Carbon Dioxide Sequestration and Related Technologies

Carbon Dioxide Sequestration and Related Technologies......Page 5
Contents......Page 7
Introduction The Three Sisters – CCS, AGI, and EOR......Page 21
Section 1: Data and Correlation......Page 27
1.1 Introduction......Page 29
1.2 Previous Studies......Page 30
1.3 Thermodynamic Model......Page 31
1.4 Calculation Results......Page 32
1.5 Discussion......Page 36
References......Page 37
2. Phase Behavior of China Reservoir Oil at Different CO2 Injected Concentrations......Page 39
2.2 Preparation of Reservoir Fluid......Page 40
2.3 PVT Phase Behavior for the CO2 Injected Crude Oil......Page 41
2.4 Viscosity of the CO2 Injected Crude Oil......Page 43
2.5 Interfacial Tension for CO2 Injected Crude Oil/Strata Water......Page 45
2.6 Conclusions......Page 46
Literature Cited......Page 47
3. Viscosity and Density Measurements for Sour Gas Fluids at High Temperatures and Pressures......Page 49
3.1 Introduction......Page 50
3.2.1 Density Measurement......Page 51
3.2.2 Viscosity Measurement......Page 53
3.2.3 Charging and Temperature Control......Page 56
3.3 Results......Page 57
References......Page 63
4.1 Introduction......Page 67
4.2 Expanded Fluid Viscosity Correlation......Page 68
4.2.1 Mixing Rules......Page 70
4.2.2 Modification for Non-Hydrocarbons......Page 71
4.3.1 Pure Components......Page 73
4.3.2 Acid Gas Mixtures......Page 74
References......Page 78
5.1 Introduction......Page 81
5.2 Model Description......Page 82
5.3 Phase Equilibrium Calculation......Page 84
5.5 Future Work......Page 88
Reference......Page 89
6.1 Introduction......Page 91
6.2.2 Experimental Apparatus and Procedure......Page 93
6.3.1 Existing Methods......Page 94
6.3.2 Proposed Method......Page 100
6.5 Comparison of the Proposed Method and Other Methods......Page 104
6.6 Conclusions......Page 109
6.8 Nomenclature......Page 110
References......Page 111
Section 2: Process Engineering......Page 113
7.1 Introduction......Page 115
7.2 Discussion......Page 116
7.3 Program Design......Page 119
7.4 Results......Page 120
7.5.1 General Comments......Page 122
7.5.2 Overall Heat Transfer Coefficient, U......Page 127
7.5.3 Viscosity......Page 130
References......Page 131
8. Glycol Dehydration as a Mass Transfer Rate Process......Page 133
8.1 Phase Equilibrium......Page 134
8.2 Process Simulation......Page 136
8.3 Dehydration Column Performance......Page 137
8.4 Stahl Columns and Stripping Gas......Page 140
8.5 Interesting Observations from a Mass Transfer Rate Model......Page 141
8.6 Factors That Affect Dehydration of Sweet Gases......Page 144
8.8 Conclusions......Page 145
Literature Cited......Page 146
9.1 Amine Applications......Page 147
9.2 Amine Technology......Page 148
9.3.1 Nucleophilic Pathway......Page 150
9.3.2 Acid-Base Pathway (Primary Secondary and Tertiary Amines)......Page 151
9.4 Types of Amine......Page 152
9.5.1 Prevention......Page 154
9.5.4 High Energy Consumption......Page 155
9.5.6 Captured CO2......Page 156
Conclusion......Page 157
10.1 Background......Page 159
10.3 Is It Adequate?......Page 164
10.4 The Gases......Page 167
10.5 Results......Page 173
10.6 Discussion......Page 177
References......Page 178
11. Diaphragm Pumps Improve Efficiency of Compressing Acid Gas and CO2......Page 181
11.1 Diaphragm Pumps......Page 188
11.2 Acid Gas Compression......Page 190
11.3 CO2 Compression for Sequestration......Page 193
11.4 Conclusion......Page 197
Literature......Page 198
Section 3: Reservoir Engineering......Page 199
12.1 Background......Page 201
12.2.1 Project Planning and Feasibility Study......Page 204
12.2.2 Reservoir/Cap Rock Identification and Regulatory Permitting......Page 207
12.2.3 Well Drilling and Testing......Page 209
12.2.5 Reservoir and Seal Evaluation......Page 212
12.2.6 Documentation, System Start-up and Reporting......Page 214
12.3.1 Permian Basin......Page 216
12.3.1.1 Linam AGI #1......Page 219
12.3.1.2 Jal 3 AGI #1......Page 222
12.3.2 San Juan Basin......Page 225
12.3.2.1 Pathfinder AGI #1......Page 226
12.4 AGI and the Potential for Carbon Credits......Page 230
12.5 Conclusions......Page 233
References......Page 234
13. CO2 and Acid Gas Storage in Geological Formations as Gas Hydrate......Page 235
13.1 Introduction......Page 236
13.2.1.1 Mixed Hydrate Phase Equilibrium......Page 237
13.2.2.1 Negative Buoyancy Zone (NBZ)......Page 239
13.2.2.2 Hydrate Formation Zone (HFZ)......Page 240
13.3.1 Depleted Gas Reservoir......Page 242
13.3.2 Ocean Sediment......Page 243
13.4.1 Depleted Gas Reservoir......Page 244
13.5 Discussion......Page 247
13.6 Conclusions......Page 249
References......Page 250
14.1 Introduction......Page 253
14.2.1 Basic Supposition......Page 254
14.2.2.1 Flow Differential Equations......Page 255
14.2.2.2 Unstable Differential Equations of Gas-liquid-solid Complex Flow......Page 256
14.2.2.3 Relationship between Saturation and Pressure of Liquid Phase......Page 257
14.3.1 Mathematical Model of Sulfur Deposition......Page 258
14.3.2 Thermodynamics Model of Three-phase Equilibrium......Page 260
14.3.4 Solubility Calculation Model......Page 262
14.3.5 Influence Mathematical Model of Sulfur Deposition Migration to Reservoir Characteristics......Page 263
14.4.1 Definite Output Solutions......Page 264
14.4.2 Productivity Equation......Page 265
14.5.3 Productivity Calculation......Page 266
References......Page 268
Section 4: Enhanced Oil Recovery (EOR)......Page 271
15. Enhanced Oil Recovery Project: Dunvegan C Pool......Page 273
15.1 Introduction......Page 274
15.2 Pool Data Collection......Page 275
15.3 Pool Event Log......Page 278
15.4.1 Fluid Characterization Program Design Questions......Page 281
15.4.2 Fluid Characterization Program......Page 283
15.5 Material Balance......Page 289
15.6 Geological Model......Page 290
15.7.3 Permeability......Page 295
15.7.5 Relative Permeability Curve Parameters......Page 296
15.8 History Match......Page 298
15.9 Black Oil to Compositional Model Conversion......Page 308
15.10 Recovery Alternatives......Page 316
15.11 Economics......Page 333
15.13.1 Reservoir Fluid Characterization......Page 338
15.13.3 Geological Model......Page 341
15.13.4 History Match......Page 342
15.14 End Note......Page 343
References......Page 344
16.1 Introduction......Page 345
16.2 Field Experiment of CO2 Flooding in China......Page 346
16.3 Mechanism of CO2 Flooding Displacement......Page 347
16.4 Perspective......Page 350
References......Page 352
17.1 Introduction......Page 355
17.2.1 Research on Phase Behavior and Swelling Experiments......Page 356
17.2.2 Tubule Flow Experiments......Page 357
17.2.3 Long Core Test Experiments......Page 358
17.3.1 Geological Characteristics of Pilot......Page 359
17.3.1.2 Characteristics of Reservoir......Page 360
17.3.1.3 Reservoir Properties and Lithology Characteristics......Page 362
17.3.3 Designed Testing Scheme......Page 365
17.3.4.1 Low Gas Injection Pressure and Large Gas Inspiration Capacity......Page 366
17.3.4.2 Production Rate and Reservoir Pressure Increase after Gas Injection......Page 367
17.3.4.3 Reservoir Heterogeneity Is the Key to Control Gas Breakthrough......Page 368
17.3.4.4 CO2 Throughput as the Supplementary Means of Fuyu Reservoir's Effective Deployment......Page 369
17.3.4.5 Numerical Result Shows that Carrying Out Water Flooding after Injecting Certain Amount of C02 Slug is Better......Page 370
17.4 Conclusion......Page 372
References......Page 375
18. Operation Control of CO2-Driving in Field Site. Site Test in Wellblock Shu 101, Yushulin Oil Field, Daqing......Page 377
18.1.2 Test Scheme Design......Page 378
18.2.1 Test Results......Page 379
18.2.2 The Stratum Pressure Status......Page 380
18.2.4 The Different Flow Pressure Control......Page 382
18.2.5 Oil Well with Poor Response......Page 384
References......Page 385
19.1 Introduction......Page 387
19.2 Application of Heteropolysaccharide in CO2 Reinjection Miscible Phase Recovery......Page 389
19.2.1.1 Test Method......Page 390
19.2.1.2 Testing results as the Figure 2 and Table 1 shows......Page 392
19.2.2 Test of Water Absorption of Mud Ball in Heteropolysaccharide Collosol......Page 393
19.3.1.2 Experiment Method......Page 396
19.3.1.2 Experiment Results......Page 398
References......Page 399
Section 5: Geology and Geochemistry......Page 401
20.1 Introduction......Page 403
20.2 Apparatus and Methods......Page 404
20.2.1 Solids and Aqueous Solution......Page 405
20.2.2 Gases......Page 406
20.3.1 Reactivity of the Blank Experiments......Page 407
20.3.2 Reactivity with pure SO2......Page 410
20.3.3 Reactivity with pure NO......Page 413
20.4 Conclusion......Page 417
References......Page 418
21.1 Introduction......Page 419
21.3 The Northwest McGregor Field, E. Goetz #1 Well Operational History......Page 421
21.4 Reservoir Mineralogy......Page 423
21.5 Preinjection and Postinjection Reservoir Fluid Analysis......Page 424
21.6 Major Observations and the Analysis of the Reservoir Fluid Sampling......Page 426
21.7 Laboratory Experimentations......Page 427
21.8 2-D Reservoir Geochemical Modeling with GEM......Page 428
21.9 Summary and Conclusions......Page 429
21.11 Disclaimer......Page 430
References......Page 431
22.1 Introduction......Page 433
22.2 Rock Unit Selection......Page 435
22.3 CO2 Chamber Experiments......Page 437
22.4 Mineralogical Analysis......Page 438
22.6 Results......Page 439
22.7 Carbonate Minerals Dissolution......Page 440
22.8 Mobilization of Fe......Page 442
22.11 Disclaimer......Page 444
References......Page 445
Section 6: Well Technology......Page 447
23. Well Cement Aging in Various H2S-CO2 Fluids at High Pressure and High Temperature: Experiments and Modelling......Page 449
23.1 Introduction......Page 450
23.2 Experimental equipment......Page 451
23.3.1 Cement......Page 452
23.3.5 Analyses......Page 453
23.4.1 Cement......Page 454
23.5 Reactive Transport Modelling......Page 456
23.6 Conclusion......Page 458
Acknowledgments......Page 459
References......Page 460
24. Casing Selection and Correlation Technology for Ultra-Deep, Ultra- High Pressure, High H2S Gas Wells......Page 463
24.2 Material Selection Recommended Practice......Page 464
24.3 Casing Selection and Correlation Technology......Page 467
24.3.1 Casing Selection and match Technology Below 90°C......Page 468
24.4 Field Applications......Page 469
24.4 Conclusions......Page 471
References......Page 473
25.1 Introduction......Page 475
25.2 Coupled Mathematical Model......Page 476
25.2.1 Gas Migration in Cement......Page 477
25.2.2 Gas Migration in Stagnant Mud......Page 478
25.2.3 Gas Unloading and Accumulation at Wellhead......Page 480
25.2.4 Coupled Gas Flows in Cement and Mud......Page 482
25.3 Illustration......Page 484
25.4 Conclusions......Page 485
25.5 Nomenclature......Page 486
References......Page 487
Section 7: Corrosion......Page 489
26. Study on Corrosion Resistance of L245/825 Lined Steel Pipe Welding Gap in H2S+CO2 Environment......Page 491
26.2 Welding Process of Lined Steel Pipe......Page 492
26.3 Corrosion Test Method of Straight and Ring Welding Gaps of L245/825 Lined Steel Pipe......Page 493
26.4.2 Corrosion Test Results at High Pressure......Page 498
26.4.3 Field Corrosion Test Results......Page 500
References......Page 503
Index......Page 505