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Authors: Huinong Zhuang, Yongxin Han, Hedong Sun, Xiaohua LiuLanguage: English
Dynamic Well Testing in Petroleum Exploration and Development, Second Edition, describes the process of obtaining information about a reservoir through examining and analyzing… Read more
Immediately download your ebook while waiting for your print delivery. No promo code is needed.
Dynamic Well Testing in Petroleum Exploration and Development, Second Edition, describes the process of obtaining information about a reservoir through examining and analyzing the pressure-transient response caused by a change in production rate. The book provides the reader with modern petroleum exploration and well testing interpretation methods, including their basic theory and graph analysis. It emphasizes their applications to tested wells and reservoirs during the whole process of exploration and development under special geological and development conditions in oil and gas fields, taking reservoir research and performance analysis to a new level.
This distinctive approach features extensive analysis and application of many pressure data plots acquired from well testing in China through advanced interpretation software that can be tailored to specific reservoir environments.
Chapter 1 Introduction1.1 THE PURPOSE OF THIS BOOK1.1.1 Well Test: A Kind of System Engineering1.1.2 Well Test: Multilateral Cooperation1.1.3 Writing Approaches of this Book1.2 ROLE OF WELL TEST IN GAS FIELD EXPLORATION AND DEVELOPMENT1.2.1 Role of Well Test in Exploration18.104.22.168 Drill Stem Test (DST) of Exploration Wells22.214.171.124 Exploration Well Completing Test126.96.36.199 Reserves evaluation1.2.2 Role of Well Test in Predevelopment188.8.131.52 Deliverability Test of Development Appraisal Wells184.108.40.206 Transient Well Test of Development Appraisal Wells220.127.116.11 Well Test of Production Test Wells18.104.22.168 Selection and Evaluation of Stimulation Treatment22.214.171.124 Verifying Reserves and Making the Development Plan1.2.3 Role of Well Test in Development1.3 KEYS OF WELL TEST ANALYSIS1.3.1 Direct Problem and Inverse Problem in Well Test Research1.3.2 How to Understand Direct Problems126.96.36.199 Analyzing the Formation Where the Oil/Gas Well Locates and Classifying it Geologically188.8.131.52 Classifying, Simulating, and Reproducing Formation from the Viewpoint of Flow Mechanics184.108.40.206 Constructing the Well Test Interpretation Model and Resolving the Related Problem220.127.116.11 Expression Forms of Research Results of Resolving Direct Problems in Well Test1.3.3 Describing Gas Reservoirs: Resolving Inverse Problem18.104.22.168 Well test design22.214.171.124 Acquiring Pressure and Flow Rate Data Onsite126.96.36.199 Graphical Analysis in Well Test Interpretation188.8.131.52 Well Test Interpretation Combining Actual Formation Conditions184.108.40.206 Recommend Knowledge Obtained from Well Test Interpretation to be Applied in Gas Field Development 1.3.4 Computer-Aided Well Test Analysis 1.4 CHARACTERISTICS OF MODERN WELL TEST TECHNOLOGY 1.4.1 One of the Three Key Technologies of Reservoir Characterizations 220.127.116.11 The Distinct Information Here Includes the Following 18.104.22.168 Deficiencies of Well Test Technology 1.4.2 1.4.2 Methods of Gas Reservoir Dynamic Description 25 22.214.171.124 Dynamic Reservoir Description with Deliverability of Gas Wells at the Core 126.96.36.199 New Thoughts in Gas Reservoir Dynamic Description Chapter 2 Introduction 2.1 BASIC CONCEPTS 2.1.1 Steady Well Test and Transient well Test 188.8.131.52 Steady Well Test 184.108.40.206 Transient Well Test 2.1.2 Well Test Interpretation Models and Well Test Interpretation Type Curves 2.1.3 Dimensionless Quantities and Pressure Derivative Curve in Well Test Interpretation Type Curves 2.1.4 Wellbore Storage Effect and its Characteristics on Type Curves 220.127.116.11 Implications of Wellbore Storage Effect 18.104.22.168 Order of Magnitude of Wellbore Storage Coefficient 22.214.171.124 Characteristics of Wellbore Storage Effect on Well Test Interpretation Type Curves 2.1.5 Several Typical Flow Patterns of Natural Gas and their Characteristics on Interpretation Type Curves 126.96.36.199 Radial Flow 188.8.131.52 Steady Flow 184.108.40.206 Pseudo-Steady Flow 220.127.116.11 Spherical Flow and Hemispherical Flow 18.104.22.168 Linear Flow 22.214.171.124 Pseudo-radial Flow 126.96.36.199 Flow Condition in Formation Having been Improved or Damaged 2.1.6 Skin Effect, Skin Factor and Equivalent Borehole Radius 2.1.7 Radius of Influence 2.1.8 Laminar Flow and Turbulent Flow 2.2 Gas flow equations 2.2.1 Definition of Reservoir as a Continuous Medium 2.2.2 Flow Equations 188.8.131.52 Deriving Flow Equations Based on Three Basic Equations 184.108.40.206 Average Flowing Velocity and Flow Velocity of Unit Cell 220.127.116.11 Darcy’s Law Applied for Flow of Viscous Fluid 18.104.22.168 Continuity Equation 22.214.171.124 State Equation of Gas 126.96.36.199 Subsurface Flow Equations of Natural Gas 188.8.131.52 Dimensionless Expressions of Gas Flow Equations 184.108.40.206 Boundary Conditions and Initial Conditions for Solving Gas Flow Equations 2.3 Summary Chapter 3 Gas Well Deliverability Test and Field Examples 3.1 GAS WELL DELIVERABILITY AND ABSOLUTE OPEN FLOW POTENTIAL (AOFP) 3.1.1 Meanings of Gas Well Deliverability 3.1.2 Gas Well Deliverability Indices 220.127.116.11 Deliverability of a Gas Well 18.104.22.168 Absolute Open Flow Potential of Gas Wells 22.214.171.124 Validity of AOFP 126.96.36.199 Initial and Dynamic AOFP 3.1.3 Initial Deliverability, Extended Deliverability, and Allocated Production of Gas Well 188.8.131.52 Initial Deliverability Index 184.108.40.206 Extended Deliverability Index 220.127.116.11 Allocating Flow Rate Index 3.2 THREE CLASSICAL DELIVERABILITY TEST METHODS 3.2.1 Back-Pressure Test Method 3.2.2 Isochronal Test Method 3.2.3 Modified Isochronal Test Method 3.2.4 Simplified Single Point Test 18.104.22.168 Stable Point LIT Deliverability Equation 22.214.171.124 AOFP Calculation With Single Point Test Method 3.2.5 Schematic Diagram of Calculating Pressure Differential for Various Test Methods 3.3 TREATMENT OF DELIVERABILITY TEST DATA 3.3.1 Two Deliverability Equations 126.96.36.199 Exponential Deliverability Equation 188.8.131.52 LIT Equation 3.3.2 Difference between Two Deliverability Equations 184.108.40.206 If Gas Flow Rate of Tested Well During Testing is Higher Than 50% of AOFP, Calculation Results of Two Deliverability Equations are Similar 220.127.116.11 Greater Error Generates from Exponential Deliverability Equation if Pressure Differences are Small of all Test Points 3.3.3 Three Different Pressure Expressions of Deliverability Equation 3.4 PARAMETER FACTORS INFLUENCING GAS WELL DELIVERABILITY 3.4.1 Expressions of Coefficients A And B in Deliverability Equation of a Well In Infinite Homogeneous Reservoir 18.104.22.168 Analysis of Expression of A [Equation (3.22)] 22.214.171.124 Analysis of Expression of B [Equation (3.23)] 3.4.2 Deliverability Equation When Gas Flow Entering into Pseudo-steady State 3.5 SHORT-TERM PRODUCTION TEST COMBINED WITH MODIFIED ISOCHRONAL TEST IN GAS WELLS 3.5.1 Pressure Simulation of Tested Wells 3.5.2 Improvement of AOFP Calculation Methods In Modified IsochronalTest 126.96.36.199 Classical Method 188.8.131.52 Improved Calculation Method 184.108.40.206 Comparison of Two Calculation Methods 3.6 STABLE POINT LAMINAR-INERTIAL-TURBULENT (LIT) DELIVERABILITY EQUATION 3.6.1 Background of Bringing Forward Stable Point LIT Deliverability Equation 220.127.116.11 Puzzles in Determining Gas Well Deliverability by Classical Methods 18.104.22.168 Existing Problems of Classical Methods 3.6.2 Stable Point LIT Deliverability Equation 22.214.171.124 Characteristics of New-Type Deliverability Equation 126.96.36.199 The New Method is Supplement and Improvement of The Original Classical Deliverability Test Method 3.6.3 Theoretical Deduction and Establishment of Stable Point LIT Deliverability Equation 188.8.131.52 Classification of Parameters Influencing Coefficients A and B 184.108.40.206 Determination of Deliverability Coefficient kh and Establishment of Initial Deliverability Equation 3.6.4 Field Examples 220.127.116.11 Application of Initial Stable Point LIT Equation in Well Kl-205 18.104.22.168 LIT Equation Established in SLG Gas Field 3.6.5 Methods of Establishing Dynamic Deliverability Equation 22.214.171.124 Initial stable point LIT equation is established firstly 126.96.36.199 Establishment of dynamic deliverability equation 188.8.131.52 Deliverability decline process in gas wells 3.6.6 Stable Point LIT Equation of Horizontal Wells 184.108.40.206 Theoretical Deduction of Stable Point LIT Equation for Horizontal Wells 220.127.116.11 Establishment the Initial Stable Point LIT Deliverability Equation for Horizontal Wells 18.104.22.168 Method of Establishing Dynamic Deliverability Equation 3.7 PRODUCTION PREDICTION IN DEVELOPMENT PROGRAM DESIGNING OF GAS FIELDS 3.7.1 Deliverability Prediction of Wells with Available Well Test Data 22.214.171.124 Determining Gas Well Flow Rate with Reasonable Producing Pressure Differential 126.96.36.199 Gas Flow Rate is Determined by Intersection of the Inflow Performance Relationship and Outflow Performance Relationship Curves 188.8.131.52 Determining Deliverability During the Process of Formation Pressure Depletion 184.108.40.206 Other Limitations for Gas Flow Rate 3.7.2 Deliverability Prediction of Production Wells in Development Program Designing 220.127.116.11 Establishing the Deliverability Equation of the Whole Gas Field 18.104.22.168 Plotting Distribution Map of kh Value over the Whole Gas Field and Determination of kh Value at Well Point 22.214.171.124 Calculating Rational Flow Rate of Planned Wells in the Development Program by Deliverability Equation 3.8 DISCUSSION ON SEVERAL KEY PROBLEMS IN DELIVERABILITY TEST 3.8.1 Design of Deliverability Test Points 126.96.36.199 Design of Flow Rate Sequence 188.8.131.52 Stabilization of Gas Flow Rate 184.108.40.206 Selection of Duration For Each Test Point 3.8.2 Why Calculated AOFP Sometimes is Lower Than Measured Wellhead Flow Rate 3.8.3 Existing Problems in Calculating AOFP by Backpressure Test Method 220.127.116.11 Backpressure Test for Homogeneous Formations 18.104.22.168 Backpressure Test for Fractured Wells in Channel Homogeneous Formation 3.8.4 Method and Analysis of Single-Point Deliverability Test and its Error 22.214.171.124 Single-Point Deliverability Test 126.96.36.199 Two Examples of AOFP Calculation Formulae for Single-Point Test in Development Areas of Gas Field 188.8.131.52 Some Examples of AOFP Calculation Formulae for Single-Point Test Method for Exploration Wells 184.108.40.206 Errors Analysis of Single-Point Deliverability Test Method 3.8.5 Deliverability Test without Any Stable Flow Points 3.8.6 Discussion on Wellhead Deliverability 3.8.7 Manually Calculating the Coefficients A and B in Deliverability Equation and AOFP 220.127.116.11 Data Acquisition 18.104.22.168 Establishment of Transient Deliverability Equation 22.214.171.124 Establishment of Stabilized Deliverability Equation 126.96.36.199 Calculating AOFP 3.9 Summary Chapter 4 Gas Reservoir Characteristics with Pressure Gradient Method 4.1 PRESSURE GRADIENT ANALYSIS OF EXPLORATION WELLS IN THE EARLY STAGE AND SOME FIELD EXAMPLES 4.1.1 Collection and Processing of Pressure Data 4.1.2 Pressure Gradient Analysis 4.2 CALCULATION OF GAS DENSITY AND PRESSURE GRADIENT UNDER FORMATION CONDITIONS 4.3 PRESSURE GRADIENT ANALYSIS DURING DEVELOPMENT OF A GAS FIELD 4.4 SOME KEY POINTS IN PRESSURE GRADIENT ANALYSIS 4.4.1 Accuracy of Acquired Pressure Data 4.4.2 Pressure Gradient Analysis should be Combined Closely with Geologic Research 188.8.131.52 The Area-Division of the Reservoir Provided by Pressure Gradient Analysis should be Supported by the Relevant Geological Basis 184.108.40.206 Analysis of Pressure Gradient Characteristics Provides Supporting Information for Validating Reserves Calculation Results 220.127.116.11 Analysis of Pressure Gradient Provides Basic Parameters for the Designing of Development Program 4.5 ACQUISITION OF DYNAMIC FORMATION PRESSURE AFTER A GAS FIELD HAS BEEN PUT INTO DEVELOPMENT 4.5.1 Dynamic Production Indices During Production of a Gas Field 4.5.2 Several Formation Pressures with Different Meanings 18.104.22.168 Measured Average Formation Pressure 22.214.171.124 Formation Pressure Determined by Deduction Based on Dynamic Model 126.96.36.199 Calculation of Formation Pressure at Gas Drainage Boundary pe 188.8.131.52 Other Frequently Used Formation Pressure Concepts 4.5.3 Performance Analysis with Dynamic Formation Pressures 184.108.40.206 Research on Reservoir Division 220.127.116.11 Dynamic Variation Analysis of Pressure Gradient Line Chapter 5 Gas Reservoir Dynamic Model and Well Test 5.1 INTRODUCTION 5.1.1 Static and Dynamic Models of Gas Reservoir 18.104.22.168 Geological Modeling of Gas Reservoirs 22.214.171.124 Dynamic Model of Gas Reservoirs and Gas Wells 5.1.2 Pressure History of a Gas Well Symbolizes the Life History of it 126.96.36.199 Different Pressure Histories Exist Under Different Reservoirs and/or Different Well Completion Conditions 188.8.131.52 Pressure History Trend of Gas Well is Determined by Reservoir Conditions 184.108.40.206 Main Approach to Confirm Reservoir Dynamic Model is Pressure History Match Verification 5.1.3 Study Characteristics of Reservoir Dynamic Model Based on Characteristics of Transient Well Test Curves 220.127.116.11 Different Portions of Transient Pressure Curve Reflect Characteristics of Different Zones of the Reservoir 18.104.22.168 Pressure Derivative Curve is the Main Basis in Identifying Reservoir Characteristics 22.214.171.124 “Graphics Analytical Method” used to Identify Reservoir Dynamic Mode 5.2 PRESSURE CARTESIAN PLOT-PRESSURE HISTORY PLOT 5.2.1 Content and Drawing of Gas Well Pressure History Plot 126.96.36.199 Preprocessing and Data Examination of Gas Well Pressure History Records 188.8.131.52 Pressure History Plot of Gas Well 5.2.2 Information About Formation and Well Shown in Pressure History Plot 184.108.40.206 Pressure History Plot During DST Of Natural Flow Gas Well 220.127.116.11 Pressure History Plot during DST of Low Production Rate Gas Well 5.3 PRESSURE SEMILOG PLOT 5.3.1 Several Semilog Plots 18.104.22.168 Pressure Drawdown Analysis Plot 22.214.171.124 Horner Plot 126.96.36.199 MDH Plot 188.8.131.52 Superposition Function Plot 5.3.2 Semilog Plot used in Analysis by Well Test Interpretation Software 184.108.40.206 Model Diagnosis in Early Interpretation Process 220.127.116.11 Verification of Match Analysis Results of Well Test Model 5.4 LOG-LOG PLOT AND MODEL GRAPH OF PRESSURE AND ITS DERIVATIVE 5.4.1 Log-log Plots and Type Curves for Modern Well Test Interpretation 18.104.22.168 Type Curve Analysis is the Core of Modern Well Test Interpretation 22.214.171.124 Some Common Log-Log Type Curves 5.4.2 Typical Characteristic Curves―Model Graphs for Well Test Analyses 5.5 CHARACTERISTIC DIAGRAM AND FIELD EXAMPLES OF TRANSIENT WELL TEST IN DIFFERENT TYPES OF RESERVOIRS 5.5.1 Characteristic Diagram (Model Graph M-1) and Field Examples of Homogeneous Formations 126.96.36.199 Homogeneous Formations in Gas Fields 188.8.131.52 Positioning Analysis 184.108.40.206 Classiﬁed Model Graphs for Positioning Analysis of Homogeneous Formations 220.127.116.11 Field Examples 5.5.2 Characteristic Graph of Double Porosity System (Model Graphs M-2 and M-3) and Field Examples 18.104.22.168 Composition and Flow Characteristics of Double Porosity System 22.214.171.124 Several Inﬂuencing Factors in Acquiring Parameters of Double Porosity System 126.96.36.199 Conditions for High-Quality Data Acquisition and Some Field Examples 5.5.3 Characteristic Graph of Homogenous Formation with Hydraulic Fractures (Model Graphs M-4 and M-5) and Field Examples 188.8.131.52 Creation and Retention Mechanism of Hydraulic Fracture 184.108.40.206 Curve Characteristics of Well Connecting with a High Conductivity Vertical Fracture 220.127.116.11 Flow Characteristics of in Fracture with Uniform Flow 18.104.22.168 Vertical Fracture with Finite Conductivity 22.214.171.124 Fracture Skin Factor and its Effect 5.5.4 Characteristic Diagram of Wells with Partial Perforation (Model Graph M-6) and Field Examples 126.96.36.199 Geological Background of Well Completion with Partial Perforation 188.8.131.52 Flow Model in Cases of Partial Perforation 184.108.40.206 Field Examples 5.5.5 Characteristic Diagram and Field Examples of Composite Formation (Model Graphs M-7 and M-8) 220.127.116.11 Principles for Evaluation of Type of Reservoir Boundary 18.104.22.168 Geological Conditions of Composite Formations 22.214.171.124 Model Graph of Composite Formation 126.96.36.199 Analysis of Field Examples 5.5.6 Characteristic Graph of Formations with No-Flow Boundaries (Model Graphs M-9-M-13) and Field Examples 188.8.131.52 Geological Background 184.108.40.206 Flow Model Graph of a Well with No-Flow Outer Boundary 5.5.7 Characteristic Graph and Field Examples of Fissured Zone with Boundaries (Model Graphs M-14 and M-15) 220.127.116.11 Strip-Like Fissured Zone with Directional Permeability 18.104.22.168 Beaded Fissured Bands 22.214.171.124 Complex Fissured Zone 5.5.8 Characteristic Graph and Field Examples of Condensate Gas Wells 126.96.36.199 Geological Background and Focused Problems 188.8.131.52 Model Graphs and Field Examples of Transient Test in Condensate Gas Well 5.5.9 Characteristic Graph of Horizontal Wells (Model Graph M-16) and Field Examples 184.108.40.206 Geological and Engineering Background 220.127.116.11 Typical Well Test Model Graph 5.6 SUMMARY Chapter 6 Interference Test and Pulse Test 6.1 APPLICATION AND DEVELOPMENT HISTORY OF MULTIPLE-WELL TEST 6.1.1 Application of Multiple-Well Test 18.104.22.168 To Identify Formation Connectivity between Wells 22.214.171.124 To Conﬁrm the Sealing of Faults 126.96.36.199 To Estimate Interwell Connectivity Parameters 188.8.131.52 To Identify the Vertical Connectivity of Reservoir 184.108.40.206 To Study Formation Anisotropy 220.127.116.11 To Study the Reservoir Areal Distribution and to Conﬁrm the Results of Reserves Estimation 6.1.2 Historical Development of Multiple-Well Test 18.104.22.168 Multiple-Well Test Development Abroad 22.214.171.124 Development of Multiple-Well Test in China 6.1.3 How to Perform and Analyze the Interference Test and Pulse Test 126.96.36.199 Factors Affecting Interference Pressure Acquisition 188.8.131.52 Dialectic Consideration for Performing Multiple-Well Test Research in a Region 6.2 PRINCIPLE OF INTERFERENCE TEST AND PULSE TEST 6.2.1 Interference Test 184.108.40.206 Test Methods 220.127.116.11 Parameter Factors Affecting Interference Pressure Response Value 18.104.22.168 Type Curve Interpretation Method for Interference Test Data 22.214.171.124 Characteristic Point Interpretation Method for Interference Test 6.2.2 Pulse Test 126.96.36.199 Pulse Test Method 188.8.131.52 Kamal’s Analysis Method for Pulse Test 184.108.40.206 Pulse Test Analysis by Conventional Interference Test Type Curve Methods 6.2.3 Multiple-Well Test Design 220.127.116.11 Principle of Multiple-Well Test Design 18.104.22.168 Multiple-Well Test Simulated Design 22.214.171.124 Make Multiple-Well Test Field Implementation Plan 6.3 FIELD EXAMPLES OF MULTIPLE-WELL TEST IN OIL AND GAS FIELD RESEARCH 6.3.1 Interference Test Research in JB Gas Field 126.96.36.199 Geological Conditions of JB Gas Field 188.8.131.52 Well Test Design and Operation 184.108.40.206 Test Results 220.127.116.11 Parameter Calculation 6.3.2 SLG Gas Field Interference Test Research 18.104.22.168 Overall Geological Conditions of Well Group of Interference Test 22.214.171.124 Interference Test Well Group Design and Implementation 126.96.36.199 Interpretation of Interference Test Data 188.8.131.52 To Identify Rational Well Spacing in SLG Gas Field by Interference Test Results 6.3.3 Gas Well Interference Test Study in Fault Block Y8 of SL Oil Field 6.3.4 Test Research on Connectivity between Injector and Producer in Fault Block 184.108.40.206 Research of Connectivity between Injector and Producer in ST Block 3, SL Oil Field 220.127.116.11 Research on Isolation of the Fault in Well Y18 Area of SL Oil Field 18.104.22.168 Efﬁciency Analysis of Injection in Fault Block B96 6.3.5 Comprehensive Evaluation of Multiple-Well Tests in KL Palaeo-Burial Hill Oil Field 22.214.171.124 Overall Geological Condition of KL Oil Region 126.96.36.199 Test Arrangement and Achieved Results 188.8.131.52 Analyzing the Characteristics of Formation Dynamic Model with Multiple-Well Test Results 6.4 SUMMARY Chapter 7 Coalbed Methane Well Test Analysis 7.1 COALBED METHANE WELL TEST 7.1.1 Function of Coalbed Methane Well Test in Coalbed Methane Reservoir 184.108.40.206 To Obtain Effective Permeability of Fissures or Cleats in Coalbed 220.127.116.11 To Obtain Average Reservoir Pressure 18.104.22.168 To Analysis Damage and Improvement of Coalbeds 22.214.171.124 To Evaluate Fracturing Effects 126.96.36.199 To Identify Coalbed Connectivity and Calculate Connectivity Parameters 188.8.131.52 To Determine of Pore Volume of Coalbed 184.108.40.206 To Analysis the Development Direction of Fissures 220.127.116.11 To Detect the Flow Boundaries in Coalbed 7.1.2 Differences between Coalbed Methane Well Test and Common Gas Well Test 18.104.22.168 Fluid Seen During Coalbed Methane Well Testing Is Often Water 22.214.171.124 Do Not Show Flow Characteristics of the Double Porosity Medium 126.96.36.199 Purpose and Analysis Methods Depend On Production Stages 7.2 FLOW MECHANISM AND WELL TESTING MODELS IN A COALBED 7.2.1 Structural Characteristics of a Coalbed and Flow of Coalbed Methane 188.8.131.52 Structure of Coalbed and Reserve of Methane 184.108.40.206 Flow Process in Coalbed Methane Production 7.2.2 Typical Dynamic Models of Coalbed Methane Well Test 7.2.3 Water Single-Phase Flow Characteristics and Data Interpretation Methods 7.2.4 Single-Phase Flow of Methane Desorption and Well Test Analysis Method 220.127.116.11 Coalbed Conditions 18.104.22.168 Flow Equation 22.214.171.124 Analyzing Coalbed Methane Well Test Data by Conventional Method 126.96.36.199 Characteristics of Well Test Curves When Desorption Happens 7.3 INJECTION/FALLOFF WELL TEST METHOD FOR COALBED METHANE WELLS 7.3.1 Equipment and Technology for Injection/Falloff Well Testing 188.8.131.52 Test String 184.108.40.206 Measuring Instruments 220.127.116.11 Water Injection Pump 18.104.22.168 Testing Process 7.3.2 Well Test Design of Injection/Falloff 22.214.171.124 Selection of Shut-In Mode 126.96.36.199 Calculation of Injection Pressure 188.8.131.52 Calculation of Water Injection Rate 184.108.40.206 Determination of Water Injection Volume 220.127.116.11 Determination of Inﬂuence Radius and Injection Duration 18.104.22.168 Effect of Coalbed Elastoplasticity 7.3.3 Data Examination and Analysis Methods of Injection/Falloff Well Testing 22.214.171.124 Variable Wellbore Storage Effect in Injection/Falloff Test Process 126.96.36.199 Inspection of Abnormal Changes of Test Curves 188.8.131.52 Comments on Data Examination and Analysis 7.4 ANALYSIS AND INTERPRETATION OF INJECTION/FALLOFF TEST DATA 7.4.1 Interpretation Methods 184.108.40.206 Model Types 220.127.116.11 Interpretation Procedure 7.4.2 Real Field Example 18.104.22.168 Well Ex 1-A Coalbed Methane Well Completed with Fracturing 22.214.171.124 Well Ex 2-A Perforated Completion Coalbed Methane Well 7.5 SUMMARY Chapter 8 Gas-field Production Test and Dynamic Gas Reservoir Description 8.1 PRODUCTION TEST IN SPECIAL LITHOLOGIC GAS FIELDS IN CHINA 8.1.1 Special Lithologic Gas Field in China 8.1.2 Production Test: An Effective Way to Solve Problems in Development of Special Lithologic Gas Reservoirs 8.1.3 Procedure of Production Test in Gas Wells 8.1.4 Dynamic Reservoir Description Based on Production Test Data of Gas Wells 8.2 DYNAMIC GAS RESERVOIR DESCRIPTION IN DEVELOPMENT PREPARATORY STAGE OF JB GAS FIELD 8.2.1 Geological Conditions of JB Gas Field 8.2.2 Focuses of the Problems 8.2.3 Dynamic Study at the Preparatory Stage of Gas Field Development 8.3 SHORT-TERM PRODUCTION TEST AND EVALUATION OF GAS RESERVOIR CHARACTERISTICS IN KL-2 GAS FIELD 8.3.1 Geological Condition 8.3.2 Procedure and Result