforator Swell for Better Risk Management Novel Perforating Job Design Triples Well Productivity Flow Performance of Perforation Tunnels Created With Shaped Charges Using Reactive Liner Technology Overcoming Near Wellbore Damage Induced Flow Impairment with Improved Perforation Job Design and Execution Methods Field-Data-Based Prediction of Well Productivity Decline Due to Sulphate Scaling Injectivity Impairment Due to Sulfate Scaling During PWRI: Analytical Model Fracture Propagation, Filter-Cake Buildup and Formation Plugging During PWRI Predicting the Production Capacity During Underbalanced-Drilling Operations in Vietnam Reduced Water Production and Increased Oil Production Using Smart Completions and MPFM Case Study"" Sand Control Completions for the Development of Albacora Leste Field Innovative Use of Expandable Sand Screens Combined With Propped Hydraulic Fracturing Technology in Two Wells With Inte Design and Implementation of a Sand-Control Completion for a Troublesome Shallow Laminated Gas Pay—A Case Study Magnolia Deepwater Experience—Frac-Packing Long Perforated Intervals in Unconsolidated Silt Reservoirs Magnolia Deepwater Experience--Frac Packing Long, Perforated Intervals in Unconsolidated Silt Reservoirs TAML Level 3 tri-lateral with Sand Control application for Saudi Aramco Deepwater Extended-Reach Sand-Control Completions and Interventions Sanding Study for Deepwater Indonesia Development Wells: A Case History of Prediction and Production Screen Development to Withstand 4,000-psi Overbalance, Subhydrostatic Completion in Deepwater GOM Subsea Waterflood

Sandface Completion for a Shallow Laminated Gas Pay With High Fines Content Lessons Learned on Sand-Control Failure and Subsequent Workover at Magnolia Deepwater Development Lessons Learned on Sand-Control Failure and Subsequent Workover at Magnolia Deepwater Development Novel Through Tubing Sand Control Solution for Failed Gravel Pack - Alpha Well - 4L Case Study Sand Control Completion Failures: Can We Talk the Same Language? Development Strategies of Soft-Friable Carbonate Gas Reservoirs Through Horizontal Open Hole Gravel Packed Completions Greater Plutonio Openhole Gravel-Pack Completions: Fluid Design and Field Applications High-Angle Well Deliverability Modeling for Openhole Gravel-Pack Completion Under Ultrahigh Gas Rate Horizontal Open Hole Gravel Pack Placement Requirements in Selective Completion Projects A Comparison of Design Placement Methodologies for Horizontal Open Hole Gravel Pack in Multizone Completion Projects A Step Change in Openhole Gravelpacking Methodology: Drilling-Fluid Design and Filter-Cake Removal Method Greater Plutonio Openhole Gravel-Pack Completions: Fluid Design and Field Applications Complex Through-Tubing Gravel-Pack Operation Increases Production on a Well in the Heidrun Field: A Case Study Openhole Gravel Packing With Exposed Shales: Waterpack Case Histories From Underground Gas Storage Wells in Italy Gravel Packing Long Openhole Intervals With Viscous Fluids Utilizing High Gravel Concentrations: Toe-to-Heel Packing Witho Single Trip Multi-Zone Gravel Packing—Case Study at Handil, Bekapai & Sisi-Nubi Fields Openhole Gravel Pack in the Roaring Forties for TOTAL AUSTRAL Integrated Approach to Modeling Gravel Packs in Horizontal Wells Openhole Gravel Packing With Oil-Based Fluids: Implementation of the Lessons Learned From Past Experiences Leads to the

Critical Conditions for Effective Sand-Sized Solids Transport in Horizontal and High-Angle Wells First Application of Novel Microemulsion Technology for Sand Control Remediation Operations-A Successful Case History From Effective Perforating and Gravel Placement: Key to Low Skin, Sand Free Production in Gravel Packs Effective Perforating and Gravel Placement: Key to Low Skin, Sand-Free Production in Gravel Packs Prediction of Sanding Using Oriented Perforations in a Deviated Well, and Validation in the Field Determination of Optimum Perforation Design and Sanding Propensity in Long Horizontal Wells Based on Modified RP 19B Se A Novel Technique for Determining Screen Failure in Offshore Wells: A GOM Case History ICD Screen Technology in Stag Field to Control Sand and Increase Recovery by Avoiding Wormhole Effect Screenless Completions as a Viable Through-Tubing Sand Control Completion Screenless Completions as a Viable Through-Tubing Sand Control Completion The Search for Alternative to Screen: Is Permeable Cement a Viable Option?

Evaluation of Sand-Control Completions in the Duri Steamflood, Sumatra, Indonesia Evolution of Sand Control Completion Techniques in the South Tapti Field Sand Quantification: The Impact on Sandface Completion Selection and Design, Facilities Design and Risk Evaluation Sand Control Robustness in a Deepwater Development: Case Histories From Girassol Field (Angola) Sand Erosion in Weakly Consolidated Reservoirs: Experiments and Numerical Modeling Cleaning Large-Diameter Proppant in Low-Bottomhole Pressure, Extended-Reach Wells With Concentric Coiled Tubing Vacuu Field and Laboratory Observations of Post-Failure Stabilizations During Sand Production Applying Sand Management Process on the Lunskoye High Gas-Rate Platform Using Quantitative Risk Assessment Case Study: The Application of a Sand Management Solution for the Sarir Field in Libya Use of Reservoir Formation Failure and Sanding Prediction Analysis for Viable Well-Construction and Completion-Design Optio Practical Approach to Achieve Accuracy in Sanding Prediction Practical Approach to Achieve Accuracy in Sanding Prediction Sanding—Not As It First Appeared Sanding—Not As It First Appeared Effect of Water Cut on Sand Production—An Experimental Study Effect of Water Cut on Sand Production—An Experimental Study

Sanding: A Rigorous Examination of the Interplay Between Drawdown, Depletion, Startup Frequency, and Water Cut Sanding: A Rigorous Examination of the Interplay Between Drawdown, Depletion, Startup Frequency, and Water Cut Controls of Coal Fabric on Coalbed Gas Production and Compositional Shift in Both Field Production and Canister Desorption Tests Comprehensive Transient Modeling of Sand Production in Horizontal Wellbores Comprehensive Transient Modeling of Sand Production in Horizontal Wellbores Bokor--A New Look at Sand Production in a Mature Field Case Study: Restoring Sand-Prone Subsea Wells to Production Sand-Production Prediction: A New Set of Criteria for Modeling Based on Large-Scale Transient Experiments and Numerical In Sand-Production Prediction: A New Set of Criteria for Modeling Based on Large-Scale Transient Experiments and Numerical Investigation Prediction of Sand Production Rate in Oil and Gas Reservoirs: Importance of Bean-Up Guidelines Influence of Rock Failure Characteristics on Sanding Behavior: Analysis of Reservoir Sandstones from the Norwegian Sea An Integrated Wellbore Stability and Sand-Production Prediction Study for a Multifield Gas Development Development of Appropriate Test Methodologies for the Selection and Application of Lead and Zinc Sulfide Inhibitors for the El Development and Implementation of a Scale-Management Strategy for Oseberg S�r Assessment of Total Skin Factor in Perforated Wells A New Skin-Factor Model for Perforated Horizontal Wells Lessons Learned From Using Viscoelastic Surfactants in Well Stimulation Recent Acid-Fracturing Practices on Strawn Formation in Terrell County, Texas Small-Scale Fracture Conductivity Created by Modern Acid-Fracture Fluids Recent Acid-Fracturing Practices on Strawn Formation in Terrell County, Texas Field Trial of a New Non-Damaging Degradable Fiber-Diverting Agent Achieved Full Zonal Coverage during Acid Fracturing in a Successful Application of Innovative Fiber-Diverting Technology Achieved Effective Diversion in Acid Stimulation Treatments in Use of Viscoelastic-Surfactant-Based Diverting Agents for Acid Stimulation: Case Histories in GOM First North Sea Application of Pinpoint-Stimulation Technology to Perform a Rig-Based Acid Fracture Treatment Through CT

Diversion and Cleanup Studies of Viscoelastic Surfactant-Based Self-Diverting Acid Use of Novel Acid System Improves Zonal Coverage of Stimulation Treatments in Tengiz Field

A New Efficiency Criterion for Acid Fracturing in Carbonate Reservoirs Acid Fracturing of Gas Wells by Use of an Acid Precursor in the Form of Solid Beads: Lessons Learned From First Field Applic Use of Novel Acid System Improves Zonal Coverage of Stimulation Treatments in Tengiz Field Optimization of Acid Stimulation for a Loosely Consolidated Brazilian Carbonate Formation--Multidisciplinary Laboratory Asses A Novel Stimulation Technique for Horizontal Openhole Wells in Carbonate Reservoirs--A Case Study in Kuwait Sandstone Matrix Stimulation Can Improve Brownfield Oil Production When the Chemistry and Procedures Are Correct Development and Field Application of a New Hydrogen Sulfide Scavenger for Acidizing Sour-Water Injectors Successful Stimulation of Thick, Naturally-Fractured Carbonates Pay Zones in Kazakhstan Matrix Acidizing of Carbonate Reservoirs Using Organic Acids and Mixture of HCl and Organic Acids An Innovative Acid Stimulation Technique for Reviving Dead Wells in the Ghawar Field of Saudi Arabia - A Holistic Approach A New Technical Standard Procedure To Measure Stimulation and Gravel-Pack Fluid Leakoff Under Static Conditions An Alternative Solution to Sandstone Acidizing Using a Nonacid Based Fluid System With Fines-Migration Control Combining Acid- and Hydraulic-Fracturing Technologies Is the Key to Successfully Stimulating the Orito Formation Chemical Diversion Techniques Used for Carbonate Matrix Acidizing: An Overview and Case Histories Foam Fracturing: New Stimulation Edge in Western Siberia

Chemical Stimulation of Gas/Condensate Reservoirs The Effect of Pore-Scale Heterogeneities on Carbonate Stimulation Treatments Optimizing Diversion and Pumping Rate to Effectively Stimulate Long Horizontal Carbonate Gas Wells

Sensitivity Study on the Main Factors Affecting a Polymeric RPM Treatment in the Near-Wellbore Region of a Mature Oil-Produ Restimulation: Candidate Selection Methodologies and Treatment Optimization New Viscoelastic Surfactant Fracturing Fluids Now Compatible With CO2 Drastically Improve Gas Production in Rockies Case Study: Application of a Viscoelastic Surfactant-Based CO2 Compatible Fracturing Fluid in the Frontier Formation, Big Hor New Viscoelastic Surfactant Fracturing Fluids Now Compatible With CO2 Drastically Improve Gas Production in Rockies Optimized Stimulation Solutions for a Mature Field in Kazakhstan A New Solution to Restore Productivity of Gas Wells With Condensate and Water Blocks Wettability Alteration in Gas-Condensate Reservoirs to Mitigate Well Deliverability Loss by Water Blocking Preventive Treatment for Enhancing Water Removal from Gas Reservoirs by Wettability Alteration Preventive Treatment for Enhancing Water Removal from Gas Reservoirs by Wettability Alteration High-Water-Cut Wells Stimulation Combined Viscoelastic Surfactant Real-Time Water Detection and Flow Rate Tracking in Vertical and Deviated Intelligent Wells with Pressure Sensors Downhole Flow Control For High Rate Water Injection Applications Downhole Flow Control For High Rate Water Injection Applications Water Hammer Effects on Water Injection Well Performance and Longevity Comparison of Vertical, Slanted, and Horizontal Wells Productivity in Layered Gas-Condensate Reservoirs Improved Wellbore Delivery in a Deepwater Reservoir via the aid of Logging-While-Drilling Imaging and Formation Pressure Da Reliability of Cement Bond Log Interpretations Compared to Physical Communication Tests Between Formations Reliability of Cement Bond Log Interpretations Compared to Physical Communication Tests Between Formations

Author

Abstract

N. Al-Araimi, SPE, Brunei Shell Petroleum Co. Sdn. Bhd. and L. Jin, SPE, Shell Abstract Intl. E&P A successful acid stimulation campaign w J.M. Mazel and H. Poitrenaud, Total E&P, and P. M’Bouyou, Total E&P Congo Abstract N’Kossa is an offshore field located 6 F.F. Chang, SPE, and M. Abbad, Schlumberger Abstract The chemical nature of carbonate rocks m Ahmed R. Al Zahrani, SPE, Redha H. Al-Nasser, SPE, and Timothy W. Collen, Abstract SPE, Saudi The Electrical Aramco; Submersible Sudhakar Khade, PumpSPE, (ESP) Sc J.W. Peirce, SPE, J.A. Burd, G.L. Schwartz, ConocoPhillips Alaska, Inc., andAbstract T.S. Pugh, Formation SPE, Weatherford powered jet International pumps (FPJP) we

Francis Nwaochei, SPE; Adebayo Olufemi, SPE; Vincent Eme, SPE; and John Ibrahim, SPE, Chevron Nigeria Limited; Eseoghene Nakpodia, SPE, and Wole Areo, SPE, Flostar Oil & Gas Nigeria Limited Abstract Application of improved Oil Recovery in m Peter O. Oyewole, SPE, BP, and James F. Lea, SPE, PL Tech LLC Abstract The Natural Gas industry is often faced w T.C. Handfield, T. Nations, S.G. Noonan; ConocoPhillips Abstract Gas lift completions for SAGD1 producers F. Gaviria, SPE, SUNCOR, and R. Santos, SPE, O. Rivas, SPE, and Y. Luy,Abstract SPE, Schlumberger The need for high-temperature electric su Siddhartha Gupta, Schlumberger Abstract Artificial lift systems are now being consid D.K. Olowoleru, K.M. Muradov, F.T. Al-Khelaiwi and D.R. Davies; SPE, Heriot-Watt AbstractUniversity, Effective well Edinburgh, cleanupU.K. during well start-up F.T. Al-Khelaiwi, SPE, and V.M. Birchenko, SPE, Heriot-Watt University; M.R. Abstract Konopczynski, Advances SPE, (from WellDynamics; conventionaland wells D.R. to ho Da L. B. Ledlow, W. W. Gilbert, N. P. Omsberg, G. J. Mencer and D. P. Jamieson, Abstract ConocoPhillips The Bayu-Undan gas recycling project is l Alain BOURGEOIS, Sebastien BOURGOIN, and Pierre PUYO, TOTAL AUSTRAL Abstract This paper outlines and discusses the iss

C.S. Kabir, SPE, Chevron Energy Technology Co.; M.-M. Chang, SPE, Chevron Intl. E&P; and O. Taghizadeh, SPE, U. of Texas at Austin Summary This paper explores multiple completion S.D. Cooper, S. Akong, K.D. Krieger, A.J. Twynam, F. Waters, and R. Morrison, Abstract BP; G. BPHurst, Trinidad Consultant; and Tobago and(bpTT) B. Lanclos has been and Sergey Ryzhov, SPE, Vladimir Malyshev, SPE, Shlumberger, and Tatyana Kruchkova, Abstract The SPE, Sporyshevskoye Anna Zubareva, oilAndrey field developmen Vasiliev, Y A. Calderon, SPE, A.F. Arag�o, SPE, and C.M. Chagas, SPE, PETROBRAS, Abstract and C. The Guimar�es, offshore northeast SPE, and Brazil R. Manati Barbedo, field S Guillermo Pitrelli and Maximiliano Giraldo, Repsol-YPF Abstract Concepts on well multiple zone completio Gary Rytlewski, Schlumberger Abstract A new method of completing multiple-laye Surej Subbiah/Schlumberger; Wielemaker.E/Schlumberger; Joia P/Petrom SA; Abstract Hopper.L/Schlumberger; Cartojani is a mature Fernandez oil field with LI/Schlum deplete J. Arukhe, SPE, Petro-Canada; L. Nwoke, SPE, Shell; C. Uchendu, SPE, BJAbstract Services Within Co.; and theS.Niger Imie,Delta SPE,clastic U. of Stavanger environmen Mason B. Tomson, Amy T. Kan, Gongmin Fu, and Dong Shen, Rice University; Summary and Hisham This paper A. Nasr-El-Din,* discusses SPE, the effects Hamad of Al-S Ca2 B.D. Poe Jr., SPE, Schlumberger Abstract This paper presents the results of an inve B.D. Poe Jr., SPE, Schlumberger Abstract This paper presents the results of an inve M. Kabir, KOC; S. Ingham, Schlumberger; D. Sibley, K. Osman, A.K. Ambastha, and M. Anderson, Chevron; and B. Rahman, KOC Abstract Mauddud reservoir in the Greater Burgan M. Kabir, KOC; S. Ingham, Schlumberger; D. Sibley, K. Osman, A.K. Ambastha, Abstract and M. Mauddud Anderson, reservoir Chevron; in the and Greater B. Rahman, BurganK Liu Song, Li Jianping, and Lv Dingyu, CNOOC, and Jeffrey Kok and Shim Yen Abstract Han, Schlumberger The lower Minghuazhen is a shallow-wat Yang Qing and D.R. Davies, Heriot Watt University Abstract This paper presents an advanced control S.M. Mubarak, T.R. Pham, and S.S. Shamrani, SPE, Saudi Aramco, and M. Abstract Shafiq, SPE, ThisSchlumberger paper describes a case-study detaili T.S. Ramakrishnan, Schlumberger-Doll Research Summary Poor displacement efficiency in hydroca S.M. Mubarak, T.R. Pham, and S.S. Shamrani, SPE, Saudi Aramco, and M. Summary Shafiq, SPE, This Schlumberger paper describes a case study that M.M.J.J. Naus, SPE, Delft U. of Technology (DUT); N. Dolle, SPE, Shell Intl.Summary E&P (SIEP); Weand developed J.-D. Jansen, an operational SPE, DUT strategy and SIE f Jose R. Amorocho, J. Ricardo Solares, Abdulmohsin Al-Mulhim, and Ali Al-Saihati, Abstract SPE, TheSaudi number Aramco; of multilateral Wassim gas Kharrat, producers SPE Mohammed M. Amro, SPE, and Mohamed S. Benzagouta, SPE, King Saud University; Abstract Current Hazim drilling A. Ayyad, technology SPE, Schlumberger; is moving towa a G.A. Alzate, SPE, U. Nacional de Colombia-Medellin; C.A. Franco, SPE, andAbstract A. Restrepo, The use SPE,ofBP stimulation Colombia; treatments and D.L. Barret based B.�. Bringedal, S.A. Morud, and N.A. Hall, ABB, and G. Huseman, Shell Abstract Waterflood injection on the Shell Bonga f A. McIntyre, SPE, Marathon Oil U.K. Ltd.; R. Adam, SPE, Amerada Hess Denmark; Abstract and Inflow J. Augustine, control devices SPE, and which D. prevent Laidlaw,ear Ba D.R. Davies, SPE, R. Narayanasamy, SPE, B. Kristensen, and J.M. Somerville, Summary SPE, Heriot-Watt Relatively few University field installations of a dua D.R. Davies, SPE, R. Narayanasamy, SPE, B. Kristensen, and J.M. Somerville, Summary SPE, Heriot-Watt Relatively few University field installations of a dua J.C. Healy, Consultant, John Martin, BP plc, Brenton McLaury, University of Tulsa, Abstract and The Raynald Cannonball Jagroop, Field BP is Trinidad a one Tcfand gasToba con J. Jaua and O. Rivas, SPE, Schlumberger, and A. Mej�as, Repsol YPF Abstract As a result of the increasing emphasis on

W.J. Bailey, SPE, Schlumberger-Doll Research; I.S. Weir, U. West of England; Summary B. Cou�t, A rigorous SPE, Schlumberger-Doll statistical methodology Research using W.J. Bailey, SPE, Schlumberger-Doll Research; I.S. Weir, U. West of England; Summary B. Cou�t, A rigorous SPE, Schlumberger-Doll statistical methodology Research using Z. Chen , M. Duan, S.Z. Miska, M. Yu, and R.M. Ahmed, University of Tulsa;Summary and J. Hallman, Foam Weatherford has proved toInternational be effective and ec Yula Tang, Chevron Energy Technology Co.; Turhan Yildiz and Erdal Ozkan, Colorado School of Mines; and Mohan Kelkar, U. of Tulsa Abstract Slotted-liner is a relatively simple and cos F.O. Garzon, H.M. Al-Marri, J.R. Solares, and C.A. Franco Giraldo, SPE, Saudi Abstract Aramco, Acid andFracturing V. Ramanathan, has been SPE, a successful Schlumber m Tim S. Schneider, David O. Uldrich, and Richard Hodge, ConocoPhillips Co.;Abstract Bob Barree, The Alpine SPE, Barree�& field locatedAssocs.; on the North and Mich Slop Tim S. Schneider, David O. Uldrich, and Richard Hodge, ConocoPhillips Co.;Abstract Bob Barree, The Alpine SPE, Barree�& field locatedAssocs.; on the North and Mich Slop C.L. Cipolla, Pinnacle Technologies; and K.K. Hansen and W.R. Ginty, Amerada Summary Hess A/S This paper details the results for 33 pro J. Paktinat, J.A. Pinkhouse, and C. Williams, Universal Well Services Inc.; G.A. Summary Clark, Phillips The primary Production; purpose and ofG.S. surfactants Penny, use CE A. Powell, Headington Oil Co., O. Bustos, W. Kordziel, T. Olsen, D. Sobernheim, Abstract and Since T. Vizurraga, the horizontal Schlumberger lateral Bakken dolom D. Oussoltsev, SPE, K. K. Butula, SPE, and A. Klyubin SPE, Schlumberger, Abstract and Albert Successful Gayfullin, hydraulic SPE, Dmitry fracturing Senchenko, in various and Maytham I. Al-Ismail, SPE, Moataz M. Al-Harbi, SPE, and Abdulaziz K. Al-Harbi, Abstract SPE,Acid Saudi fracturing Aramco,has andbeen Venkateshwaran part of Saudi Ra Ar S. Sitdikov, SPE, A. Serdyuk, and A. Nikitin, SPE, Rosneft, and A.Yudin, SPE, Abstract K. Mullen, ThisSPE, paper D.describes Oussoltsev, successful SPE, and impleme K.K. B Matthew Law, George W. Chao, Hafeez A. Alim, Ahmad F. Hashim, Elsamma Abstract Samuel, This and paper Mathew discusses Samuel, theSchlumberger application ofW fib Paul R. Howard, Sumitra Mukhopadhyay, Nita Moniaga, Laura Schafer, Schlumberger, Abstract Flowback and Glenn aidsPenny, are usually Keith surfactants Dismuke, CES or c Hongren Gu, SPE, and Eduard Siebrits, SPE, Schlumberger Summary Much study has been conducted on the Lloyd Simms III and Brad Clarkson, Halliburton, and Gilbert Navaira, Chevron Abstract With Gulf of Mexico (GOM) hydrocarbon d Daren Bulat, SPE, Talisman Energy Inc., and Yiyan Chen, Matthew K. Graham, Abstract Richard Natural Marcinew, gas reservoir Goke Adeogun, development Jackcontin Shen S.M. Rimassa, SPE, P.R. Howard, SPE, and K.A. Blow, SPE, SchlumbergerAbstract As mature fields produce larger quantities H. Mahdiyar, Shiraz University, and M. Jamiolahmady and M. Sohrabi, Heriot-Watt Abstract University An optimized design for hydraulic fracturi Bilu Cherian, SPE, Schlumberger; Kirk Fields, SPE, and Seth Crissman, SPE, Abstract ConocoPhillips; The key to and theTarik success Itibrout, of aSPE, tight-gas and Mal field O. Hidalgo, Schlumberger Well Services; O. Gonz�lez and V. Gonz�lez, Abstract PDVSA;Frac-pack and A. S�nchez, is a pervasively and A.used Pe�a, completi Sch A.V. Yudin and K.K. Butula, Schlumberger, and Y.V. Novikov, OAO Tomskneft Abstract VNK The productive pay of the low permeability M.Y. Soliman, Reinhard Pongratz, Halliburton; Martin Rylance, TNK-BP; andAbstract Dean Prather, Fracturing Halliburton has become a viable and impo Majdi Al Mutawa, SPE, Bader Al Matar, SPE, and Yousef Abdul Rahman, SPE, Abstract Kuwait InOil theCompany; recent years Haihorizontal Liu, SPE, well Redha technol Kelk Raul Sanchez, Regis Agut, and David Coulon, Total Australia, and Roberto Sentinelli, Abstract The BJ Services Aguada Pichana field is located in the R. Arangath, SPE, Schlumberger, and J.F. Obamba, SPE, P. Saldungaray, SPE, Abstract and H. A common Malonga,scenario SPE, EniinCongo many mature oilf Pedro Saldungaray, Schlumberger; Efrain Huidobro Salas, Pemex; Sebastian Abstract Vargas,Latin Apache; America Fabiohasn’t Pe�acorada, escaped YPF; theJos ge Alberto Casero, SPE, and Giamberardino Pace, SPE, Eni E&P; Brad Malone,Abstract SPE, and Many Francois West Africa Cantaloube, offshore SPE, fields Schlumber are matu J.R. Solares, SPE, C.A. Franco, SPE, H.M. Al-Marri, SPE, and H.A. Al-Jubran, Abstract SPE, Saudi One of Aramco; the keyVenkateshwaran strategies in Saudi Ramana Aramc Tomislav Bukovac, Rafik Belhaouas and Daniel Perez, SPE, Schlumberger; Abstract Alexandru Offshore Dragomir, operations SPE, and areViorel extremely Ghita,expens Petro Tomislav Bukovac, Rafik Belhaouas and Daniel Perez, SPE, Schlumberger; Abstract Alexandru Current Dragomir, Free Fluid offshore SPE, System, operations Petrom Executed member are extremely from ofaOM Su Andrey V. Dedurin, TNK-BP; Vadim A. Majar, Gazpromneft; Andrey A. Voronkov, Summary SPE, Non-Darcy SIAM; Alexey andG.multiphase Zagurenko, flow SPE, effects Ros Andrey V. Dedurin, TNK-BP; Vadim A. Majar, Gazpromneft; Andrey A. Voronkov, SPE, SIAM; Alexey G. Zagurenko, SPE, Rosneft; and Alexander Y. Zakharov, SPE, Terry Palisch, SPE, and M.C. Vincent, SPE, Carbo Ceramics Summary Non-Darcy and multiphase flow effects Andrey V. Dedurin, TNK-BP; Vadim A. Majar, Gazpromneft; Andrey A. Voronkov, Summary SPE, Non-Darcy SIAM; Alexey andG.multiphase Zagurenko, flow SPE, effects Ros Rajiv Sagar, Schlumberger; A.K. Pandey, Durga Prasad, A.K. Vinod ONGC, Abstract Rohit Panse, Gandhar Ikhsan is one Nugraha, of ONGC’s Pankaj Taneja majorSch bro B.D. Poe Jr., SPE, Schlumberger, and J.F. Marique, SPE, Consultant Abstract This paper presents the results of an inve T.N. Olsen, T.R. Bratton, and M.J. Thiercelin, Schlumberger Abstract Since the widespread proliferation microA.N. Parfenov, SPE, S.S. Sitdikov, SPE, O.V. Evseev, SPE, and V.A. Shashel, Abstract Rosneft, The and majority K.K. Butula, of hydraulic SPE, Schlumberger fracturing work George Waters, Barry Dean, and Robert Downie, Schlumberger, and Ken Kerrihard, Abstract Lance Hydraulic Austbo, fracturing and Bruce of horizontal McPherson, wellsCo in G. Rytlewski and J. Lima, Schlumberger, and B. Dolan, Petrogulf Abstract A new method of completing multiple laye G.L. Rytlewski and J.M. Cook, Schlumberger Abstract A new method of completing multiple-lay Olga Alekseenko, Schlumberger Abstract Petroleum engineers have faced the prob P.F. Sullivan, B. Gadiyar, R.H. Morales, R. Hollicek, D. Sorrells, and J. Lee, Abstract Schlumberger, Visco-Elastic and D. Fischer, Surfactant Remington (VES) fluids Oil and are M.E. Semmelbeck, W.E. Deupree, and J.K. von Plonski, SPE, Escondido Resource, Abstract and A novel F.A. Mueller, carbon dioxideY. Chen,(CO2-) J.W. Lewis, emulsifi L. Vibhas J. Pandey and Tarik Itibrout, SPE, Schlumberger; Larry S. Adams, SPE, Abstract Chevron; Thisand paper Tracy discusses L. Cowan theand selection Oscarcriteri A. Bu

P. Parra, E. Miquilena, A. S�nchez, and A. Pe�a, Schlumberger Well Services, Abstract and Tip-Screen-Out Permeability A. Garc�a Generation Reservoirs (TSO) and M.stimulations Mill�n, Viscoelastic Using aPDVSA New of Flu hig M. Mahajan, SPE, and N. Rauf, SPE, BJ Services; T. Gilmore, SPE, Chevron; and A. Maylana, SPE, Pertamina Abstract Water production in mature fields is a com L.K. Britt and M.B. Smith, NSI Technologies; Z. Haddad and P. Lawrence, Devon Abstract Energy TheCo.; key S. objective Chipperfield, of hydraulic Santosfracturing Corp.; ani Josef Shaoul, SPE, and Winston Spitzer, SPE, Pinnacle Technologies, and Michael Summary Ross, Most Oil Stuart Reservoir existing Wheaton production in India , SPE, ofPaul waxyMaylan oils oc Areiyando Makmun, Schlumberger, and Fathi Issa and Gadalla Hameed, Sirte Abstract Oil Company Offshore A drilling program on North Rag M. Jamiolahmady, D. Ganesh, M. Sohrabi, and A. Danesh, Petroleum Engineering Abstract Inst., TheHeriot-Watt performance U. of fracturing treatments Qasem Dashti, SPE, Mir Kabir, SPE, Raju Vagesna, SPE, Feras Al-Ruhaimani, Abstract SPE, This Kuwait paper Oil Company, presents the and process Hai Liu, ofSPE, candid S J.A. Ayoub, SPE, and R.D. Hutchins, SPE, Schlumberger; F. Van der Bas, SPE, Abstract Shell;ItS. is Cobianco, well documented SPE, and in the C.N. literature Emiliani, that S J.A. Ayoub, SPE, and R.D. Hutchins, SPE, Schlumberger; F. Van der Bas, SPE, Abstract Shell;ItS. is Cobianco, well documented SPE, and in the C.N. literature Emiliani, that S P. Ghahri, M. Jamiolahmady, and M. Sohrabi, Heriot Watt University Abstract In tight gas reservoirs gas well production

J.A. Ayoub, SPE, and R.D. Hutchins, SPE, Schlumberger; F. Van der Bas, SPE, Shell; S. Cobianco, SPE, and C.N. Emiliani, SPE, Eni; M. Glover, SPE, BP America Inc.; S. Marino, SPE, Schlumberger; G. Nitters, SPE, Shell; D. Norman, SPE, Chevron, and G. Turk, SPE, BP America Inc. Abstract It is well documented in the literature that Jason Baihly, Schlumberger; Andrew Coolidge and Steven Dutcher, Devon; and Abstract Ruben Microseismic Villarreal, Mike hydraulic Craven, fracture Keith monitorin Brook, an Torsten Friedel, George Mtchedlishvili, Aron Behr, Hans-Dieter Voigt, and Frieder Abstract H�fner, Productivity Freiberg impairment University in tight-gas forma P. Bulant, Charles U.; L. Eisner, Schlumberger Cambridge Research; I. PšenĿ�k, Summary Significant Geophysical errors Inst. in of the the calculated Academy of azim Sc S.L. Wolhart, SPE, Pinnacle Technologies; T.A. Harting, SPE, J.E. Dahlem, Abstract SPE, andThis T.J. paper Young,reports SPE, BP on a America; study conducted and M.J. M.N. Bulova, SPE, A.N. Cheremisin Jr., SPE, K.E. Nosova, SPE, J.T. Lassek, Abstract SPE, and To Permeability D. achieve Willberg, maximum Formations SPE, Schlumberger production tight-g Terry Palisch, SPE, and Robert Duenckel, SPE, CARBO Ceramics Inc., and Abstract Lucas Bazan, To hydraulically SPE, Harmon fracture J. Heidt, a well SPE, requires and Ge la C. Malagon, SPE, M. Pournik, SPE, and A.D. Hill, SPE, Texas A&M University Summary In an acid-fracturing treatment fracture A. Nikitin and A. Shirnen, Rosneft, and J. Maniere, Schlumberger Abstract The generalization of Hydraulic fracturing R.R. McDaniel, SPE, and J.F. Borges, SPE, Hexion Specialty Chemicals, and Abstract S.S. Dakshindas, For years SPE, radioactive Marathon tracers Oil Corporation have been Alexey Nikitin, SPE, Rosneft-Yuganskneftegaz; Alexey Yudin, SPE, Schlumberger; Abstract and The Ilyas focus Latypov, of ourAzat research Haidar, is on SPE, a remote and G Y. Shumakov, A.A. Burov, and K.K. Butula, SPE, Schlumberger, and I.A. Zynchenko, Abstract Gazprom Though there are many proven ways of p A.H. Akram, SPE, and A. Samad, SPE, Schlumberger Abstract A study was carried out to forecast the p V.M. Entov, Inst. for Problems in Mechanics, Russian Academy of Sciences;Abstract E.M. Chekhonin, PressureSchlumberger distribution at Moscow the tip ofResearc a hydrau H.A. Nasr-El-Din, SPE, S. Al-Driweesh, SPE, and K. Bartko, SPE, Saudi Aramco, Abstract and The H. Al-Ghadban, deep tight carbonate V. Ramanathan, formations S. Kelk in S J.F. Manrique, SPE, Occidental Oil and Gas Corp., and B.D. Poe Jr., SPE, Schlumberger Abstract This paper presents the results of an inve David Abbott, Chris Neale, and James Lakings, Microseismic Inc., and Lynn Wilson, Jay C. Close, and Evan Richardson, Chevron Abstract A surface microseismic array was utilized S.C. Maxwell, U. Zimmer, R. Gusek, and D. Quirk, Pinnacle Technologies Canada Summary Microseismic imaging of a hydraulic-fra Liang-Biao Ouyang, SPE, Chevron Energy Technology Company Abstract Well completion plays a critical role in the G.R. Aidagulov and M. Thiercelin, Schlumberger, and V.N. Nikolaevskiy, S.M. Abstract Kapustyanskiy, Proppantand flowback A.G. Zhilenkov, is an extremely Inst. ofimport Phys X. Weng and E. Siebrits, Schlumberger Abstract In this work the propagation of an orthogo Smirnov N.N., Kisselev A.B., Nikitin V.F., and Zvyaguin A.V., Moscow M.V. Lomonosov Abstract The State practical U.; Thiercelin problemM. arises SRE,inSchlumbe enhancin H. Mahdiyar, M. Jamiolahmady, and A. Danesh, Heriot-Watt U. Abstract Hydraulic fracturing is one of the most com A. Nikitin and A. Pasynkov, Rosneft YNG, and G. Makarytchev, J. Maniere, R. Abstract SunderIn Kalyanaraman, a waterfloodedand reservoir S. Tcherkashnev, hydrocarbon S J.A. Ayoub, SPE, and R.D. Hutchins, SPE, Schlumberger; F. van der Bas, SPE, Abstract Shell;This S. Cobianco, paper summarizes SPE, and part C.N.ofEmiliani, the resul S J.A. Ayoub, SPE, and R.D. Hutchins, SPE, Schlumberger; F. van der Bas, SPE, Abstract Shell;This S. Cobianco, paper summarizes SPE, and part C.N.ofEmiliani, the resul S

R.A. McCarty, SPE, Chevron IE&P, and W.D. Norman, SPE, Chevron ETC Abstract This paper documents the utilization of fr Tamara Webb, Jusni Omar, Murphy Oil Corporation, Saifon Daungkaew, LeeAbstract Chin Lim, Kikeh RayField Tibbles, is a deepwater Ivan Munoz, project Hugo located Morale Almeida, C.M.C. de, Schlumberger; Melo, R.L.C., Petrobras; Holzberg, B. B.;Abstract Guimaraes, Hydraulic C., SPE, fracturing Schlumberger plays a very importan R.G. Jeffrey and X. Zhang, SPE, CSIRO Petroleum, and M. Thiercelin, SPE,Abstract Schlumberger Offsets RTC along UGthe hydraulic fracture path Bart Vos and Hans de Pater, Pinnacle Technologies; Chris Cook, Norsk Hydro; Abstract Tommy The Skjerven, Joint Chalk BP Research Norway; Rene (JCR) Frederikse initiative M. Jamiolahmady, M. Sohrabi, and Shaun Ireland, Heriot-Watt University Abstract Hydraulic fracturing is one of the most com H. Poitrenaud, P. Ferrand, and P. Pouget, SPE, Total E&P, and J. Mani�re, Abstract SPE, Schlumberger The Kharyaga field is located in Timan-P Xing Zhenhui, Saint-Gobain (Guanghan) Proppant; Andrew Pfaff, Thomas Weller, Abstract David Massive Wendt, hydraulic EOG Resources fracturing has China been Ltd suc Jairam Kamath, Chevron Distinguished Author Series articles are general d

A.P. Leemhuis, E.D. Nennie, and S.P.C Belfroid, SPE, and G.J.N. Alberts, SPE, Abstract TNO A Science strong and increase Industry; in gas E. inflow Peters,due TNO to ga Bu Adam Vasper, SPE, Schlumberger Summary The terms auto natural and in-situ gas S.D. Cooper, S. Akong, K.D. Krieger, A.J. Twynam, F. Waters, and R. Morrison, Abstract BP; G. BPHurst, Trinidad Consultant; and Tobago and(bpTT) B. Lanclos has been and K. Zeidani, SPE and M. Polikar, SPE, University of Alberta Abstract Laboratory investigations were conducted Myeong Noh* and Abbas Firoozabadi, SPE, Reservoir Engineering Research Institute (RERI) * now with Chevron Corporation Summary Gas-well productivity is affected by two P. Leschi, SPE, and G. Demarthon, Total E&P, and E. Davidson, SPE, and D. Abstract Clinch, ItHalliburton is well known that the use of hydrochlo A. Bond, Pioneer Natural Resources Alaska Inc., and D. Zhu and R. Kamkom, Abstract Texas Horizontal A&M U. wells provide extended contact V.U. Imeh, L. Murray, D. Lenig, and D. Robertson, BP, and M. Panda, PRA Abstract Thermal fracturing in water injectors plays K. M. Al-Naimi, SPE, B. O. Lee, SPE, K. M. Bartko, Saudi Aramco, S. K. Kelkar, Abstract SPE,Horizontal M. Shaheen, completion SPE, Z. technology Al-Jalal, Schlumbe has pro K. M. Al-Naimi, B. O. Lee, S. M. Shourbagi, Saudi Aramco, S. K. Kelkar, M. Shaheen, Abstract Horizontal Schlumberger, completion B. Johnston, technology Packer hasPlus pro Hassan Chaabouni, Schlumberger, Pierre Baux, Dasa Manalu, Muhammad Sobirin, AbstractTotal Completing E&P Indonesie, horizontalPhilippe wells with Enkababian openhole Hassan Chaabouni, Schlumberger, Pierre Baux, Dasa Manalu, Muhammad Sobirin, AbstractTotal Completing E&P Indonesie, horizontalPhilippe wells with Enkababian openhole Michael D. Erwin, SPE, ConocoPhillips Alaska, and David O. Ogbe,SPE, University Summary of Alaska The Colville Fairbanks River field represents the fi M. Kerem, SPE, Shell E&P B.V.; M. Proot, Shell GSI B.V.; and P. Oudeman,Summary SPE, ShellThis E&Ppaper B.V presents the results of a pro A.F. Harun, SPE, G. Fung, SPE, and M. Erdogmus, SPE, BP America Summary A dry tree well in the Gulf of Mexico (GO G.A. Carvajal, E. Arreaza, C. Gonz�lez, C. Cesin, M. Fern�ndez, and J.Abstract Bello, PDVSA Most ofE&P the cases in gas condensate well V. Ogoke, SPE, Shell; C. Aihevba, SPE, Petroleum Development Oman; andAbstract F. Marketz, A new SPE, costShell effective life-cycle profile cont Liang-Biao Ouyang, SPE, Chevron E&P Technology Co., and Ramzy Sawiris, SPE, Chevron Overseas Petroleum Co. Summary Production and Tubing injection profiling throug Liang-Biao Ouyang, SPE, and Dave Belanger, SPE, Chevron Corp. Summary Permanent downhole monitoring can pr

B. Sand�y, SPE, T. Tjomsland, SPE, D.T. Barton, and G.H. Daae, Statoil;Summary and E.S. Johansen, A four-zone SPE, intelligent and G.water-alternating Vold, SPE, Wea Muhammad Shafiq and Athar Ali, SPE, Schlumberger; and Haider Al-Haj, Ibrahim Abstract Obaidi, ThisMuhammad paper describes Qasim anQazi, innovative and S.M. comp M A. Chacon, SPE, J.B. McCutcheon, SPE, D.W. Schott, SPE, B. Arias, SPE, and Abstract J.M. The Wedgwood, Na Kika SPE, project BPlocated America in the deepw F.T. Alkhelaiwi, Heriot-Watt University and Saudi Aramco, and D.R. Davies, Heriot-Watt Abstract Horizontal University and multilateral completions ar E. Davila, R. Almeida, I. Vela, J. Pazos, and K. Coello, Petroamazonas;�F.Abstract Chinellato Horizontal and�O. wells Humbert, are superior Schlumberger; in productio an F. Ebadi, SPE, and D.R. Davies, SPE, Heriot-Watt U. Abstract Intelligent Well (IW) Technology improve M.A. Ali, SPE, and M. Shafiq, SPE, Schlumberger Abstract Intelligent completions have been in com F. Ebadi, SPE, and D.R. Davies, SPE, Heriot-Watt U. Abstract Intelligent Well (IW) Technology combin D.J. Goggin, M.A. Ovuede, N. Liu, U. Ozdogan, P.B. Coleman, and D.P. Meinert, Chevron Intl. E&P Co.; I. Nygard, Statoil; and J. Gontijo, Petroleo Brasileiro Nigeria Ltd. Abstract Large deepwater fields with a limited num Mohammed A. Abduldayem, SPE, Saudi Aramco, Muhammad Shafiq, SPE, Abstract Schlumberger, This paper Naderdescribes D. Al Douhan, an innovative SPE, and comp Zul E.A. Addiego-Guevara, SPE, and M.D. Jackson, SPE, Department of Earth Science Abstractand Significant Engineering, challenges Imperial remain College in the London deve L. Casas and J.L. Miskimins, Colorado School of Mines, and A. Black and S.Abstract Green, TerraTek The design and subsequent results of a h L. Casas and J.L. Miskimins, Colorado School of Mines, and A. Black and S.Abstract Green, TerraTek The design and subsequent results of a h Rouhollah Farajzadeh, SPE, Shell International Exploration and Production, and Abstract Department Foam isofwidely Geotechnology, used to divert Delft acid University or aban F. Farshbaf Zinati, R. Farajzadeh, and P.L.J. Zitha, Dept. of Geotechnology, Abstract Delft U. of We Tech. present a new 2D analysis based on t M.D. Carretero-Carralero, R. Farajzadeh, D.X. Du, and P.L.J. Zitha, Dept. of Abstract Geotechnology, In this paper Delft we U. of present Tech. a 1D and 2D ana Robert P. Sutton and Stuart A. Cox, Marathon Oil Company; James F. Lea, PLTech AbstractLLC; Critical andvelocity O. Lynn calculations Rowlan, Echometer in the formCom of

Yula Tang and W.S. (Bill) Huang, Chevron Energy Technology Company Abstract A dual-lateral well was completed in a Ch P. Oudeman, SPE, Shell Intl. E&P Abstract In depleted gas wells the produced gas r D.Orta, S. Ramanchandran, J. Yang, M. Fosdick, T. Salma, J. Long, and J. Blanchard, Abstract Continuous Baker Petrolite increase Corp., in and worldwide A. Allcorn, brownC. Werner Schinagl and Mark Denny, BP Abstract As North Sea gas fields become mature S.P.C. Belfroid, SPE, W. Schiferli, SPE, and G.J.N. Alberts, SPE, TNO Science Abstract and Industry, As reservoir C.A.M. pressures Veeken,decrease SPE, and in E. matur Biez A.V. Bondurant, SPE, B.D. Dotson, SPE, and P.O. Oyewole, SPE, BP America Abstract A common characteristic of “challeng Werner Schinagl, SPE, Steve R. Green, and Alan C. Hodds, BP, and Mark Caskie Abstract andLiquid Martinloading Docherty, in gas Baker wellsPetrolite is a phenomen B. Dotson and E. Nu�ez-Paclibon, BP America Production Company Abstract A new perspective is introduced to the pr

B. Khoshnevis, R. Rastegar Moghadam, SPE, and I. Ershaghi, SPE, U. of Southern California, and K. Larbi, SPE, and V. Villagran, SPE, Chevron Abstract Several methods for unloading water from Yula Tang, SPE, Chevron Energy Technology Company, Zheng Liang, Southwest Petroleum Institute Abstract This work presents a new dynamic model R.P. Sutton, T.K. Skinner, Marathon Oil Company; R.L. Christiansen, Colorado Summary School of AnMines; investigation and L. Wilson, into gas Centrilift carryover resu Varun Mishra, D. Zhu, and A.D. Hill, Texas A&M U., and K. Furui, ConocoPhillips Abstract In several places around the world notab E. Zuluaga and J.H. Schmidt, Chevron ETC, and R.H. Dean, Simwulf Systems Abstract Cavity completions have been widely use R. North, SPE, C.P. Lenn, SPE, and I. Stowe, SPE, Schlumberger Abstract A new processing workflow has been eng Saifon Daungkaew, Michel Claverie, Boon Cheong, Steve Hansen, Richard Leech, Abstract Mohd As the Norcost Hisham of exploration Mohd Azam, wells Edna continue Malim M. A. Mohiuddin, Schlumberger, M. M. Najem, Y. R. Al-Dhaferi, H. A. Bajunaid, Abstract Al-Khafji Sanding Joint problems Operations, areand often C. observed P. Tan, Schlu in f Kirk M. Bartko, Saudi Aramco, and Frank F. Chang, Larry A. Behrmann, andAbstract Ian C. Walton, It is well Schlumberger known that in cased-hole comple Achille Tiribelli, Giovanni Luca Minneci, and Ahmed Daoud, Groupement Sonatrach AbstractAgip, The and transition Fathi Ghodbane from completion and Ahmed to produc Dah M.I. Omar, SPE, A. Md Ali, SPE, and Z. Ali, Petronas Carigali Sdn. Bhd., andAbstract A. Parapat, Coiled SPE, tubing W. Speck, has been SPE, widely and used E. Parta, world S M. Medina, SPE, Helix RDS; G. Morantes, SPE, and J. Morales, PDVSA; and Abstract W. Guevara, Located SPE, in Eastern J. Romero, Venezuela and Y. the Gonzalez, Santa A A. Burtsev, B. Kuvshinov, E. de Rouffignac, and A.M. Mollinger, Shell Intl. E&P Abstract b.v. This paper presents an assessment of th Italo Pizzolante, Steve Grinham, Tian Xiang, and Jihong Lian, CACT Operators Abstract Group, China and Chee National KinOffshore Khong, L.A. Oil Corporation Behrmann, a( M.R.G. Bell, SPE, and J.B. Davies, SPE, Shell Intl. E&P, and S. Simonian, SPE, Abstract FloDynamic While assisting production engineers in m Cesar Gama, David Gerez, and Paul A. Babasick, SPE, Schlumberger, and Jose Abstract Piedras, Fracturing SPE, is Total an important E&P USA,technique Inc. for s Cesar Gama, David Gerez, and Paul A. Babasick, SPE, Schlumberger, and Jose Abstract Piedras, Fracturing SPE, is Total an important E&P USA,technique Inc. for s Al-Marri Faisal and Hassan Ibrahim Khalil, ADMA-OPCO, and Alan SalsmanAbstract and Majed A major Shaaban challenge Abu Lawi, identified Schlumberger by ADMA OP Ashraf Aly Abou Elnaga, Chevron San Jorge S.R.L., and Edgar Almanza, Marcelo Batocchio, Kent Folse, and Martin�Schoener-Scott, Halliburton Energy Services Inc. Abstract Chevron San Jorge S.R.L. operates in the Fergus Robinson, SPE, Sarawak Shell Berhad; Kent C. Folse, SPE, Halliburton Abstract EnergyTwo Services gas fields (M) Sdn offshore Bhd*Sarawak now employed Malayb Fergus Robinson, SPE, Sarawak Shell Berhad; Kent C. Folse, SPE, Halliburton Abstract EnergyTwo Services gas fields (M) Sdn offshore Bhd*Sarawak now employed Malayb Lang Zhan, SPE, Fikri Kuchuk, SPE, Jim Filas, SPE, Dhani Kannan, SPE, Jawaid Abstract Saeedi, Reliable SPE,estimates and Charles of post Vanperforation Petegem, dam SP Graeme Rae, Mohd. Bakri Yusof, and Juanih Ghani, Talisman, and Shahril Mokhtar Abstractand In Malaysia Jock Munro, coiled Schlumberger tubing (CT) conveyanc Emmanuel Ifediora, Charles Ibrahim, and Davis Ekeke, SPE, Addax Petroleum Development (Nigeria) Ltd.; Francis Nwaochei and Emeka Ogugua, SPE, Chevron Nigeria Ltd.; Emeka C. Ene, Sylvester Orumwese, and Kingsley Idedevbo, SPE, Oildata Wireline Services Abstract Electric line remedial work such as throug C. Han, Michael H. Du, and Ian C. Walton, SPE, Schlumberger Abstract A detonated shaped charge fired from a p Hanaey Ibrahim, SPE, and Sameer Balushi, Petroleum Development Oman,Abstract and AlanWell Salsman productivity SPE, Alvaro is driven Javier by establishing Nunez, and D.C. Atwood, SPE, W. Yang, SPE, B.M. Grove, SPE, L.A. Behrmann, SPE; Schlumberger Abstract We report Technology on a series Corp.of laboratory flow e Hanaey Ibrahim SPE, Ali Harrasi, Petroleum Development Oman, Alan Salsman, Abstract Alvaro Optimal Javierwell Nunez, productivity Haposan is achieved Situmorang; by es S P.G. Bedrikovetsky and R.P.S. Monteiro, North Fluminense State U., and J.S. Abstract Daher, The J.A.T. system Gomes, where andsulphate V.C. Amorim, scalingPetrobr dama P. Bedrikovetsky, SPE, North Fluminense State U. (LENEP/UENF); E. Mackay, Abstract SPE, Herriot-Watt Previous work U.;has R.P. derived Monteiro an analytical and F. Pa K.S. Zaki, SPE, M.D. Sarfare, SPE, and A.S. Abou-Sayed, SPE, Advantek Intl. Abstract Corp., Produced and L.R. Murray, water reinjection BP (PWRI) offer C. Nguyen, J.M. Somerville, SPE, and B.G.D. Smart, SPE, Heriot-Watt University Abstract During recent years interest in underbala Mohammad S. Al-Shenqiti, Alaa A. Dashash, Ibrahim H. Al-Arnaout, Saad M.Abstract Al-Driweesh, SaudiSaudi Aramco's Aramco, drilling andstrategy Zaki Bakhteyar, witnesse C.A. Pedroso, SPE, E.M. Sanches, and N.S. Oliveira, Petrobras, and I.J. Mickelburgh, Abstract The SPE, Campos and C.R Basin Guimaraes, in Brazil is SPE, oneSchlum of the Sakamrin Abdul-Rahman, Brunei Shell Petroleum Co. Sdn. Bhd., and Derek Abstract Lim, Jit Juan Oil and Lim,gas andproducers Kuo Chuan have Ong, long Halliburto been lo J.H. Terwogt, N.S. Hadfield, and A.A. Van Karanenburg, Sarawak Shell Berhad, Abstract and S. The Salahudin Shallowand Clastics K. King, FieldHalliburton operated Ene by S Luke F. Eaton and W. Randall Reinhardt, ConocoPhillips Co.; J. Scott Bennett, Abstract DevonConocoPhillips Energy Corp.; is and developing Kenyon Blake the Magnolia and Hu Luke F. Eaton, SPE, and W. Randall Reinhardt, SPE, ConocoPhillips; J. Scott Summary Bennett, ConocoPhillips SPE, Devon Energy is developing Corporation; the Magno Kenyo Ibrahim Refai, SPE Saudi Aramco, Anwar Assal, SPE Schlumberger, Jeremie Abstract Fould, A Schlumberger, number of theTim wells O’Rourke, reach there econom Schlum Robert D. Pourciau, Chevron Corporation Summary Extended-reach naturally perforated w Ian D. Palmer and Nigel G. Higgs, Higgs-Palmer Technologies; Robert M. Mathers & Scott R. Herman, Chevron Abstract A detailed sand prediction has been made George Gillespie, SPE, Weatherford International; Chuck Hinnant, SPE, Chris Abstract Davis, This SPE,paper and Jamie describes Schober, challenges SPE, Shell; test equ an

Neil S. Hadfield, Jan H. Terwogt, and Aart A van Kranenburg, Sarawak Shell;Summary and Sharifudin TheSalahudin Shallow Clastics and Kimberly field operated King, Hal by George Colwart, Robert C. Burton, Luke F. Eaton, and Richard M. Hodge, ConocoPhillips Abstract ConocoPhillips Co., and Kenyon is developing Blake, Schlumberg the Magnolia George Colwart, SPE, Robert C. Burton, SPE, Luke F. Eaton, SPE, and Richard Summary M. Hodge, ConocoPhillips SPE, ConocoPhillips is developing Company, the Magno an I.O. Yahaya, A. Opusunju, B. Ajaraogu, G. Agbogu, O. Williams, and C. Uchendu, Abstract SPDC; Alpha and field M. is Udeh, situated T. Oyetade, in SPDC’s and M.OM Ba Brian T. Wagg, SPE, and Jonathan L. Heseltine, SPE, C-FER Technologies,Abstract and Abraham Several T.operators Faga, SPE, have andrecently Howardlaunched L. McKi 0 0 Kevin Whaley, Colin Price-Smith, Allan Twynam, and David Burt, BP Exploration Abstract Ltd.,Initial and Phillip Open Jackson, Hole Gravel Baroid Pack (OHGP) co

Yula Tang, W.S. (Bill) Huang, Chevron Energy Technology Company Abstract Open-hole Gravel packing is increasingly B.V. Loureiro, UCL - Faculdade do Centro Leste, J.V.M. de Magalh�es, SPE, Abstract M.V.D. Horizontal Ferreira,Open A. Calderon, Hole Gravel SPEPack and A.L. (HOHG Ma B.V. Loureiro, UCL-Faculdade do Centro Leste, and�J.V.M. de Magalhaes, Abstract SPE, A.L. Horizontal Martins,Open SPE, hole and gravel A. Calderon, pack isSPE, the c Matthew Law, George W. Chao, Hafeez Ab Alim, and Elsamma Samuel, Schlumberger Abstract The Well major Services, trend of and completion Aziz Ejan,method Abdul Ha in Kevin Whaley, Colin Price-Smith, Allan Twynam, and David Burt, BP Exploration Abstract Ltd.,Initial and Phillip Open Jackson, Hole Gravel Baroid Pack (OHGP) co Ina H. Stroemsvik, Kjell Tore Nesvik, SPE, Frode Vik, and Karin Stene, StatoilHydro, Abstract and WellMohamed Heidrun A-45 Ridene, located SPE,inand theDaniele Norweg A. Zanchi, Stogit; G. Ripa, M. Colombo, and G. Ferrara, SPE, Eni E&P; and E. Abstract Belleggia, OneR.ofBarbedo, the majorR.�Illuminati, challenges in undergrou J. Rezen M. Tolan, BG Group, and R.J. Tibbles, J. Alexander, P. Wassouf, L. Schafer,Abstract and M. Parlar, Openhole Schlumberger gravel packing is one of the mo Mark Banman, Eric Delattre, Muhammad Sofyan, and Siswara Suryadana, Total Abstract E&P Stacked Indonesiagravel-packs involve limited tech P. Puyo and A. Bourgeois, Total Austral, and A. Penno and A. Oliveira, Halliburton Abstract Energy TOTAL Services AUSTRAL Inc. operates the Carina a Samyak Jain, SPE, Rajesh Chanpura, SPE, Renato Barbedo, and Marcos Moura, Abstract SPE, Gravel Schlumberger packing has routinely been used E.P. Ofoh and M.E. Wariboko, Nigerian Petroleum Development Co., F.E. Uwaifo Abstract and A M.large Parlar, majority Schlumberger of the recent deepwate Mingqin Duan, Stefan Miska, Mengjiao Yu, Nicholas Takach, and Ramadan Ahmed,SPE, University of Tulsa; and Claudia Zettner, SPE, ExxonMobil Summary Effective removal of small sand-sized s F. Lavoix, P. Leschi, and E. Aubry, Total E&P, and L. Quintero, X. Le Prat, and Abstract T. Jones, ThisBaker paperHughes documents Drilling a novel Fluids engineerin Samyak Jain, SPE, Raymond Tibbles, and Jock Munro, SPE, Schlumberger,Abstract Rajeswary Cased-hole Suppiah and gravel Norhisham packing Safin, is commonly SPE, P Shahryar Saebi, SPE, Samyak Jain, SPE, Raymond Tibbles, SPE, and Jock Abstract Munro, SPE, Cased-hole Schlumberger, gravel packing and Rajeswary is commonly Supp I. Palmer and N. Higgs, Higgs Technologies, and I. Ispas, K. Baksh, and K. Abstract Krieger, BP The X-1 well in a gas field in Trinidad wa J. S. Andrews, SPE, H. Bj�rkesett, SPE, J. Djurhuus, StatoilHydro; I. C. Walton, Abstract SPE, Gj�a D. C.isAtwood, an oil and SPE, gasJ.field Heiland, located SPE, off B G. Navaira, SPE, Chevron; M. Hupp, T. Palisch, SPE, CARBO Ceramics Inc; J. Renkes, SPE, PropTester, Inc Abstract Offshore completions in the Gulf of Mexic S. Wibawa, S. Kvernstuen, Schlumberger, and A. Chechin, J. Graham, and K.R. Abstract Dowling, This Apache paper presents Energy the first installation o M.R. Wise and R.J. Armentor, Chevron, R.A. Holicek, B.R. Gadiyar, M.D. Bowman, R.A. Jansen, and S.N. Krenzke, Schlumberger Abstract Screenless sand control completions pro M.R. Wise and R.J. Armentor, Chevron, R.A. Holicek, B.R. Gadiyar, M.D. Bowman, AbstractR.A. Screenless Jansen, and sandS.N. control Krenzke, completions Schlumbe pro B. Vidick, SPE, S. James, SPE, and B. Drochon, SPE, Schlumberger Abstract The search for a cost-effective alternative David Underdown, SPE, Chevron; Henky Chan, SPE, Chevron Pacific Indonesia Summary The Duri field in Sumatra Indonesia sh J.D. Holmes and M.P. Tolan, BGEPIL, and C. Hale, BJ Services Abstract The stacked sands of the South Tapti fie M.A. Addis, SIEP, M.C. Gunningham, SEIC, Ph. Brassart, SEIC, J. Webers, Abstract SEIC, H.Sand Subhi, Quantification SEIC, J.A. Hother, involves Proneta predicting th G. Petit, H. Foucault, and A. Iqbal, Total E&P Abstract Wells in the Girassol field offshore Angol G. Servant, IFP; P. Marchina, Total S.A.; and Y. Peysson, E.�Bemer, and Abstract J.-F. Nauroy, Allowing IFP sand to be produced is widely k J. Skufca and J. Li, BJ Services Company Abstract Cleaning Reach Wells sand fill With outConcentric of large diameter Coiled Tu d N. Morita, Waseda U., and G.-F. Fuh and B. Burton, ConocoPhillips � Abstract Sand flow models have been succe M.C. Gunningham, SPE, Sakhalin Energy Investment Company; M.A. Addis,Abstract SPE, Shell This International paper is a case E&P;and studyJ.A. which Hother, describ SP K. Qiu, SPE, Schlumberger; Y. Gherryo and M. Shatwan, SPE, AGOCO, Libya; Abstract R. Marsden, Sand production J. Alexander, fromand the A. Sarir Retnanto, field becam SP G.-F. Fuh, I. Ramshaw, K. Freedman, and N. Abdelmalek, ConocoPhillips, and Abstract N. Morita, Using Waseda two field U.case examples this pape K. Qiu, J.R. Marsden, J. Alexander, and A. Retnanto, Schlumberger, and O.A. This Abdelkarim paper wasand also M.presented Shatwan, as SPE, SPE�100948 Agoco K. Qiu, J.R. Marsden, J. Alexander, and A. Retnanto, Schlumberger, and O.A. This Abdelkarim paper wasand also M.presented Shatwan, as SPE, SPE�100948 Agoco Ahmed Abulsayen and Abdulwahab Enneamy, VEBA (Libya), and Kaibin Qiu,Abstract Rob Marsden, This paper Joe described Alexander,a and caseMuhammad study involve S Ahmed Abulsayen and Abdulwahab Enneamy, VEBA (Libya), and Kaibin Qiu,Abstract Rob Marsden, This paper Joe described Alexander,a and caseMuhammad study involve S Bailin Wu, SPE, and Chee P. Tan (Now with Schlumberger Oilfield Support Sdn Summary Bhd.), SPE, It is commonly CSIRO Petroleum, acknowledged and Ning in theLu, petC Bailin Wu, SPE, and Chee P. Tan (Now with Schlumberger Oilfield Support Sdn Summary Bhd.), SPE, It is commonly CSIRO Petroleum, acknowledged and Ning in theLu, petC

Hans Vaziri, BP America; Robbie Allam, Gordon Kidd, Clive Bennett, and Trevor Summary Grose,Factors BP plc;and Peter mechanisms Robinson, BP leading Australia; to san Hans Vaziri, BP America; Robbie Allam, Gordon Kidd, Clive Bennett, and Trevor Summary Grose,Factors BP plc;and Peter mechanisms Robinson, BP leading Australia; to san

Xiaojun Cui and R. Marc Bustin, U. of British Columbia Summary The production rates of coalbed gas we Alireza Nouri, SPE, Dalhousie University; Hans Vaziri, SPE, BP-America Inc.;Summary and Hadi Belhaj, Installing SPE, sand and control M. Rafiqul in longIslam, horizonta SPE Alireza Nouri, SPE, Dalhousie University; Hans Vaziri, SPE, BP-America Inc.;Summary and Hadi Belhaj, Installing SPE, sand and control M. Rafiqul in longIslam, horizonta SPE Abdullah Kasim, SPE, Petronas Carigali; and Frank Wijnands, SPE, and Surej Summary Subbiah,Although SPE, Schlumberger the stacked reservoirs of the B M. Vazir and L.G. Acosta, BP Abstract This paper provides a case study of an in Alireza Nouri, Dalhousie U.; Hans Vaziri, BP plc America Inc.; and Hadi Belhaj Summary and Rafiqul ThisIslam, paperDalhousie introducesU.a predictive tool t

Alireza Nouri, Dalhousie U.; Hans Vaziri, BP plc America Inc.; and Hadi Belhaj Summary and Rafiqul ThisIslam, paperDalhousie introducesU.a predictive tool t P.J. van den Hoek, SPE, and M.B. Geilikman, SPE, Shell Intl. E&P B.V. Abstract Most sand production prediction models J. Heiland, SPE, and M.E. Flor, Schlumberger Abstract During production of hydrocarbons the f B. Wu, SPE, CSIRO Petroleum; Nulwhoffal Arselan Mohamed, SPE, Petronas Abstract Research This&paper Scientific presents Services a geomechanical Sdn. Bhd.; C.P. stu S. Dyer, Scaled Solutions; K. Orski and C. Menezes, Total E&P U.K. Ltd.; S.Abstract Heath and Lead C. MacPherson, zinc and iron Clariant; sulphide and scales C. are Simp k Niall Fleming, SPE, Kari Ramstad, SPE, Synn�ve H. Eriksen, SPE, ErlendSummary Moldrheim, Oseberg SPE, and S�r Thomas field Rudberg operatedJohansen by Hydro Turhan Yildiz, SPE, Colorado School of Mines Summary In this study the available methods and K. Furui* , D. Zhu**, and A.D. Hill**, University of Texas at Austin * now with ConocoPhillips Summary Using ** anow combination with Texas ofA&M analytical University calcul Hisham A. Nasr-El-Din, SPE, Saudi Aramco, and Mathew Samuel, SPE, Schlumberger Summary Viscoelastic Well Services surfactant systems are use G. Zaeff and C. Sievert, SPE, ConocoPhillips, and O. Bustos, SPE, A. Galt, SPE, Abstract D. Stief, The goal SPE,ofL.anTemple, acid fracture SPE, and treatment V. Rodrig is t M. Pournik, C. Zou, C. Malagon Nieto, M.G. Melendez, D. Zhu, and A.D. Hill,Abstract Texas A&M TheU., effects and X. of Weng, acid solutions Schlumberger injected into G. Zaeff and C. Sievert, SPE, ConocoPhillips, and O. Bustos, SPE, A. Galt, SPE, Abstract D. Stief, The goal SPE,ofL.anTemple, acid fracture SPE, and treatment V. Rodrig is t J. Ricardo Solares, SPE, J.J. Duenas, SPE, Moataz Al-Harbi, SPE, Abdulaziz Abstract Al-Sagr,Acid SPE, fracturing Saudi Aramco, has been Venkateshwaran an integral part R o J. Ricardo Solares, SPE, Moataz Al-Harbi, SPE, Abdulaziz Al-Sagr, SPE, andAbstract Ricardo Acid Amorocho, fracturing SPE, hasSaudi beenAramco, an integral andpart Ve Chuck Zeiler, SPE, David Alleman, and Qi Qu, SPE, BJ Services Summary Viscoelastic-surfactant (VES) -based di David Barclay, SPE, and Iain Trodden, SPE, Halliburton, and Robbie Allam, SPE, Abstract and This Alastair paper Chisholm, presentsBP the prejob engineeri Bernhard Lungwitz, SPE, Chris Fredd, SPE, Mark Brady, SPE, and Matthew Miller, SPE, Schlumberger; Syed Ali, SPE and Kelly Hughes, SPE, ChevronTexaco Summary A self-diverting-acid based on viscoelas M.A.P. Albuquerque, SPE, Schlumberger; A.G. Ledergerber, SPE, Chevron; and C. Smith, SPE, and A. Saxon, SPE, Schlumberger Abstract Between December 2003 and February M.S. Newman, Chevron Australia Pty. Ltd., and�M.M. Rahman, SPE, The University of Adelaide Abstract The success of a stimulation technique is H.A. Nasr-El-Din, SPE, A.A. Al-Zahrani, SPE, F.O. Garzon, SPE, C.A.F. Giraldo, Summary SPE, I.M. Acid-fracturing Al-Hakami, treatments SPE, H.M. are Al-Marri, used com SPE M.A.P. Albuquerque, SPE, Schlumberger; A.G. Ledergerber, SPE, Chevron;Abstract and C. Smith, Between SPE, December and A. Saxon, 2003 SPE, and February Schlumb B. Lungwitz, SPE, Schlumberger; R. Hathcock, SPE, K. Koerner, SPE, D. Byrd, Abstract SPE, and The M. Maca� Gresko,formation SPE, Devon (Cretaceous Energy Cor ag Hai Liu, SPE, Chad Coston, and Mohamed Yassin, SPE, Schlumberger; Shahab Summary Uddin,Effective SPE, Kuwait matrix Gulf acidizing Oil Company; in Kuwait’ and Fa Yin-Chong Yong and Karim Saaikh, Brunei Shell Petroleum; Joao Queiros, Yan Abstract Song,Improving and Surasak oil and Srisa-ard, gas production Well Services from the Br H.A. Nasr-El-Din, SPE, and M. Zabihi, SPE, Saudi Aramco, and S.K. Kelkar,Abstract SPE, andInM. treating Samuel, sour SPE, water Schlumberger injectors in carbon R. Arangath, SPE, Schlumberger; K.W. Hopkins, Aral Petroleum Capital; D. Abstract Lungershausen, Stimulation Zhaikmunai of carbonate LLP;reservoirs and N.T. Bolysp is ofte F.F. Chang, SPE, Schlumberger; H.A. Nasr-El-Din, SPE, Texas A&M University; Abstract and Hydrochloric T. Lindvig and acid X.W. is the Qiu,most Schlumberger commonly u Surajit Haldar, SPE, Ahmed A. Al-Jandal, SPE, Saad M. Al-Driweesh, Mufeed Abstract H. Al-Eid, TheSPE, Uthmaniyah Saudi Aramco; field is one Venkateshwaran of the bigges M. Asadi, ProTechnics; G.S. Penny, CESI Chemical; B.R. Ainley, Chandler Engineering; Abstract A group D.J. Archacki, of industryWeatherford; experts haveF.compiled Bas va Rafael Rozo, SPE, and Javier Paez, Petrominerales; Alberto Mendoza, SPE,Abstract Ecopetrol; The and Caballos Arthur Milne, formation SPE, is Diego thick laminated Soler, SP Rafael Rozo and Javier Paez, Petrominerales; Alberto Mendoza, Ecopetrol; and Abstract Arthur The Milne Orito and field Diego in the Soler, southSchlumberger of Colombia w Frank F. Chang and Xiangdong Qiu, Schlumberger, and Hisham A. Nasr-El-Din, Abstract SaudiThe Aramco purpose of matrix treatments in carb D. Oussoltsev, I. Fomin, K.K. Butula, and K. Mullen, SPE, Schlumberger, andAbstract A. Gaifullin, The A. majority Ivshin,ofD.oilSenchenko, exploited from andRussian I. Faizu V. Kumar, SPE, V. Bang, SPE, G.A. Pope, SPE, and M.M. Sharma, SPE, U. of Texas at Austin, and P.S. Ayyalasomayajula, SPE, and J. Kamath, SPE, Chevron Abstract Significant productivity loss occurs in gas Murtaza Ziauddin, SPE, and Emmanuel Bize, SPE, Schlumberger Abstract Most carbonate reservoirs are heterogen Liang Jin and Paul Wong, Shell Intl. E&P, and Brent Sinanan, BJ Services Co. Abstract Malaysia is a significant gas producer and

O. Vazquez, M. Singleton, SPE, and K.S. Sorbie, SPE, Heriot-Watt U., and R. Abstract Weare,This SPE,paper Bakerdescribes Petrolite a sensitivity study o L.P. Moore, SPE, and H. Ramakrishnan, SPE, Schlumberger Abstract Restimulation of existing wells represents K. Hughes and N. Santos, SPE, Chevron, and R.E. Arias and S.V. Nadezhdin, SPE, Schlumberger Well Services Abstract Historically carbon dioxide (CO2)–foam O. Bustos, Y. Chen, M. Stewart, K. Heiken, and T. Bui, Schlumberger, and P.Abstract MuellerCO2 and E. based Lipinski, fluidsSaga are commonly Petroleum used to f K. Hughes and N. Santos, SPE, Chevron, and R.E. Arias and S.V. Nadezhdin, Abstract SPE, Schlumberger Historically carbon Well Services dioxide (CO2)–foam S.A. Utegalyev and S.K. Duzbayev, KazMunaiGas RD, and K. Kulbatyrov and Abstract S.V. Nadezhdin, Well stimulation SPE, Schlumberger techniques like hydraul Vishal Bang, SPE, Gary A. Pope, SPE, and Mukul M. Sharma, SPE, The University AbstractofDuring Texasproduction at Austin; Jimmie from gas R.condensate Baran Jr., 3M re Myeong Noh* and Abbas Firoozabadi, RERI *currently with Chevron Corporation Summary Liquid blocking in some gas-condensate Mohan K.R. Panga and�Suzylawati Ismail, Schlumberger Well Services;�Pascal Abstract Water Cheneviere, blocks Total;�and and condensate Mathew drop out Samu n Mohan K.R. Panga and�Suzylawati Ismail, Schlumberger Well Services;�Pascal Abstract Water Cheneviere, blocks Total;�and and condensate Mathew drop out Samu n Majdi Al Mutawa, Bader Al Matar, SPE, and Abdulaziz Abdulla Dashti, SPE, Kuwait AbstractOilDual Company, completed andwells Redha�Kelkouli, producing fromSPE the George Aggrey* and David Davies, Heriot-Watt University, UK Abstract Value addition via real-time reservoir mon Mark F. Barrilleaux and Thomas A. Boyd, BP Abstract Smart completions that can remotely con Mark F. Barrilleaux and Thomas A. Boyd, BP Abstract Smart completions that can remotely con Xiuli Wang and Knut Hovem, BP; Daniel Moos, GMI; and Youli Quan, Stanford Abstract University Water hammer effects resulting from the M. Jamiolahmady, P. Ghahri, O.E. Victor, and A. Danesh, Heriot-Watt U. Abstract: The performance of a horizontal (highly s Ron Day, Ramsey Fisher, SPE, and Louise Jacobsen Plutt, SPE, BP America Abstract Inc., and AsNesny capitalPardo, costs SPE, continue Segun to escalate Jebutu, SPE in th Douglas Boyd, Salah Al-Kubti, Osama Hamdy Khedr, Naeem Khan, and Kholoud Abstract Al-Nayadi, Two classes ZADCO; (sonic Didier andDegouy, ultrasonic) ADMA-OP of cem Douglas Boyd, Salah Al-Kubti, Osama Hamdy Khedr, Naeem Khan, and Kholoud Abstract Al-Nayadi, Two classes ZADCO; (sonic Didier andDegouy, ultrasonic) ADMA-OP of cem

ul acid stimulation campaign was conducted in 2004 in Brunei Shell Petroleum (BSP). This paper discusses what have been done differently 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 al nature of carbonate rocks makes acidizing an effective matrix stimulation technique. Acid dissolves carbonates at high reaction rate to cre al Submersible Pump (ESP) a form of artificial lift technology has proven to be a durable solution for delivering the required rates from Sau owered jet pumps (FPJP) were pioneered for use in Kuparuk Field wells on the North Slope of Alaska. Unlike conventional surface powered

of improved Oil Recovery in mature fields is almost inevitable. However the method applied in the IOR process is dependent on the econom Gas industry is often faced with the challenge of selecting an optimal Artificial Lift method for a well in the midst of various artificial lift type ch pletions for SAGD1 producers are unique. Conventional gas lift valves and mandrels with a packer completion cannot be used due to the ext or high-temperature electric submersible pump (ESP) systems is growing as the oil industry matures. Canada's nonconventional oil reserves ystems are now being considered of extreme importance as the reserves across the globe are depleting and the wells are unable to flow nat l cleanup during well start-up ensures efficient formation damage removal and maximises the resulting well production potential. Horizontal w from conventional wells to horizontal and then multi-lateral) in well architecture for maximising reservoir contact have been paralleled by adv ndan gas recycling project is located north of Australia in the East Timor Sea and is designed to produce 1 100 MMscf/D of wet gas strip ou outlines and discusses the issues surrounding the TOTAL AUSTRAL Carina and Aries field development project and the engineering issues

r explores multiple completion options in gas/condensate reservoirs with compositional simulations. Besides intelligent-well completion (IWC and Tobago (bpTT) has been developing highrate gas fields in Trinidad & Tobago since 1999 and has six high rate gas fields currently on p hevskoye oil field development started in 1995. In 2002 by the time when all the designed vertical wells had been drilled practically all the re e northeast Brazil Manati field is located in the Camamu Bay with water depths less than 50 m. The sandstone gas reservoirs in this field hav n well multiple zone completion systems applied in marginal wells in Los Perales Oil Field located in the Gulf of San Jorge Basin Santa Cruz od of completing multiple-layer formations has been successfully tested in the United States and Canada. This new method places sliding sle a mature oil field with depleted reservoir pressure supported by an aquifer in the deeper Cretaceous horizon. The Cartojani structure is loca Niger Delta clastic environment horizontal well completions have been widely used with success. Although conventional wells have been app r discusses the effects of Ca2+ Mg2+ and Fe2+ on inhibitor retention and release. Better understanding of phosphonate reactions during in presents the results of an investigation of the design of production tubing string setting depths in gas wells to optimize gas recovery in wells t presents the results of an investigation of the design of production tubing string setting depths in gas wells to optimize gas recovery in wells t

servoir in the Greater Burgan field is a thin carbonate reservoir containing light oil in a 10-20 ft target zone with “good porosity.� Matri servoir in the Greater Burgan field is a thin carbonate reservoir containing light oil in a 10-20 ft target zone with “good porosity.� Matri Minghuazhen is a shallow-water delta-plain sedimentary-deposit reservoir sand in Bohai Bay China. It has relatively heavy oil in place that is presents an advanced control method for online regulation of downhole Interval Control Valves (ICVs) to achieve optimal production via chok describes a case-study detailing planning completion testing and production of the first Maximum Reservoir Contact (MRC) Multilateral (M acement efficiency in hydrocarbon formations is often caused by the natural variation in the mobility of fluids across the reservoir strata. Histo r describes a case study that details the planning completion testing and production of the first maximum reservoir contact (MRC) multilate oped an operational strategy for commingled production with infinitely variable inflow control valves (ICVs) using sequential linear programmin r of multilateral gas producers drilled in the Ghawar field has significantly increased over the past few years as part of the reservoir developm ing technology is moving towards maximum reservoir contact (MRC) by means of extended-reach horizontal and multilateral wells in all type stimulation treatments based on alcohol to remove liquid blockage or condensate banking in the near well zone date from sixties. Among th injection on the Shell Bonga field offshore Nigeria is accomplished via a network of subsea flowlines and 15 subsea injection wells. Maximizi rol devices which prevent early water breakthrough by passively controlling the inflow profile of a well have had a long and successful histo few field installations of a dual-electric submersible-pump (DESP) completion have been reported. In general the purpose of the second pum few field installations of a dual-electric submersible-pump (DESP) completion have been reported. In general the purpose of the second pum ball Field is a one Tcf gas condensate development offshore Trinidad producing at a sustained rate in excess of 800 MMcf/D from three wel of the increasing emphasis on reducing operating costs and minimizing deferred production a new system was designed for perforating well

statistical methodology using survival analysis (SA) was developed and applied to electrical submersible pump (ESP) system performance d statistical methodology using survival analysis (SA) was developed and applied to electrical submersible pump (ESP) system performance d proved to be effective and economical in underbalanced operations (UBO) and is gaining wider applications in many areas. It provides the d

is a relatively simple and cost-effective well completion technique for horizontal wells. However fluid flow into a slotted-liner completion is qu uring has been a successful method to stimulate the Khuff Carbonate wells of Saudi Arabia since the beginning of the gas development prog eld located on the North Slope of Alaska was developed using open-hole horizontal completions drilled along the maximum principle stress a eld located on the North Slope of Alaska was developed using open-hole horizontal completions drilled along the maximum principle stress a r details the results for 33 propped-fracture treatments in low-porosity zones in the South Arne (SA) field Danish North Sea. To date seven h ry purpose of surfactants used in stimulating sandstone reservoirs is to reduce surface tension and contact angle and provide leakoff control rizontal lateral Bakken dolomite play began in 1999 in eastern Montana more than 330 wells have been permitted and more than 200 wells hydraulic fracturing in various risky" oil reservoirs has been the biggest challenge for fracturing engineers in the Western Siberia basin as a s ng has been part of Saudi Aramco’s gas development strategy to maximize productivity from for vertical wells in the Khuff carbonates ov describes successful implementation of degradable fiber-laden fluids for hydraulic fracturing in one of the largest oilfield in Western Siberia. P iscusses the application of fibers for the Frac and Pack application for Brunei Shell Petroleum (BSP). Seven wells with a total of seventeen f ds are usually surfactants or cosolvents added to stimulation treatments to reduce capillary pressure and water blocks. As the gas reservoirs y has been conducted on the effect of formation Young’s modulus and in situ stress on hydraulic fracture height containment in layered

Mexico (GOM) hydrocarbon discoveries reaching record depths and very high bottomhole pressures the need for proven weighted fracturin reservoir development continues at a record pace in North America. Additionally reservoir pressure depletion and declining quality of reserve elds produce larger quantities of water operators and service companies find themselves challenged with disposing flowback and produced d design for hydraulic fracturing is of great importance especially with the growing demand for this method as a means of production enhanc he success of a tight-gas field development program in a fluvial environment is to understand the reservoir’s deliverability and what the o s a pervasively used completion technique in wells targeting high permeability poorly consolidated and depleted sandstone formations locate ve pay of the low permeability Ryabchyk formation in the mature fields of Western Siberia is separated from underlying water zones by a we has become a viable and important option for completing horizontal wells. There are many fracturing processes and methods to consider for years horizontal well technology evolved in the Middle East field development strategies becomes favored over vertical and deviated wells o 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 n scenario in many mature oilfields is to have most of the wells producing hydrocarbons with high water cuts. These wells are commonly not ca hasn’t escaped the general industry trend of finding reserves in ever challenging environments. Complex geology and low permeabilit Africa offshore fields are maturing and operators are completing secondary targets in their wells to maintain the economic operation of their v key strategies in Saudi Aramco’s optimum gas development project is drilling single and multilateral wells to achieve maximum reservoir erations are extremely expensive because of the operational environment and the necessary infrastructure. In this environment emphasis is d System, Executed from a Supply Vessel; Black Sea Offshore y and multiphase flow effects in hydraulic fractures have been well documented in the last several years. The pressure losses caused by thes

y and multiphase flow effects in hydraulic fractures have been well documented in the last several years. The pressure losses caused by thes y and multiphase flow effects in hydraulic fractures have been well documented in the last several years. The pressure losses caused by thes one of ONGC’s major brownfields discovered in 1983 and located in Gujarat. The Field produces approximately 30 000 bopd and is on d presents the results of an investigation of the design and analysis of the boundary-dominated flow production performance of a vertically frac idespread proliferation micro-seismic fracture mapping it has been observed that some naturally fractured formations exhibit a non planar o y of hydraulic fracturing work in Russia is being done in the Western Siberian basin where operators and service companies have gathered s acturing of horizontal wells in shale gas reservoirs is now an established commercially successful technique.� The evolution of the compl od of completing multiple layer wells has been successfully tested in the Piceance basin for Petrogulf Corporation. This new method placed s hod of completing multiple-layer tight gas wells is being investigated. The main concept is to place sliding sleeve valves in the casing string engineers have faced the problem of hydraulic fracturing in soft rock formations for many years. However existing programs used with soft ro ic Surfactant (VES) fluids are polymer-free fluids that generate viscosities suitable for fracturing operations without the use of polymer addit rbon dioxide- (CO2-) emulsified viscoelastic surfactant (VES) fluid system has recently been used to improve the Olmos production in the C discusses the selection criteria design methodology and analysis of hydraulic fracturing treatments pumped using a solids-free liquid CO2 f

Generation Viscoelastic Fluid: Successful Case Histories in West Venezuela

uction in mature fields is a common situation.� In many mature areas every barrel of oil is being produced with six to ten barrels of water. ective of hydraulic fracturing in tight formation gas reservoirs is the creation of “effective fracture length.� The creation of effective frac

drilling program on North Raguba field in Libya has been suspended since the current well’s performance in this area was not promising ance of fracturing treatments has been an issue for over fifty years and considerable effort has been devoted to improve its prediction perfor resents the process of candidate well selection design execution and evaluation that lead to the successful implementation of acid fracturin cumented in the literature that hydraulic fracture treatments although successful often underperform: Frac and Pack completions exhibit pos cumented in the literature that hydraulic fracture treatments although successful often underperform: Frac and Pack completions exhibit pos eservoirs gas well production after hydraulic fracturing (HF) is often greatly impaired through various mechanisms by invasion of fracturing

cumented in the literature that hydraulic fracture treatments although successful often underperform: Frac and Pack completions exhibit pos c hydraulic fracture monitoring is having a major impact in how wells are being completed in tight sand reservoirs.� This existing technolo impairment in tight-gas formations is a typical phenomenon for fractured wells. Processes responsible for this behavior are related to the cha errors in the calculated azimuth and other parameters of a monitored fracture can be caused by not performing accurate borehole deviation reports on a study conducted to assist with field development in the Jonah Field in Wyoming. Microseismic and surface tiltmeter fracture map lity Formations cally fracture a well requires large investments in equipment horsepower materials and manpower.� An engineer can be overwhelmed w fracturing treatment fracture conductivity is created by differential etching of the fracture surface by the acid; without nonuniform dissolution lization of Hydraulic fracturing in West Siberia and the increase of job size over the recent year can impact the field development strategy. Th adioactive tracers have been used in combination with standard industry logging tools to gain valuable insight about the fracture height (near f our research is on a remote oilfield in western Siberia currently in the initial stages of development. There are two producing horizons of Ju ere are many proven ways of predicting productivity in hydraulically fractured wells in medium-permeability oil reservoirs there is still no sim s carried out to forecast the productivity of a hydraulically fractured well in a retrograde gas-condensate sandstone reservoir using a numer stribution at the tip of a hydraulic fracture is a key element for controlling fracture propagation. In low-permeability formations under downhol ght carbonate formations in Saudi Arabia are ideally suited for acid fracturing treatments. Various types of acids such as regular in-situ gelle presents the results of an investigation of the design and analysis of low conductivity fractures. The mathematical model used in this work is

microseismic array was utilized to perform hydraulic fracture diagnostics during stimulation of the Chevron Skinner Ridge (SR) #698-22-1 well mic imaging of a hydraulic-fracture stimulation showed significant fracture reorientation across a thrust fault. Fracture orientations were identi etion plays a critical role in the performance of a well in its entire life. More and more advanced well completion options are available for pote wback is an extremely important phenomenon in hydraulic fracturing technology and may cause severe problems for well completion. Variou the propagation of an orthogonal fracture and reopening along the initial fracture during a refracture treatment is studied by taking into accou al problem arises in enhancing oil recovery and is relevant to hydraulic fracturing process and subsequent frontal displacement of fluids from cturing is one of the most common well stimulation techniques. Hence considerable amount of efforts has been devoted to study their perfo ooded reservoir hydrocarbon recovery optimization is impacted by well spacing and hydraulic fracture extent. An excessive fracture length m summarizes part of the results of an investigation of fracture clean-up mechanisms undertaken under a Joint Industry Project active since th summarizes part of the results of an investigation of fracture clean-up mechanisms undertaken under a Joint Industry Project active since th

documents the utilization of fracpack completion technology for water injectors in sand control environments.� This paper is a look back a s a deepwater project located in Malaysia. The development plan for this field requires fifteen water injectors eighteen producers and one g acturing plays a very important role in these mature and complex geology fields located onshore northeast Brazil – Carm�polis and Siriz ng the hydraulic fracture path have been observed in mapping of mined fractures and attempts have been made to reproduce their effects on halk Research (JCR) initiative is set up by a group of operators and partners in the Southern North Sea. The objective of the initiative is to inc cturing is one of the most common well stimulation techniques for gas-condensate reservoirs. In recent years considerable effort has been d 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 raulic fracturing has been successfully applied in tight gas reservoir development. Economic completion of tight gas sands with large hydrau Series articles are general descriptive representations that summarize the state of the art in an area of technology by describing recent deve

rease in gas inflow due to gas coning and the resulting bean-back because of Gas to Oil Ratio (GOR) constraints can severely limit oil produ auto natural and in-situ gas lift all refer to artificial lift systems that use gas from a gas-bearing formation to gas lift a well. The gas lift gas is and Tobago (bpTT) has been developing highrate gas fields in Trinidad & Tobago since 1999 and has six high rate gas fields currently on p nvestigations were conducted to examine the effectiveness of heavy oil-in-water emulsion in plugging the near wellbore matrix thereby reduc

roductivity is affected by two distinct mechanisms: liquid blocking and high-velocity flow in two-phase flow. The former has been studied exte own that the use of hydrochloric acid to clean up and restore permeability of open holes drilled in limestone formations is a questionable pro ells provide extended contact with the reservoir and have unique advantages over vertical wells in many applications. As nominally horizonta cturing in water injectors plays a large role in controlling and determining injectivity. Vertical wells cannot always deliver the required rates to s ompletion technology has progressed dramatically over the last six years with the latest technical barriers being eclipsed with open-hole tech ompletion technology has progressed dramatically over the last six years with the latest technical barriers being eclipsed with open-hole tech horizontal wells with openhole sections or non-cemented liners is a common practice. This type of openhole wells is preferred to maximize re horizontal wells with openhole sections or non-cemented liners is a common practice. This type of openhole wells is preferred to maximize re e River field represents the first widespread and successful application of horizontal openhole completions on the North Slope of Alaska and r presents the results of a project that was initiated to analyze the inflow performance and inflow distribution of one smart and two problemati well in the Gulf of Mexico (GOM) has been producing oil with more than 50% water cut. This raises a concern because the existing Anti-Agg cases in gas condensate wells produce below dew point pressure generating a saturated zone in liquid that blockage the gas flow efficiency t effective life-cycle profile control completion system has been developed to solve major problems associated with surveillance and interventio

Conveyed Workover Operation t downhole monitoring can provide valuable information for production decisions in real time without the need to perform an intervention to c

e intelligent water-alternating-gas (WAG) injector was installed at the Statoil Veslefrikk Field in the North Sea in May 2004. The completion in describes an innovative completion solutions with reservoir monitoring and control completion technologies that allows commingled oil produ project located in the deepwater Gulf of Mexico is a unique development which ties-back six small to medium-sized oil and gas fields to the nd multilateral completions are a proven superior development option compared to conventional solutions in many reservoir situations. How wells are superior in production and recovery to conventional wells however they are subjected to early water coning towards the heel (water Well (IW) Technology improves well and field performance management by combining zonal production control using Interval Control Valves ompletions have been in commercial use for over ten years. Application of intelligent completions technology has evolved from intervention-l Well (IW) Technology combines zonal production control using Interval Control Valves (ICVs) together with installation of appropriate flow m

water fields with a limited number of wells may require intelligent well systems to maximize production capacity under facility constraints. Agb describes an innovative completion solution with state-of-the-art reservoir monitoring and control completion technologies that allows commin challenges remain in the development of optimized control techniques for intelligent wells particularly with respect to properly incorporating th and subsequent results of a hydraulic fracturing test performed on a large block of high modulus and low permeability rock (Colton sandston and subsequent results of a hydraulic fracturing test performed on a large block of high modulus and low permeability rock (Colton sandston ely used to divert acid or abandon the high permeable layers. In this type of application foam should considerably reduce gas mobility. The n a new 2D analysis based on the recently developed stochastic bubble population foam model focusing on the effect of the core heterogenei we present a 1D and 2D analysis of foam development in porous media based upon a new stochastic bubble population foam model and pr city calculations in the form of charts or simple equations are frequently used by field personnel to evaluate a gas well’s flowing condition

al well was completed in a Chevron subsea condensate field with high peak rate. Within one year the production significantly declined with h gas wells the produced gas rate and consequently the velocity will drop to the extent that produced liquids are no longer carried to surface. T increase in worldwide brown-field activity and overall depletion of current gas fields has renewed focus on maximizing gas production from e a gas fields become mature significant production losses are increasingly caused by liquid loading. The reservoir energy is insufficient to tra pressures decrease in maturing gas wells liquid drop-out forms an increasing restriction on gas production. Even though virtually all of the w characteristic of “challenging unconventional gas resources namely low permeability sands shale and coal bed methane is that the ultim ng in gas wells is a phenomenon that increasingly limits production in mature gas wells where reservoir pressures are insufficient to lift liquid pective is introduced to the problem of liquid loading in gas wells. Gas wells cease producing as reservoir pressure depletes and gas velocity

thods for unloading water from gas wells have been used in the industry. These methods commonly have a combination of the following cha

esents a new dynamic model to describe the plunger motion by considering the changes of the tubing and casing pressures liquid accumula gation into gas carryover resulting from the downward flow of water was conducted. Water accumulation in a gas well is responsible for wellaces around the world notably the North Sea and the Middle East carbonate reservoirs are being accessed with very long horizontal wells (2

letions have been widely used to increase productivity from non-conventional sources such as coalbed methane reservoirs and “heavy o essing workflow has been engineered to combine reservoir deliverability defined by production logging (PL) measurements with nodal analy of exploration wells continue to escalate we need more than ever to evaluate each well quickly and efficiently to improve the appraisal proce blems are often observed in fields after a period of relatively smooth operation. These occurrences usually coincide with an increase in deple own that in cased-hole completions productivity is enhanced by maximizing shaped charge penetration and shot density while minimizing per on from completion to production often requires the well to be killed immediately after perforation is completed thus exposing the formation t g has been widely used worldwide to perform perforating and zonal isolation operation due to the ability in intervening highly deviated and lon astern Venezuela the Santa Ana Field is part of the most important gas province of Venezuela: Anaco District. Its main productive zones are presents an assessment of the performance of a horizontal well completed by limited-entry perforation (LEP) technique based on reservoir nal Offshore Oil Corporation (CNOOC) Chevron and ENI the field operator are partners in the development of the HZ oil and gas fields op ting production engineers in managing the perforating process Shell recognized the need for an engineering software tool to guide and advis an important technique for stimulating production in low-permeability formations and requires special consideration in designing the preced an important technique for stimulating production in low-permeability formations and requires special consideration in designing the preced lenge identified by ADMA OPCO is the time delay and subsequent lost�production between a well being completed with the drilling rig un

n Jorge S.R.L. operates in the Loma Negra area and El Trapial field located in the Neuqu�n Basin Argentina. El Trapial wells are charact elds offshore Sarawak Malaysia are characterised by heavily karstified carbonate reservoirs.� These reservoirs are typified by significant elds offshore Sarawak Malaysia are characterised by heavily karstified carbonate reservoirs.� These reservoirs are typified by significant imates of post perforation damage skin are important for designing remedial solutions and productivity enhancement operations. Underbalan coiled tubing (CT) conveyance is used to optimize underbalanced perforating especially for rig-related operations. Well trajectory temperatu

remedial work such as through tubing perforation has been successfully carried out in most vertical/deviated wells. However in high angle/h shaped charge fired from a perforating string or perforating gun will not only perforate its targets but also possibly cause excessive damage ivity is driven by establishing a clean connection through the near wellbore zone of drilling and completion induced permeability impairment c n a series of laboratory flow experiments comparing the productivity of perforations created with reactive liner charges against those created productivity is achieved by establishing a clean connection to the wellbore through the near wellbore zone of drilling and completion induced where sulphate scaling damage occurs is determined by two governing parameters: the kinetics coefficient characterising the velocity of che ork has derived an analytical model for simultaneous flow of incompatible waters in porous media with sulphate salt precipitation determine water reinjection (PWRI) offers an efficient and effective means of disposing of the PW waste stream and provides an opportunity for a wate nt years interest in underbalanced drilling (UBD) has grown rapidly. As a drilling technique it has gained acceptance because it provides a m co's drilling strategy witnessed a change in the last few years by drilling horizontal and extended reach maximum reservoir contact (MRC) we s Basin in Brazil is one of the most challenging areas for completions in the world due to the lack of formation consolidation the large percen producers have long been looking for effective sand control methods that allow completion flexibility and improved productivity throughout a w Clastics Field operated by Sarawak Shell targets two shallow gas-bearing reservoirs H1 and H2 at approximately 2 650 ft true vertical de ps is developing the Magnolia field with a Tension Leg Platform (TLP) in 4 674 ft of water at Garden Banks block 783 in the Gulf of Mexico. T illips is developing the Magnolia field with a tension-leg platform (TLP) in 4 674 ft of water at Garden Banks Block 783 in the Gulf of Mexico. the wells reach there economical production limit and are consequently abandoned or mothballed until viable solutions are available to enha reach naturally perforated water-injection frac-pack producing completions and frac-pack producing selective completion interventions wer

and prediction has been made for three wells at Chevron’s West Seno field based on logs/lab data and the results have been calibrated escribes challenges test equipment test program and results in the development of a screen product and contingency fluid-loss control (FL

llow Clastics field operated by Sarawak Shell primarily targets two shallow gas-bearing reservoirs H1 and H2 at approximately 2 650 ft true ps is developing the Magnolia field with a tension leg platform (TLP) in 4 674 ft of water at Garden Banks block 783 in the Gulf of Mexico. Th illips is developing the Magnolia field with a tension leg platform (TLP) in 4 674 ft of water at Garden Banks Block 783 in the Gulf of Mexico. s situated in SPDC’s OML 22 in the eastern part of the Niger delta belt some 60kM NW of Port Harcourt. The field discovered in 1986 c rators have recently launched a new industry-wide initiative on sand control reliability. The aim of the initiative is to gain a better understandin

Hole Gravel Pack (OHGP) completions that have been installed in Greater Plutonio to date have all achieved complete annular packs and ze

Gravel packing is increasingly becoming a standard practice in the deep-water subsea completion environment. A Chevron offshore gas res pen Hole Gravel Pack (HOHGP) is the conventional sand control technique for offshore non consolidated reservoirs in Brazil. Gravel pack p Open hole gravel pack is the conventional sand control technique for offshore non consolidated reservoirs in Brazil. Gravel pack placement re rend of completion method in offshore reservoirs with sand control requirement is Horizontal Open Hole Gravel Packing (OHGP).� Thoug Hole Gravel Pack (OHGP) completions that have been installed in Greater Plutonio to date have all achieved complete annular packs and ze n A-45 located in the Norwegian Sea was completed in an unconsolidated sandstone reservoir that required sand control. The lower zone w major challenges in underground gas storage wells in Italy is to maximize the sand layers exposure by drilling slanted or sub-horizontal wells ravel packing is one of the most popular completion techniques due to its high reliability along with the ability to deliver high-productivity well 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 king has routinely been used as a sand control method in open-hole horizontal wells. With the advances in drilling technology in recent years ajority of the recent deepwater developments in West Africa require sand control applications. Openhole gravel packing is the preferred sand

emoval of small sand-sized solids is critical for successful drilling and completion operations in sand reservoirs. Recent experience in extend ocuments a novel engineering approach and the operational methodology used to achieve high efficiency remediation on two offshore applic e gravel packing is commonly utilized to control sand production from oil and gas wells. The success of a cased-hole gravel-pack job depend gravel packing is commonly utilized to control sand production from oil and gas wells. The success of a cased-hole gravel-pack job depends ell in a gas field in Trinidad was designed to be a high-rate gas producer from a 65� deviated well through the S1U S1L and S2U sands a n oil and gas field located off the Norwegian Coast that is due to be developed with subsea infrastructure tied back to a floating production fa

mpletions in the Gulf of Mexico must typically address sand control. Our industry has made significant progress with respect to sand control e presents the first installation of nozzle-based passive inflow control devices (ICD) for Apache Corporation in Australasia. This recent technolo

sand control completions provide a cost-effective means of completing wells in the Gulf of Mexico by eliminating the need to have a rig on lo sand control completions provide a cost-effective means of completing wells in the Gulf of Mexico by eliminating the need to have a rig on lo for a cost-effective alternative to screens has been intensive in the sand control field. Different systems have been proposed in the past incl

eld in Sumatra Indonesia shown in Fig. 1 and operated by Chevron Pacific Indonesia (CPI) is one of the largest onshore steamflood opera d sands of the South Tapti field have presented completion challenges from field start-up in 1997 to the present-day. A large part of these ch fication involves predicting the volumes of sand which can be produced at the sandface completion and transported to the surface facilities f 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 ells With Concentric Coiled Tubing Vacuuming Technology low models have been successfully applied to heavy oil reservoirs .1 2 3 However when these models are applied to light oil and gas reserv s a case study which describes how Quantitative Risk Assessment (QRA) is applied to sand management in the specific case of Lunskoye ction from the Sarir field became a major concern for AGOCO at the end of the 1980s when ESPs were introduced to the field. The sanding s eld case examples this paper presents our current well construction and completion design analysis based on the following approach: (1) ca presented as SPE�100948 at the 2006 SPE International Oil & Gas Conference and Exhibition in China held in Beijing 5-7 December 200 presented as SPE�100948 at the 2006 SPE International Oil & Gas Conference and Exhibition in China held in Beijing 5-7 December 200 escribed a case study involved an investigation in a field in Libya where massive unexplained fill had been reported accompanying obstructi escribed a case study involved an investigation in a field in Libya where massive unexplained fill had been reported accompanying obstructi only acknowledged in the petroleum industry that water cut increases sand-production risk and a number of possible mechanisms have bee only acknowledged in the petroleum industry that water cut increases sand-production risk and a number of possible mechanisms have bee

nd mechanisms leading to sanding are described within an integrated-rock and soil-mechanics framework.� While the conventional sandin nd mechanisms leading to sanding are described within an integrated-rock and soil-mechanics framework.� While the conventional sandin

ction rates of coalbed gas wells commonly vary significantly even in the same field with similar reservoir permeability and gas content. The c sand control in long horizontal wells is difficult and particularly challenging in offshore fields. It is therefore imperative to make decisions with sand control in long horizontal wells is difficult and particularly challenging in offshore fields. It is therefore imperative to make decisions with he stacked reservoirs of the Bokor field offshore Sarawak Malaysia are prone to sand production the field-development team did not opt a rovides a case study of an intervention effort which returned to production three wells that had been on extended shut in two subsea and on r introduces a predictive tool that forecasts the drawdown associated with the onset of sanding as well as it predicts the sanding rate in real t

r introduces a predictive tool that forecasts the drawdown associated with the onset of sanding as well as it predicts the sanding rate in real t production prediction models to date have the capability to indicate whether initial sand production may take place during the lifetime of a res duction of hydrocarbons the formation is subjected to increasing levels of effective stress resulting from the reduction in pore pressure. In presents a geomechanical study on the potential of wellbore instability and sand production for a multi-field gas development in offshore Pen and iron sulphide scales are known to be particular issues with gas production fields particularly those producing from HP/HT reservoirs.� S�r field operated by Hydro Oil & Energy is situated 130 km west of the Norwegian coast on the eastern flank of the Viking Graben structu dy the available methods and software to predict the well productivity and total skin factor in fully perforated vertical wells have been reviewe ombination of analytical calculations and 3D finite-element simulation we have developed a comprehensive skin-factor model for perforated h ic surfactant systems are used in the industry for several applications. Initially the application was focused on low-friction and solids-suspens an acid fracture treatment is to generate a highly conductive pathway of sufficient length from the reservoir to the wellbore. Depth of penetrat of acid solutions injected into hydraulic fractures created in carbonate formations can be assessed at the laboratory scale in acid fracture co an acid fracture treatment is to generate a highly conductive pathway of sufficient length from the reservoir to the wellbore. Depth of penetrat ng has been an integral part of Aramco’s gas development strategy for the vertical wells in the Khuff carbonates over the last several yea ng has been an integral part of Aramco’s gas development strategy for the vertical wells in the Khuff carbonates over the last several ye ic-surfactant (VES) -based diverting products have been used successfully in matrix acidizing in the Gulf of Mexico (GOM) in recent years.ï¿ presents the prejob engineering process and executional summary of the first North Sea application of a novel tubing-conveyed fracturing tec

rting-acid based on viscoelastic surfactant (SDVA) has been successfully used recently on numerous stimulation treatments of carbonate fo

ecember 2003 and February 2005 eight wells were stimulated in Tengiz field in Kazakhstan using a viscoelastic diverting acid system to eva

s of a stimulation technique is often measured by its stimulation ratio. This paper however presents a novel way of calculating the value tha uring treatments are used commonly to enhance the productivity of carbonate formations with low-permeability zones. Various forms of hydro ecember 2003 and February 2005 eight wells were stimulated in Tengiz field in Kazakhstan using a viscoelastic diverting acid system to eva ¿½ formation (Cretaceous age Campos Basin Brazil) is predominantly an oolitic and oncolitic grainstone and packstone limestone with a b matrix acidizing in Kuwait’s horizontal openhole wells is a big challenge. Reservoir heterogeneity and the length of the horizontal wells ma il and gas production from the Brown Fields is now more important than ever to the operating companies as the oil price remains record hig our water injectors in carbonate formations in Saudi Arabia sulfide scavenging prevention of sulfur and iron sulfide precipitation is a major of carbonate reservoirs is often considered a routine operation. When the reservoirs are thick (more than 200 m) the stimulation process is m acid is the most commonly used acid for carbonate acidizing due to its low cost and high dissolving power. However there are two major dr iyah field is one of the biggest sub fields and older producing sections in the giant Ghawar structure. A few wells have been dead for sometim ndustry experts have compiled their years of experiences in developing a new technical standard to measure stimulation and gravel-pack flui os formation is thick laminated sandstone with less than 10% of total clays and permeability ranging from 20 mD to as high as one Darcy.� ld in the south of Colombia was initially put on production in 1969 and has produced continuously since then. The most prolific reservoir is th e of matrix treatments in carbonate reservoirs is to increase connectivity of a formation with the wellbore in the entire zone of interest. Succe y of oil exploited from Russian oilfields today comes from the Volga-Urals and Western Siberian basin where large-scale fracturing and coile

productivity loss occurs in gas-condensate wells when the bottom hole flowing pressure drops below the dewpoint pressure. The decline in p nate reservoirs are heterogeneous at multiple-length scales.� These heterogeneities strongly influence the outcome of acid stimulation tre a significant gas producer and LNG exporter within Asia-Pacific region. Many of the country’s gas fields are offshore carbonate reservoir

describes a sensitivity study on the main factors affecting a polymeric Relative Permeability Modifier (RPM) treatment in the near wellbore re n of existing wells represents a vast underexploited resource. A successful refracturing treatment is one that creates a fracture having highe

carbon dioxide (CO2)–foamed fracturing fluids were used to stimulate wells in the Waltman field in Wyoming—due to the low formation p fluids are commonly used to fracture stimulate formations with low reservoir pressure as well as formations that are more sensitive to water t carbon dioxide (CO2)–foamed fracturing fluids were used to stimulate wells in the Waltman field in Wyoming—due to the low formation p lation techniques like hydraulic fracturing which can involve large financial investments call for a basin- or reservoir-specific approach to m uction from gas condensate reservoirs significant productivity loss occurs after the pressure near the production wells drops below the dew p

cking in some gas-condensate reservoirs is a serious problem when the permeability is low (for example of the order of 10 md or less). The s and condensate drop out near the wellbore in a gas reservoir can cause rapid production decline. The liquid (water/condensate) is trapped s and condensate drop out near the wellbore in a gas reservoir can cause rapid production decline. The liquid (water/condensate) is trapped ted wells producing from the mature carbonate formation in northern Kuwait are encroached by injected water from adjacent wells presentin on via real-time reservoir monitoring and optimisation is one of the main drivers for the increasing implementation of intelligent (I-)well comple pletions that can remotely control the flow from multiple layers of a reservoir interval were introduced in the mid 1990’s. Downhole flow-co pletions that can remotely control the flow from multiple layers of a reservoir interval were introduced in the mid 1990’s. Downhole flow-co mer effects resulting from the shutting in of water injection wells are an often ignored issue in petroleum production operations but they have c mance of a horizontal (highly slanted) well (HW) or a slanted well (SW) is generally believed to be better than that of a vertical well (VW) due osts continue to escalate in the deepwater environment there is greater pressure on operators to deliver wells in a more efficient manner. Th (sonic and ultrasonic) of cement bond log tools are run in tandem as part of ZADCO’s standard cement evaluation program. The effecti (sonic and ultrasonic) of cement bond log tools are run in tandem as part of ZADCO’s standard cement evaluation program. The effecti

ses what have been done differently best practices and learning. What is different in this campaign from previous ones? Detailed design oducing light sweet oil from an Albian age reservoir buried between 3100m and 3400m TVD. In order to access reserves located in the south arbonates at high reaction rate to create flow channels (wormholes"). The high reaction rate often needs to be reduced to allow wormholes to elivering the required rates from Saudi Aramco fields. Therefore this form of artificial lift was selected to increase production rate from one o Unlike conventional surface powered jet pumps these pumps are hydraulically powered by a prolific producing upper zone called the C sand

process is dependent on the economics and value of the method. In the Southern Offshore area of Chevron operations there are huge cost e midst of various artificial lift type choices. These challenges become more complex with increasing dynamic changes in well characteristic pletion cannot be used due to the extreme temperatures of the downhole environment. Most lift gas enters the production stream downhole v nada's nonconventional oil reserves are estimated at just over 1 trillion barrels andOnePetro Suncor's heavy oil reserves in northern Alberta Canada g and the wells are unable to flow naturally. Over the years a number of artificial lift techniques have evolved as a result of extensive research well production potential. Horizontal wells are more susceptible than vertical wells to formation damage due to the longer completion length contact have been paralleled by advances in completion equipment development of OnePetro both Passive" Inflow Control Devices (ICDs) and "Active e 1 100 MMscf/D of wet gas strip out 110 000 B/D of condensate/LPG initially reinject 950 MMscf/D of lean gas and later export up to 700 nt project and the engineering issues addressed to facilitate achieving the project goals of producing gas at high rates from the shallow uncon

ides intelligent-well completion (IWC) options included commingling two reservoirs of contrasting conductivity (permeability-thickness produc six high rate gas fields currently on production with several more in planning stages. All of the wells require sand control and this has resulte had been drilled practically all the reserves of the main reservoirs within the production targets were put into production. There emerged a ne dstone gas reservoirs in this field have net pays with a thickness greater than 300 m and an average true vertical depth (TVD) of 1 400 m. T Gulf of San Jorge Basin Santa Cruz province Argentina. The field is fully operatedOnePetro by Repsol-YPF. OnePetro The paper narrates the challenge and e a. This new method places sliding sleeve valves in the casing string and completes the well with normal cementing operations. The sliding sl rizon. The Cartojani structure is located in the central alignment of the Moesic Platform. It is a monocline with large dimensions and low laye gh conventional wells have been applied to drain reservoirs in Niger-Delta extensively in recent years horizontal wells have also gained acc g of phosphonate reactions during inhibitor squeeze treatments has direct implication on how to design and improve scale inhibitor squeeze lls to optimize gas recovery in wells that produce free liquids in conjunction with the gas.� Particularly important in this work has been the lls to optimize gas recovery in wells that produce free liquids in conjunction with the gas.� Particularly important in this work has been the

one with “good porosity.� Matrix permeability is low and natural fracture density can be quite variable in this reservoir.� Thus this re one with “good porosity.� Matrix permeability is low and natural fracture density can be quite variable in this reservoir.� Thus this re has relatively heavy oil in place that is high in viscosity. With the understanding thatOnePetro horizontal or multilateral profiled wells are the most favora achieve optimal production via choke performance management. A Generalized Predictive Controller (GPC) has been shown to be capable ervoir Contact (MRC) Multilateral (ML) and Smart Completion (SC) deployment in Ghawar Field.� The well was drilled and completed as uids across the reservoir strata. Historically completions with cemented casing packers conformance controlling fluids/gels and selective p um reservoir contact (MRC) multilateral (ML) and smart completion (SC) deployment in Ghawar Field Saudia Arabia. A well was drilled and s) using sequential linear programming (SLP). The optimization algorithm requires instantaneous and derivative information. We propose a w ars as part of the reservoir development strategy OnePetro to maximize well productivity through maximum reservoir contact. Although these wells are ontal and multilateral wells in all types and shapes. Horizontal and Multilateral applications become more commonplace to improve the well p well zone date from sixties. Among the proposed mechanisms to explain the enhancement in gas effective permeability and also the higher d 15 subsea injection wells. Maximizing water injection volume is an important economic OnePetro objective OnePetro for Bonga. Water injection is used for main have had a long and successful history in the Norwegian Sector of the North Sea and in Saudi Arabia.�This paper will document the first neral the purpose of the second pump was either to increase the pumping capacity or to act as a backup to improve the reliability of the pu neral the purpose of the second pump was either to increase the pumping capacity OnePetro or to act as a backup to improve the reliability of the pu xcess of 800 MMcf/D from three wells. The completion design selected was 7 inch production tubing with an open-hole gravel pack. The initi em was designed for perforating wells lifted with electrical submersible pumps (ESPs). The purpose of this project was to develop and apply

e pump (ESP) system performance data. The approach extracts unbiased information OnePetro from performance data and permits lifetime modeling e pump (ESP) system performance data. The approach extracts unbiased information from performance data and permits lifetime modeling ions in many areas. It provides the desired flexibility in controlling pressure profile and equivalent circulating density (ECD). However the kn

w into a slotted-liner completion is quite complicated due to three dimensional flow convergence around slots and limited open-to-flow areas. ginning of the gas development program. Various types of acid systems including conventional emulsified and surfactant-based have been u along the maximum principle stress and dominant fault orientation (northwest/southeast). Open-hole completions were considered the best c along the maximum principle stress and dominant fault orientation (northwest/southeast). Open-hole completions were considered the best c Danish North Sea. To date seven horizontal wells (2900 m total vertical depth [TVD]) have been completed using 100 tip screenout (TSO) act angle and provide leakoff control. However many of these chemicals adsorb rapidly OnePetro within the first few inches of the sandstone formatio n permitted and more than 200 wells are now producing. The lateral play began in Richland County Montana and the success there is now a s in the Western Siberia basin as a significant number of the oil-bearing formations in the basin are located near a water zone. These hydrau rtical wells in the Khuff carbonates over the last several years. During acid fracturing the wormholes created by the reaction with the formatio e largest oilfield in Western Siberia. Placement advantage of fiber-assisted fluid already becomes obvious after initial campaign of four fractu even wells with a total of seventeen fracturing treatments in this study are on a multilayered unconsolidated formation where sand control is d water blocks. As the gas reservoirs being stimulated become tighter the perceived value of these additives has grown. This value must be acture height containment in layered formations. It has been well documented that in situ stress contrast is the dominant parameter controllin

e need for proven weighted fracturing stimulation fluids has become urgent. As previous studies have shown frac packs have a significant letion and declining quality of reserves have resulted in escalating drilling completion and workover costs per unit of gas produced. This in th disposing flowback and produced water to reduce costs handling the logistics of getting enough water to hydraulically fracture the well as od as a means of production enhancement from tight gas reservoirs. The first optimum fracture design (OFD) approach which maximizes w voir’s deliverability and what the optimum fracture half-length is as a function of geological setting and stress state.� The application an depleted sandstone formations located in Bachaquero T�a Juana and Lagunillas fields in West Venezuela. This technique combines stim from underlying water zones by a weak stress barrier. Operating and service companies alike applied various techniques to prevent the brea cesses and methods to consider for placement fractures. Optimization of the completion process including the number and size of fractures red over vertical and deviated wells offering the advantage of maximized reservoir contact higher production rates and better access to rese resent one of the main gas producers in Argentina. The completion programs of Aguada Pichana wells imply the stimulation of Middle Mulic cuts. These wells are commonly not considered as good candidates for matrix stimulation. Water based treating fluids would enter preferen Complex geology and low permeability are the common denominator in today’s environment. Developing reserves under these conditions tain the economic operation of their valuable assets. Large quantities of reserves can OnePetro be foundOnePetro in low permeability consolidated formations wells to achieve maximum reservoir contact to maximize well productivity. This strategy has proven very successful over the past few years ure. In this environment emphasis is placed on high-efficiency OnePetro operations based on specially tailored solutions combining available resources OnePetro The pressure losses caused by these phenomena are accepted widely to be of great significance in most gas-well completions in the United

The pressure losses caused by these phenomena are accepted widely to be of great significance in most gas-well completions in the United The pressure losses caused by these phenomena are accepted widely to be of great significance in most gas-well completions in the United pproximately 30 000 bopd and is on decline. A joint team from ONGC and Schlumberger carried out a rigorous process of candidate selectio ction performance of a vertically fractured well located in a closed rectangularly bounded reservoir.� The solution for dimensionless produ ed formations exhibit a non planar or complex set of micro seismic events. This fracture OnePetro mapping technique has provided some valuable ins d service companies have gathered significant amount of experience and knowledge. The sweeping success of hydraulic fracturing in Weste ique.� The evolution of the completion technique has reached the point that numerous OnePetro stimulation OnePetro stages through multiple perforation clus orporation. This new method placed sliding sleeve valves in the casing string and completed the well with normal cementing operations. The ng sleeve valves in the casing string and complete the well with normal cementing operations. The sliding sleeves would then be opened on r existing programs used with soft rock formations often do not provide satisfactory treatment designs. Difficulties emerge because hydrauli ons without the use of polymer additives.�VES fluids do not form polymer filter-cake and thus viscous resistance of the fluid flowing thro prove the Olmos production in the Caterina SW field in Texas. The reservoir is characterized OnePetro by thin streaks of pay with potential water pro mped using a solids-free liquid CO2 foam-based visco-elastic surfactant (VES) fluid system in Morrow Sand reservoirs located in Southeast N

uced with six to ten barrels of water. The production of water results in increased operating OnePetroexpenses along with other water related well pro gth.� The creation of effective fracture length requires that sufficient fracture conductivity be developed to allow effective fracture fluid clea

mance in this area was not promising. Well Raguba E-97 in this area was not producing OnePetro even several attempts such as acidizing re-perforati voted to improve its prediction performance. However the effect of cleanup in tightOnePetro gas-condensate reservoirs where fracturing considered a ssful implementation of acid fracturing treatment in Marrat field. The acid fracturing treatment is quite challenging due to presence of high pre rac and Pack completions exhibit positive skin values and traditional hydraulic fracture completions show discrepancies between the placed rac and Pack completions exhibit positive skin values and traditional hydraulic fracture completions show discrepancies between the placed mechanisms by invasion of fracturing fluid (FF) into OnePetro the matrix and fracture and poor cleanup efficiency. In the last four decades fracture face

rac and Pack completions exhibit positive skin values and traditional hydraulic fracture completions show discrepancies between the placed eservoirs.� This existing technology is being utilized in new and innovative ways to provide operators a clearer picture of the fracture deve or this behavior are related to the characteristics of the porous media and are induced OnePetro as a consequence of the fracturing process. Fracture rforming accurate borehole deviation surveys for hydraulic fracture monitoring (HFM) and neglecting the effects of the deviating borehole traj mic and surface tiltmeter fracture mapping was performed on ten wells in two areas of the field and over 100 fracture treatments were mappe

An engineer can be overwhelmed with the selection of completion fluids perforation strategy and treatment size as well as coordination of f acid; without nonuniform dissolution along the fracture face the fracture will close after pumping ceases and little lasting conductivity will be act the field development strategy. The correct estimation of the fracture dimension is critical to maximize the recovery factor of heterogeneo nsight about the fracture height (near-wellbore vertical coverage) of proppant-packed fractures. The existing tracer technology has a number here are two producing horizons of Jurassic age OnePetro with a shale barrier in between them and variable oil/water contact (OWC). Each new well of ity oil reservoirs there is still no simple practical production forecasting methodology for hydraulically propped fracturing stimulations for th sandstone reservoir using a numerical model. The fracture was explicitly modeled as a set of high-conductivity cells. At the gas velocities meability formations under downhole reservoir conditions a severe pressure drop occurs at the tip of the fracture and a lag zone develops d of acids such as regular in-situ gelled and emulsified acids have been used in order to achieve optimum fracture length and conductivity. A hematical model used in this work is a practical alternative to estimate the degree of stimulation by means of a Stimulation Index (SD) and fo

n Skinner Ridge (SR) #698-22-1 well Williams Fork Formation (Late Cretaceous) Garfield County western Piceance Basin western Colora ault. Fracture orientations were identified through a combination of alignment of event locations polarization of the seismic waves and inject pletion options are available for potential deployment in new wells especially thoseOnePetro in deep water and offshore; however the cost could vary problems for well completion. Various models have been developed to predict the onset of proppant flowback but the physics of the phenom atment is studied by taking into account the production induced stress field surrounding the initial fracture. It is shown that the propagation pr nt frontal displacement of fluids from subterranean environment. Entrapment of residual fluid by the displacing one lowers down the displace has been devoted to study their performance under different prevailing conditions. Description OnePetro OnePetro of hydraulically fractured wells using the existin xtent. An excessive fracture length may lead to an earlier than desired increase in water cut. Uncertainty in propped fracture dimension is rela a Joint Industry Project active since the year 2002. It is well documented in the literature that hydraulic fractures although successful often a Joint Industry Project active since the year 2002. It is well documented in the literature OnePetro that hydraulic fractures although successful often

ents.� This paper is a look back after five years of operation.� It includes a review OnePetro of the goals of the project and issues that occurred d ctors eighteen producers and one gas injector to be completed in more than 4 300 ft of water depth. In order to maintain the oil production t ast Brazil – Carm�polis and Sirizinho Fields – on the revitalization of the oil production. The purpose of this work is to demonstrate the n made to reproduce their effects on fracture growth using numerical hydraulic fracture models. Such offsets have long been recognized as The objective of the initiative is to increase the ultimate recovery in their respective chalk assets to 60%. Analyzing the different production t years considerable effort has been directed towards understanding of flow around hydraulically fractured wells especially for tight gas reserv The field is producing principally from a Devonian age carbonate reservoir this limestone formation having an average porosity of 8 to 12% a of tight gas sands with large hydraulic fracturing treatments requires cost effective and time saving operations. Traditional large fracturing jo technology by describing recent developments for readers who are not specialists in the topics discussed. Written by individuals recognized

onstraints can severely limit oil production and reservoir drive energy. In this paper we will use a coupled reservoir-well model to demonstrat on to gas lift a well. The gas lift gas is produced downhole and bled into the production tubing via an auto gas lift valve designed for gas oper six high rate gas fields currently on production with several more in planning stages. All of the wells require sand control and this has resulte e near wellbore matrix thereby reducing gas (and water) coning or eliminating gas leakage to the surface. Experiments at micro- and macro

w. The former has been studied extensively recently but the understanding of the latter is limited. High-velocity gas flow in single phase has 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 y applications. As nominally horizontal wells get longer and follow more complicated trajectories wellbore hydrodynamics becomes an impor always deliver the required rates to support offtake and achieve voidage replacement. Thus horizontal wells are often selected to provide be rs being eclipsed with open-hole technology. These completions have allowed multiple zones to be fractured and the benefits of utilizing ope rs being eclipsed with open-hole technology. These completions have allowed multiple zones to be fractured and the benefits of utilizing ope hole wells is preferred to maximize reservoir productivity. Some questions that always come up for this type of wells are: will it be necessary hole wells is preferred to maximize reservoir productivity. Some questions that always come up for this type of wells are: will it be necessary ons on the North Slope of Alaska and one of the first in the world. The purposes of this paper are to examine why this completion technique ion of one smart and two problematic conventional long and tortuous horizontal wells in Brunei. Following a detailed hydraulic analysis of th ncern because the existing Anti-Agglomerants Low Dosage Hydrate Inhibitor (AA LDHI) used during extended shutdowns and cold restarts hat blockage the gas flow efficiency to the well. Not only is the gas well productivity affected by fluid but also velocity. The conventional theor ated with surveillance and interventions in horizontal and TAML level 2 multilateral OnePetro wells completed with ESP. As fields age and produced w

need to perform an intervention to collect data. One of the commercial permanent monitoring technologies is the fiber-optic DTS which can

h Sea in May 2004. The completion includes one on/off and three variable downhole chokes for controlling injection rate into each of the four ies that allows commingled oil production from multi-laterals wells in Shaybah inside expandable liner.Slim intelligent completions technology medium-sized oil and gas fields to the world's second deepest permanently moored production facility. Production from 12 subsea wells in w ns in many reservoir situations. However they are still susceptible to coning toward the heel of the well despite their maximizing of reservoir water coning towards the heel (water can breakthrough anywhere in the well not only at the heel due to permeability (K) variation and proxim control using Interval Control Valves (ICVs) with the installation of flow monitoring devices. The “Added Value for an IW is dependent o ology has evolved from intervention-less completion for sub-sea wells to new applications where intelligent completions are delivering better w with installation of appropriate flow monitoring devices to improve well and field performance management. Zonal flow control can maximise

apacity under facility constraints. Agbami field a highly-dipping reservoir with many producing zones and few wells will use an intelligent wel tion technologies that allows commingled oil production from quad laterals wells in Abqaiq field. Many intelligent completions wells have bee h respect to properly incorporating the impact of reservoir uncertainty. Most optimization methods are model-based and are effective only if w permeability rock (Colton sandstone) are presented. The focus of this experimental study was to assess the effects of discontinuities on hy w permeability rock (Colton sandstone) are presented. The focus of this experimental study was to assess the effects of discontinuities on hy siderably reduce gas mobility. The nature of the gas and the surfactant may influence foaming behavior and thus the efficiency of the foam. on the effect of the core heterogeneity. In the frame of the model presented in a parent paper in the conference we assume that the bubble bubble population foam model and provide a detailed experimental validation. We present systematic experiments consisting of the co-inject ate a gas well’s flowing conditions to determine if the well is experiencing liquid loading problems. Literature detailing the critical velocity n

roduction significantly declined with high water-cut. The well was shut down and then brought back to production observing much reduced fl ds are no longer carried to surface. The liquids accumulate in the well bore increasing the sand face pressure. This further reduces the inflo on maximizing gas production from existing wells. In most gas wells water and/or condensate OnePetro is produced along with gas. In mature gas we reservoir energy is insufficient to transport liquid particles to surface liquid falls back and builds up a hydrostatic column in the wellbore that tion. Even though virtually all of the world’s gas wells are either at risk of or suffering from liquid loading the modeling of liquid loading b nd coal bed methane is that the ultimate recovery is dependent on economic removal of liquids accumulation generally termed “deliquif pressures are insufficient to lift liquids out of wellbores. Various technologies to artificially lift liquid associated with gas production exist how ir pressure depletes and gas velocity decreases. Below the critical rate liquids cannot be lifted from the wellbore and instead settle to the bo

e a combination of the following characteristics: a) they use external energy b) they use consumables and c) they restrict gas production. T

nd casing pressures liquid accumulation liquid fallback and the resistance force to the plunger. The characteristics of the tubing and casing in a gas well is responsible for well-productivity decline and left untreated will eventually result in the well loading up and ceasing to produce ssed with very long horizontal wells (2000 to 20 000 feet of reservoir section.) These wells are often acid stimulated to remove drilling fluid filt

methane reservoirs and “heavy oil from weakly consolidated formations. In the 1990s the technique was applied to conventional wells wh PL) measurements with nodal analysis evaluation. This allows the effects of various OnePetro completion modifications to be quantitatively modeled ciently to improve the appraisal process and avoid unnecessary expenditure. At the same time an accurate reservoir characterization is the k ally coincide with an increase in depletion water cut or changes in the artificial lift mechanism used to produce the hydrocarbon. Sanding is d nd shot density while minimizing perforation damage.� However in tight carbonate reservoirs creating deep and clean perforations may s pleted thus exposing the formation to potentially damaging kill fluid. To obtain a perforation tunnel with maximum productivity this transition in intervening highly deviated and long section of horizontal wells under live condition where slickline and E-line have difficulties. This pape District. Its main productive zones are the Merecure and San Juan formations which are sandstones characterized by their high permeabilitie LEP) technique based on reservoir and well simulation of a typical HVO reservoir e.g. Peace River field and theoretical calculations. The is pment of the HZ oil and gas fields operating as the CACT Operators Group (CACT) in the South China Sea. The HZ fields are stacked thin ering software tool to guide and advise them.� It needed to address selecting the optimum perforating system for given well and formation onsideration in designing the preceding perforating job. Aligning the perforations along the direction of maximum geological stress known as onsideration in designing the preceding perforating job. Aligning the perforations along the direction of maximum geological stress known as ing completed with the drilling rig until it is acid�stimulated using a multi purpose barge and put on production. Some wells in�ADMA O

gentina. El Trapial wells are characterized by stratified shallow- to medium-depth reservoirs with permeabilities of 35md to 85md and poros reservoirs are typified by significant porosity and permeability heterogeneities such that large fluid loss zones are commonly encountered wh reservoirs are typified by significant porosity and permeability heterogeneities such that large fluid loss zones are commonly encountered wh enhancement operations. Underbalanced perforating (UBP) which is widely used in well completions induces transient fluid flow that provide operations. Well trajectory temperatures and fluids can create uncertainties on both depth control and the accuracy of hydrostatic cushion b

iated wells. However in high angle/horizontal wells it has become a major undertaking due to inability of the gravity-assisted electric line to c so possibly cause excessive damage or swell to its carrier. Comprehensive understanding of the post-perforating conditions of the perforator on induced permeability impairment commonly referred to as the “near wellboreOnePetro damaged zone. This connection through the damaged zo liner charges against those created with conventional liner charges. Three of the tests involved shots into an outcrop carbonate rock called ne of drilling and completion induced permeability impairment commonly referred to as the “near wellbore damaged zone. This connectio ent characterising the velocity of chemical reaction and the formation damage coefficient reflecting permeability decrease due to salt precipit sulphate salt precipitation determined typical values of kinetics reaction coefficient from corefloods and what the impact would be on produ nd provides an opportunity for a water drive when applied during waterflooding.�The required rate of produced water reinjection can be a acceptance because it provides a method of minimizing OnePetroformation damage preventing lost circulation risks and increasing penetration rates maximum reservoir contact (MRC) wells. One of the objectives behind this strategy is to improve the well productivity by maximizing oil produ ation consolidation the large percentage of fines present in the reservoir the heavy oil the low frac gradients the low net-to-gross ratio the d improved productivity throughout a well’s lifecycle. This paper discusses the many challenges encountered during the planning and com pproximately 2 650 ft true vertical depth (TVD). An appraisal/early-producer well with a deviated wellbore was drilled through the H1 H2 targ nks block 783 in the Gulf of Mexico. The wells target multiple zones resulting in complex directional wells with 50�-60� maximum hole-a nks Block 783 in the Gulf of Mexico. The wells target multiple zones resulting in complex directional wells with 50–60� maximum hole a viable solutions are available to enhance there production to an economically feasible level. The Hawtah field (see Figure 1) discovered in th elective completion interventions were successfully implemented in the deepwater Gulf of Mexico Petronius field setting both Gulf of Mexico

and the results have been calibrated with production data. Both maximum allowable drawdown and depletion increase with depth. Additionall nd contingency fluid-loss control (FLC) pill formulation to withstand 4 600-psi burst resistance pressure. In maturing deepwater fields such

nd H2 at approximately 2 650 ft true vertical depth (TVD). An appraisal early-producer well was drilled with a deviated wellbore through the s block 783 in the Gulf of Mexico. The wells produce primarily from thick fine-grained OnePetro Pleistocene-age reservoirs. Due to the long lengths o nks Block 783 in the Gulf of Mexico. The wells produce primarily from thick fine-grained Pleistocene reservoirs. Because of the long lengths court. The field discovered in 1986 currently has 9 wells completed and 13 drainage points. Well A-4L is one of the completed intervals on t ative is to gain a better understanding of Sand Control Completion (SCC) systemsOnePetro equipment performance and reliability in a variety of app

eved complete annular packs and zero mechanical skin factors resulting in well productivity indices that are significantly greater than expect

onment. A Chevron offshore gas reservoir will be developed with high-angle near-horizontal wells with openhole gravel packs completion (O ed reservoirs in Brazil. Gravel pack placement requirements include the design of pumping pressures inside the operational window formed b s in Brazil. Gravel pack placement requirementsOnePetro include the design of pumping pressures inside the operational window formed by the minim Gravel Packing (OHGP).� Though gravel packing is a proven method to stabilize the well bore controlling sand and maximizing productiv eved complete annular packs and zero mechanical skin factors resulting in well productivity indices that are significantly greater than expect quired sand control. The lower zone was completed OnePetro with a gravel pack completion and the upper zone was left unperforated. To enable produ rilling slanted or sub-horizontal wells through several shale bodies to obtain high gas rate performances during the production and the injecti ability to deliver high-productivity wells. Currently there are two techniques used for gravel placement one utilizing low-viscosity carrier fluids 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 in drilling technology in recent years horizontal wells with lengths ranging from 2 000 to 6 000 ft have become more common. Executing the e gravel packing is the preferred sand control technique adopted by many operators in this region. It is considered one of the proven method

servoirs. Recent experience in extended-reach drilling also indicates that inefficientOnePetro transport ofOnePetro smaller cuttings is a main factor for excessive cy remediation on two offshore applications. Results are presented detailing specific placement procedures in-situ treatment design and pro a cased-hole gravel-pack job depends on the ability to effectively pack perforation tunnels which act as conduits between the reservoir and th cased-hole gravel-pack job depends on the ability to effectively pack perforation tunnels which act as conduits between the reservoir and th ough the S1U S1L and S2U sands at ~9200 ft TVD. After a pre-drill sand prediction the well was cased and perforated without sand contro e tied back to a floating production facility. Nine horizontal oil producers and four S-shaped gas producers are planned and all will require som

ogress with respect to sand control equipment and implementation. However even properly designed and executed completions are subjec n in Australasia. This recent technology was simultaneously applied in a production well and a water injection well and served as a demonst

minating the need to have a rig on location. To date six screenless completions have been performed for a major operator in the Gulf of Me minating the need to have a rig on location. To date six screenless completions have been performed for a major operator in the Gulf of Me have been proposed in the past including various solutions based on permeable cement OnePetro but none of them have made a real breakthrough.

he largest onshore steamflood operations in the world. Producing heavy oil (approximately 25�API) from an essentially unconsolidated res present-day. A large part of these challenges have been caused by reactive shales interbedding the sand bodies. This has had a persistent i transported to the surface facilities for different operational scenarios. Sand quantification estimation is still novel in the industry and this pa 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 OnePetro are applied to light oil and gas reservoirs the equations controlling generation of eroded solid mass or sand release rate are vastly simplified ent in the specific case of Lunskoye to minimise risk of failure while maximising production OnePetro reducing OnePetro cost and safeguarding reserves.� introduced to the field. The sanding severely impaired the performance of field and consequently led to significant economic loss. AGOCO sed on the following approach: (1) carry out detailed evaluation or determination of reservoir formation strength distribution using core testing na held in Beijing 5-7 December 2006. Abstract Sand production is a major concern for many operators. It can impact production cause er na held in Beijing 5-7 December 2006. Abstract Sand production is a major concern for many operators. It can impact production cause er een reported accompanying obstruction of production for majority of production wells since the onset of production indicating possible sandin een reported accompanying obstruction of production for majority of production wells since the onset of production indicating possible sandin er of possible mechanisms have been proposed. This paper presents the results of a series of laboratory perforation-collapse tests aimed at er of possible mechanisms have been proposed. This paper presents the results of a series of laboratory perforation-collapse tests aimed at

rk.� While the conventional sanding models generally consider a single-mechanism for sanding namely the critical depletion resulting in r rk.� While the conventional sanding models generally consider a single-mechanism for sanding namely the critical depletion resulting in r

r permeability and gas content. The compositional variation in produced gas is also not everywhere predictable although in most fields produ re imperative to make decisions with regard to the most optimum completion type objectively and based on reliable assessment of the sand re imperative to make decisions with regard to the most optimum completion type objectively and based on reliable assessment of the sand field-development team did not opt a priori for gravel packs in every well. While such OnePetro completions can indeed eliminate sanding risk the team extended shut in two subsea and one dry tree in a mature BP operated Gulf of Mexico deepwater field. The three wells involved in this oper s it predicts the sanding rate in real time. Experimental data on hollow cylinder samples (HCS) are used to support the validity of the numeric

s it predicts the sanding rate in real time. Experimental data on hollow cylinder samples (HCS) are used to support the validity of the numeric ake place during the lifetime of a reservoir but they are unable to predict whether the OnePetro sand production OnePetro will be ‘problematic’ (excessive m the reduction in pore pressure. In weak but consolidated sandstones this can lead to shear failure in the rock surrounding the perforation eld gas development in offshore Peninsular Malaysia. The objectives of the study were 1) to develop strategies to maintain mechanical and t producing from HP/HT reservoirs.� The Elgin/Franklin Field is located 240 kilometres east of Aberdeen in the Central Graben Area of the ern flank of the Viking Graben structure. It comprises a sequence of fault-bounded structural units of varying geological complexity. Within th ted vertical wells have been reviewed. The methods have been compared against the experimental data obtained on an electrolytic apparatu ive skin-factor model for perforated horizontal wells. In this paper we present the mathematical model development and validation by compa ed on low-friction and solids-suspension (fracturing and CT-cleanout) characteristics of the fluid. In the last 4 years the application of viscoe oir to the wellbore. Depth of penetration of live acid is the critical factor in determining the success of an acid-fracturing treatment. Depth of p e laboratory scale in acid fracture conductivity tests that mimic the conditions in an actual acid fracture treatment. We conducted a series of oir to the wellbore. Depth of penetration of live acid is the critical factor in determining the success of an acid-fracturing treatment. Depth of p carbonates over the last several years. The Khuff formation is a deep gas carbonate reservoir that is ideally suited for acid fracturing. Durin f carbonates over the last several years. The Khuff formation is a deep gas carbonate reservoir that is ideally suited for acid fracturing. Durin f of Mexico (GOM) in recent years.�� The uses of VES diverters range from remedial matrix-acid or nonacid-cleanup treatments to use novel tubing-conveyed fracturing technique. The logistical challenges that were overcome during the completion of the project will also be d

imulation treatments of carbonate formations in various fields. �The decrease of acid concentration during the spending process viscosif

coelastic diverting acid system to evaluate the effectiveness of this system in achieving diversion and zonal coverage in large limestone res

novel way of calculating the value that can be added OnePetro from acid fracturing. A model predicting the effect of acid fracturing in carbonate reservo eability zones. Various forms of hydrochloric acid (HCL) are used to create deep etched fractures. However regular HCl reacts very fast with coelastic diverting acid system to evaluate the effectiveness of this system in achieving diversion and zonal coverage in large limestone res ne and packstone limestone with a bottomhole static temperature (BHST) of about 150�F. The formation permeability often exceeds one the length of the horizontal wells make acid placement and diversion difficult particularly in high-water-cut (WC) wells in which water has br s as the oil price remains record high. Matrix stimulation is often preferred as it could generate additional production gain with relatively low d iron sulfide precipitation is a major requirement during acidizing treatments. �As OnePetro the acid spends on the carbonate surfaces and in the p n 200 m) the stimulation process is much more complex because factors such as reservoir heterogeneity damage to each zone matrix mine wer. However there are two major drawbacks associated with using concentrated HCl solutions in deep wells. The first is its high reaction ra ew wells have been dead for sometimes due to high water cut (60 to 80%). In all cases OnePetro the target interval was only 5’-10’ at the top o sure stimulation and gravel-pack fluid leakoff under static conditions. This method details step-by-step procedure for making fluids and meas m 20 mD to as high as one Darcy.� However the production from this formation is OnePetro often limited due to the low critical flow rate in the matrix then. The most prolific reservoir is the Caballos Formation a thick (250 ft avg.) laminated sandstone located at a depth of 6100 to 7500 ft th in the entire zone of interest. Successful matrix treatments depend on the uniform distribution of the treating fluid over the entire interval. W where large-scale fracturing and coiled tubing operations have been on-going for the past six years.� In the mainly brown fields tertiary rec

dewpoint pressure. The decline in productivity is due to near-well accumulation of condensate in the reservoir rock which is significant even e the outcome of acid stimulation treatments which are routinely performed to improve well productivity.� However most previous studies lds are offshore carbonate reservoirs. The exploitation of these reserves involves drilling horizontal wells for maximizing reservoir contact an

PM) treatment in the near wellbore region of a mature oil producing well. The study is divided into several parts where various factors which a that creates a fracture having higher fracture conductivity and/or penetrating an area of higher pore pressure than the previous fracture. Re

yoming—due to the low formation permeability and rock properties—and have been proven effective but still not perfect. Limitations on th ons that are more sensitive to water treatments (high capillary pressure swelling clays etc). In particular the Frontier Formation located in Bi yoming—due to the low formation permeability and rock properties—and have been proven effective but still not perfect. Limitations on th - or reservoir-specific approach to maximize production. Integrated solutions use a performance-based process that integrates petrophysic oduction wells drops below the dew point of the hydrocarbon fluid. Many of these gas reservoirs also have some water accumulation near th

of the order of 10 md or less). The current practice centers mainly on hydraulic fracturing OnePetro to improve OnePetro gas flow. In most cases the frequency e liquid (water/condensate) is trapped near the wellbore due to strong capillary forces OnePetro and/or viscous fingering of gas through the liquid. To re e liquid (water/condensate) is trapped near the wellbore due to strong capillary forces OnePetro and/or viscous fingering of gas through the liquid. To re water from adjacent wells presenting a challenge for the operating company. Greater oil demand coupled with limited surface water handlin mentation of intelligent (I-)well completions. The benefits from these more expensive completions will be realized through increased reserves he mid 1990’s. Downhole flow-control (DHFC) as it has become known has since been installed in hundreds of wells. However there h he mid 1990’s. Downhole flow-control (DHFC) as it has become known has since been installed in hundreds of wells. However there h production operations but they have considerable impact on injection well performance and longevity. Mismanaged they can result in substa than that of a vertical well (VW) due to its greater exposure to the reservoir. However the costs of drilling and completion are more and the r wells in a more efficient manner. This paper will review the drilling and data acquisition strategies to successfully deliver a challenging deep ment evaluation program. The effectiveness of these tools and their evaluations are often challenged and are not regarded as a replacement ment evaluation program. The effectiveness of these tools and their evaluations are often challenged and are not regarded as a replacement

m previous ones? Detailed design Detailed well-by-well review for first round candidate selection. Fundamental data collection (well data access reserves located in the southernmost compartments of the reservoir Extended Reach Drilling (ERD) was implemented. Six ERD we s to be reduced to allow wormholes to penetrate deep into the reservoir hence extending the effective wellbore drainage radius. The wormho increase production rate from one of the offshore fields while optimizing offshore producing facilities. This offshore field has favourable con ducing upper zone called the C sand to generate greater drawdown on a less productive lower zone called the A sand. Formation powered je

vron operations there are huge cost implications in the implementation of gas lift on several offshore jackets. New facilities for gas lift opera namic changes in well characteristics over the life of a well. This paper presents a case study on artificial lift selection strategy for unloading ers the production stream downhole via open-ended tubing or nozzles which if not properly sized can result in operational issues such as flu

lved as a result of extensive research and ground work. All the systems have proven their worth by increasing the productivity of the field by due to the longer completion length the longer drilling time the potentially increased overbalance and the reduced cleanup efficiency caused

lean gas and later export up to 700 MMscf/D of lean gas to a LNG plant in Darwin. The initial development called for 16 North Sea-style 7 in at high rates from the shallow unconsolidated sand stone reservoirs. The main challenge in terms of completion architecture was to maxim

ctivity (permeability-thickness product) and selectively perforating zones or reservoirs to offset the permeability contrast. At the outset a valu uire sand control and this has resulted in five sandface completion types (Open Hole Gravel Pack Cased Hole Frac Pack Cased Hole Grav into production. There emerged a necessity to develop the oil-water zones and marginal areas zones with poor reservoir properties and min e vertical depth (TVD) of 1 400 m. The original development project for this field did not include sand control for the initially forecasted produ

cementing operations. The sliding sleeve valves are opened one at a time to fracture layers independently without perforating. Completions e with large dimensions and low layer inclinations. The main hydrocarbon accumulation is found in the Sarmatian formation (Base Cretaceou horizontal wells have also gained acceptance as a proven reservoir management and well completion method. Production improvement facto and improve scale inhibitor squeeze treatments for optimum scale control. Putting various amounts of metal ions in the inhibitor pill adds ano important in this work has been the evaluation of the conditions for which the well outflow velocity is less than that which would be required t important in this work has been the evaluation of the conditions for which the well outflow velocity is less than that which would be required t

ble in this reservoir.� Thus this reservoir must be exploited using horizontal wells in all areas.� In areas where fractures may not be do ble in this reservoir.� Thus this reservoir must be exploited using horizontal wells in all areas.� In areas where fractures may not be do

GPC) has been shown to be capable of automatically controlling the area open to flow of multiple ICVs to achieve a specified production rate he well was drilled and completed as a proof of concept. It was completed as a trilateral and was equipped with a SC that encompasses surfa controlling fluids/gels and selective perforations have been used to mitigate the disparities in water encroachment over the reservoir interval. Saudia Arabia. A well was drilled and completed as a proof of concept. It was set up as a trilateral and was equipped with an SC that encom erivative information. We propose a workflow in which the production engineer relies on measurements to determine the flow rate and pressu

e commonplace to improve the well productivity by providing maximum reservoir contact minimizing operating costs lowering the pressure d ive permeability and also the higher degree of cleaning and liquid removal obtained in laboratory and field studies are interfacial tension red

½This paper will document the first application of inflow control devices in the UK sector of the North Sea. This application took place on up to improve the reliability of the pumping system. However DESPs potentially can address a much wider range of reservoir management

h an open-hole gravel pack. The initial well (CAN01) has produced at 333 MMcf/D. These rates are higher than typically experienced which h his project was to develop and apply a new concept for well completion involving ESP systems tubing-conveyed perforating (TCP) drillstem

e data and permits lifetime modeling with parameter combinations employing all available data. The analysis explicitly accounts for ESPs tha ating density (ECD). However the knowledge of rheology and hydraulics of polymer-thickened foams is still limited. This paper summarizes th

slots and limited open-to-flow areas. Furthermore the compounded effects of formation damage and non-Darcy flow on the fluid flow toward ed and surfactant-based have been used in an attempt to achieve optimum fracture length and conductivity.� Acids used for these treatme mpletions were considered the best completion option based on rock mechanics improved profile surveillance and cost. The original Alpine mpletions were considered the best completion option based on rock mechanics improved profile surveillance and cost. The original Alpine pleted using 100 tip screenout (TSO) propped-fracture treatments containing 70 million pounds of proppant. The target oil bearing Tor and Ek

tana and the success there is now accelerating the transfer of technology to the North Dakota side of the Bakken trend and is attracting sev ted near a water zone. These hydraulic fracturing difficulties created a niche for technologies that offer fracture-geometry control without sac ated by the reaction with the formation results in excessive fluid loss. Controlling fluid loss is one of the key objectives in acid fracturing treat us after initial campaign of four fracturing treatments. It demonstrated good proppant carrying capabilities and allowed decrease of polymer lo ted formation where sand control is a part of well management during the production life of the wells. Previous techniques of open hole exte tives has grown. This value must be balanced with the cost of the additives which can be significant in slickwater fracturing treatments. The is the dominant parameter controlling fracture height growth and that Young’s modulus contrast is less important. However a recent st

shown frac packs have a significant impact in maintaining well productivity in the later production life stages of unconsolidated reservoirs. Th sts per unit of gas produced. This in turn forced industry to focus on increasing efficiency by refining completion processes and field operatio er to hydraulically fracture the well as well as complying with stricter governmental regulations. As produced water is recycled and used in fra (OFD) approach which maximizes well productivity for a given fracture volume was introduced by Prats in 1960 for single-phase Darcy flow d stress state.� The application and appropriate modification of basin best practices and the application of technology for reservoir charac zuela. This technique combines stimulation and sand production control in a single treatment by placing a short and wide fracture which bypa arious techniques to prevent the breakthrough of hydraulic fractures into the underlying water zone but so far without clear success. The pa ng the number and size of fractures is still a challenge. Although fundamentally similar to fracturing vertical wells horizontal well fracturing h ction rates and better access to reserves. However most of these horizontal wells are completed openhole with little alternatives for stimulat imply the stimulation of Middle Mulichinco Formation (primary target) through hydraulic fractures. Mulichinco Formation is 30 to 80 meters th d treating fluids would enter preferentially into zones with high water saturations leaving oil zones untreated with a final result of increasing o ping reserves under these conditions with conventional vertical wells is in most cases uneconomical. In this setting horizontal wells have co

y successful over the past few years as the majority of the horizontal gas producers have yielded excellent results with open-hole completion

ost gas-well completions in the United States and elsewhere (Palisch et al. 2007; Forchheimer 1901; Milton-Tayler 1993a; Penny and Jin 199

ost gas-well completions in the United States and elsewhere (Palisch et al. 2007; Forchheimer 1901; Milton-Tayler 1993a; Penny and Jin 199 ost gas-well completions in the United States and elsewhere (Palisch et al. 2007; Forchheimer 1901; Milton-Tayler 1993a; Penny and Jin 199 igorous process of candidate selection fracture design and implementation of fit-for-purpose technologies. 10 candidate wells were selecte The solution for dimensionless productivity index of a finite-conductivity vertically fractured well in a closed rectangularly bounded reservoir a

cess of hydraulic fracturing in Western Siberia organically expanded to projects in Tymen-Pechora and Volga-Urals basin. Both basins are g

h normal cementing operations. The sliding sleeves were opened one at a time to fracture layers independently without perforating. The valv ng sleeves would then be opened one at a time to fracture layers independently without perforating. The possibility of high fracture initiation Difficulties emerge because hydraulic fracturing in soft rock involves development of a plastic zone near the fracture surface where rocks pa us resistance of the fluid flowing through the rock matrix primarily governs fluid loss.�This has historically limited the application to fractu

and reservoirs located in Southeast New Mexico (SENM).� The wells discussed in the paper were completed in various Morrow Sand int

ed to allow effective fracture fluid cleanup. It is also fairly well understood that occasionally conventional cross-linked gel fracture stimulations

allenging due to presence of high pressure/high temperature and high asphaltene content in the crude oil which renders the situation even m w discrepancies between the placed propped length and the effective production fracture length. Ineffective fracture clean-up is often cited a w discrepancies between the placed propped length and the effective production fracture length. Ineffective fracture clean-up is often cited a

w discrepancies between the placed propped length and the effective production fracture length. Ineffective fracture clean-up is often cited a a clearer picture of the fracture development.� This information can be combined with other fracture diagnostic techniques and along wit

effects of the deviating borehole trajectory. For common HFM geometries a 2� deviation uncertainty of the positions of monitoring or trea 100 fracture treatments were mapped. The fracture mapping study was performed as part of a pilot project to evaluate ten-acre well spacing

ment size as well as coordination of frac crews.� In the end however the primary characteristic of the treatment that provides any econom s and little lasting conductivity will be created. Despite this critical role of differential etching in the creation of fracture conductivity little is kno e the recovery factor of heterogeneous reservoir developed with water flood. Three main uncertainties exist: fracture height half-length and a ting tracer technology has a number of safety and environmental issues that must be addressed when using this technology as part of a frac

ropped fracturing stimulations for the gas and gas-condensate wells in the Western Siberian Arctic sector. The candidate selection proces nductivity cells. At the gas velocities normally encountered in hydraulic fracture proppant packs non-Darcy pressure drops dominate and t he fracture and a lag zone develops due to fluid cavitation. Properly taking into account the controlling parameters of tip behavior has resulte um fracture length and conductivity. Acids used for these treatments were based on 28 wt% HCl. A mixture of 15 wt% HCl and 9 wt% formic ns of a Stimulation Index (SD) and for evaluating the efficiency of wells with low conductivity hydraulically induced fractures. We utilize the dim

tern Piceance Basin western Colorado. Production from very low permeability Williams Fork gas sandstones requires fracture stimulation to tion of the seismic waves and injection details. Stimulation below the fault indicated a near-horizontal fracture geometry. Above the fault a n

wback but the physics of the phenomenon has still to be understood to predict the amount of proppant flowback during the life of a well. In pa e. It is shown that the propagation pressure of the orthogonal fracture quickly increases to above the closure stress on the initial fracture due lacing one lowers down the displacement quality leaving most of residual viscous fluid in porous matrix. The present paper provides the dat

in propped fracture dimension is related to the distribution of stresses and elastic properties as well as fluid leak off. Those factors have str actures although successful often underperform: Frac and Pack completions exhibit positive skin values and traditional hydraulic fracture

order to maintain the oil production target for this field the water injection rate should double the target oil rate. To achieve this water must b se of this work is to demonstrate the benefits of applying an integrated analysis for a hydraulic fracturing evaluation that is performed using a ffsets have long been recognized as sites of restricted width in the fracture channel potentially leading both to significant pressure drops and . Analyzing the different production technology options used in the assets thus far was the next step in better understanding the different rec d wells especially for tight gas reservoirs. However there has been no report of a study of flow behaviour within propped fractured porous m 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 rations. Traditional large fracturing jobs are usually pumped down 5.5 or 4.5 casing to meet the requirement of high pumping rate (30~55bpm ed. Written by individuals recognized as experts in the area these articles provide key references to more definitive work and present specific

d reservoir-well model to demonstrate that oil production can be increased by using controlled inflow from a gas cone as a natural lift.� Th o gas lift valve designed for gas operations. The value of auto gas lift is probably easier to demonstrate than for other types of intelligent well uire sand control and this has resulted in five sandface completion types (Open Hole Gravel Pack Cased Hole Frac Pack Cased Hole Grav e. Experiments at micro- and macro-scale levels were performed to: a) provide a detailed understanding of emulsion flow and blocking mec

velocity gas flow in single phase has been studied thoroughly by a large number of authors. Despite the fact that high-velocity coefficient in th ll bore face but more importantly the low permeability crushed zone created during the drilling operation. To achieve uniform treatment of e hydrodynamics becomes an important issue on well performance. In this paper we will discuss a problem in horizontal wells - the elevation wells are often selected to provide better sweep efficiency and achieve higher injection rates than conventional vertical injectors. However s ured and the benefits of utilizing open-hole horizontal completion technology have been well documented. The efficiencies and benefits of ut ured and the benefits of utilizing open-hole horizontal completion technology have been well documented. The efficiencies and benefits of ut 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 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 mine why this completion technique was selected and identify key parameters that favored its successful application in the Colville River field wing a detailed hydraulic analysis of these wells a good match with field measurements was obtained. Simulation results show that the proble tended shutdowns and cold restarts is effective only up to 50% water cut. Because more time and resources would be required to bring a n also velocity. The conventional theory to analyze the phenomena associated at rate dependent is commonly interpreted using Isochronal or f

ies is the fiber-optic DTS which can record the wellbore temperature profile in real time with decent accuracy and resolution. A key potential

ng injection rate into each of the four zones. The completion also includes three downhole optical flowmeters and three optical pressure and im intelligent completions technology has been successfully installed in Shaybah field operated by Saudi Aramco. Included in the description roduction from 12 subsea wells in water depths ranging from 5800 to 7000 feet is routed to the production host through three flowline loops despite their maximizing of reservoir contact. This is due to frictional pressure drop and/or permeability variations along the well. Annular flow permeability (K) variation and proximity of water traps). Furthermore conventional completions do not handle effectively heterogeneity or per dded Value for an IW is dependent on the number and location of the ICV controlled zones. Too many valves lead to unnecessary and exce nt completions are delivering better wells through improved efficiency productivity and hydrocarbon recovery with fewer wells both offshore ent. Zonal flow control can maximise produced oil value minimise unwanted fluids or a combination of both objectives. We have previous

d few wells will use an intelligent well systems to manage fluid fronts in a gravity-stable recovery scheme. The reservoir has many producing ntelligent completions wells have been successfully installed in Abqaiq operated by Saudi Aramco. Included in the description are equipment model-based and are effective only if the model can be used to predict future reservoir behavior with no uncertainty. Recently developed sche ss the effects of discontinuities on hydraulic fracture growth. A high viscosity fluid was used in order to provide fracture growth similar to actu ss the effects of discontinuities on hydraulic fracture growth. A high viscosity fluid was used in order to provide fracture growth similar to actu and thus the efficiency of the foam. In this paper an experimental study of the behavior of CO2 and N2 foams in granular porous media usin ference we assume that the bubble generation kinetics is dependent on layer permeability. We present experiments consisting of co-injectio periments consisting of the co-injection of N2 gas and surfactant solution in homogenous sandstone cores varying the liquid and gas injectio terature detailing the critical velocity necessary to keep a gas well unloaded suggests using the conditions at the top of the well as an evaluat

oduction observing much reduced flow rate for three days and eventually stopped flow. During the production depletion shuts-in restarts a essure. This further reduces the inflow so that more liquid collects and eventually the flow dies down completely.� This phenomenon is kn

ydrostatic column in the wellbore that balances out with the reservoir pressure killing the well and - if nothing is done - leaving significant rese ding the modeling of liquid loading behavior is still quite immature and the prediction of the minimum stable gas rate not very reliable. Many w ulation generally termed “deliquification. This resource is making up an ever-increasing part of the North American gas supply. Since the ciated with gas production exist however in offshore fields most of them are not applicable for well completion or legal requirements. In the p wellbore and instead settle to the bottom. At this point we apply artificial lift which involves either the better use of the remaining reservoir e

and c) they restrict gas production. This paper presents a new approach to water unloading that does not restrict or interrupt gas production

aracteristics of the tubing and casing pressures in plunger-lifted gas well are described quantitatively according to a field test data set. A bett ll loading up and ceasing to produce. Submersible pumps offer a viable means of removing water from the well; however gas interference c stimulated to remove drilling fluid filter cakes and to overcome formation damage effects or to create acid fractures or deep matrix stimulat

was applied to conventional wells where massive sand production was allowed with the objective of creating a cavity. The benefits expected

ate reservoir characterization is the key to successful reservoir development. This is especially true in thinly laminated reservoirs which exhi oduce the hydrocarbon. Sanding is detrimental to optimum field development and therefore information about the possible advent and exten ng deep and clean perforations may still not be enough to generate the desired productivity.� Therefore the wells are often stimulated by a maximum productivity this transition requires an optimal cleanup and the removal of the perforation damages. A new underbalanced oriente nd E-line have difficulties. This paper presents case history of coiled tubing perforating and zonal isolation evolution in infill well at Resak field aracterized by their high permeabilities (100 - 500 md) and low pressures (1200 - 2200 psi). The wells in Anaco District are normally perforat ld and theoretical calculations. The issues that are primarily covered in the LEP simulation work address the comparison of horizontal LEP in Sea. The HZ fields are stacked thin high-permeability sandstone reservoirs interlayered with low-permeability layers. The shallower layers g g system for given well and formation properties and work at log resolution to eliminate problems experienced with existing packages that us maximum geological stress known as the preferred fracture plane (PFP) provides significant opportunities to improve the efficiency of the fra maximum geological stress known as the preferred fracture plane (PFP) provides significant opportunities to improve the efficiency of the fra oduction. Some wells in�ADMA OPCO fields that are perforated using conventional perforating techniques�will not produce until stimu

eabilities of 35md to 85md and porosities of 18 to 30%. The wells are completed in oil reservoirs that have been perforated using convention zones are commonly encountered while drilling the reservoir section.� The drilling strategy for the subsea development wells called for the zones are commonly encountered while drilling the reservoir section.� The drilling strategy for the subsea development wells called for the duces transient fluid flow that provides an opportunity for quantifying the formation parameters. However the skin factor can rarely be estima he accuracy of hydrostatic cushion before firing the guns. The conventional method of correlating the CT on depth involves two CT runs the

f the gravity-assisted electric line to convey perforating guns to angles greater than 65�. With this electric line limitation the options availa erforating conditions of the perforator or perforator system is required if such damage and potential retrievability risks are to be avoided. In pr

to an outcrop carbonate rock called Indiana Limestone. Three of the tests involved shots into an outcrop sandstone rock called Berea Sands llbore damaged zone. This connection through the damaged zone is usually achieved by perforating and the effectiveness of this connection meability decrease due to salt precipitation. We derived an analytical model-based method for determination of kinetics and formation damag what the impact would be on productivity impairment during sulphate scaling. This paper extends the previous work by modelling the inje produced water reinjection can be anticipated using the expected pore volume replacement ratio and water-cut estimated from the producti

l productivity by maximizing oil production and minimizing water production. The paper will demonstrate the challenges and successes of red dients the low net-to-gross ratio the low bottomhole temperatures and the requirement for pressure maintenance. The development of the ountered during the planning and completion of two wells in the Egret Field in Brunei operated by Brunei Shell Petroleum (BSP) how the ch e was drilled through the H1 H2 targets and a completion design consisting of a cased and perforated commingled completion inside 9-5/8s with 50�-60� maximum hole-angles. The wells are completed using dry trees from the TLP and are producing primarily from massive lls with 50–60� maximum hole angles. The wells are completed using dry trees from the TLP and are produced primarily from massive h field (see Figure 1) discovered in the late 1980s is located 180 km south of Riyadh the capital of Saudi Arabia (figure 1). Hawtah is one of ius field setting both Gulf of Mexico and world records. Success was achieved through careful planning of procedures and specification of e

etion increase with depth. Additionally oriented perforations offer an improvement to perforation stability against sanding: the maximum allow In maturing deepwater fields such as Shell Ursa/Princess where depleted reservoir pressures are significantly below the hydrostatic pressu

with a deviated wellbore through the H1/H2 targets and a completion design consisting of a cased perforated and commingled completion i

servoirs. Because of the long lengths of the producing reservoirs and large variations in sand-grain sizes/permeabilities premium screens w s one of the completed intervals on the S7000E horizon. Production from this interval began in April 1997 and oil recovery averaged 2000 ST

t are significantly greater than expected. The success of the Greater Plutonio OHGP completions has been attributed primarily to the rigorou

penhole gravel packs completion (OHGP) for its first phase development. The ultra high rate for individual well could be up to 320 MMSCFD side the operational window formed by the minimum pump rate to avoid premature rat hole screen-out and maximum pump rate to avoid form

olling sand and maximizing productivity it entraps the filtercake formed by the reservoir drilling fluid.� This results in low production rate a t are significantly greater than expected. The success of the Greater Plutonio OHGP completions has been attributed primarily to the rigorou

during the production and the injection cycles. This challenge has a significant effect in selection of the completion technique in these wells ne utilizing low-viscosity carrier fluids and low gravel concentration. In this technique the gravel is placed in two waves commonly called Alph 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 ecome more common. Executing these open-hole gravel-pack jobs (alpha-beta packs) has been a challenge. Although scattered attempts onsidered one of the proven methods of sand control from both reliability and productivity standpoints and allows access to larger reserves

ures in-situ treatment design and productivity improvements. Two wells were recently drilled and completed for the Rosa deepwater project conduits between the reservoir and the wellbore for hydrocarbon production. This project presents a system approach for removal of perfora onduits between the reservoir and the wellbore for hydrocarbon production. This project presents a system approach for removal of perfora d and perforated without sand control but the perforations were oriented in the vertical plane (ie topside and bottomside perfs) to limit sand rs are planned and all will require some form of sand prevention. Extensive rock mechanical work using Statoil’s finite element modeling

nd executed completions are subject to mechanical failure with the first indications often being production of solids into a common separatio ection well and served as a demonstration of its potential benefits in the development of Stag oilfield. Located offshore in the North-West she

or a major operator in the Gulf of Mexico. Each of the six treatments provided significant cost savings as well as excellent return on investm or a major operator in the Gulf of Mexico. Each of the six treatments provided significant cost savings as well as excellent return on investm

om an essentially unconsolidated reservoir with a depth that ranges from 300 to 700 ft using steam injection at 300 to 400�F poses a uniq d bodies. This has had a persistent influence on the sandface completion design and in particular on the drilling and completion fluid system still novel in the industry and this paper describes its application in completion selection and design facilities design and operation and faci 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

and release rate are vastly simplified4-11 necessitating further field observations controlling sand flow rate in order to improve accuracy.�

significant economic loss. AGOCO recognized that it was facing a major challenge in terms of understanding potential sanding risk for Sarir trength distribution using core testing log data and drilling data analysis for rock strength estimate and its correlation with core testing results s. It can impact production cause erosion in downhole and surface facilities require additional separation and disposal and lead to significa s. It can impact production cause erosion in downhole and surface facilities require additional separation and disposal and lead to significa production indicating possible sanding issues for this field. To investigate this problem relevant data from different sources and different do production indicating possible sanding issues for this field. To investigate this problem relevant data from different sources and different do y perforation-collapse tests aimed at demonstrating and quantifying the water-cut effect on perforation failure and sand production. The labo y perforation-collapse tests aimed at demonstrating and quantifying the water-cut effect on perforation failure and sand production. The labo

ely the critical depletion resulting in rock disaggregation the proposed approach considers the interplay of several mechanisms that can lead ely the critical depletion resulting in rock disaggregation the proposed approach considers the interplay of several mechanisms that can lead

ictable although in most fields produced gas becomes progressively enriched in CO2 through the production life of a reservoir such as part d on reliable assessment of the sanding potential and its severity over the life of the well for the intended production target. This paper introd d on reliable assessment of the sanding potential and its severity over the life of the well for the intended production target. This paper introd

The three wells involved in this operation had been shut in due to incidences of sand production. The production facility was not designed w to support the validity of the numerical model.� Experiments on hollow-cylinder synthetic-sandstone specimens were conducted involvin

to support the validity of the numerical model.� Experiments on hollow-cylinder synthetic-sandstone specimens were conducted involvin

the rock surrounding the perforations and the borehole. Sand production in weakly consolidated formations is generally assumed to be a tw ategies to maintain mechanical and time-dependent stabilities of extended reach wells and 2) to assess sand production risk in the developm 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 rying geological complexity. Within these units the reservoir intervals are of moderate to poor quality and can exhibit strong contrasts in perm a obtained on an electrolytic apparatus and their accuracy has been investigated. It has been observed that the 3D semianalytical model SP development and validation by comparison with finite-element simulation results. With the new perforation skin model we then show how to o ast 4 years the application of viscoelastic surfactants was extended to acid-based systems for carbonate stimulation. These surfactants hav acid-fracturing treatment. Depth of penetration is controlled by the acid reaction rate leakoff and stimulation rate. Acid reaction rate is a fun reatment. We conducted a series of acid fracture conductivity tests using a protocol that mimics the fluxes in a hydraulic fracture both in the acid-fracturing treatment. Depth of penetration is controlled by the acid reaction rate leakoff and stimulation rate. Acid reaction rate is a fun eally suited for acid fracturing. During acid fracturing the wormholes created by the reaction results in excessive fluid loss. Controlling fluid deally suited for acid fracturing. During acid fracturing the wormholes created by the reaction results in excessive fluid loss. Controlling fluid or nonacid-cleanup treatments to use before gravel- or frac-packing operations to clean up long intervals after perforating. Success or failure ompletion of the project will also be discussed. This fracturing technique was implemented successfully to perform a large multistage acid tre

during the spending process viscosifies the fluid through the transformation from spherical micelles to an entangled wormlike micellar structu

onal coverage in large limestone reservoirs. The viscoelastic diverting acid system was pumped through coiled tubing in three of these wells

ver regular HCl reacts very fast with limestone and high-temperature dolomite formations and unless retarded will produce a fracture with l onal coverage in large limestone reservoirs. The viscoelastic diverting acid system was pumped through coiled tubing in three of these wells ation permeability often exceeds one darcy. The mineralogy is composed of calcite (98 to 99%) with about 1% halite and < 1% quartz; there cut (WC) wells in which water has broken through as a result of high-permeability streaks or natural fractures. Furthermore acid penetration al production gain with relatively low level of investment. In the recent acidizing campaign in Brunei a particular challenge was the flowback o

y damage to each zone matrix mineralogical composition and pressure regimes of each zone need to be taken into consideration. The pre wells. The first is its high reaction rate with carbonate rocks which limits acid penetration in the formation. The second is its corrosivity to we

rocedure for making fluids and measuring leakoff under static conditions. Stimulation and gravel-pack fluids are defined for the purpose of th

cated at a depth of 6100 to 7500 ft that has produced (30 to 45 �API crude) for over 35 years with production peaking at 66 000 BOPD. T ating fluid over the entire interval. When fluids are pumped into a well they naturally tend to flow into the zone with the highest permeability o In the mainly brown fields tertiary recovery methods such as water-flooding are implemented to maintain financial viability of the well stock. I

servoir rock which is significant even for wells producing very lean gas with liquid dropout values less than 1%. Many different methods such � However most previous studies reported in the literature have focused on investigating the effects of injection rate temperature and flu s for maximizing reservoir contact and hydrocarbon drainage. Many of these wells experience drilling mud damage. One of the challenges in

l parts where various factors which affect the application of RPM technology in a chosen field base case well are studied. These factors inc ssure than the previous fracture. Refracturing requirements are different in highly permeable formations (high fracture conductivity) as comp

but still not perfect. Limitations on the amount of proppant placed near water zones and formation damage from polymer residuals were the the Frontier Formation located in Bighorn Basin Wyoming has seen a variety of stimulation fluids used over the past years with varying deg but still not perfect. Limitations on the amount of proppant placed near water zones and formation damage from polymer residuals were the process that integrates petrophysical and reservoir characterization expertise with production and completion knowledge by developing an ve some water accumulation near the wells. This adds significantly to the total liquid blocking. Experiments were conducted using both outcr

ed with limited surface water handling facilities increased the importance of stimulating this type of challenging wells due to the drastic perme realized through increased reserves generated by increased drainage efficiency and reduction in well numbers and intervention frequency. A hundreds of wells. However there has been very little use of these valves to control water injection distribution within the layers of a reservo hundreds of wells. However there has been very little use of these valves to control water injection distribution within the layers of a reservo smanaged they can result in substantial and perhaps irreparable damage. This paper presents a study on the creation and propagation of w ng and completion are more and the options for monitoring control and intervention often limited. Gas-condensate reservoirs are increasingly ccessfully deliver a challenging deepwater development well. First the well was the longest stepout and highest angle well drilled in the field d are not regarded as a replacement for reservoir inter-zonal communication tests performed between producing reservoirs on every well. C d are not regarded as a replacement for reservoir inter-zonal communication tests performed between producing reservoirs on every well. C

ndamental data collection (well data pressure formation fluids - water and oil mineralogy data and lab tests…). Data management system ERD) was implemented. Six ERD wells have been drilled to date with lateral extensions close to 6500 m leading to total depths sometimes in ellbore drainage radius. The wormholes created by a retarded acid are deep but thin. During production the flux through the thin wormholes his offshore field has favourable conditions for ESP application producing from carbonate reservoir with no anticipated fines production low ed the A sand. Formation powered jet pumps increase oil rate from the A sand while reducing the water rate from the C sand. Gas lift can be

kets. New facilities for gas lift operation entails the installation of a compressor liquid knock out equipment pipelines manifold configuratio al lift selection strategy for unloading liquid from gas well in San Juan basin located in Southwestern Colorado and Northwestern New Mexi sult in operational issues such as fluid / gas slugging and pressure instabilities which negatively impact the overall lift efficiency. In 2006 Co

easing the productivity of the field by many folds. But each of these artificial lift systems has economic and operating limitations that eliminate he reduced cleanup efficiency caused by the heal-toe effect. Extensive modelling and simulation work has been previously performed analys

ent called for 16 North Sea-style 7 in. monobore wells (11 producers and 5 gas injectors). By May of 2003 it became apparent that the orig ompletion architecture was to maximize the well head flowing pressure while insuring “long term integrity of wells.� This was addresse

eability contrast. At the outset a value-of-information exercise suggested probing downhole sensing and completion issues in a stacked-res d Hole Frac Pack Cased Hole Gravel Pack Stand Alone Screen and Orientated Perforating). Based on the experience and field performanc with poor reservoir properties and minor reservoirs in order to maintain the production rates. Application of horizontal drilling allowed achieve ontrol for the initially forecasted production rates. However the possibility of expanding the gas production rates of each well to more than 1 M

ntly without perforating. Completions using these casing valves are called Treat And Produce (TAP) Completions and have a unique design Sarmatian formation (Base Cretaceous Paleorelif) at the depth of 1100 to 1150 m. Currently the main productive horizons are sands from the ethod. Production improvement factors (compared to conventional wells) of two or higher is not uncommon. To make decisions on the corre etal ions in the inhibitor pill adds another degree of freedom in squeeze design especially in controlling return concentrations and squeeze li s than that which would be required to continuously transport and unload liquids from the well.� Sub-critical velocities are often encountere s than that which would be required to continuously transport and unload liquids from the well.� Sub-critical velocities are often encountere

areas where fractures may not be dominant it is crucial to achieve maximum reservoir contact (MRC) through the well architecture.� To th areas where fractures may not be dominant it is crucial to achieve maximum reservoir contact (MRC) through the well architecture.� To th

o achieve a specified production rate. A black box model was established using real-time downhole instrument data as a predictive model f ed with a SC that encompasses surface remotely controlled hydraulic tubing retrievable advanced system coupled with pressure and temper oachment over the reservoir interval. Recently completion technologies using downhole valves which allow production and injection control was equipped with an SC that encompassed a surface-remotely-controlled hydraulic-tubing-retrievable advanced system coupled with a pres o determine the flow rate and pressure values and on models to determine the derivative information (i.e. the changes in flow rates as a res

erating costs lowering the pressure drawdown and maximizing profitability. This paper presents the results of a numerical study performed to eld studies are interfacial tension reduction and the miscibility characteristics reached between the treatment fluids and the formation fluids

ea. This application took place on a 4 288 ft horizontal sidetrack of a well in the West Brae field.�The completion was designed for a ho der range of reservoir management challenges. This paper will analyze the performance of a DESP in a range of reservoir scenarios. It will s

her than typically experienced which has raised concerns concerns about the resultant potential for metal erosion. As a result a rigorous eros onveyed perforating (TCP) drillstem testing (DST) and chemical treatment of the formation by using standard equipment and techniques. Th

alysis explicitly accounts for ESPs that are still operational at the time of the study thus removing a historical source of statistical bias. The a still limited. This paper summarizes the significant effects of polymer on foam rheology and presents a hydraulic model that simulates aqueou

on-Darcy flow on the fluid flow towards slotted-liners must be considered in well completion design process. This paper presents a compreh vity.� Acids used for these treatments have been typically formulated with 28-wt% HCl and have been used successfully to increase produ illance and cost. The original Alpine field development plan did not include hydraulic fracture stimulation based on the reservoir characteriza illance and cost. The original Alpine field development plan did not include hydraulic fracture stimulation based on the reservoir characteriza ant. The target oil bearing Tor and Ekofisk intervals range from 40 to 120 m of combined thickness with a Young’s modulus and permea

he Bakken trend and is attracting several new and existing operators to the area. Different drilling and completion techniques have been tried racture-geometry control without sacrificing proppant-pack conductivity. The conventional approach is based on net pressure control. This c key objectives in acid fracturing treatments to be able to create longer and wider fractures and hence maximize well productivity. Alternating s and allowed decrease of polymer load without increasing risk of premature screenout. Fibers proved to be reliable for successful placemen revious techniques of open hole external gravel packing and cased hole Internal Gravel Packing (IGP) for controlling formation sand were ch slickwater fracturing treatments. There is a range of different flowback additives containing water-wetting nonionic to amphoteric microemuls less important. However a recent study pointed out that modulus contrast can have significant implications on fracture geometry and proppa

ges of unconsolidated reservoirs. Thus sustaining the ability to pump frac packs in these challenging environments is a priority. With conve mpletion processes and field operations to make wells commercially viable. Strategies such as multiple-zone commingled completions the se ced water is recycled and used in fracturing applications each cycle of re-used water returns with a more complex chemical make up than b in 1960 for single-phase Darcy flow systems. This method which was later modified and presented in the form of Unified Fractured Design on of technology for reservoir characterization can shorten the learning curve of an operator in the development of a basin.� Numerous c a short and wide fracture which bypasses the near-wellbore damage while gravel-packing the zone of interest. This paper describes a nove so far without clear success. The paper describes a technique of physical barrier placement and tailoring fracturing fluid systems to control f ical wells horizontal well fracturing has unique aspects that require special attention to ensure successful treatment. Differences exist betwe hole with little alternatives for stimulation water shutoff or workover treatments. A very challenging task to stimulate long openhole sections e hinco Formation is 30 to 80 meters thick and has a variable permeability throughout the pay zone. The gas drainage from the best permeabi ated with a final result of increasing overall water production. However if the water production mechanism is understood and the appropriat this setting horizontal wells have come to mitigate the problem however in most unfavorable conditions where oil and gas are found in tight

ent results with open-hole completions in particular. Consequently most of the planned future wells will be drilled as open-hole horizontal com

ton-Tayler 1993a; Penny and Jin 1995; Flowers et al. 2003; Miskimins et al. 2005; Handren et al. 2001; Lolon et al. 2004; Vincent 2004; Olso

ton-Tayler 1993a; Penny and Jin 1995; Flowers et al. 2003; Miskimins et al. 2005; Handren et al. 2001; Lolon et al. 2004; Vincent 2004; Olso ton-Tayler 1993a; Penny and Jin 1995; Flowers et al. 2003; Miskimins et al. 2005; Handren et al. 2001; Lolon et al. 2004; Vincent 2004; Olso ies. 10 candidate wells were selected and the target zone was the GS-3A reservoir. 10-15ft above the GS-3A was a water bearing sand. Mo ed rectangularly bounded reservoir and the corresponding pseudosteady state shape factor of this type of well and reservoir completion unde

Volga-Urals basin. Both basins are geologically lithologically and stratigraphically vastly different from West Siberia. Adding the difference in

ndently without perforating. The valves have a unique design feature which allows an unlimited number of valves to be placed in a single we e possibility of high fracture initiation pressures is identified as the main risk with this approach. This paper will discuss the theoretical and the fracture surface where rocks partly lose their cohesion. This study has developed a more appropriate model for fracture design which t ically limited the application to fracturing reservoirs with low permeabilities. A new VES fracturing fluid has been developed for use in high p

ompleted in various Morrow Sand intervals around 10 500 ft with an average Bottom Hole Static Temperature (BHST) of 190oF.� Wellbor

cross-linked gel fracture stimulations do not create the desired fracture dimensions. The potential reasons for the shorter than desired effect

oil which renders the situation even more difficult because of fluid incompatibility issues. The formation tends to produce oil with asphaltene c tive fracture clean-up is often cited as a likely culprit. This paper presents some of the results of an investigation of fracture clean-up mecha tive fracture clean-up is often cited as a likely culprit. This paper presents some of the results of an investigation of fracture clean-up mecha

tive fracture clean-up is often cited as a likely culprit. This paper presents some of the results of an investigation of fracture clean-up mecha diagnostic techniques and along with sound engineering practices can have a profound impact on how wells are completed.����

of the positions of monitoring or treatment well surveys can cause more than a 40o uncertainty of the inverted fracture azimuths. Furthermo ect to evaluate ten-acre well spacing. The Jonah Field is located in the Green River Basin in Sublette County WY. Production is primarily fr

treatment that provides any economic benefit is a conductive fracture that economically increases well production. Although the primary go on of fracture conductivity little is known about the texture of the fracture surface created during acid fracturing or about the dependence of t xist: fracture height half-length and azimuth. Commercial fracture models provide length estimate once a reliable estimate of height is know using this technology as part of a fracturing treatment. These issues along with regulations concerning the transportation of radioactive mate

ctor. The candidate selection process including production prediction is at an infant development stage and is additionally hampered by th Darcy pressure drops dominate and the apparent proppant permeability is one or two orders of magnitude lower than the Darcy permeability arameters of tip behavior has resulted in more accurate and robust fracture propagation models. However the situation is still unclear in high ure of 15 wt% HCl and 9 wt% formic acid was used in wells completed with super Cr-13 tubulars. A high pH borate gel was pumped in stage y induced fractures. We utilize the dimensionless productivity index solution (JD) for finite-conductivity vertically fractured wells in closed recta

tones requires fracture stimulation to enhance wellbore-to-reservoir connectivity. The use of surface microseismic monitors without borehole acture geometry. Above the fault a near-vertical fracture geometry was observed. A change in fault orientation was supported by differences

owback during the life of a well. In particular determining whether the proppant flowback will stop after a few days of production or will contin sure stress on the initial fracture due to the fracture penetrating into the higher stress region which leads to fracture reopening along the initi The present paper provides the data on hydraulic fracture simulation accounting for accumulation of damages in elastoviscoplastic medium

fluid leak off. Those factors have strong implication on proppant distribution especially when larger size proppant are used. Although the lat ues and traditional hydraulic fracture completions show discrepancies between the placed propped length and the effective production frac

oil rate. To achieve this water must be injected into the formation at fracturing pressures. The completion campaign started with three wate evaluation that is performed using a workflow including time-lapse Sonic Anisotropy and Flexural Waveform Dispersion Analysis (open hole oth to significant pressure drops and to proppant bridging as fluid and slurry move through the restrictions. New modeling results are presen better understanding the different recovery increment options. The initial 4 year productivity from 4 assets was analyzed. This paper presents ur within propped fractured porous media for these low interfacial tension (IFT) systems. It is now a well established finding both experimenta 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 ment of high pumping rate (30~55bpm). Post-frac snubbing operations are often needed to run tubing and clean out wellbores. Snubbing ope e definitive work and present specific details only to illustrate the technology. Purpose: to inform the general readership of recent advances i

m a gas cone as a natural lift.� This model was developed in the knowledge centre Integrated System Approach Petroleum Production (IS han for other types of intelligent well because it provides a direct replacement for conventional gas lift equipment compressors and pipeline d Hole Frac Pack Cased Hole Gravel Pack Stand Alone Screen and Orientated Perforating). Based on the experience and field performanc g of emulsion flow and blocking mechanism b) set criteria for controlling an emulsion penetration depth before it breaks down and seals a po

fact that high-velocity coefficient in the presence of an immobile and a mobile liquid phase is much higher than that in single phase only a h on. To achieve uniform treatment of the entire openhole section with hydrochloric acid is difficult: the rapid reaction of the acid in downhole blem in horizontal wells - the elevation change in well trajectory and its effect on well performance. In general a horizontal wellbore is never p entional vertical injectors. However studies from Prudhoe Bay mature waterflood field indicate that these additional benefits can decline with d. The efficiencies and benefits of utilizing open-hole completion with mechanical isolation has lead to the operational benefits of multiple fra d. The efficiencies and benefits of utilizing open-hole completion with mechanical isolation has lead to the operational benefits of multiple fra or while starting production? Will the filtercake disperse and get removed while producing the well and applying drawdown to the formation? or while starting production? Will the filtercake disperse and get removed while producing the well and applying drawdown to the formation? ul application in the Colville River field. The optimal completion technique for a candidate well is determined by reservoir properties geologic imulation results show that the problems in the conventional wells were not as severe as those interpreted from the measurements of distrib urces would be required to bring a new AA LDHI more detailed analysis were performed to evaluate the possibility of managing hydrate risk only interpreted using Isochronal or flow-after-flow tests. After this test the negative impact of inertia on gas deliverability can be very well an

uracy and resolution. A key potential application for DTS data is to profile injection or production for wells which is the primary motivation an

eters and three optical pressure and temperature gauges. Measurement of surface injection rate and the rate from each of the three flowmet i Aramco. Included in the description are equipment selection design and development details installation procedures and “lessons lea ion host through three flowline loops and one separate flowline. The project has been an economic and technological success. The applicati ariations along the well. Annular flow leading to severe erosion hot-spots" and plugging of screens is another challenge. Inflow Control Devi andle effectively heterogeneity or permeability contrasts exposed along the sand face. The ICD controls and interrogates more optimally both valves lead to unnecessary and excessive cost as well as the potential for reduced reliability. Too few valves will not provide sufficient flexib overy with fewer wells both offshore and on land. Intelligent completions have proven their value in managing production from multilateral we both objectives. We have previously shown[1] that a minimum degree of un-evenness of an invading fluid front is needed for effective ICV

e. The reservoir has many producing zones with high-quality rock properties. Intelligent well systems which consist of interval control valves ded in the description are equipment selection design and development details installation procedures and “lessons learned after insta uncertainty. Recently developed schemes which update models with data acquired during the optimization process are computationally very rovide fracture growth similar to actual field conditions. Fracture growth and its internal fluid pressure were monitored by fixed probes placed rovide fracture growth similar to actual field conditions. Fracture growth and its internal fluid pressure were monitored by fixed probes placed foams in granular porous media using X-ray Computed Tomography is reported. In the experiments gas is forced through natural porous me experiments consisting of co-injection of N2 gas and surfactant solution in layered cores with layering parallel and to the flow directions. Th res varying the liquid and gas injection rates. During the experiments X-ray computed tomography (CT) scans were used to map locally the ns at the top of the well as an evaluation point. �This is convenient for personnel conducting the evaluation as wellhead pressure and temp

duction depletion shuts-in restarts and finally stop flowing periods the gas well experienced liquid load-up involving unstable operation cond mpletely.� This phenomenon is known as liquid loading. Velocity strings are a commonly applied remedy to liquid loading in gas wells. By

hing is done - leaving significant reserves behind. This is in North Sea gas fields a relatively new problem and is being addressed by Gas ble gas rate not very reliable. Many wells start liquid loading at gas rates well above the values predicted by classic steady state prediction m orth American gas supply. Since there is no one “perfect solution and the problem affects thousands of wells the opportunity involves n pletion or legal requirements. In the past soap sticks have been tried to foam up liquids however these may never have reached the area wh etter use of the remaining reservoir energy or the addition of external energy. The objective of this study is to understand the appropriate ap

ot restrict or interrupt gas production can operate without external energy and uses no consumables. Physical and software simulators have

cording to a field test data set. A better liquid accumulation mechanism is proposed. The effect of liquid falling back and liquid transfer from t the well; however gas interference can significantly degrade pump performance and even result in pump failure. An effective means of mitig cid fractures or deep matrix stimulation to enhance productivity. Good acid coverage with a relatively small acid volume is required to econo

ating a cavity. The benefits expected from a cavity completion are four-fold: 1) increase in PI by reducing skin 2) increase in effective wellbo

hinly laminated reservoirs which exhibit vertical heterogeneity and a wide range of flow properties. Therefore it is critical to combine high reso n about the possible advent and extent of sanding will be helpful in planning for completions and facilities. The study presented in this paper re the wells are often stimulated by a matrix acidizing treatment after the perforating.� A prevalent mind set in the industry is that acid diss mages. A new underbalanced oriented perforating technique has been successfully implemented in Algeria. It combines the use of a formatio on evolution in infill well at Resak field one of the gas field operated by Malaysia National E&P Company Petronas Carigali Sdn Bhd. Since n Anaco District are normally perforated using conventional static underbalanced techniques. The productivity of these wells was evaluated u s the comparison of horizontal LEP injector with conventionally perforated liner for a generic reservoir; the role of the sand-screen in LEP des eability layers. The shallower layers generally have better permeability and were developed first while the deeper lower-permeability reservoi enced with existing packages that use input values averaged across the reservoir. After consultation with staff engineers the tool was creat es to improve the efficiency of the fracture job maximizing ultimate production from the well. Wells are frequently completed with multiple tu es to improve the efficiency of the fracture job maximizing ultimate production from the well. Wells are frequently completed with multiple tu niques�will not produce until stimulated with acid.�A new perforating technique has been deployed that creates clean low skin perforati

ve been perforated using conventional methods fracture stimulated to increase production and later completed with electro-submersible pu bsea development wells called for the use of a solid drill-in liner as a contingency should major losses be encountered while drilling the reserv bsea development wells called for the use of a solid drill-in liner as a contingency should major losses be encountered while drilling the reserv r the skin factor can rarely be estimated reliably from pressure data acquired in the current UBP operations if without flowing on surface in s T on depth involves two CT runs the first to run a memory gamma ray (GR) and casing collar locator (CCL) and the second run for the actua

ctric line limitation the options available for deploying the guns are limited to wireline tractor and e-coiled tubing since most through tubing p evability risks are to be avoided. In practice the perforating design engineers do not have a well-established analytical tool to help them unde

p sandstone rock called Berea Sandstone. Four different charge types were tested including one standard (conventional) charge and three d d the effectiveness of this connection is the result of the perforating system selection the well environment in which the perforating job is exe tion of kinetics and formation damage coefficients from production well data consisting of barium concentrations in the produced water and o previous work by modelling the injectivity impairment during simultaneous injection of incompatible waters i.e. cation-rich produced water water-cut estimated from the production forecast. Fracturing is likely to occur during produced water reinjection at voidage replacement rate

the challenges and successes of reducing produced water by using smart completions and how multiphase flow meters (MPFM) helped in g intenance. The development of the Albacora Leste Field in the ultra deep water Campos Basin was a key component of Brazil’s drive to i Shell Petroleum (BSP) how the challenges were addressed and the best practices identified for future operations. Sand-control technique commingled completion inside 9-5/8-in. casing was implemented. The sand-face completion design consisted of a large-OD expandable san are producing primarily from massive fine-grained Pleistocene-aged reservoirs. These reservoirs require sand-control to prevent sand prod re produced primarily from massive fine-grained Pleistocene reservoirs. These reservoirs require sand control to prevent sand production i Arabia (figure 1). Hawtah is one of several small fields located along the Hawtah Trend (others are Ghinah Hazmiyah Nisalah and Umm J of procedures and specification of equipment. This paper describes the planning for these challenging extended-reach completion and inter

against sanding: the maximum allowable drawdowns and depletions are increased for all sands. Finally an analysis is presented on the eco ificantly below the hydrostatic pressure of a seawater column a modified screen design was required since screen products currently availa

orated and commingled completion inside 95/8-in. casing was implemented. The sandface-completion design consisted of a large-outside-d

s/permeabilities premium screens with shunt tubes in conjunction with cased-hole frac packs have been used to complete the wells. The th 7 and oil recovery averaged 2000 STB/D. Sand production was anticipated under normal drawdown from production onset and as such the

een attributed primarily to the rigorous design and field application of the fluid systems used at all stages of the well from drilling the reservoi

ual well could be up to 320 MMSCFD and the non-Darcy effect is too significant to overlook. The objective of this investigation is to build an a nd maximum pump rate to avoid formation fracture. Some special projects require additional equipment to provide selective completion –

This results in low production rate and consequently leads to the requirement of high drawdown pressure. �Hence it is imperative that the een attributed primarily to the rigorous design and field application of the fluid systems used at all stages of the well from drilling the reservoi

completion technique in these wells which require an effective and reliable sand control for long term and open-hole and large tubular size t in two waves commonly called Alpha/Beta packing. The second method utilizes a viscous carrier fluid and high concentrations of gravel in c 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 lenge. Although scattered attempts have been made to separately understand different parts of the gravel-pack process the industry still lac and allows access to larger reserves through fewer wells. Since most of these reservoirs contain reactive shale streaks they require synth

eted for the Rosa deepwater project Block 17 offshore Angola using a Non-Aromatic Oil-Based Mud (NAOBM) weighted with sized calcium stem approach for removal of perforation damage effective gravel placement and packing of the perforation tunnels. It was found that surgin tem approach for removal of perforation damage effective gravel placement and packing of the perforation tunnels. It was found that surgin e and bottomside perfs) to limit sand production. Perforations were shot at 4 spf and 180� phasing with ~1 000 psi underbalance.�Th Statoil’s finite element modeling method suggests that oriented perforations can prevent sand production in the horizontal wells. This wa

on of solids into a common separation facility. In many offshore completions particularly sub-sea or multi-zone completions it is often difficu cated offshore in the North-West shelf of Australia Stag field is a shallow and unconsolidated glauconitic sandstone reservoir with a top and

s well as excellent return on investment for the operator. Screenless completions are an integrated solution that involve many field-proven te s well as excellent return on investment for the operator. Screenless completions are an integrated solution that involve many field-proven te

tion at 300 to 400�F poses a unique challenge in designing an effective yet economic completion. One of the biggest problems associat he drilling and completion fluid systems. The completion design has evolved from stacked cased hole gravel pack to open hole gravel pack d cilities design and operation and facilities risk evaluation with reference to a high rate gas field development. The estimation of sand produc 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

te in order to improve accuracy.� Sand flow is catastrophic when formation is soft. However if certain conditions are satisfied the sand ra

anding potential sanding risk for Sarir and that it was necessary to design and implement a sandface completion and sand management stra ts correlation with core testing results; (2) conduct a series of triaxial tests on selected reservoir core samples in the low to intermediate stren on and disposal and lead to significant economic loss. On the other hand precautionary but unnecessary sand prevention will mean unwarra on and disposal and lead to significant economic loss. On the other hand precautionary but unnecessary sand prevention will mean unwarra om different sources and different domains (i.e. wireline logs laboratory test data drilling data well data and field data) were integrated to g om different sources and different domains (i.e. wireline logs laboratory test data drilling data well data and field data) were integrated to g ailure and sand production. The laboratory perforation-collapse tests were conducted on weak sandstones obtained from downhole and out ailure and sand production. The laboratory perforation-collapse tests were conducted on weak sandstones obtained from downhole and out

of several mechanisms that can lead to the rock breakup and sand transport.� One important difference is that rock disaggregation is not of several mechanisms that can lead to the rock breakup and sand transport.� One important difference is that rock disaggregation is not

uction life of a reservoir such as parts of the San Juan basin. In contrast it is generally observed that the ratio of CO2:CH4 declines with tim d production target. This paper introduces a predictive tool that forecasts not only the initiation of sanding but also its rate and severity in real d production target. This paper introduces a predictive tool that forecasts not only the initiation of sanding but also its rate and severity in real

roduction facility was not designed with any sand management capability such as hydrocyclones sand jets etc. Thus historically any incide specimens were conducted involving real-time sand-production measurement under various conditions. A numerical approach was used fo

specimens were conducted involving real-time sand-production measurement under various conditions. A numerical approach was used fo

tions is generally assumed to be a two-step process with the shear failure being the first step and the transport of the sand out of the perfo sand production risk in the development wells and eliminate unnecessary downhole sand control. The data required for the study include: 1 ures of 200�C and pressures of 16 000psi this is one of the highest pressure and temperature developments ever undertaken. The fields d can exhibit strong contrasts in permeability and formation water composition. Reservoir support is provided by combined injection of gas an that the 3D semianalytical model SPAN 6.0 software and the simple hybrid model described in this paper replicate the experimental results on skin model we then show how to optimize horizontal well perforating to maximize well productivity. A cased perforated well may have low e stimulation. These surfactants have the ability to significantly increase the apparent viscosity and elastic properties of the treating fluids. Th ation rate. Acid reaction rate is a function of several factors the most important of which is the reservoir temperature. Yet another concern i es in a hydraulic fracture both in the main flow direction along the fracture and in the fluid loss direction. In our tests the injection rate into th ation rate. Acid reaction rate is a function of several factors the most important of which is the reservoir temperature. Yet another concern i excessive fluid loss. Controlling fluid loss is key to optimize acid fracturing treatments by creating longer and wider fractures. Diesel emulsifie excessive fluid loss. Controlling fluid loss is key to optimize acid fracturing treatments by creating longer and wider fractures. Diesel emulsifie after perforating. Success or failure of these treatments is often related to the efficiency of diverting agents especially for acid treatments o o perform a large multistage acid treatment from a semisubmersible rig. Historically wells in this field have been treated using dedicated stim

n entangled wormlike micellar structure while penetrating the carbonate rock. The highly viscous fluid acts as a temporary barrier and diverts

h coiled tubing in three of these wells and bullheaded in five other wells for comparison between both methods of placement. Pre- and post-

etarded will produce a fracture with low conductivity. In addition concentrated HCl-based acids are very corrosive to well tubulars especially h coiled tubing in three of these wells and bullheaded in five other wells for comparison between both methods of placement. Pre- and postout 1% halite and < 1% quartz; therefore the formation is a potential candidate for acid stimulation. This limestone is atypical because of its tures. Furthermore acid penetration is limited by the large surface area of the horizontal wellbore and this is exacerbated by the relatively s rticular challenge was the flowback of tubing pickling and spent acids and neutralization of the spent acid on the surface. A series of effectiv

be taken into consideration. The presence of natural fractures makes the entire treatment more complex. Acid placement and diversion nee on. The second is its corrosivity to well tubulars. Hence organic acids become viable material for matrix acidizing to alleviate these two proble

uids are defined for the purpose of this technical standard as fluids used to enhance production from oil and gas wells by fracturing or acidiz

oduction peaking at 66 000 BOPD. The permeability varies from 20 to 200 mD with streaks exceeding one Darcy. At different times in the pa e zone with the highest permeability or least damage. Field experiences showed that there is no assurance of complete zone coverage witho n financial viability of the well stock. In many areas however production wells do not benefit enough from the water flood or the injection sch

an 1%. Many different methods such as hydraulic fracturing dry gas injection and solvent injection have been proposed and implemented to of injection rate temperature and fluid properties and few have focused on the influence of rock properties on stimulation treatments.� Th ud damage. One of the challenges in stimulating long horizontal wells with open-hole completion is the placement of stimulation fluids for effe

e well are studied. These factors include the effects of instantaneous vs. kinetic adsorption for the treatment and the further influence of trea (high fracture conductivity) as compared to low permeable ones (moderate fracture conductivity). Understanding these basic differences is

age from polymer residuals were the main drawbacks. A never ending quest for efficiency and higher production rates called for different opti d over the past years with varying degrees of success. When dealing with water sensitive formations a common practice has been to use oil age from polymer residuals were the main drawbacks. A never ending quest for efficiency and higher production rates called for different opti mpletion knowledge by developing and refining more complete interpretation and completion models based on comprehensive data. This pro ents were conducted using both outcrop sandstone and reservoir cores to measure the effect of liquid blocking on gas relative permeability. A

enging wells due to the drastic permeability contrast across the pay zones. Typically the treating fluid in a matrix treatment flows into high pe umbers and intervention frequency. A more rigorous exploitation of the real time production data is necessary to fully achieve this objective. ribution within the layers of a reservoir interval at high rates (>25 000 BWPD) in a continuous proportional operating mode. This paper will re ribution within the layers of a reservoir interval at high rates (>25 000 BWPD) in a continuous proportional operating mode. This paper will re on the creation and propagation of water hammer due to rapid shut-in of water injectors. Water hammer1-4 or pressure surge is a pressure ondensate reservoirs are increasingly considered as suitable candidates for drilling SWs or HWs. These reservoirs pose special challenges highest angle well drilled in the field to date. Second the well targeted a fault block in a portion of the field that was poorly constrained due t producing reservoirs on every well. Consequently the value of continuing to run these tools was raised by management. In response the relia producing reservoirs on every well. Consequently the value of continuing to run these tools was raised by management. In response the relia

ests…). Data management system allowing for quick access to well production history data. A design tool (Stim2001) for detailed candidat leading to total depths sometimes in excess of 8600m. In addition to the challenges pertaining to the drilling itself the completion also carrie the flux through the thin wormholes can be so high that high pressure gradient occurs. Therefore the optimized wormhole geometry should h no anticipated fines production low GOR low temperature low bubble point pressure and high API gravity. All new installations were carrie rate from the C sand. Gas lift can be used in formation powered jet pump wells to further enhance drawdown on a well while jet pumping. M

ment pipelines manifold configuration and associated piping etc. In many cases gas lift sourcing might require completely fresh construction orado and Northwestern New Mexico. Various modeling techniques were applied to evaluate the lowest bottom hole flowing pressure for va the overall lift efficiency. In 2006 ConocoPhillips conducted a study to design a gas lift system for the Surmont SAGD development that wou

nd operating limitations that eliminate it from consideration under certain operating condition. However all the conventional artificial lift system as been previously performed analysing the impact of formation damage and well cleanup in horizontal wells. This paper extends that work t

003 it became apparent that the original well design would not achieve the 1.1 Bcf/D production target because of well construction problem grity of wells.� This was addressed through implementation of limited - or even not - proven technologies. Introduction TOTAL AUSTRAL

d completion issues in a stacked-reservoir situation. The ultimate objective of this study was to ascertain economic completion strategy so th n the experience and field performance open-hole gravel packing has become the preferred option. The techniques used in completing these of horizontal drilling allowed achievement of the above tasks.� Horizontal completions resulted in not only enhancement of individual well on rates of each well to more than 1 MMm3/D �increased the associated sand production risk and led to the need for evaluating� the be

mpletions and have a unique design feature in the valves that allows a theoretically unlimited number of valves to be placed in a single well w oductive horizons are sands from the lower Sarmatian (Basal Sarmatian). The facies variation can be seen both vertically and horizontally on mon. To make decisions on the correct completion type to select it is important to be aware of the many sand control issues and the relative return concentrations and squeeze life. Phosphonate reactions during squeeze treatments involve a series of self-regulating reactions with c ritical velocities are often encountered in low productivity gas wells that produce liquids whether the wellbore liquids are produced directly fro ritical velocities are often encountered in low productivity gas wells that produce liquids whether the wellbore liquids are produced directly fro

rough the well architecture.� To this end a tri-lateral MRC well with a mother bore and two laterals has been recently drilled in this reservo rough the well architecture.� To this end a tri-lateral MRC well with a mother bore and two laterals has been recently drilled in this reservo

strument data as a predictive model for the controller. The model parameters were updated in real-time using the Decay Recursive Least Squ m coupled with pressure and temperature monitoring system. The SC provides isolation and down hole control of commingled production fr allow production and injection control over multiple zones have become available. The central idea is that downhole control may be used to a dvanced system coupled with a pressure- and temperature-monitoring system. SC provides isolation and downhole control of commingled p e. the changes in flow rates as a result of a change in an ICV setting). Such a model typically would be a steady-state wellbore simulator inc

ults of a numerical study performed to determine the production performance of dual opposed laterals compared to horizontal wells. With a to tment fluids and the formation fluids. This paper presents the results for compatibility and displacement tests carried out among reservoir

he completion was designed for a homogeneous permeability but the as-drilled permeability as shown by logging-while-drilling data had v range of reservoir scenarios. It will show how DESP performance can be modeled by use of commercially available coupled well-performa

l erosion. As a result a rigorous erosion study was initiated. The objective was to quantitatively evaluate erosion at various rates over the life andard equipment and techniques. The concept was developed after identifying the opportunity to optimize operations in wells where the abo

rical source of statistical bias. The analysis uses Kaplan-Meier (KM) (Kaplan and Meier 1958) and Cox proportional hazards (CPHs) (Cox 19 ydraulic model that simulates aqueous and polymer-based foam flow in directional and horizontal wellbores. Experimental studies on the rhe

ess. This paper presents a comprehensive semi-analytical model for estimating the productivity of horizontal wells completed with slotted lin n used successfully to increase production from the Khuff carbonates. Although acid fracture treatments create significant conductivity enha based on the reservoir characterization. Well performance had proven to be economic in this Jurassic marine sandstone without hydraulic based on the reservoir characterization. Well performance had proven to be economic in this Jurassic marine sandstone without hydraulic a Young’s modulus and permeability that can vary from less than 0.5 to over 2.5 million psi and 0.1 to 4 m respectively along the horiz

ompletion techniques have been tried since the start of the play with different degrees of success. In June of 2005 a new technique was intro based on net pressure control. This can be achieved using low-viscosity fluids such as viscoelastic systems oil-based systems or reduced p aximize well productivity. Alternating stages of polymer pad with diesel emulsified acid for deeper penetration and in-situ gelled acid a polym o be reliable for successful placement of 10/14-mesh size Intermediate Strength Proppants (ISP) at concentration up to 1000 kgPA and high or controlling formation sand were challenged by reduced flow efficiency of the wells. The recent development of Expandable Sand Screen (E g nonionic to amphoteric microemulsion and oil-wetting components. Determining the best additive for a specific reservoir is not a simple m ons on fracture geometry and proppant placement (Smith et al. 2001). To expand on this topic we consider the combined effects of modulus

nvironments is a priority. With conventional frac pack fluids these greater depths and higher bottomhole pressures often would result in the one commingled completions the selection of fluids and additives to maximize hydraulic fracture effective length and conductivity and fluid e complex chemical make up than before. Therefore the usable lifetime of the recycled water is shortened or requires expensive cleaning o he form of Unified Fractured Design (UFD) charts by other investigators is widely used in the petroleum industry even for gas condensate s lopment of a basin.� Numerous completion strategies (Limited Entry high rate limited entry and various Pin-point Stimulation Technique nterest. This paper describes a novel and economical frac-and-pack technique which consists of pumping a sand plug with the downhole to g fracturing fluid systems to control fracture net pressure development that combined is used to mitigate fracture height growth. The method ul treatment. Differences exist between horizontal and vertical wells in the areas of rock mechanics reservoir engineering and operations. T o stimulate long openhole sections effectively due to poor acid distribution especially in reservoirs with high permeability streaks that require gas drainage from the best permeability zones causes a differential depletion in reservoir pore pressure affecting by consequence the mecha sm is understood and the appropriate fluids are selected then stimulating producer wells with high water cuts can be a rewarding operation. s where oil and gas are found in tight formations fracture stimulation needs to be added to the equation. Conventional multistage fracturing t

be drilled as open-hole horizontal completions. Nonetheless due to the highly complex nature of the Khuff carbonate reservoir some wells h

Lolon et al. 2004; Vincent 2004; Olson et al. 2004). Although the importance in gas wells is evident the authors pose the question of whethe

Lolon et al. 2004; Vincent 2004; Olson et al. 2004). Although the importance in gas wells is evident the authors pose the question of whethe Lolon et al. 2004; Vincent 2004; Olson et al. 2004). Although the importance in gas wells is evident the authors pose the question of whethe GS-3A was a water bearing sand. Most of the candidate wells were primarily in an area of the reservoir that had experienced poor recovery p of well and reservoir completion under boundary-dominated flow conditions has been developed and utilized in this study. The mathematical

West Siberia. Adding the difference in the maturity of the fields with significantly depleted reservoirs high asphaltene and paraffin oil content

of valves to be placed in a single well without incremental reductions to the ID thus allowing normal cementing operations. A control line is c aper will discuss the theoretical and experimental study that was conducted to assess the viability of the cemented sliding sleeve concept b ate model for fracture design which takes into account processes in the plastic zone for the special case of soft rock that is a cohesionless g has been developed for use in high permeability reservoirs and successfully pumped in the Gulf of Mexico.�The fluid exhibits enhanced f

ature (BHST) of 190oF.� Wellbore completion constraints combined with reservoir parameters inclusive of low-pressured water sensitive

ns for the shorter than desired effective fracture lengths are numerous with the most likely being excessive fracture height growth and poor fr

ends to produce oil with asphaltene content when the flowing bottomhole pressure is drawn below the Asphalting Onset Pressure (AOP). An estigation of fracture clean-up mechanisms. This investigation was undertaken under a Joint Industry Project (JIP) active since the year 2002 estigation of fracture clean-up mechanisms. This investigation was undertaken under a Joint Industry Project (JIP) active since the year 2002

estigation of fracture clean-up mechanisms. This investigation was undertaken under a Joint Industry Project (JIP) active since the year 2002 w wells are completed.������ This paper discusses the completion design methodology execution and results from two off

nverted fracture azimuths. Furthermore if the positions of the injection point and the receiver array are not known accurately and the velocity ounty WY. Production is primarily from over-pressured and tight sandstones of the Lance Formation. The Lance in Jonah consists of many

production. Although the primary goal of a hydraulic fracture is to create a highly conductive flowpath it is often the most poorly understood cturing or about the dependence of this texture on the acidizing conditions. To study this important aspect of the acid-fracturing process we a reliable estimate of height is known. This is evident for 2D model which requires a direct knowledge of the height but also for p3D model w he transportation of radioactive materials have impacted the application of this technology in international markets. This paper will describe

e and is additionally hampered by the lack of or ambiguity in the reservoir and production data. This is particularly true for the Yamburgsk de lower than the Darcy permeability measured at single phase low-rate conditions. This is particularly true if a liquid phase is also flowing. er the situation is still unclear in high permeability formations because the formation fluid can invade the tip zone where the pressure drops pH borate gel was pumped in stages to reduce leak-off and maintain the bottomhole pressure at values greater than the fracturing pressure ertically fractured wells in closed rectangular bounded reservoirs and their corresponding pseudo-steady state shape factors under boundary

roseismic monitors without borehole equipment in downhole configurations represents a relatively new and untested technology for hydraulic ntation was supported by differences in the microseismic-signal characteristics and the treatment-injection data. This difference in fracture g

a few days of production or will continue at a given rate during the well's life is a key issue when selecting an appropriate completion method. s to fracture reopening along the initial fracture plane (called in-plane frac hereafter). A dual-frac PKN model is developed to predict the grow amages in elastoviscoplastic medium as well as the effect of inhomogenity of porous media properties on fracture propagation. After hydrau

proppant are used. Although the latter could lead to more conductive fractures they could also bridge at the wellbore impeding both lateral gth and the effective production fracture length. Ineffective fracture clean-up is often cited as a likely culprit. The main results presented in

on campaign started with three water injector wells. The initial results were not as expected i.e. after pumping 1000 bbls of treated seawater eform Dispersion Analysis (open hole and cased hole) which main objectives consisted on the generation of a horizontal stress map for the s ns. New modeling results are presented that quantify these and other effects of offsets by using a coupled 2D hydraulic fracture model. Offse s was analyzed. This paper presents the results of a study focused on increasing the understanding of productivity drivers using a database established finding both experimentally and theoretically that the flow of gas-condensate fluid systems in porous media is affected by both co 30 to 80 m in length and the wells were traditionally matrix-acid stimulated following perforation. The wells produced initially unassisted then l nd clean out wellbores. Snubbing operations can be costly in terms of investment and time. Annular fracs have been applied in the industry a eral readership of recent advances in various areas of petroleum engineering. Introduction Predicting and assuring well deliverability often

Approach Petroleum Production (ISAPP) of TNO TU Delft and Shell and is based on a commercially available dynamic multiphase well sim quipment compressors and pipelines and the ancillary equipment they require. An estimated 60 auto gas lift systems have been installed a n the experience and field performance open-hole gravel packing has become the preferred option. The techniques used in completing these before it breaks down and seals a porous medium. In these experiments well-characterized oil-in-water emulsions were injected into etche

er than that in single phase only a handful of studies have been made on the subject. In this work we have measured the high-velocity coef 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 neral a horizontal wellbore is never perfectly horizontal. The inclination angle could be a result of drilling control or sometimes could be desi e additional benefits can decline with time. A clearer understanding of the injection mechanism and an integrated solution was required to im he operational benefits of multiple fracturing operations being pumped in one continuous operation equating to time savings more efficient f he operational benefits of multiple fracturing operations being pumped in one continuous operation equating to time savings more efficient f applying drawdown to the formation? Will the remaining filtercake impair well productivity? The paper presents the case of a gas producing h applying drawdown to the formation? Will the remaining filtercake impair well productivity? The paper presents the case of a gas producing h ned by reservoir properties geologic setting rock mechanics development plan and completion design. In this paper we will review the uniq ed from the measurements of distributed temperature sensing systems (DTSs). It is also demonstrated that the compartmentalized completi e possibility of managing hydrate risks through operating procedures. It was found that during extended shutdown the wellbore fluid can be p gas deliverability can be very well analyzed using special graphics. However the actual effect related to capillary number and its dependenc

s which is the primary motivation and focus of this project. In the present paper a thermal model recently developed for single-phase- and

e rate from each of the three flowmeters provides real-time measurement of injection rate into each zone regardless of choke positions. The on procedures and “lessons learned after installation of the fully hydraulic tubing-retrievable advance completion system with digital perm technological success. The application of intelligent well technology has enabled co-owners Shell and BP to successfully develop Na Kika w nother challenge. Inflow Control Devices (ICDs) were proposed as a solution to these difficulties in the early ‘90s. ICDs have recently gaine and interrogates more optimally both rock and fluid properties in the reservoir hence delaying early water breakthrough. This early water bre alves will not provide sufficient flexibility for efficient control. We previously showed[1] that a minimum degree of un-even fluid-front progre naging production from multilateral wells horizontal wells with multiple zones and wells with heterogeneous reservoirs using a single wellbor fluid front is needed for effective ICV control. This work studies scenarios to identify when “Proactive rather than “Reactive ICV chok

hich consist of interval control valves (ICVs) and many sensors will be used to monitor analyze and control (MAC) injection and production and “lessons learned after installation of the fully hydraulic tubing-retrievable advanced completion system with digital permanent down on process are computationally very expensive. We suggest that simple reactive control techniques triggered by permanently installed dow ere monitored by fixed probes placed normal to the expected plane of propagation. Fracture tip arrivals were captured by the fixed pressure p ere monitored by fixed probes placed normal to the expected plane of propagation. Fracture tip arrivals were captured by the fixed pressure p s is forced through natural porous media initially saturated with a surfactant solution a process known as SurfactantAlternatingGas (SAG). Th parallel and to the flow directions. The cores are obtained by combining two porous media chosen from Benteimer and Berea sandstone and scans were used to map locally the fluid saturations with high spatial and temporal resolution. Introduction Foam is an excellent acid divers ation as wellhead pressure and temperature data are readily available. �A number of situations exist where the use of the wellhead as the

up involving unstable operation conditions and changing reservoir deliverability. The conventional steady-state based liquid load-up predictio medy to liquid loading in gas wells. By installing a small diameter string inside the tubing the flow area is reduced which increases the velocit

em and is being addressed by Gas Well Deliquification which aims to produce the liquids artificially in order to help the gas to flow unobstru d by classic steady state prediction models such as Turner. The loading point is strongly dependent on inclination angle flow regime transitio ds of wells the opportunity involves not only technology development but also knowledge management and building resource capability. This may never have reached the area where liquid had accumulated due to wellbore deviation. It was therefore decided to try liquid batch injectio y is to understand the appropriate application of external energy to maximize economic recovery. Our research was conducted in two stages

hysical and software simulators have been developed to demonstrate the feasibility of the new approach and to configure the approach for v

falling back and liquid transfer from the tubing into the annulus during shutting-in period is specially considered for liquid accumulation and s p failure. An effective means of mitigating this problem is to place the pump below the producing interval effectively allowing gravity to separ mall acid volume is required to economically obtain the desired broad reservoir access. We have developed a model to predict the placemen

g skin 2) increase in effective wellbore radius 3) creation of an enhanced permeability (dilatant) zone near the wellbore and 4) decrease in p

fore it is critical to combine high resolution formation evaluation logs and formation tests to predict the well performance prior to the product s. The study presented in this paper characterizes the geomechanic behavior of a field in which sanding problems are expected after depleti nd set in the industry is that acid dissolves the perforation debris and creates wormholes that bypass the perforating and other near wellbore eria. It combines the use of a formation isolation valve (FIV) to keep damaging completion fluid off the formation immediately after perforation y Petronas Carigali Sdn Bhd. Since the beginning of Resak Field production coiled tubing has been used to perforate numbers of infill wells ctivity of these wells was evaluated using nodal analysis techniques coupled with perforating performance simulations. The quality and amou e role of the sand-screen in LEP design during HVO production and the analysis of the pressure drops through the LEP hardware. Modelling deeper lower-permeability reservoirs have been developed more recently. The lower-permeability reservoirs are generally of lower porosity th staff engineers the tool was created in Excel to test functionality and later transformed into a desktop application.� It includes a perfora frequently completed with multiple tubing strings (up to four in some cases) sensor lines control lines or other hardware that can be damag frequently completed with multiple tubing strings (up to four in some cases) sensor lines control lines or other hardware that can be damag that creates clean low skin perforations�and allows the well to be produced at commercial rates while waiting for the multipurpose barge

ompleted with electro-submersible pumps (ESPs). To effectively meet the operator’s needs for a method that would help optimize well p encountered while drilling the reservoir section. This strategy stands opposed to using a pre-drilled liner.� The use of a drill-in liner howe encountered while drilling the reservoir section. This strategy stands opposed to using a pre-drilled liner.� The use of a drill-in liner howe ons if without flowing on surface in sufficient time. The reasons are that (a) the flow rate after an UBP continuously varies during the surge; ( CL) and the second run for the actual perforation. The underbalanced condition calculated based on wellbore fluid displacement is often deem

d tubing since most through tubing perforation are done in real time. Apart from space constraint at the wellsite and cumbersome logistics th hed analytical tool to help them understand post-perforating behavior of perforators. They have to rely on their own experiences and previous

ard (conventional) charge and three different designs of reactive liner charges. Among all charges the only difference of note was the design ent in which the perforating job is executed and what happens to the perforations after shooting and before they are used for production or in ntrations in the produced water and of well productivity decline. We analyse production data for five scaled-up producers from giant offshore aters i.e. cation-rich produced water (PWRI) and seawater with sulphate anions. An analytical model with explicit expressions for deposited njection at voidage replacement rates.�The extent (size) of the induced fracture(s) will significantly impact the waste disposal process.�

ase flow meters (MPFM) helped in getting better results to allow faster decision making. In one of the challenging areas in Ghawar field whe ey component of Brazil’s drive to achieve petroleum self sufficiency by 2006. Because of the challenges presented by the heavy oil and e operations. Sand-control techniques such as an extension packing and hydraulic fracturing were evaluated to help minimize the risk of fine sisted of a large-OD expandable sand screen with 150 micron weave across the 2 zones. Upon completion the reservoirs were cleaned up re sand-control to prevent sand production at the expected drawdowns planned during the life of the wells. To help ensure high rate long life d control to prevent sand production at the expected drawdowns planned during the life of the wells. To help ensure high-rate long-life comp inah Hazmiyah Nisalah and Umm Jurf). The Trend runs approximately 30 km east to west and 50 km north to south. Production in Hawtah extended-reach completion and intervention operations along with the lessons learned while implementing these case-history jobs. Introduc

y an analysis is presented on the economics and trade-offs of vertically-oriented perforating (with possibly managed sand production) versus nce screen products currently available were limited to