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Advanced Reservoir Management and Engineering 2nd edition [Kõva köide]

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(Consultant, Tarek Ahmed and Associates, Ltd.), (President of CMG Petroleum Consulting, United States)
  • Formaat: Hardback, 712 pages, kõrgus x laius: 235x191 mm, kaal: 1420 g, 150 illustrations; Illustrations, unspecified
  • Ilmumisaeg: 01-Nov-2011
  • Kirjastus: Gulf Professional Publishing
  • ISBN-10: 0123855489
  • ISBN-13: 9780123855480
Teised raamatud teemal:
Advanced Reservoir Management and Engineering 2nd editionSuurem pilt
  • Formaat: Hardback, 712 pages, kõrgus x laius: 235x191 mm, kaal: 1420 g, 150 illustrations; Illustrations, unspecified
  • Ilmumisaeg: 01-Nov-2011
  • Kirjastus: Gulf Professional Publishing
  • ISBN-10: 0123855489
  • ISBN-13: 9780123855480
Teised raamatud teemal:
Püsilink: https://www.kriso.ee/db/9780123855480.html
Märksõnad:

Reservoir management is concerned with the geoscience and reservoir/production engineering required to plan and optimize the development of discovered or producing oil and gas assets. One of the only books to cover both management and engineering issues, Advanced Reservoir Management and Engineering is redesigned to be the only book you need throughout your career. Written by two of the industry's best-known and well respected reservoir engineers and managers, this new edition offers readers a complete guide for formulating workflow solutions on a day to day bases.

Authoritative in its approach, the book begins with the theory and practice of transient flow analysis and offers a brief but thorough hands-on guide to gas and oil well testing. Chapter two documents water influx models and their practical applications in conducting comprehensive field studies, widely used throughout the industry. Essential topics such as Type-Curve Analysis, unconventional gas reservoirs, and gas hydrates are also covered. The book moves on to provide a clear exposition of key economic and financial management methods for evaluation criteria and cash flow analysis, analysis of fixed capital investments and advanced evaluation approaches. This is followed by a frank discussion of advanced evaluation approaches such as integration of decision analysis and professional ethics.

Readers will find the website a valuable guide for enhancing their understanding of different techniques used for predicting reservoir performance and cost. The website will also include information such as properties, tables and simple calculations. This combination book and website arrangement will prove particularly useful to new professionals interested in increasing their skills or more experienced professional wishing to increase their knowledge of current industry best practices.

The 2nd Edition of the book includes 3 new management chapters, representing a 30% increase over the previous edition. The new subjects include step by step approach to cash flow analysis, analysis of fixed capital investments, cash flow consequences, maintenance as well as a detailed approach to managing working capital. This is followed by a clear exposition of advanced evaluation approaches such as integration of decision analysis and economic evaluation and professional ethics.

  • Maximize cash flow, subject to capital and operating budget
  • Deliver new high-quality investment opportunities to management
  • Effectively manage the development of oil and gas assets
  • Maximize the benefit to the legitimate stakeholders

Muu info

Maximize operational benefits while keeping high standards of safety, environmental, technical and commercial integrity.
Preface ix
Chapter 1 Well Testing Analysis
1(226)
1.1 Primary Reservoir Characteristics
1(5)
1.1.1 Types of Fluids
1(1)
1.1.2 Flow Regimes
2(2)
1.1.3 Reservoir Geometry
4(2)
1.1.4 Number of Fluids Flowing in the Reservoir
6(1)
1.2 Fluid Flow Equations
6(58)
1.2.1 Darcy's Law
6(1)
1.2.2 Steady-state Flow
7(15)
1.2.3 Unsteady-state Flow
22(1)
1.2.4 Basic Transient Flow Equation
23(3)
1.2.5 Radial flow of Slightly Compressibility Fluids
26(12)
1.2.6 Radial Flow of Compressible Fluids
38(6)
1.2.7 Pseudosteady State
44(4)
1.2.8 Radial Flow of Slightly Compressible Fluids
48(5)
1.2.9 Radial Flow of Compressible Fluids (Gases)
53(1)
1.2.10 Skin Factor
54(3)
1.2.11 Turbulent Flow Factor
57(2)
1.2.12 Principle of Superposition
59(5)
1.3 Transient Well Testing
64(32)
1.3.1 Drawdown Test
66(12)
1.3.2 Pressure Buildup Test
78(1)
1.3.3 Horner Plot
79(7)
1.3.4 Miller---Dyes---Hutchinson Method
86(3)
1.3.5 MBH Method
89(5)
1.3.6 Ramey-Cobb Method
94(1)
1.3.7 Dietz Method
95(1)
1.4 Type Curves
96(13)
1.4.1 Gringarten Type Curve
101(8)
1.5 Pressure Derivative Method
109(62)
1.5.1 Model Identification
121(1)
1.5.2 Analysis of Early-time Test Data
122(2)
1.5.3 Analysis of Middle-time Test Data
124(16)
1.5.4 Hydraulically Fractured Reservoirs
140(31)
1.6 Interference and Pulse Tests
171(25)
1.6.1 Interference Testing in Homogeneous Isotropic Reservoirs
173(4)
1.6.2 Interference Testing in Homogeneous Anisotropic Reservoirs
177(6)
1.6.3 Pulse Testing in Homogeneous Isotropic Reservoirs
183(12)
1.6.4 Pulse Testing in Homogeneous Anisotropic Reservoirs
195(1)
1.6.5 Pulse Test Design Procedure
195(1)
1.7 Injection Well Testing
196(11)
1.7.1 Supercharging
197(1)
1.7.2 Flow Analysis
197(2)
1.7.3 Example Use of Gradients
199(3)
1.7.4 Solution
202(1)
1.7.5 Fluid Identification
203(1)
1.7.6 Advanced Application
204(3)
1.8 Injection Well Testing
207(14)
1.8.1 Injectivity Test Analysis
207(4)
1.8.2 Pressure Falloff Test
211(9)
1.8.3 Step-rate Test
220(1)
1.9 Problems
221(6)
Chapter 2 Water Influx
227(54)
2.1 Classification of Aquifers
227(2)
2.1.1 Degree of Pressure Maintenance
227(1)
2.1.2 Outer Boundary Conditions
228(1)
2.1.3 Flow Regimes
228(1)
2.1.4 Flow Geometries
229(1)
2.2 Recognition of Natural Water Influx
229(1)
2.3 Water Influx Models
230(51)
2.3.1 The Pot Aquifer Model
230(2)
2.3.2 The Schilthuis Steady-state Model
232(2)
2.3.3 The Hurst Modified Steady-state Equation
234(2)
2.3.4 The van Everdingen and Hurst Unsteady-state Model
236(35)
2.3.5 The Carter and Tracy Water Influx Model
271(3)
2.3.6 The Fetkovich Method
274(7)
Chapter 3 Unconventional Gas Reservoirs
281(152)
3.1 Vertical Gas Well Performance
281(18)
3.1.1 Gas Flow under Laminar (Viscous) Flowing Conditions
281(4)
3.1.2 Gas Flow under Turbulent Flow Conditions
285(5)
3.1.3 Back-Pressure Test
290(6)
3.1.4 Future Inflow Performance Relationships
296(3)
3.2 Horizontal Gas Well Performance
299(2)
3.3 Material Balance Equation for Conventional and Unconventional Gas Reservoirs
301(24)
3.3.1 The Volumetric Method
301(2)
3.3.2 The Material Balance Method
303(1)
3.3.3 Volumetric Gas Reservoirs
304(5)
3.3.4 Water Drive Gas Reservoirs
309(16)
3.4 Coalbed Methane
325(25)
3.4.1 Gas Content
327(9)
3.4.2 Density of the Coal
336(1)
3.4.3 Deliverability and Drainage Efficiency
337(2)
3.4.4 Permeability and Porosity
339(1)
3.4.5 Material Balance Equation for Coalbed Methane
340(6)
3.4.6 Prediction of CBM Reservoir Performance
346(3)
3.4.7 Flow of Desorbed Gas in Cleats and Fractures
349(1)
3.5 Tight Gas Reservoirs
350(56)
3.5.1 Compartmental Reservoir Approach
352(5)
3.5.2 Combined Decline Curve and Type Curve Analysis Approach
357(49)
3.6 Gas Hydrates
406(19)
3.6.1 Phase Diagrams for Hydrates
407(16)
3.6.2 Hydrates in Subsurface
423(2)
3.7 Shallow Gas Reservoirs
425(8)
Chapter 4 Performance of Oil Reservoirs
433(52)
4.1 Primary Recovery Mechanisms
433(10)
4.1.1 Rock and Liquid Expansion
433(1)
4.1.2 Depletion Drive Mechanism
434(1)
4.1.3 Gas Cap Drive
435(3)
4.1.4 Water Drive Mechanism
438(2)
4.1.5 Gravity Drainage Drive
440(2)
4.1.6 Combination Drive Mechanism
442(1)
4.2 The Material Balance Equation
443(1)
4.3 Generalized MBE
444(13)
4.3.1 Basic Assumptions in the MBE
444(5)
4.3.2 Increasing Primary Recovery
449(2)
4.3.3 Reservoir Driving Indices
451(6)
4.4 The MBE as an Equation of a Straight Line
457(22)
4.4.1 Case 1: Volumetric Undersaturated Oil Reservoirs
458(3)
4.4.2 Case 2: Volumetric Saturated Oil Reservoirs
461(8)
4.4.3 Case 3: Gas Cap Drive Reservoirs
469(4)
4.4.4 Case 4: Water Drive Reservoirs
473(4)
4.4.5 Case 5: Combination Drive Reservoirs
477(1)
4.4.6 Case 6: Average Reservoir Pressure
478(1)
4.5 Tracy's Form of the MBE
479(2)
4.6 Problems
481(4)
Chapter 5 Predicting Oil Reservoir Performance
485(56)
5.1 Phase
1. Reservoir Performance Prediction Methods
485(23)
5.1.1 Instantaneous GOR
485(4)
5.1.2 The Reservoir Saturation Equations and their Adjustments
489(6)
5.1.3 Undersaturated Oil Reservoirs
495(1)
5.1.4 Saturated Oil Reservoirs
496(12)
5.2 Phase
2. Oil Well Performance
508(27)
5.2.1 Vertical Oil Well Performance
509(19)
5.2.2 Horizontal Oil Well Performance
528(3)
5.2.3 Horizontal Well Productivity under Steady-State Flow
531(3)
5.2.4 Horizontal Well Productivity under Semisteady-state Flow
534(1)
5.3 Phase
3. Relating Reservoir Performance to Time
535(2)
5.4 Problems
537(4)
Chapter 6 Introduction to Enhanced Oil Recovery
541(46)
6.1 Mechanisms of Enhanced Oil Recovery
541(2)
6.2 Enhanced Oil Recovery Methods
543(1)
6.3 Thermal Processes
544(22)
6.3.1 Cyclic Steam Stimulation
544(2)
6.3.2 Steam Flooding (Steam Drive)
546(14)
6.3.3 Steam-Assisted Gravity Drainage
560(2)
6.3.4 In Situ Combustion
562(4)
6.4 Chemical Flood
566(14)
6.4.1 Polymer Flood
567(7)
6.4.2 Surfactant Slug and Micellar Solution Flood
574(5)
6.4.3 ASP Flood
579(1)
6.5 Miscible Gas Flood
580(7)
6.5.1 Miscibility
581(6)
Chapter 7 Economic Analysis
587(64)
7.1 Introduction
587(4)
7.1.1 Tight Gas Optimal Spacing Example
588(2)
7.1.2 Drill vs. Farmout Example
590(1)
7.1.3 Value of Advanced Technology
590(1)
7.2 Evaluation Criteria and Cash Flow Analysis
591(6)
7.2.1 Payout
591(3)
7.2.2 Number of Times Investment Returned
594(1)
7.2.3 Discounting of Future Cash Flows, Time Value of Money
594(3)
7.2.4 Period Discounting
597(1)
7.3 Price Escalation and Constant Price Cases
597(1)
7.3.1 SPEE Guidelines for Escalations
598(1)
7.4 Present Value
598(5)
7.4.1 SPEE-Recommended Evaluation Practice
600(1)
7.4.2 Discounted Payout
600(1)
7.4.3 Discounted Cash Flow Return on Investment
600(2)
7.4.4 Net Present Value and Discounted Cash Flow Return on Investment
602(1)
7.5 Rate Acceleration Investments
603(5)
7.5.1 Present Value Ratio (PVR)
606(1)
7.5.2 Growth Rate-of-Return (GRR)
607(1)
7.5.3 Perpetuity
608(1)
7.6 Weighted Average Cost of Capital
608(2)
7.6.1 Conceptual Framework
608(1)
7.6.2 Value of a Corporation
609(1)
7.6.3 Market Value of Debt
609(1)
7.6.4 Market Value of Equity
610(1)
7.6.5 Value of the Firm
610(1)
7.7 Risk Analysis
610(9)
7.7.1 Adjusted Discount Rates
612(1)
7.7.2 Sensitivity Analysis
612(1)
7.7.3 Decision Trees and Utility Theory
613(2)
7.7.4 Monte Carlo Simulations
615(4)
7.8 Types of International Petroleum Fiscal Regimes
619(6)
7.8.1 Background
619(1)
7.8.2 Generic Contract Styles
619(1)
7.8.3 Concessions
620(1)
7.8.4 Joint Ventures
620(1)
7.8.5 Tax/Royalty Schemes
621(1)
7.8.6 Production Sharing Contracts
621(2)
7.8.7 Ring Fencing
623(1)
7.8.8 Reserve Treatment and Issues for PSCs
624(1)
7.8.9 Service Contracts
624(1)
7.8.10 Issues with PSC and Service Contracts
625(1)
7.9 Country Examples
625(5)
7.9.1 Brazil (Excluding Pre-Salt)
625(1)
7.9.2 Indonesia
626(1)
7.9.3 United Kingdom
627(1)
7.9.4 Iraq Service Contracts
628(1)
7.9.5 Summary
629(1)
7.10 General Reserve Booking Issues
630(6)
7.10.1 Petroleum Resources
630(1)
7.10.2 Guidelines for Resource Estimation and Accounting
631(1)
7.10.3 Resource Classification Framework
632(1)
7.10.4 A Note on Risk and Uncertainty
633(1)
7.10.5 Project-Based Resource Evaluations
634(1)
7.10.6 Project Maturity Sub-Classes and Reserve Classes
634(1)
7.10.7 Resource and Reserve Uncertainty
635(1)
7.11 Historical SEC Reserve Regulations
636(15)
7.11.1 Proved Area Definition ("Offsets")
646(1)
7.11.2 2009 SEC Changes
647(4)
Chapter 8 Financial Analysis
651(10)
8.1 Fixed Capital Investments
651(2)
8.1.1 Cost Basis
652(1)
8.1.2 Cash Flow Consequences
652(1)
8.1.3 Maintenance Expense
653(1)
8.1.4 Additions of Fixed Capital
653(1)
8.1.5 Working Capital
653(1)
8.2 Financial Reporting
653(3)
8.2.1 Generally Accepted Accounting Principles (GAAP)
653(1)
8.2.2 Net Income
654(1)
8.2.3 Timing Differences
654(1)
8.2.4 Depreciation, Depletion, and Amortization (DD&A)
655(1)
8.2.5 Deferred Tax
655(1)
8.2.6 Cash Flow Generation
656(1)
8.3 Mergers and Acquisitions
656(1)
8.4 Overview of E&P Acquisition Environment
657(4)
8.4.1 Tax Consequences
658(1)
8.4.2 Accounting for Acquisitions
658(1)
8.4.3 Pooling Accounting
658(1)
8.4.4 Purchase Accounting
659(1)
8.4.5 Due Diligence in Acquisitions
659(1)
8.4.6 Valuation
660(1)
Chapter 9 Professionalism and Ethics
661(22)
9.1 What Is a Profession?
661(1)
9.2 Ethics
661(2)
9.2.1 Guide for Professional Conduct
662(1)
9.3 The Engineer as an Expert Witness
663(9)
9.3.1 Credibility and Credentials
664(1)
9.3.2 Compensation and Payments
665(1)
9.3.3 The Expert Report
666(1)
9.3.4 Depositions
667(1)
9.3.5 Direct Examination
668(1)
9.3.6 Cross-Examination
669(2)
9.3.7 Intellectual Property
671(1)
9.3.8 Junk Science
671(1)
9.4 FCPA Considerations
672(1)
9.5 Ethics Gone Awry, Ethical Dilemmas
673(10)
9.5.1 The Case of the Unintended Consequences of Success Bonuses
673(2)
9.5.2 How Much of Your Expertise Belongs to Your Employer?
675(1)
9.5.3 Whose Witness Anyway?
676(1)
9.5.4 Forced Rankings
677(1)
9.5.5 Gifts and Entertainment
678(1)
9.5.6 The Bribery Coast
679(4)
References 683(6)
Index 689
consulting firm that specializes in in-house petroleum engineering courses and consulting services worldwide. Prior to that, he was a Reservoir Engineering Advisor for Anadarko, Baker Hughes, and Gaffney, Cline and Associates and was a Professor and head of the Petroleum Engineering Department at Montana Tech of the University of Montana for 22 years. Dr. Ahmed has authored numerous papers and several successful books with Elsevier, including Advanced Reservoir Management and Engineering, 2nd Edition. Dr. D. Nathan Meehan is President of CMG Petroleum Consulting, an energy advisory firm founded in 2001. He was formerly President of Gaffney, Cline & Associates and a senior executive at Baker Hughes. Previously, he was Vice President of Engineering for Occidental Oil & Gas, and served as the 2016 President of the Society of Petroleum Engineers. Dr. Meehan holds a BSc in Physics from the Georgia Institute of Technology, an MSc in Petroleum Engineering from the University of Oklahoma, and a PhD in Petroleum Engineering from Stanford University. With more than 42 years of industry experience, he is an SPE Distinguished Member and received SPE Honorary Membership, the highest award the Society gives. He serves on the boards of the University of Oklahoma Board of Visitors for the Mewbourne College of Earth and Energy and the University of Texas Petroleum Engineering Department. He is a licensed professional engineer in four states.
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