E-Book, Englisch, 1042 Seiten, Format (B × H): 191 mm x 235 mm
Civan Reservoir Formation Damage
3. Auflage 2015
ISBN: 978-0-12-801910-8
Verlag: Academic Press
Format: EPUB
Kopierschutz: 6 - ePub Watermark
Fundamentals, Modeling, Assessment, and Mitigation
E-Book, Englisch, 1042 Seiten, Format (B × H): 191 mm x 235 mm
ISBN: 978-0-12-801910-8
Verlag: Academic Press
Format: EPUB
Kopierschutz: 6 - ePub Watermark
Reservoir Formation Damage, Third Edition, provides the latest information on the economic problems that can occur during various phases of oil and gas recovery from subsurface reservoirs, including production, drilling, hydraulic fracturing, and workover operations.
The text helps readers better understand the processes causing formation damage and the factors that can lead to reduced flow efficiency in near-wellbore formation during the various phases of oil and gas production.
The third edition in the series provides the most all-encompassing volume to date, adding new material on conformance and water control, hydraulic fracturing, special procedures for unconventional reservoirs, field applications design, and cost assessment for damage control measures and strategies.
- Understand relevant formation damage processes by laboratory and field testing
- Develop theories and mathematical expressions for description of the fundamental mechanisms and processes
- Predict and simulate the consequences and scenarios of the various types of formation damage processes encountered in petroleum reservoirs
- Develop methodologies and optimal strategies for formation damage control and remediation
Autoren/Hrsg.
Fachgebiete
Weitere Infos & Material
Preface
Chapter 01- Overview of Formation Damage PART I - Characterization of Reservoir Rock for Formation Damage-Reservoir Formations, Description and Characterization, Damage Potential, and Petrographics Chapter 02 - Description and Characterization of Oil and Gas Reservoirs for Formation Damage Potential Chapter 03 - Petrographical Characteristics of Petroleum-Bearing Formations
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 04 - Alteration of the Porosity and Permeability of Geological Formations- Basic and Advanced Relationships Chapter 05 - Mineral Sensitivity of Petroleum-Bearing Formations Chapter 06- Petrophysical Alterations- Fluid Disposition, Distribution, and Entrapment, Flow Functions, and Petrophysical Parameters of Geological Formations Chapter 07 - Phase Equilibria, Solubility, and Precipitation in Porous Media Chapter 08 - Particulate Processes in Porous Media Chapter 09 - Multi-Phase and Multi-Species Transport in Porous Media
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 Chapter 11- Multi-Phase Formation Damage by Fines Migration Chapter 12 - Cake Filtration: Mechanism, Parameters and Modeling Chapter 13 - Injectivity of the Waterflooding Wells Chapter 14 - Drilling-Induced Near-Wellbore Formation Damage: Drilling Mud Filtrate and Solids Invasion and Mudcake Formation Chapter 15 - Reservoir Stress-Induced Formation Damage: Formation Compaction, Subsidence, Sanding Tendency, Sand Migration, Prediction and Control, and Gravel-Pack Damage
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 Chapter 17 Formation Damage by Organic Deposition
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 Chapter 19 - Laboratory Evaluation of Formation Damage
PART VI - Field Diagnosis and Mitigation of Formation Damage-Measurement, Assessment, Control, and Remediation Chapter 20 - Field Diagnosis and Measurement of Formation Damage Chapter 21 - Determination of Formation- and Pseudo-Damage from Well Performance- Identification, Characterization, and Evaluation Chapter 22 - Formation Damage Control and Remediation- Fundamentals Chapter 23 - Reservoir Formation Damage Abatement- Guidelines, Methodology, Preventive Maintenance, and Remediation Treatments
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 Chapter 25 - Interactions and Coupling of Reservoir Fluid, Completion, and Formation Damages Chapter 26 - Formation Damage Simulator Development Chapter 27 - Model Assisted Analysis and Interpretation of Laboratory and Field Tests
Chapter 1 Overview of Formation Damage
A comprehensive review of the various types of formation damage problems encountered in petroleum reservoirs is presented. The factors and processes causing these problems are described in detail. The design of a team effort necessary for understanding and controlling of the formation damage problems in the field is explained. The motivation for the writing of this book and the specific objectives are stated. The approach taken in the presentation of the materials in this book is explained. A brief executive summary of the topics covered in the book is given. The roles played by different professionals, such as the petroleum and chemical engineers, chemists, physicist, geologists, and geochemists, are described. Keywords
Petroleum; petroleum reservoirs; formation damage; deformation; remediation Summary
A comprehensive review of the various types of formation damage problems encountered in petroleum reservoirs is presented. The factors and processes causing these problems are described in detail. The design of a team effort necessary for understanding and controlling of the formation damage problems in the field is explained. The motivation for the writing of this book and the specific objectives are stated. The approach taken in the presentation of the materials in this book is explained. A brief executive summary of the topics covered in the book is given. The roles played by different professionals, such as the petroleum and chemical engineers, chemists, physicist, geologists, and geochemists, are described. 1.1 Introduction
Formation damage is a generic term that refers to the impairment of the permeability of petroleum-bearing formations by various adverse processes. Formation damage is an undesirable operational and economic problem that can occur during the various phases of oil and gas recovery from subsurface reservoirs, including drilling, production, hydraulic fracturing, and workover operations (Civan, 2005a,b,c,d). As expressed by Amaefule et al. (1988): “Formation damage is an expensive headache to the oil and gas industry.” Bennion (1999) described formation damage as: “The impairment of the invisible, by the inevitable and uncontrollable, resulting in an indeterminate reduction of the unquantifiable!” Formation damage assessment, control, and remediation are among the most important issues to be resolved for efficient exploitation of hydrocarbon reservoirs (Energy Highlights, 1990). Formation damage may be caused by many factors, including physico-chemical, chemical, biologic, hydrodynamic, and thermal interactions of porous formation, particles, and fluids, and the mechanical deformation of formation under stress and fluid shear. These processes are triggered during the drilling, production, workover, and hydraulic fracturing operations. Ordinarily, the mineral matter and fine particles loosely attached to the pore surface are at equilibrium with the pore fluids. However, variations in chemical, thermodynamic, and stress states may create nonequilibrium conditions and induce the salinity, velocity, and thermal shock phenomena, as well as particle detachment and precipitate formation. When the equilibrium condition existing between the pore surface and the fluids is disturbed during reservoir production by primary, secondary, and enhanced recovery processes, the mineral matter may dissolve and generate many different ions in the aqueous phase, and the fine particles are unleashed from the pore surface into the fluid phases. Once these ions and particles are introduced into the fluid phases, they become mobile. Thus, a condition is created, like a bowl of soup of the mobile ions and fine particles in the pore space, which may interact freely with each other in many intricate ways to create severe reservoir formation damage problems. Formation damage indicators include permeability impairment, skin damage, and decrease in well performance. As stated by Porter (1989): “Formation damage is not necessarily reversible” and “what gets into porous media does not necessarily come out.” Porter (1989) called this phenomenon “the reverse funnel effect.” Therefore, it is better to avoid formation damage than to try to restore the formation. A verified formation damage model and carefully planned laboratory and field tests can provide scientific guidance and help develop strategies to avoid or minimize formation damage. Properly designed experimental and analytic techniques, and the modeling and simulation approaches can help with the understanding, diagnosis, evaluation, prevention, remediation, and controlling of formation damage in oil and gas reservoirs. The consequences of formation damage are the reduction of the oil and gas productivity of reservoirs and noneconomic operation. Therefore, it is essential to develop experimental and analytic methods for understanding and preventing and/or controlling formation damage in oil- and gas-bearing formations (Energy Highlights, 1990). The laboratory experiments are important steps in reaching an understanding of the physical mechanisms of formation damage phenomena. “From this experimental basis, realistic models which allow extrapolation outside the scalable range may be constructed” (Energy Highlights, 1990). These efforts are necessary to develop and verify accurate mathematic models and computer simulators that can be used for predicting and determining strategies to avoid and/or mitigate formation damage in petroleum reservoirs (Civan, 1994a,b,c,d,e, 1996a, 2007b,c). Confidence in formation damage prediction using phenomenologic models cannot be gained without field testing. Planning and designing field test procedures for verification of the mathematic models are important. Once a model has been validated, it can be used for accurate simulation of the reservoir formation damage and designing effective measures for formation damage mitigation. Current techniques for reservoir characterization by history matching do not consider the alteration of the characteristics of reservoir formation during petroleum production. In reality, formation characteristics vary (Civan, 2001a,b,c, 2002a,b,c,d,e,f) and a formation damage model can help incorporate this variation into the history-matching process for accurate characterization of reservoir systems and, hence, an accurate prediction of future performance. Formation damage is an exciting, challenging, and evolving field of research. Eventually, the research efforts will lead to a better understanding and simulation tools that can be used for model-assisted analysis of rock, fluid, and particle interactions and the processes caused by rock deformation and scientific guidance for development of production strategies for formation damage control in petroleum reservoirs. In the past, numerous experimental and theoretic studies have been carried out for the purpose of understanding the factors and mechanisms that govern the phenomena involving formation damage. Although various results were obtained from these studies, a unified theory and approach still do not exist. In spite of extensive research efforts, development of technologies and optimal strategies for cost-effective mitigation of formation damage is still as much art as science. Civan (1996a) explains: A formation damage model is a dynamic relationship expressing the fluid transport capability of porous medium undergoing various alteration processes. Modeling formation damage in petroleum reservoirs has been of continuing interest. Although many models have been proposed, these models do not have the general applicability. However, an examination of the various modeling approaches reveals that these models share a common ground and, therefore, a general model can be developed, from which these models can be derived. Although modeling based on well accepted theoretical analyses is desirable and accurate, macroscopic formation damage modeling often relies on some intuition and empiricism inferred by the insight gained from experimental studies. As J. Willard Gibbs stated in a practical manner: “The purpose of a theory is to find that viewpoint from which experimental observations appear to fit the pattern” (Duda, 1990). Civan (1996a) states: The fundamental processes causing damage in petroleum bearing formations are: (1) physico-chemical, (2) chemical, (3) hydrodynamic, (4) thermal, (5) mechanical, and (6) biological. Formation damage studies are carried out for (1) understanding of these processes via laboratory and field testing, (2) development of mathematical models via the description of fundamental mechanisms and processes, (3) optimization for prevention and/or reduction of the damage potential of the reservoir formation, and (4) development of formation damage control strategies and remediation methods. These tasks can be accomplished by means of a model-assisted data analysis, case studies, and extrapolation and scaling to conditions beyond the limited test conditions. The formulation of the general purpose formation damage model describes the relevant phenomena on the macroscopic scale, i.e., by representative elementary porous media averaging (Civan, 2002). As stated by Civan (1996a): Development of a numerical solution scheme for the highly nonlinear phenomenological model and its modification and verification by means of experimental testing of a variety of cores...
