Chaudhri - Oil Well Testing Handbook
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683 |
Index terms |
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Links |
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Linear data plots (Continued) |
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Injection well test data plots |
465 |
497 |
501 |
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Logical well test data acquisition and analysis |
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program |
4 |
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Late time radial flow (pseudo-radial flow) |
87 |
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Linear flow analysis-high conductivity |
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fractures |
384 |
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Late data parameter |
312 |
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Layer fracture conductivity |
509 |
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M |
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Mathews-Brons-Hazebrock |
236 |
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Miller-Dyes-Hutchison |
237 |
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Muskat method |
240 |
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Total mobility ratio |
195 |
196 |
198 |
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Multiple-rate testing |
463 |
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Analysis plot, slope, intercept |
487 |
491 |
495 |
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Estimating permeability |
469 |
470 |
473 |
477 |
487 |
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491 |
492 |
493 |
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Estimating skin factor |
481 |
487 |
488 |
491 |
492 |
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496 |
499 |
502 |
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Estimating pressure drop across skin |
469 |
475 |
481 |
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Radius of investigation |
469 |
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Distance to well bank |
471 |
471 |
487 |
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Radius of drainage |
471 |
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Flow efficiency |
471 |
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Injectivity index |
481 |
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Calculate compressibility in swept zone |
482 |
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Mobility ratio |
488 |
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Volume of oil bank |
489 |
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Volume of water bank |
490 |
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684 |
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Index terms |
Links |
Multiple-rate testing (Continued) |
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Fracture gradient |
497 |
Multilayered reservoir systems |
504 |
Classification of layered reservoir systems |
551 |
Crossflow reservoirs |
504 |
With crossflow |
505 |
Without-crossflow reservoirs |
506 |
Commingled reservoirs |
507 |
Composite reservoir |
507 |
Interlayered crossflow reservoirs |
508 |
Two-layered reservoir without crossflow |
512 |
Three layer without crossflow reservoirs |
506 |
Four layer crossflow reservoir |
505 |
Muskat plot characteristics |
516 |
MDH method |
516 |
Constant producing rate |
511 |
Constant producing pressure |
510 |
Determine degree of communication and |
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types of crossflow |
513 |
Pressure buildup behavior curve in two- |
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layered gas reservoir |
563 |
Factors affecting performance |
520 |
Relative permeability |
520 |
Pore size |
520 |
Reservoir geometry |
520 |
Permeability anisotropy |
520 |
Reservoir n-layer system |
521 |
Economic aspects |
521 |
Most common gas well test interpretation |
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methods |
5 |
Major flow regimes in horizontal oil wells |
86 |
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685
Index terms |
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Methods of evaluating MHF oil wells |
372 |
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Match of interference test data |
433 |
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Muskat straight-line intercepts for two-layer |
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reservoirs without cross flow |
506 |
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Muskat plot for-layer reservoir with a |
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permeability contract of 2 |
518 |
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Mechanical skin factor |
73 |
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Multiphase pressure buildup plot |
197 |
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MDH drawdown pressure plot |
237 |
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Muskat graph for average pressure |
250 |
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Main characteristics of matrix block and |
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fracture system |
256 |
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Main characteristics and behavior of naturally |
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fractured reservoir |
260 |
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Mud gradient |
392 |
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Model selection process or optimum selection |
28 |
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Multi rate drawdown test plot |
141 |
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MBH graph |
180 |
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MDH graph |
181 |
188 |
Muskat data plot |
184 |
189 |
Multiphase pressure buildup data plot |
197 |
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Multiphase and multi-rate pressure buildup |
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data plot |
217 |
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MDH dimensionless pressure for circular and |
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square areas |
237 |
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Main characteristics of matrix blocks and |
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fracture systems |
256 |
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Most common interpretation methods for |
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naturally fractured reservoirs |
259 |
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686 |
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Index terms |
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Links |
Main characteristics and behavior of naturally |
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fractured reservoirs |
260 |
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Methods of evaluating MHF oil wells |
373 |
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Matrix storage |
274 |
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Matrix permeability |
272 |
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Matrix block shape factor |
369 |
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Mud gradient |
408 |
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Matrix pore volume |
424 |
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Matrix porosity |
424 |
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Mobility ratio |
488 |
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N |
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Nomenclature |
640 |
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No-flow barrier |
342 |
526 |
Numerical models and their applications |
26 |
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Solution of radial diffusivity equation |
21 |
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Various dimensional flow geometry |
24 |
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Linear flow |
24 |
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Radial cylindrical flow |
25 |
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Radial spherical flow |
25 |
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Reservoir model development process |
26 |
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Selection of numerical simulation models |
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and their applications |
27 |
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One-dimensional horizontal model |
29 |
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One-dimensional dipping model |
29 |
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Two-dimensional horizontal model |
30 |
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Three-dimensional layered model |
30 |
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Two-dimensional coning model |
31 |
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Two-dimensional vertical model |
31 |
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Three-dimensional continuous model |
32 |
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687
Index terms |
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Numerical models and their applications (Continued) |
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Three-dimensional continuous (section) |
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model |
32 |
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O |
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Original reservoir pressure |
234 |
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One-dimensional coordinate systems |
24 |
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Linear flow |
24 |
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Radial cylindrical flow |
25 |
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Radial spherical flow |
25 |
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Oil saturation |
432 |
554 |
Oil well test data acquisition, analysis, and |
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management |
2 |
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Oil well test analysis programs |
2 |
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Oil wells for optimum stimulation treatment |
2 |
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Odeh’s equation for calculating skin factor due |
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to restricted entry |
168 |
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P |
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Pulse tests |
429 |
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Pressure buildup analysis methods |
153 |
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Single-rate |
162 |
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Two-rate test |
173 |
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Buildup following variable rate test |
201 |
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Production stimulation, (see stimulation) |
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Pseudo-steady state (finite) flow |
17 |
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Pseudo skin factor with a finite conductivity |
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vertical fracture |
258 |
274 366 |
Pressure response in pulse test |
434 |
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Pulse test responses with flow and shut-in time |
434 |
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688 |
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Index terms |
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Links |
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Pressure derivative trends for common flow |
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regimes |
370 |
371 |
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Pressure derivative type curves |
361 |
366 |
369 |
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Calculating interporosity flow parameter |
258 |
259 |
263 |
265 |
269 |
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283 |
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Calculating ratio of matrix permeability to |
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fracture permeability |
264 |
258 |
267 |
271 |
273 |
Pulse test design procedure |
453 |
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Pressure buildup for crossflow oil reservoir |
505 |
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Pressure buildup curve for a layered reservoir |
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system |
513 |
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Pressure buildup behavior in a two-layer oil |
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reservoir |
520 |
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Porosity partition in heterogeneous porous |
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media |
424 |
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Partitioning coefficient estimation |
427 |
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Procedures and guidelines to describe |
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reservoir heterogeneity |
537 |
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Pseudoskin factor |
97 |
98 |
99 |
282 |
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Porosity-compressibility product: |
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Estimating by type curve matching |
293 |
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Estimating from interference testing |
433 |
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Estimating from pulse testing |
436 |
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Porosity-compressibility-thickness product: |
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Estimating from interference test, |
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Estimating from pulse test |
445 |
457 |
458 |
459 |
460 |
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461 |
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Pressure drop due skin |
123 |
122 |
124 |
128 |
132 |
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134 |
137 |
143 |
146 |
161 |
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186 |
193 |
216 |
398 |
401 |
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409 |
469 |
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689 |
Index terms |
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Links |
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Pore volume |
112 |
114 |
115 |
120 |
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Pseudoproducing time |
163 |
265 |
326 |
328 |
338 |
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355 |
480 |
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Permeability: |
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Estimating by type-curve matching of |
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vertical oil wells |
290 |
296 |
300 |
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Of fractured oil wells |
314 |
317 |
319 |
323 |
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Estimating from drawdown testing of two- |
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rate drawdown test |
122 |
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Estimating from drawdown testing after |
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short shut in |
389 |
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Estimating from interference testing |
431 |
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Estimating from multi-rate pressure buildup |
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testing |
210 |
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Estimating from pressure buildup testing |
154 |
165 |
179 |
183 |
186 |
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190 |
193 |
200 |
204 |
207 |
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218 |
228 |
230 |
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Estimating from pulse testing |
442 |
446 |
461 |
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Estimating in composite system |
505 |
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Estimating permeability and thickness |
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product |
112 |
113 |
148 |
200 |
264 |
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268 |
392 |
482 |
487 |
566 |
Partial differential equations: |
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One-dimensional model |
24 |
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Linear flow |
24 |
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Radial cylindrical flow |
25 |
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Radial spherical flow |
25 |
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Pressure buildup test and data |
154 |
163 |
178 |
186 |
198 |
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194 |
196 |
201 |
202 |
205 |
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208 |
213 |
214 |
215 |
216 |
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222 |
223 |
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690 |
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Index terms |
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Links |
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Pressure buildup curves |
155 |
156 |
164 |
165 |
174 |
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176 |
179 |
180 |
181 |
182 |
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184 |
187 |
188 |
189 |
193 |
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197 |
203 |
206 |
209 |
212 |
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217 |
223 |
227 |
229 |
230 |
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231 |
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Pressure drawdown test and data |
118 |
127 |
131 |
135 |
140 |
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144 |
145 |
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Pressure drawdown curves |
108 |
109 |
110 |
112 |
114 |
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119 |
120 |
123 |
127 |
131 |
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136 |
141 |
149 |
150 |
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Pressure data analysis |
347 |
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Bilinear flow type of analysis |
348 |
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Pressure data partially match curve for the |
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transition period between bilinear and |
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linear flow |
350 |
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Pressure data exhibit a half slope line on a |
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log-log graph |
351 |
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Pressure data partially falling in the pseudo |
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radial flow period |
352 |
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Pseudo skin factor equation |
168 |
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Calculating skin factor due to restricted |
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entry |
168 |
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PVT properties |
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Oil PVT properties |
607 |
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Saturation pressure |
608 |
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Solution gas oil ratio |
612 |
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Oil formation volume factor |
613 |
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Total formation volume factor |
616 |
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Oil density |
616 |
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Oil viscosity |
618 |
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Oil compressibility |
622 |
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691 |
Index terms |
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Links |
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PVT properties (Continued) |
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Water PVT properties |
624 |
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Gas free conditions |
625 |
627 |
629 |
631 |
633 |
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635 |
637 |
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Gas saturated conditions |
626 |
628 |
630 |
632 |
634 |
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636 |
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Pore volume |
112 |
115 |
120 |
191 |
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Purpose and objective of reservoir simulation |
26 |
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Pressure time histories for a const rate |
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drawdown test |
108 |
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Pressure buildup plot dominated by afterflow |
199 |
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Pressure buildup curve in naturally fractured |
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reservoir |
258 |
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Pressure derivative type curves |
264 |
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Pressure derivative applications in oil well |
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testing |
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Infinite-acting Homogeneous reservoir. |
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Systems |
361 |
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Fractured reservoir systems |
365 |
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Pseudo-state interporosity flow |
365 |
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Transient interporosity flow |
368 |
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Pressure derivative trends for other common |
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flow regimes |
370 |
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Pore volume |
17 |
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Productivity index |
166 |
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Pseudo-steady state time |
20 |
21 |
177 |
239 |
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Pressure drop due to skin |
113 |
134 |
137 |
139 |
143 |
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186 |
187 |
210 |
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Calculating from drawdown testing |
113 |
114 |
118 |
122 |
130 |
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132 |
134 |
137 |
139 |
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Calculating from buildup testing |
186 |
187 |
210 |
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692 |
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Index terms |
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Links |
Pressure chart interpretation for various testing |
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conditions |
391 |
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Fluid loss before packer |
392 |
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Leak in drill pipe |
392 |
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Leak in drill pipe |
392 |
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Packer failed and could not be set |
393 |
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Runaway clock. Clock spring released |
393 |
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Tool failed to close, no buildup is obtained |
393 |
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Effect of large seperpressure. Pressure |
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buildup during flow and buildup |
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period |
393 |
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Low permeability formation |
393 |
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Gauge plugged after packer was set but |
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before tool was opened |
394 |
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Two-layer effects. Caused by two producing |
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zones |
394 |
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DST is usually too short to notice |
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interference with today’s well pacing |
394 |
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Two tests with the same gauge |
394 |
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Gauge gradually plugged during flow period |
394 |
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Gauge plugged during flow and unplugged |
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late in buildup |
395 |
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Single test with two gauges |
395 |
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Pressure drop through |
595 |
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Hagedorn and Brown method |
596 |
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Beggs and Brill method |
602 |
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Computer flow diagram for the Beggs and |
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Brill method |
503 |
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Porosity estimation |
410 |
433 |
Using DST Testing |
410 |
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Using Interference testing |
433 |
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