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Carbon Dioxide Sequestration and Related Technologies [Kõva köide]

Edited by (Southwest Petroleum University), Edited by (Sphere Technology Connection), Edited by (Gas Liquids Engineering, Ltd.)
  • Formaat: Hardback, 508 pages, kõrgus x laius x paksus: 243x164x32 mm, kaal: 862 g
  • Sari: Advances in Natural Gas Engineering
  • Ilmumisaeg: 22-Jul-2011
  • Kirjastus: Wiley-Scrivener
  • ISBN-10: 0470938765
  • ISBN-13: 9780470938768
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Carbon Dioxide Sequestration and Related TechnologiesSuurem pilt
  • Formaat: Hardback, 508 pages, kõrgus x laius x paksus: 243x164x32 mm, kaal: 862 g
  • Sari: Advances in Natural Gas Engineering
  • Ilmumisaeg: 22-Jul-2011
  • Kirjastus: Wiley-Scrivener
  • ISBN-10: 0470938765
  • ISBN-13: 9780470938768
Teised raamatud teemal:
Püsilink: https://www.kriso.ee/db/9780470938768.html
Märksõnad:
Carbon dioxide sequestration is a technology that is being explored to curb the anthropogenic emission of CO2 into the atmosphere. Carbon dioxide has been implicated in the global climate change and reducing them is a potential solution.

The injection of carbon dioxide for enhanced oil recovery (EOR) has the duel benefit of sequestering the CO2 and extending the life of some older fields. Sequestering CO2 and EOR have many shared elements that make them comparable.

This volume presents some of the latest information on these processes covering physical properties, operations, design, reservoir engineering, and geochemistry for AGI and the related technologies.

Arvustused

"Each separately readable chapter is structured in introduction, experimentals, results and discussion. This allows a structured understanding.  Although this book does not solve all the questions raised when talking about safety and reliability of CCS-technology, it provides a base of knowledge. Increased research on this questions contributes to a tremendous extension of current knowledge, basing on this publication."  (Materials & Corrosion, 1 November 2012)

 

 

Introduction The Three Sisters - CCS, AGI, and EOR xix
Ying Wu
John J. Carroll
Zhimin Du
Section 1 Data and Correlation
1 Prediction of Acid Gas Dew Points in the Presence of Water and Volatile Organic Compounds
3(10)
Ray. A. Tomcej
1.1 Introduction
3(1)
1.2 Previous Studies
4(1)
1.3 Thermodynamic Model
5(1)
1.4 Calculation Results
6(4)
1.5 Discussion
10(1)
References
11(2)
2 Phase Behavior of China Reservoir Oil at Different CO2 Injected Concentrations
13(10)
Fengguang Li
Xin Yang
Changyu Sun
Guangjin Chen
2.1 Introduction
14(1)
2.2 Preparation of Reservoir Fluid
14(1)
2.3 PVT Phase Behavior for the CO2 Injected Crude Oil
15(2)
2.4 Viscosity of the CO2 Injected Crude Oil
17(2)
2.5 Interfacial Tension for CO2 Injected Crude Oil/Strata Water
19(1)
2.6 Conclusions
20(1)
Literature Cited
21(2)
3 Viscosity and Density Measurements for Sour Gas Fluids at High Temperatures and Pressures
23(18)
B.R. Giri
P. Blais
R.A. Marriott
3.1 Introduction
24(1)
3.2 Experimental
25(6)
3.2.1 Density Measurement
25(2)
3.2.2 Viscosity Measurement
27(3)
3.2.3 Charging and Temperature Control
30(1)
3.3 Results
31(6)
3.4 Conclusions
37(1)
References
37(4)
4 Acid Gas Viscosity Modeling with the Expanded Fluid Viscosity Correlation
41(14)
H. Motahhari
M.A. Satyro
H.W. Yarranton
4.1 Introduction
41(1)
4.2 Expanded Fluid Viscosity Correlation
42(5)
4.2.1 Mixing Rules
44(1)
4.2.2 Modification for Non-Hydrocarbons
45(2)
4.3 Results and Discussion
47(5)
4.3.1 Pure Components
47(1)
4.3.2 Acid Gas Mixtures
48(4)
4.4 Conclusions
52(1)
4.5 Acknowledgements
52(1)
References
52(3)
5 Evaluation and Improvement of Sour Property Packages in Unisim Design
55(10)
Jianyong Yang
Ensheng Zhao
Laurie Wang
Sanjoy Saha
5.1 Introduction
55(1)
5.2 Model Description
56(2)
5.3 Phase Equilibrium Calculation
58(4)
5.4 Conclusions
62(1)
5.5 Future Work
62(1)
Reference
63(2)
6 Compressibility Factor of High CO2-Content Natural Gases: Measurement and Correlation
65(24)
Xiaoqiang Bian
Zhimin Du
Yong Tang
Jianfen Du
6.1 Introduction
65(2)
6.2 Experiment
67(1)
6.2.1 Measured Principles
67(1)
6.2.2 Experimental Apparatus and Procedure
67(1)
6.2.3 Experimental Results
68(1)
6.3 Methods
68(10)
6.3.1 Existing Methods
68(6)
6.3.2 Proposed Method
74(4)
6.5 Comparison of the Proposed Method and Other Methods
78(5)
6.6 Conclusions
83(1)
6.7 Acknowledgements
84(1)
6.8 Nomenclature
84(1)
References
85(4)
Section 2 Process Engineering
7 Analysis of Acid Gas Injection Variables
89(18)
Edward Wichert
James van der Lee
7.1 Introduction
89(1)
7.2 Discussion
90(3)
7.3 Program Design
93(1)
7.4 Results
94(2)
7.5 Discussion of Results
96(9)
7.5.1 General Comments
96(5)
7.5.2 Overall Heat Transfer Coefficient, U
101(3)
7.5.3 Viscosity
104(1)
7.6 Conclusion
105(1)
References
105(2)
8 Glycol Dehydration as a Mass Transfer Rate Process
107(14)
Nathan A. Hatcher
Jaime L. Nava
Ralph H. Weiland
8.1 Phase Equilibrium
108(2)
8.2 Process Simulation
110(1)
8.3 Dehydration Column Performance
111(3)
8.4 Stahl Columns and Stripping Gas
114(1)
8.5 Interesting Observations from a Mass Transfer Rate Model
115(3)
8.6 Factors That Affect Dehydration of Sweet Gases
118(1)
8.7 Dehydration of Acid Gases
119(1)
8.8 Conclusions
119(1)
Literature Cited
120(1)
9 Carbon Capture Using Amine-Based Technology
121(12)
Ben Spooner
David Engel
9.1 Amine Applications
121(1)
9.2 Amine Technology
122(2)
9.3 Reaction Chemistry
124(2)
9.3.1 Nucleophilic Pathway
124(1)
9.3.2 Acid-Base Pathway (Primary, Secondary and Tertiary Amines)
125(1)
9.4 Types of Amine
126(2)
9.5 Challenges of Carbon Capture
128(3)
9.5.1 Prevention
128(1)
9.5.2 Reclaimers
129(1)
9.5.3 Purging and Replacing Amine
129(1)
9.5.4 High Energy Consumption
129(1)
9.5.5 Size of the Amine Facility
130(1)
9.5.6 Captured CO2
130(1)
9.6 Conclusion
131(2)
10 Dehydration-through-Compression (DTC): Is It Adequate? A Tale of Three Gases
133(22)
Wes H. Wright
10.1 Background
133(5)
10.2 Water Saturation
138(1)
10.3 Is It Adequate?
138(3)
10.4 The Gases
141(6)
10.5 Results
147(4)
10.6 Discussion
151(1)
References
152(3)
11 Diaphragm Pumps Improve Efficiency of Compressing Acid Gas and CO2
155(20)
Josef Jarosch
Anke-Dorothee Braun
11.1 Diaphragm Pumps
162(2)
11.2 Acid Gas Compression
164(3)
11.3 CO2 Compression for Sequestration
167(4)
11.4 Conclusion
171(1)
Literature
172(3)
Section 3 Reservoir Engineering
12 Acid Gas Injection in the Permian and San Juan Basins: Recent Case Studies from New Mexico
175(34)
David T. Lescinsky
Alberto A. Gutierrez
James C. Hunter
Julie W. Gutierrez
Russell E. Bentley
12.1 Background
175(3)
12.2 AGI Project Planning and Implementation
178(12)
12.2.1 Project Planning and Feasibility Study
178(3)
12.2.2 Reservoir/Cap Rock Identification and Regulatory Permitting
181(2)
12.2.3 Well Drilling and Testing
183(3)
12.2.4 Well Completion and Construction
186(1)
12.2.5 Reservoir and Seal Evaluation
186(2)
12.2.6 Documentation, System Start-up and Reporting
188(2)
12.3 AGI Projects in New Mexico
190(9)
12.3.1 Permian Basin
190(3)
12.3.1.1 Linam AGI#1
193(3)
12.3.1.2 Jal 3 AGI#1
196(3)
12.3.2 San Juan Basin
199(5)
12.3.2.1 Pathfinder AGI #1
200(4)
12.4 AGI and the Potential for Carbon Credits
204(3)
12.5 Conclusions
207(1)
References
208(1)
13 CO2 and Acid Gas Storage in Geological Formations as Gas Hydrate
209(18)
Farhad Qanbari
Olga Ye Zatsepina
S. Hamed Tabatabaie
Mehran Pooladi-Darvish
13.1 Introduction
210(1)
13.2 Geological Settings
211(5)
13.2.1 Depleted Gas Reservoirs
211(1)
13.2.1.1 Mixed Hydrate Phase Equilibrium
211(2)
13.2.1.2 Assumptions
213(1)
13.2.2 Ocean Sediments
213(1)
13.2.2.1 Negative Buoyancy Zone (NBZ)
213(1)
13.2.2.2 Hydrate Formation Zone (HFZ)
214(2)
13.3 Model Parameters
216(2)
13.3.1 Depleted Gas Reservoir
216(1)
13.3.2 Ocean Sediment
217(1)
13.4 Results
218(3)
13.4.1 Depleted Gas Reservoir
218(3)
13.4.2 Ocean Sediment
221(1)
13.5 Discussion
221(2)
13.6 Conclusions
223(1)
13.7 Acknowledgment
224(1)
References
224(3)
14 Complex Flow Mathematical Model of Gas Pool with Sulfur Deposition
227(20)
W. Zhu
Y. Long
Q. Liu
Y. Ju
X. Huang
14.1 Introduction
227(1)
14.2 The Mathematical Model of Multiphase Complex Flow
228(4)
14.2.1 Basic Supposition
228(1)
14.2.2 The Mathematical Model of Gas-liquid-solid Complex Flow in Porous Media
229(1)
14.2.2.1 Flow Differential Equations
229(1)
14.2.2.2 Unstable Differential Equations of Gas-liquid-solid Complex Flow
230(1)
14.2.2.3 Relationship between Saturation and Pressure of Liquid Phase
231(1)
14.2.2.4 Auxiliary Equations
232(1)
14.2.2.5 Definite Conditions
232(1)
14.3 Mathematical Models of Flow Mechanisms
232(6)
14.3.1 Mathematical Model of Sulfur Deposition
232(2)
14.3.2 Thermodynamics Model of Three-phase Equilibrium
234(2)
14.3.3 State Equations
236(1)
14.3.4 Solubility Calculation Model
236(1)
14.3.5 Influence Mathematical Model of Sulfur Deposition Migration to Reservoir Characteristics
237(1)
14.4 Solution of the Mathematical Model Equations
238(2)
14.4.1 Definite Output Solutions
238(1)
14.4.2 Productivity Equation
239(1)
14.5 Example
240(2)
14.5.1 Simulation Parameter Selection
240(1)
14.5.2 Oil-gas Flow Characteristics near Borehole Zones of Gas-well
240(1)
14.5.3 Productivity Calculation
240(2)
14.6 Conclusions
242(1)
14.7 Acknowledgement
242(1)
References
242(5)
Section 4 Enhanced Oil Recovery (EOR)
15 Enhanced Oil Recovery Project: Dunvegan C Pool
247(72)
Darryl Burns
15.1 Introduction
248(1)
15.2 Pool Data Collection
249(3)
15.3 Pool Event Log
252(3)
15.4 Reservoir Fluid Characterization
255(8)
15.4.1 Fluid Characterization Program Design Questions
255(2)
15.4.2 Fluid Characterization Program
257(6)
15.4.3 Solubility of Acid Gas Mixtures in the Dunvegan C Oil
263(1)
15.5 Material Balance
263(1)
15.6 Geological Model
264(5)
15.7 Geological Uncertainty
269(3)
15.7.1 Formation Bulk Volume
269(1)
15.7.2 Porosity
269(1)
15.7.3 Permeability
269(1)
15.7.4 Residual (Immobile) Fluid Saturations
270(1)
15.7.5 Relative Permeability Curve Parameters
270(2)
15.7.6 Fluid Contacts
272(1)
15.8 History Match
272(10)
15.9 Black Oil to Compositional Model Conversion
282(8)
15.10 Recovery Alternatives
290(17)
15.11 Economics
307(5)
15.12 Economic Uncertainty
312(1)
15.13 Discussion and Learning
312(5)
15.13.1 Reservoir Fluid Characterization
312(3)
15.13.2 Material Balance
315(1)
15.13.3 Geological Model
315(1)
15.13.4 History Match
316(1)
15.13.5 Black Oil to Compositional Model Conversion
317(1)
15.13.6 Recovery Alternatives
317(1)
15.13.7 Economics
317(1)
15.14 End Note
317(1)
References
318(1)
16 CO2 Flooding as an EOR Method for Low Permeability Reservoirs
319(10)
Yongle Hu
Yunpeng Hu
Qin Li
Lei Huang
Mingqiang Hao
Siyu Yang
16.1 Introduction
319(1)
16.2 Field Experiment of CO2 Flooding in China
320(1)
16.3 Mechanism of CO2 Flooding Displacement
321(3)
16.4 Perspective
324(2)
16.5 Conclusion
326(1)
References
326(3)
17 Pilot Test Research on CO2 Drive in Very Low Permeability Oil Field of in Daqing Changyuan
329(22)
Weiyao Zhu
Jiecheng Cheng
Xiaohe Huang
Yunqian Long
Y. Lou
17.1 Introduction
329(1)
17.2 Laboratory Test Study on CO2 Flooding in Oil Reservoirs with Very Low Permeability
330(3)
17.2.1 Research on Phase Behavior and Swelling Experiments
330(1)
17.2.2 Tubule Flow Experiments
331(1)
17.2.3 Long Core Test Experiments
332(1)
17.3 Field Testing Research
333(13)
17.3.1 Geological Characteristics of Pilot
333(1)
17.3.1.1 Structural Characteristics
334(1)
17.3.1.2 Characteristics of Reservoir
334(2)
17.3.1.3 Reservoir Properties and Lithology Characteristics
336(3)
17.3.2 Distribution and Features of Fluid
339(1)
17.3.3 Designed Testing Scheme
339(1)
17.3.4 Field Test Results and Analysis
340(1)
17.3.4.1 Low Gas Injection Pressure and Large Gas Inspiration Capacity
340(1)
17.3.4.2 Production Rate and Reservoir Pressure Increase after Gas Injection
341(1)
17.3.4.3 Reservoir Heterogeneity Is the Key to Control Gas Breakthrough
342(1)
17.3.4.4 CO2 Throughput as the Supplementary Means of Fuyu Reservoir's Effective Deployment
343(1)
17.3.4.5 Numerical Result Shows that Carrying Out Water Flooding after Injecting Certain Amount of CO2 Slug is Better
344(2)
17.4 Conclusion
346(3)
17.5 Acknowledgement
349(1)
References
349(2)
18 Operation Control of CO2-Driving in Field Site. Site Test in Wellblock Shu 101, Yushulin Oil Field, Daqing
351(10)
Xinde Wan
Tao Sun
Yingzhi Zhang
Tiejun Yang
Changhe Mu
18.1 Test Area Description
352(1)
18.1.1 Characteristics of the Reservoir Bed in the Test Area
352(1)
18.1.2 Test Scheme Design
352(1)
18.2 Test Effect and Cognition
353(6)
18.2.1 Test Results
353(1)
18.2.2 The Stratum Pressure Status
354(2)
18.2.3 Air Suction Capability of the Oil Layer
356(1)
18.2.4 The Different Flow Pressure Control
356(2)
18.2.5 Oil Well with Poor Response
358(1)
18.3 Conclusions
359(1)
References
359(2)
19 Application of Heteropolysaccharide in Acid Gas Injection
361(16)
Jie Zhang
Gang Guo
Shugang Li
19.1 Introduction
361(2)
19.2 Application of Heteropolysaccharide in CO2 Reinjection Miscible Phase Recovery
363(7)
19.2.1 Test of Clay Polar Expansion Rate
364(1)
19.2.1.1 Test Method
364(2)
19.2.1.2 Testing results as the Figure 2 and Table 1 shows
366(1)
19.2.2 Test of Water Absorption of Mud Ball in Heteropolysaccharide Collosol
367(3)
19.3 Application of Heteropolysaccharide in H2S Reinjection formation
370(3)
19.3.1 Experiment Process, Method and Instruction
370(1)
19.3.1.1 Experiment Process
370(1)
19.3.1.2 Experiment Method
370(2)
19.3.1.2 Experiment Results
372(1)
19.4 Conclusions
373(1)
References
373(4)
Section 5 Geology and Geochemistry
20 Impact of SO2 and NO on Carbonated Rocks Submitted to a Geological Storage of CO2: An Experimental Study
377(16)
Stephane Renard
Jerome Sterpenich
Jacques Pironon
Aurelien Randi
Pierre Chiquet
Marc Lescanne
20.1 Introduction
377(1)
20.2 Apparatus and Methods
378(3)
20.2.1 Solids and Aqueous Solution
379(1)
20.2.2 Gases
380(1)
20.3 Results and Discussion
381(10)
20.3.1 Reactivity of the Blank Experiments
381(3)
20.3.2 Reactivity with pure SO2
384(3)
20.3.3 Reactivity with pure NO
387(4)
20.4 Conclusion
391(1)
Acknowledgments
392(1)
References
392(1)
21 Geochemical Modeling of Huff `N' Puff Oil Recovery With CO2 at the Northwest Mcgregor Oil Field
393(14)
Yevhen I. Holubnyak
Blaise A.F. Mibeck
Jordan M. Bremer
Steven A. Smith
James A. Sorensen
Charles D. Gorecki
Edward N. Steadman
John A. Harju
21.1 Introduction
393(2)
21.2 Northwest McGregor Location and Geological Setting
395(1)
21.3 The Northwest McGregor Field, E. Goetz #1 Well Operational History
395(2)
21.4 Reservoir Mineralogy
397(1)
21.5 Preinjection and Postinjection Reservoir Fluid Analysis
398(2)
21.6 Major Observations and the Analysis of the Reservoir Fluid Sampling
400(1)
21.7 Laboratory Experimentations
401(1)
21.8 2-D Reservoir Geochemical Modeling with GEM
402(1)
21.9 Summary and Conclusions
403(1)
21.10 Acknowledgments
404(1)
21.11 Disclaimer
404(1)
References
405(2)
22 Comparison of CO2 and Acid Gas Interactions with reservoir fluid and Rocks at Williston Basin Conditions
407(16)
Yevhen I. Holubnyak
Steven B. Hawthorne
Blaise A. Mibeck
David J. Miller
Jordan M. Bremer
Steven A. Smith
James A. Sorensen
Edward N. Steadman
John A. Harju
22.1 Introduction
407(2)
22.2 Rock Unit Selection
409(2)
22.3 CO2 Chamber Experiments
411(1)
22.4 Mineralogical Analysis
412(1)
22.5 Numerical Modeling
413(1)
22.6 Results
413(1)
22.7 Carbonate Minerals Dissolution
414(2)
22.8 Mobilization of Fe
416(2)
22.9 Summary and Suggestions for Future Developments
418(1)
22.10 Acknowledgments
418(1)
22.11 Disclaimer
418(1)
References
419(4)
Section 6 Well Technology
23 Well Cement Aging in Various H2S-CO2 Fluids at High Pressure and High Temperature: Experiments and Modelling
423(14)
Nicolas Jacquemet
Jacques Pironon
Vincent Lagneau
Jeremie Saint-Marc
23.1 Introduction
424(1)
23.2 Experimental equipment
425(1)
23.3 Materials, Experimental Conditions and Analysis
426(2)
23.3.1 Cement
426(1)
23.3.2 Casing
427(1)
23.3.3 Environment
427(1)
23.3.4 Exposures (Figure 3)
427(1)
23.3.5 Analyses
427(1)
23.4 Results and Discussion
428(2)
23.4.1 Cement
428(2)
23.4.2 Steel
430(1)
23.5 Reactive Transport Modelling
430(2)
23.6 Conclusion
432(1)
Acknowledgments
433(1)
References
434(3)
24 Casing Selection and Correlation Technology for Ultra-Deep, Ultra- High Pressure, High H2S Gas Wells
437(12)
Yongxing Sun
Yuanhua Lin
Taihe Shi
Zhongsheng Wang
Dajiang Zhu
Liping Chen
Sujun Liu
Dezhi Zeng
24.1 Introduction
438(1)
24.2 Material Selection Recommended Practice
438(3)
24.3 Casing Selection and Correlation Technology
441(2)
24.3.1 Casing Selection and match Technology Below 90°C
442(1)
24.3.2 Casing Selection and Match Technology Above 90°C
443(1)
24.4 Field Applications
443(2)
24.4 Conclusions
445(2)
24.5 Acknowledgments
447(1)
References
447(2)
25 Coupled Mathematical Model of Gas Migration in Cemented Annulus with Mud Column in Acid Gas Well
449(16)
Hongjun Zhu
Yuanhua Lin
Yongxing Sun
Dezhi Zeng
Zhi Zhang
Taihe Shi
25.1 Introduction
449(1)
25.2 Coupled Mathematical Model
450(8)
25.2.1 Gas Migration in Cement
451(1)
25.2.2 Gas Migration in Stagnant Mud
452(2)
25.2.3 Gas Unloading and Accumulation at Wellhead
454(2)
25.2.4 Coupled Gas Flows in Cement and Mud
456(2)
25.3 Illustration
458(1)
25.4 Conclusions
459(1)
25.5 Nomenclature
460(1)
25.6 Acknowledgment
461(1)
References
461(4)
Section 7 Corrosion
26 Study on Corrosion Resistance of L245/825 Lined Steel Pipe Welding Gap in H2S+CO2 Environment
465(14)
Dezhi Zeng
Yuanhua Lin
Liming Huang
Daijiang Zhu
Tan Gu
Taihe Shi
Yongxing Sun
26.1 Introduction
466(1)
26.2 Welding Process of Lined Steel Pipe
466(1)
26.3 Corrosion Test Method of Straight and Ring Welding Gaps of L245/825 Lined Steel Pipe
467(5)
26.4 Corrosion Test Results of Straight and Ring Welding Gaps of 1245/825 Lined Steel Pipe
472(5)
26.4.1 Atmospheric Corrosion Test Results
472(1)
26.4.2 Corrosion Test Results at High Pressure
472(2)
26.4.3 Field Corrosion Test Results
474(3)
26.5 Conclusions
477(1)
26.6 Acknowledgments
477(1)
References
477(2)
Index 479
Ying (Alice) Wu is currently the President of Sphere Technology Connection Ltd. (STC) in Calgary, Canada. From 1983 to 1999 she was an Assistant Professor and Researcher at Southwest Petroleum Institute (now Southwest Petroleum University, SWPU) in Sichuan, China. She received her MSc in Petroleum Engineering from the SWPU and her BSc in Petroleum Engineering from Daqing Petroleum University in Heilongjiang, China.

John J. Carroll, PhD, PEng is the Director, Geostorage Process Engineering for Gas Liquids Engineering, Ltd. in Calgary, Canada. Dr. Carroll holds bachelor and doctoral degrees in chemical engineering from the University of Alberta, Edmonton, Canada, and is a registered professional engineer in the provinces of Alberta and New Brunswick in Canada. His fist book, Natural Gas Hydrates: A Guide for Engineers, is now in its second edition, and he is the author or co-author of 50 technical publications and about 40 technical presentations.