
Reservoir Formation Damage
Fundamentals, Modeling, Assessment, and Mitigation
- 4th Edition - March 29, 2023
- Imprint: Gulf Professional Publishing
- Author: Faruk Civan
- Language: English
- Hardback ISBN:9 7 8 - 0 - 3 2 3 - 9 0 2 2 8 - 1
- eBook ISBN:9 7 8 - 0 - 3 2 3 - 9 8 4 7 3 - 7
Reservoir Formation Damage: Fundamentals, Modeling, Assessment, and Mitigation, Fourth Edition gives engineers a structured layout to predict and improve productivity, providing… Read more

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Request a sales quoteReservoir Formation Damage: Fundamentals, Modeling, Assessment, and Mitigation, Fourth Edition gives engineers a structured layout to predict and improve productivity, providing strategies, recent developments and methods for more successful operations. Updated with many new chapters, including completion damage effects for fractured wells, flow assurance, and fluid damage effects, the book will help engineers better tackle today’s assets. Additional new chapters include bacterial induced formation damage, new aspects of chemically induced formation damage, and new field application designs and cost assessments for measures and strategies.
Additional procedures for unconventional reservoirs get the engineer up to date. Structured to progress through your career, Reservoir Formation Damage, Fourth Edition continues to deliver a trusted source for both petroleum and reservoir engineers.
- Covers new applications through case studies and test questions
- Bridges theory and practice, with detailed illustrations and a structured progression of chapter topics
- Considers environmental aspects, with new content on water control, conformance and produced water reinjection
- Cover image
- Title page
- Table of Contents
- Copyright
- Dedication
- About the author
- Preface
- Chapter 1. Overview of formation damage
- Abstract
- Summary
- 1.1 Introduction
- 1.2 Common formation damage problems, factors, and mechanisms
- 1.3 Completion and fluid damage problems
- 1.4 Supporting subsurface energy storage for global energy transition
- 1.5 Team for understanding and mitigation of formation damage
- 1.6 Objectives of the book
- Exercises
- Part I: Characterization of reservoir rock for formation damage—reservoir formations, description and characterization, damage potential, and petrographics
- Chapter 2. Description and characterization of oil and gas reservoirs for formation damage potential
- Abstract
- Summary
- 2.1 Introduction
- 2.2 Origin of petroleum-bearing formations
- 2.3 Types and properties of sedimentary rocks
- 2.4 Operational classification of the constituents of sedimentary rocks
- 2.5 Composition of petroleum-bearing formations
- 2.6 Classification of rock types: depositional, petrographic, and hydraulic
- 2.7 Flow units classification of rock types
- 2.8 Geologic controls on hydrocarbon production
- 2.9 Formation evaluation and reservoir characterization
- Exercises
- Chapter 3. Petrographic characteristics of petroleum-bearing formations
- Abstract
- Summary
- 3.1 Introduction
- 3.2 Petrographic characteristics
- 3.3 Morphology of dispersed clays in sandstones
- 3.4 Rock damage tendency and formation damage index number
- Exercises
- Part II: Characterization of the porous media processes for formation damage—porosity and permeability, mineralogy sensitivity, petrophysics, rate processes, rock-fluid-particle interactions, and accountability of phases and species
- Chapter 4. Alteration of the porosity and permeability of geologic formations—basic and advanced relationships
- Abstract
- Summary
- 4.1 Introduction
- 4.2 Basic models for permeability of rocks
- 4.3 Special effects on porosity—permeability relationships
- 4.4 Advanced permeability equations
- 4.5 Variation of the properties of naturally fractured formations under stress and thermal effects
- Exercises
- Chapter 5. Mineral sensitivity of petroleum-bearing formations
- Abstract
- Summary
- 5.1 Introduction
- 5.2 Mineral sensitivity of sedimentary formations
- 5.3 Mechanism of clay swelling
- 5.4 Modeling of clay swelling
- 5.5 Cation exchange capacity
- 5.6 Physicochemical sensitivity of clayey formation and clay reactivity coefficient
- 5.7 Clay stabilization
- 5.8 Clay and silt fines
- 5.9 Intense heat treatment
- Exercises
- Chapter 6. Petrophysical alterations—fluid disposition, distribution, and entrapment, flow functions, and petrophysical parameters of geologic formations
- Abstract
- Summary
- 6.1 Introduction
- 6.2 Dependence of end-point saturations to porosity and permeability
- 6.3 Alteration and temperature dependency of the rock wettability
- 6.4 Alteration of flow functions: capillary pressure and relative permeability
- 6.5 Mobility of gas and water phases, entrapment shock—critical phase entrapment condition
- 6.6 Water-blockage in hydraulically created fractures and reservoir formation
- 6.7 Clay swelling by water imbibition
- 6.8 Sensitivity of shale formations to water
- 6.9 Description of shale behavior
- 6.10 Shale swelling and stability
- 6.11 Simplified modeling of processes affecting wellbore stability
- 6.12 Remediation methods
- 6.13 Variation of the relative permeability and capillary pressure curves under stress and thermal effects
- Exercises
- Chapter 7. Phase equilibria, solubility, and precipitation in porous media
- Abstract
- Summary
- 7.1 Introduction
- 7.2 Types of precipitation
- 7.3 Solid/liquid equilibrium and solubility equation
- 7.4 Solid/gas equilibrium and solubility equation
- 7.5 Crystallization phenomena
- 7.6 Particle growth and dissolution in solution
- 7.7 Scale formation and dissolution at the pore surface
- 7.8 Crystal surface pitting and displacement by dissolution
- Exercises
- Chapter 8. Particulate processes in porous media
- Abstract
- Summary
- 8.1 Introduction
- 8.2 Particulate processes
- 8.3 Properties affecting particles and suspension of particles
- 8.4 Forces acting upon particles
- 8.5 Rate equations for particulate processes in porous matrix
- 8.6 Particulate phenomena in multiphase systems
- 8.7 Temperature effect on particulate processes
- 8.8 Modified rate equations for pore-surface and pore-throat particle deposition/mobilization in porous formations
- 8.9 Modified rate equations implementing maximum or critical particle retention concentration in porous formations
- 8.10 Effect of particle retention on flow, permeability, and relative permeability in porous formations
- 8.11 Effect of surface heterogeneities on particle attachment–detachment processes
- Exercises
- Chapter 9. Multiphase and multispecies transport in porous media
- Abstract
- Summary
- 9.1 Introduction
- 9.2 Multiphase and multispecies systems in porous media
- 9.3 Alternative expressions of various species-content and flow for systems in porous media
- 9.4 Multispecies and multiphase macroscopic transport equations
- 9.5 EXAMPLE 1: Estimation of the spontaneous clearing time of water block created by hydraulic fracturing fluid invasion
- 9.6 EXAMPLE 2: Modeling detachment, retention, and transport of fine particles in cohesionless granular porous formations
- Exercises
- Part III: Formation damage by particulate processes—single- and multi-phase fines migration, clay swelling, filtrate and particulate invasion, filter cake, stress sensitivity, and sanding
- Chapter 10. Single-phase formation damage by fines migration and clay swelling
- Abstract
- Summary
- 10.1 Introduction
- 10.2 Algebraic core impairment model
- 10.3 Simple partial differential core impairment model
- 10.4 Partial differential core impairment model considering the clayey formation swelling and both the indigenous and external particles
- 10.5 Plugging–nonplugging parallel pathways partial differential core impairment model
- 10.6 Model-assisted analysis of experimental data
- Exercises
- Chapter 11. Multiphase formation damage by fines migration, salinity effect, and microbial/bio-clogging
- Abstract
- Summary
- 11.1 Introduction
- 11.2 Formulation of a multiphase formation damage model
- 11.3 Model-assisted analysis of experimental data
- Exercises
- Chapter 12. Cake filtration: mechanism, parameters and modeling
- Abstract
- Summary
- 12.1 Introduction
- 12.2 Incompressive cake filtration without fines intrusion
- 12.3 Compressive cake filtration including fines invasion
- Exercises
- Chapter 13. Injectivity of the water-flooding wells
- Abstract
- Summary
- 13.1 Introduction
- 13.2 Injectivity of wells
- 13.3 Water quality ratio
- 13.4 Single-phase filtration processes
- 13.5 Diagnostic-type curves for water injectivity tests
- 13.6 Injection rate decline function
- 13.7 Field applications
- 13.8 Water injectivity management
- Exercises
- Chapter 14. Drilling-induced near-wellbore formation damage: drilling mud filtrate and solids invasion and mud cake formation
- Abstract
- Summary
- 14.1 Introduction
- 14.2 Formation damage in vertical and horizontal wells
- 14.3 Formation damage caused by drilling and completion fluids
- 14.4 Effect of drilling fluids on shale stability
- 14.5 Mitigation of formation damage induced by completion fluids and crude-oil emulsions
- 14.6 Depth of mud damage prediction
- 14.7 Single phase mud filtrate invasion model
- 14.8 Two-phase wellbore mud invasion and filter cake formation model
- 14.9 Near-wellbore filtrate invasion
- 14.10 Dynamically coupled mud-cake buildup and immiscible multiphase filtrate invasion
- 14.11 Drilling mud loss into naturally fractured reservoirs
- 14.12 Pore-size distribution effect on drilling fluids particulate invasion and removal in porous rocks
- 14.13 Mud cake growth modeling
- Exercises
- Chapter 15. Reservoir stress-induced formation damage: formation compaction, subsidence, sanding tendency, sand migration, prediction and control, and gravel-pack damage
- Abstract
- Summary
- 15.1 Introduction
- 15.2 Stress fields and yield surfaces
- 15.3 Stress shock, critical yield stress, and sand fluidization and production
- 15.4 Review and discussion of sand control issues
- 15.5 Sand management strategies and techniques
- 15.6 Criteria for selection and design of sand control techniques
- 15.7 Pressure pulse workovers
- 15.8 Prediction of sanding conditions using a simple model
- 15.9 Prediction of massive sand production using a differential model
- 15.10 Modeling sand retention in gravel packs
- 15.11 Reservoir compaction and subsidence
- 15.12 Alteration, deformation, damage, and hysteresis in subsurface porous rock formations
- Exercises
- Part IV: Formation damage by inorganic and organic precipitation processes—chemical reactions, saturation phenomena, dissolution, precipitation, and deposition
- Chapter 16. Inorganic scaling and geochemical formation damage
- Abstract
- Summary
- 16.1 Introduction
- 16.2 Geochemical phenomena—classification, formulation, modeling, and simulation
- 16.3 Reactions in porous media
- 16.4 Geochemical modeling
- 16.5 Graphic description of the rock–fluid chemical equilibrium
- 16.6 Geochemical simulation approaches
- 16.7 Geochemical model assisted analysis and simulation of fluid–fluid and rock–fluid compatibility
- 16.8 Geochemical simulation of rock–fluid interactions in brine-saturated sedimentary basins
- 16.9 Treatment of inorganic scales
- Exercises
- Chapter 17. Formation damage by organic deposition
- Abstract
- Summary
- 17.1 Introduction
- 17.2 Characteristics of asphaltenic oils
- 17.3 Mechanisms of the heavy organic deposition
- 17.4 Asphaltene and wax phase behavior
- 17.5 Prediction of asphaltene stability and measurement (detection) of the onset of asphaltene flocculation
- 17.6 Algebraic model for formation damage by asphaltene precipitation in single phase
- 17.7 Plugging–nonplugging pathways model for asphaltene deposition in single phase
- 17.8 Two-phase and dual-porosity model for simultaneous asphaltene-paraffin deposition
- 17.9 Single-porosity and two-phase model for organic deposition
- 17.10 Naphthenate soap deposition-induced formation damage
- 17.11 Control, mitigation, and remediation methods
- Exercises
- Part V: Laboratory assessment of the formation damage potential—instrumental techniques, testing, analysis, and interpretation
- Chapter 18. Instrumental and laboratory techniques for characterization of reservoir rock
- Abstract
- Summary
- 18.1 Introduction
- 18.2 Instrumental laboratory techniques
- 18.3 Mineral quantification
- 18.4 Difference maps technique
- 18.5 Characterization of pore-fracture structure and pore-scale formation damage processes using digital and analytical approaches
- Exercises
- Chapter 19. Laboratory evaluation of formation damage
- Abstract
- Summary
- 19.1 Introduction
- 19.2 Fundamental processes of practical importance for formation damage in petroleum reservoirs
- 19.3 Selection of reservoir compatible fluids
- 19.4 Experimental setup for formation damage testing
- 19.5 Recommended practice for laboratory formation damage tests
- 19.6 Protocol for standard core flood tests
- 19.7 Laboratory procedures for evaluation of common formation damage problems
- 19.8 Evaluation of the reservoir formation damage potential by laboratory testing—a case study
- 19.9 Evaluation of fine particles invasion, plugging, and removal processes during invasion and backflow in fractured and fractured-vuggy reservoirs
- 19.10 Evaluation of the sand holding and plugging processes in nonconsolidated prepacked gravel screens
- Exercises
- Part VI: Field diagnosis and mitigation of formation damage—measurement, assessment, control, and remediation
- Chapter 20. Field diagnosis and measurement of formation damage
- Abstract
- Summary
- 20.1 Introduction
- 20.2 Diagnosis and evaluation of formation damage in the field
- 20.3 Pseudodamage versus formation damage
- 20.4 Measures of formation damage
- 20.5 Model-assisted analysis of the near-wellbore permeability alteration using pressure transient data
- 20.6 Estimation of near-wellbore depth of permeability impairment by mud-filtrate invasion
- 20.7 Productivity decline caused by mud invasion into naturally fractured reservoirs
- 20.8 Continuous real-time series analysis for detection and monitoring formation damage effects
- 20.9 Formation damage expert system
- Exercises
- Chapter 21. Determination of formation- and pseudodamage from well performance: identification, characterization, evaluation, and abatement
- Abstract
- Summary
- 21.1 Introduction
- 21.2 Completion damage and flow efficiency
- 21.3 Formation damage assessment in the field—well surveillance
- 21.4 Well-testing techniques, reservoir parameters, and interpretation methods
- 21.5 Components of the total skin factor
- 21.6 Variable skin factor
- 21.7 Well performance analysis—the inflow performance relationship
- 21.8 Productivity impairment and inflow performance of horizontal and multilateral wells in damaged zones
- 21.9 Perforated well productivity in low-permeability subsurface reservoirs
- Exercises
- Chapter 22. Formation damage control and remediation: conventional techniques and remedial treatments for common problems
- Abstract
- Summary
- 22.1 Introduction
- 22.2 Selection of treatment fluids
- 22.3 Well stimulation
- 22.4 Sandstone and carbonate formation acidizing
- 22.5 Placement of stimulation fluids
- 22.6 Effectiveness of clay-swelling-inhibiting additives
- 22.7 Nanoparticle fluids injection
- 22.8 Scale management
- 22.9 Chelating agents
- 22.10 Explosive well stimulation and completion
- 22.11 Acoustic well stimulation
- 22.12 Near-wellbore formation and wellbore cleanup
- 22.13 Formation damage caused by pressure-pulse induced by valve closure
- 22.14 Controlling the adverse side effects of remedial treatments
- 22.15 Treatment fluid application methods
- 22.16 Thermal effects on treatment fluids
- 22.17 Controlling multiscale formation damage caused by drilling fluid invasion in naturally fractured tight porous reservoir formations
- 22.18 Recapitulation of the methods for formation damage mitigation
- Exercises
- Chapter 23. Reservoir formation damage abatement: guidelines, methodology, preventive maintenance, and remediation treatments
- Abstract
- Summary
- 23.1 Introduction
- 23.2 Common operating constraints and their impact on production and surveillance
- 23.3 Comprehensive methodology for mitigation of formation damage
- Exercises
- Part VII: Modeling and simulation of formation damage—prediction of the near-wellbore formation damage and the combined effects of fluid, completion, and formation damages on well performance by various modeling and simulation approaches and examples
- Chapter 24. Near-wellbore formation damage by inorganic and organic precipitates deposition
- Abstract
- Summary
- 24.1 Introduction
- 24.2 Modeling near-wellbore deposition and its effect on well performance
- 24.3 Near-wellbore sulfur deposition
- 24.4 Near-wellbore calcite deposition
- 24.5 Near-wellbore asphaltene deposition
- 24.6 Near-wellbore wax deposition and formation damage caused by cold-water injection
- Exercises
- Chapter 25. Formation and completion damage problems in tight reservoirs: conventional or unconventional
- Abstract
- Summary
- 25.1 Introduction
- 25.2 Impairment of hydraulic-fracture conductivity by proppant diagenesis, embedment, and compaction in hydraulically fractured tight reservoirs
- 25.3 Fracturing fluid-induced formation damage involving multistage hydraulically fractured horizontal wells completed in tight gas reservoirs
- 25.4 Aqueous phase trapping damage
- Exercises
- Chapter 26. Interactions and coupling of reservoir fluid, completion, and formation damages
- Abstract
- Summary
- 26.1 Introduction
- 26.2 Fundamental damage processes, mechanisms, and skin effects
- 26.3 Wellbore transport processes
- 26.4 Thermal and hydraulic coupling of wellbore with reservoir during remedial fluid treatments illustrated for hydraulically fractured well acidizing
- 26.5 Formation damage effect on the coupled horizontal well/near-well performance
- Exercises
- Chapter 27. Reservoir formation damage simulator development
- Abstract
- Summary
- 27.1 Introduction
- 27.2 Description of fundamental model equations
- 27.3 Numerical solution of formation damage models
- 27.4 Ordinary differential equations
- 27.5 Partial differential equations
- Exercises
- Chapter 28. Model-assisted analysis and interpretation of laboratory and field tests
- Abstract
- Summary
- 28.1 Introduction
- 28.2 Measurement error
- 28.3 Model validation, refinement, and parameter estimation
- 28.4 Formation damage potential of stimulation and production techniques
- 28.5 Reactive-transport simulation of dolomitization, anhydrite cementation, and porosity evolution
- 28.6 Impact of scale deposition in a reservoir
- 28.7 Simulation of fine-particle mobilization, migration, and deposition in a core plug
- Exercises
- Chapter 29. Unit conversion: base and derived units, consistent and inconsistent units, and direct and functional unit-conversion factors
- Abstract
- Summary
- 29.1 Introduction
- 29.2 An SI refresher
- 29.3 Derived units
- 29.4 Direct and functional unit-conversion factors
- 29.5 Unit conversion in equations
- Exercises
- Bibliography
- Further reading
- Index
- Edition: 4
- Published: March 29, 2023
- Imprint: Gulf Professional Publishing
- No. of pages: 1096
- Language: English
- Hardback ISBN: 9780323902281
- eBook ISBN: 9780323984737
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