Reservoir Formation Damage

Fundamentals, Modeling, Assessment, and Mitigation

4th Edition - March 29, 2023
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

Purchase options

LIMITED OFFER

Save 50% on book bundles

Immediately download your ebook while waiting for your print delivery. No promo code is needed.

Institutional subscription on ScienceDirect

Request a sales quote

Resources

Textbook support for instructors(opens in new tab/window)

Reservoir 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.

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

Faruk Civan

Faruk Civan is the Martin G. Miller Chair Professor of the Mewbourne School of Petroleum and Geological Engineering at the University of Oklahoma in Norman. He formerly held the Brian and Sandra O’Brien Presidential and Alumni Chair Professorships. Previously, he worked in the Chemical Engineering department at the Technical University of Istanbul, Turkey. Dr. Civan received an Advanced Engineering Degree from the Technical University of Istanbul, Turkey, a M.S. degree from the University of Texas at Austin, Texas, and a Ph.D. degree from the University of Oklahoma, Norman, Oklahoma. All of his degrees are in chemical engineering. Dr. Civan specializes in petrophysics and reservoir characterization; fossil and sustainable energy resources development; carbon sequestration; unconventional gas and condensate reservoirs; reservoir and well/pipeline hydraulics and flow assurance; formation and well damage modeling, diagnosis, assessment, and mitigation; reservoir and well analyses, modeling, and simulation; natural gas engineering, measurement, processing, hydrates, transportation, and storage; carbon dioxide sequestration; coalbed methane production; improved reservoir recovery techniques; corrosion protection in oil and gas wells; filtration and separation techniques; oil and gas processing, transportation, and storage; multiphase transport phenomena in porous media; environmental pollution assessment, prevention, and control; mathematical modeling and simulation, and solving differential equations by numerical methods including by the quadrature, cubature, and finite-analytic methods. Dr. Civan is the author of two books, has published more than 330 technical articles in journals, edited books, handbooks, encyclopedia, and conference proceedings, and presented worldwide more than 125 invited seminars and/or lectures at various technical meetings, companies, and universities. He teaches short industry courses on a number of topics worldwide. Additionally, he has written numerous reports on his funded research projects. Dr. Civan’s publications have been cited frequently in various publications, as reported by the Science Author Citation Index. He is a member of the Society of Petroleum Engineers and the American Institute of Chemical Engineers. and a member of the editorial boards of several journals. He has served on numerous petroleum and chemical engineering, and other related conferences and meetings in various capacities, including as committee chairman and member, session organizer, chair or co-chair, and instructor. Civan has received 21 honors and awards, including five distinguished lectureship awards and the 2003 SPE Distinguished Achievement Award for Petroleum Engineering Faculty and the 2014 SPE Reservoir Description and Dynamics Award.

Affiliations and expertise

Martin G. Miller Chair Professor, Mewbourne School of Petroleum and Geological Engineering, University of Oklahoma in Norman, USA