AAPG. See American Association of Petroleum Geologists
Abou-Kassem. See Dranchuk
AGA. See American Gas Association
Agarwal, Al-Hussainy, and Ramey, 97
Al-Hussainy and Ramey, 261
Al-Hussainy, Ramey, and Crawford, 240–41
Alkaline flooding, 412, 421, 424–25
Allen, 121
Allowable production rate, 473
American Association of Petroleum Geologists (AAPG), 2
American Gas Association (AGA), 2
American Petroleum Institute (API), 2
American Society for Testing and Materials (ASTM), 24
Anschutz Ranch East Unit, 152
Anticline, 473
API. See American Petroleum Institute
Aquifers, 6
Areal sweep efficiency, 366–67, 473
Artificial lift, 219, 250, 473
Ashman. See Jogi
Associated gas, 2, 28, 67, 80, 473
ASTM. See American Society for Testing and Materials
“Attic” (updip) oil, 382
Azimuth, 473
Aziz. See Mattar
Bacon Lime Zone, 143
Barnes. See Fancher
Bassiouni. See Arcaro
Bedding planes, 163–64, 229–30. See also Undersaturated oil reservoirs
in measuring permeability, 229–30
Bell gas field, 28, 33, 35, 89, 92–96
Berry. See Jacoby
Bierwang field, 97
Big Sandy reservoir, 45, 47–49, 68
Bitumen, 473
Blackwell. See Richardson
Bobrowski. See Cook
Borshcel. See Sinha
Botset. See Wycoff
Bottom-hole pressure, 4, 67–68, 265–66, 289–90, 476
Bottom-hole pressure gauge, 4
Boundary conditions, 264, 305, 474
Bounded reservoir, 474
Bourgoyne, Hawkins, Lavaquial, and Wickenhauser, 110
Boyd. See McCarthy
Brady. See Lutes
Brar. See Mattar
Bruskotter. See Russel
Bubble point, 474
Bubble-point pressure, 5, 11, 45–47, 50–56, 210–11, 221–24
Buckley and Leverett, 6, 369–75. See also Displacement, oil and gas
pseudosteady-state time region in, 277–78
Burrows. See Carr
Calculation (initial), gas and oil, 124–31
Callaway. See Steward
Calvin. See Kleinsteiber
Canyon Reef reservoir (Kelly-Snyder field, Texas), 171–76, 384
Capillary number, 412–14, 421, 424
Capillary pressure, 24, 220, 357–58
Carbonate rock, 474
Carpenter, Schroeder, and Cook, 210
Carr, Kobayashi, and Burrows, 41–42
Casing, 474
Caudle. See Slobod
Charles’s law, 24
Chatas, 322
Chemical flooding processes, 421–26. See also Tertiary oil recovery
micellar-polymer processes, 422–24
problems in applying, 426
Chen. See Allen
Chiang. See Lutes
Chin. See Cook
Christensen, 411
Clark and Wessely, 6
Coats, 323
Coleman, Wilde, and Moore, 5
Compressibility factors, 21, 30, 36, 192, 196, 222–24. See also Gas deviation factor; Isothermal compressibility; Supercompressibility factor
Condensate, 474
Connate water, 5, 149, 194–97, 283–84, 474
Conroe Field (Texas), 203–8, 220, 299–301, 350–51
Cook. See Carpenter
Cook, Spencer, and Bobrowski, 217
Cook, Spencer, Bobrowski, and Chin, 161
Core, 474
Core Laboratories Inc., 160, 211–15
Crawford. See Al-Hussainy
Craze and Buckley, 163
Critical point, 9, 415, 418–19, 474
Critical saturation, 360–61, 400–401, 423
correlations, 44
formation volume factor (Bo) 47–51
isothermal compressibility, 51–53
saturated vs. undersaturated, 44
solution gas-oil ratio (Rso), 21, 44–47, 61–62, 477
Darcy, 5
Darcy, as unit of measure, 474
Darcy flow, 347
Darcy’s law, 227–32, 236–39, 245, 247–48, 297, 474
Davis. See Fatt
DDI. See Depletion drive index
Depletion drive index (DDI), 80–81, 204–6, 217, 220
Dew-point pressure, 9, 27–28, 122–23, 141–42, 152
Differential process, 145–47, 209–10, 214
Displacement efficiency, 357–59, 365–69, 474
Displacement, oil and gas, 357–404
Buckley-Leverett displacement mechanism, 369–75
enhanced oil recovery processes (EOR)
alkaline flooding, 412, 421, 424–25
capillary number, 412–14, 421, 424
chemical flooding processes, 421–26
dynamic miscible process, 417–19
forward dry combustion process, 430
forward wet combustion process, 430
in situ combustion, 430
miscible flooding processes, 414–21
multiple-contact miscible process, 417–20
in oil-wet systems, 42
polymer flooding, 421
residual oil, mobilization of, 412–14
single-contact miscible process, 415–17
steam-cycling or stimulation process, 428
in water-wet systems, 412
macroscopic displacement efficiency, 365–69
anisotropy of hydro-carbon-bearing formation, effect on, 365–66
areal sweep efficiency, 366–67, 473
heterogeneities of hydro-carbon-bearing formation, 365–66
limestone formations, 366, 369
pressure maintenance, 152–53, 172, 176, 222
sandstone formations, 369
viscous fingering, 366, 406–7, 411, 414, 421–26, 478
mechanism
drag zone, 375
flood front, 244, 284, 361, 366, 375, 401–2
microscopic displacement efficiency, 357–59
absolute permeability, 359–60, 399–402
capillary pressure, 24, 220, 357–58
critical saturation, 360–61, 400–401, 423
fractional flow curve, 364–65, 377
hydrocarbon saturation, 150, 361
interfacial tensions between fluids, 358, 362
residual saturation, 361–62, 417–18
transition zone, 362–264, 371–74, 381, 400–401
oil recovery by internal gas drive, 382–99
iteration techniques, 390
secant method, 390
waterflooding, 14, 233, 405–6, 412, 422, 478
pattern flooding, 407
Displacement, oil by gas
gravitational segregation in, 376–82
oil recovery by internal gas drive, 382–99
oil-wet rock, 475
updip (“attic”) oil, 382
water wet rock, 478
Dissolved gas, 2
Distillate, 121
Dotson, Slobod, McCreery, and Spurlock, 22
Downdip water wells, 97
Dranchuk and Abou-Kassem, 31, 38
Dry gas, 66, 103, 117, 153–56, 416–20. See also Lean gas
Eakin. See Lee
Earlougher, Matthews, Russell, and Lee, 272
East Texas field, 82
Echo Lake field, 113
Economics, in relation to gas, 18
Egbogah, 55
Elk Basin field (Wyoming and Montana), 161
Elk City field (Oklahoma), 217
Ellenburger formation (West Texas), 296
Emulsion, 474
Enhanced oil recovery (EOR), 14, 405–35, 474
secondary, 406–12. See also Secondary oil recovery
tertiary, 412–33. See also Tertiary oil recovery
EOR. See Enhanced oil recovery
Equations of state, 24. See also Ideal gas law; Pressure-volume-temperature
Equilibrium ratios, 138–40, 144–47
Estimated ultimate recovery (EUR), 4
EUR. See Estimated ultimate recovery
Fancher, Lewis, and Barnes, 5
Farshad. See Ramagost
Fatt and Davis, 237
Fault, 475
Fetkovich, 6, 346–50, 355, 438
Flash process, 145, 209–10, 214. See also Saturated oil reservoirs
Flood front, 244, 284, 361, 366, 375, 401–2
Fluid flow, single-phase. See Single-phase fluid flow
Fluid saturations, 24
Formation damage, 475
Formation volume factor (Bo), 34–35, 47–51, 61
Fracking. See Fracturing
Fractional flow curve, 364–65, 377
Fracturing, 4, 17–18, 250, 407–9, 475
Free gas volume, 49, 75, 77, 83
Gas and oil (initial) calculation, 124–31
Gas compressibility factor, 21, 36, 223
Gas-condensate reservoirs, 121–58
calculating initial gas and oil in, 124–31
lean gas cycling and water drive in, 147–51
performance of volumetric reservoirs, 131–40
predicted vs. actual production histories of volumetric reservoirs, 143–47
use of material balance in, 140–43
use of nitrogen for pressure maintenance in, 152–53
Gas deviation factor, 27–37, 100–117, 125–27, 141–42, 153–55
Gas distillate, 2
Gas formation volume factor, 34, 76, 239, 444, 475
Gas-oil contact, 475
Gas-oil ratio (GOR), 21, 44–47, 61–62, 477
as a crude oil property, 44–47
history matching and, 453
net cumulative produced in volumetric, 169
solution GOR in saturated oil reservoirs, 215–17
formation volume factor and density, 34–35
gas deviation factor, 27–37, 100–17, 125–27, 141–42, 153–55
isothermal compressibility, 35–41
supercompressibility factor, 26–27
Gas reservoirs. See also Gas-condensate reservoirs; Single-phase gas reservoirs
Gas saturation, 475
Gas volume factors, 35, 65, 89–93, 112–14
Gas-water contact, 7, 114, 475
Geffen, Parish, Haynes, and Morse, 95
General material balance equation. See Material balance equation
Gladfelter. See Stewart
Glen Rose Formation, 143
Gloyd-Mitchell Zone (Rodessa field), 177–84
average monthly production data, 179–80
development, production, and reservoir pressure curves, 177
production history vs. cumulative produced oil, 181
production history vs. time, 181
solution gas-drive reservoir, 171
Gonzalez. See Lee
Goodrich. See Russel
GOR. See Gas-oil ratio
Gravitational segregation characteristics, 219–220, 402, 453
displacement of oil by gas and, 376–82
Gray. See Jogi
Hall, 184
Harrison. See Rodgers
Harville and Hawkins, 110
Havlena and Odeh, 73, 83–85. See also Material balance equation
Hawkins. See Bourgoyne, Harville
Haynes. See Geffen
Hinds. See Reudelhuber
decline curve analysis, 437–41
incorporating flow equation, 442
material part of model, 441
discussion of history-matching results, 451–65
fluid property data, conversion of, 448–49, 451–53
summary comments concerning, 465–66
gas-oil ratios, 453
gas production rate, 465
multidimensional, multiflow reservoir simulators, 437
oil production rate, 451
zero-dimensional Schilthuis material balance equation, 441–42
Holden Field, 116
Holland. See Sinha
Hollis, 109
Horizontal drilling, 17–18, 434
Hubbert, 15
Hurst, 6, 274, 303–6, 322–23, 349–50
Hydrate, 475
Hydraulic fracturing, 4, 17–18, 250, 407–9, 475
Hydrocarbon saturation, 150, 361
Hydrocarbon trap, 475
IEA. See International Energy Agency
Ikoku, 108
Injection wells, 475
International Energy Agency (IEA), 16
Interstitial water, 83, 92, 115, 162, 473
Ira Rinehart’s Yearbooks, 121–23
Isobaric maps, 82
Isopach maps, 82, 88, 102, 455, 468, 475
Isothermal compressibility, 21–24, 76, 233, 260
Jackson. See Matthes
Jacoby and Berry, 217
Jacoby, Koeller, and Berry, 140
Jogi, Gray, Ashman, and Thompson, 110
Kaveler, 90
Keller, Tracy, and Roe, 218
Kelly-Snyder Field (Canyon Reef Reservoir), 171–76, 384
Kennedy. See Wieland
Kennedy and Reudelhuber, 161
Kern, 382
Kleinsteiber, Wendschlag, and Calvin, 152–53
Kobayashi. See Carr
Koeller. See Jacoby
Laminar flow, 228, 244, 253, 274
LaSalle Oil Field, 67
Lavaquail. See Bourgoyne
Lean gas, 140, 147, 152. See also Dry gas
Lee. See Earlogher
Lee, Gonzalez, and Eakin, 43
Leverett. See Buckley
Leverett and Lewis, 5
Limestone formations, 23
Linear flow, 233, 236–37, 242–45, 254, 371
Liquefied natural gas (LNG), 475
Liquefied petroleum gas (LPG), 135, 415, 475
LNG. See Liquefied natural gas
Louisiana Gulf Coast Eugene Island Block Reservoir, 98
LPG. See Liquefied petroleum gas
Lutes, Chiang, Brady, and Rossen, 97
Marudiak. See Matthes
Mass density, 475
Material balance equation, 73–85
calculating gas in place using, 98–105
in gas-condensate reservoirs, 140–43
Havlena and Odeh method of applying, 83–85
history matching with, 441
in saturated oil reservoirs, 200–206
in undersaturated oil reservoirs, 167–71
uses and limitations of, 81–83
volumetric gas reservoirs, 98–100
water-drive gas reservoirs, 100–105
zero-dimensional Schilthuis, 441–42
Mathews, Roland, and Katz, 128
Matthes, Jackson, Schuler, and Marudiak, 97
Matthews. See Earlougher
Matthews and Russell, 254
Maximum efficient rate (MER), 199, 218–20
McCain, Spivey, and Lenn, 44, 50
McCarthy, Boyd, and Reid, 107
McCord, 161
MEOR. See Microbial enhanced oil recovery
MER. See Maximum efficient rate
Mercury, 132
Micellar-polymer flooding, 421
Microbial enhanced oil recovery (MEOR), 425
Mile Six Pool (Peru), 219, 378–83
Miscible flooding processes, 414–21. See also Tertiary oil recovery
inert gas injection processes, 420–21
problems in applying, 421
Mobility, 365–68, 383–84, 421–26, 475
Moore. See Coleman
Moore and Truby, 296
Morse. See Geffen
Moscrip. See Woody
M sand, 114
Mueller, Warren, and West, 453
Muskat, 198, 384–85, 393, 397, 402, 471
Muskat, Standing, Thornton, and Eilerts, 121
National Institute for Petroleum and Energy Research (NIPER), 425
Natural gas liquids, 476
Net isopachous map. See Isopach maps
NIPER. See National Institute for Petroleum and Energy Research
Nitrogen, for pressure maintenance, 152–53
Nonconformity. See Unconformity
North Sea gas field. See Rough gas field
Oil and Gas Journal, The, 172, 425, 434
Oil formation volume factor, 51, 76, 80, 196, 203, 215, 390, 476
Oil saturation, 476
Oil-water contact, 7, 297, 305, 320, 353, 362, 476
Oil-wet rock, 476
Original oil in place (OOIP), 196, 224, 476
Osif, 62
Overburden, 21, 23, 237, 428, 430, 476
Paradox limestone formation, 146
Parish. See Geffen
Permeability, 476
recovery efficiency and, 359–65
Perry. See Russell
Petroleum, 476
Petroleum Resources Management System (PRMS), 2–3
Petrophysics, 5
PI. See Productivity index
Poiseuille’s law, 245
Pore volume compressibility, 21, 23
Porosity, 7, 21–23, 112–17, 476
PR. See Productivity ratio
Pressure
average, 66, 75–76, 80–82, 140–41, 441–42
bottom-hole, 4, 67–68, 265–66, 289–90, 476
bubble-point, 5, 11, 45–47, 50–56, 210–11, 221–24, 283, 288, 382
constant terminal pressure case, 304
dew point, 9, 27–28, 122–23, 141–42, 152
standard, 477
Pressure buildup test, 278–79, 291, 475, 476
Pressure maintenance program, 152–53, 172, 176, 222
Pressure transient testing, 272–82, 476
pseudosteady-state time region in, 277–78
Pressure-volume-temperature (PVT), 5, 154–57, 167–70, 193–95, 198, 209–22, 301
Primary production, 13, 159, 405–6, 476
PRMS. See Petroleum Resources Management System
Production, 3
primary production (hydrocarbons), 13, 159, 405–6, 476
secondary recovery operation. See Secondary oil recovery
tertiary recovery processes. See Tertiary oil recovery
Production wells, 14, 97, 114, 171, 365–67, 407–8, 477
Productivity index (PI), 254–66
injectivity index, 266
Productivity ratio (PR), 266–67
Properties, 21. See also Crude oil properties; Gas properties; Reservoir water properties; Rock properties
Prospective resources, 3
P sand reservoir, 116
Pseudosteady-state flow, 261–64
compressible fluids, 264
slightly compressible fluids, 261–64
PVT. See Pressure-volume-temperature
Quantities of gas liberated, 5
Radial flow, 233, 236, 246, 250, 254–55
Ramagost and Farshad, 110
Ramey. See Agarwal, Al-Hussainy, Wattenbarger
Rangely Field, Colorado, 161
macroscopic displacement efficiency, 365–69
microscopic displacement efficiency, 357–59
Redlich-Kwong equation of state, 152
Reed. See Wycoff
Regier. See Rodgers
Reid. See McCarthy
Reservoir engineering, 6
terminology, xix-xxv, 7–8, 473–79
Reservoir mathematical modeling, 6
Reservoir pressure, 5
Reservoir rock, 477
Reservoirs
bounded, 474
flow systems
pseudosteady. See Pseudosteady-state flow
steady-state. See Steady-state flow systems
transient. See Transient flow
Reservoir simulation, 6
Reservoir voidage rate, 219
Reservoir water properties, 61–64
formation volume factor, 61
isothermal compressibility, 62–63
solution gas-water ratio, 61–62
viscosity, 63
Residual gas saturation, 95–96
Residual oil, 477
Residual saturation, 361–62, 417–18
Retrograde condensation, 9–10, 141, 147–48, 152
Retrograde liquid, 10–11, 36–37, 132
Reudelhuber. See Kennedy
Reudelhuber and Hinds, 217
Richardson and Blackwell, 376
Robinson. See Beggs
Rock collapse theory, 110
fluid saturation, 24
isothermal compressibility, 22–24
porosity, 22
Rodessa field. See Gloyd-Mitchell Zone (Rodessa field)
Rodgers, Harrison, and Regier, 139–40, 146
Roe. See Allen
Roland. See Mathews
Rossen. See Lutes
Rough Gas Field, 109
Russell. See Earlougher; Matthews
Russell, Goodrich, Perry, and Bruskotter, 240
Salt dome, 477
San Juan County, Utah, 146
Saturated oil reservoirs, 199–225
differential vaporization and separator tests, 215–17
factors affecting overall recovery, 199–200
continuous uniform formations, 200
gravitational segregation characteristics, 200
large gas caps, 200
formation volume factor and, 215–17
gas liberation techniques, 209–15
material balance as straight line, 206–9
material balance calculations for, 202–6
maximum efficient rate (MER) in, 218–20
solution gas-oil ratio, 215–17
water drive
Saturation
critical, 360–61, 400–401, 423
gas, 475
residual hydrocarbon, 150, 361
Saturation pressure. See Bubble-point pressure
Schatz. See Sinha
Schilthuis, 5–6, 302–3, 441–52
Schroeder. See Carpenter
Schuler. See Matthes
Schuler field, 89
Sclater and Stephenson, 4
Scurry Reef Field, Texas, 161, 213
SDI. See Segregation (gas cap) index
SEC. See Securities and Exchange Commissions
candidates, 407
estimating recovery efficiency, 409–11
location of injectors and producers, 407–9
Secondary recovery process, 14, 477. See also Secondary oil recovery
Securities and Exchange Commissions (SEC), 2
Seep, 477
Segregation (gas cap) index (SDI), 80–81, 204–5
Shale, 477
Shreve and Welch, 382
Shrinkage factor, 47
Shrinkage of oil, 5
Simpson’s rule, 241
Single-phase fluid flow, 227–93
classification of flow systems, 232–367
Darcy’s law and permeability in, 227–32
pressure transient testing, 272–82
productivity index (PI), 254–66
productivity ratio (PR), 266–67
pseudosteady-state flow, 261–64. See also Pseudosteady-state flow
radial diffusivity equation and, 251–53
steady-state, 236–51. See also Steady-state flow
transient flow, 253–61. See also Transient flow
Single-phase gas reservoirs, 87–119
calculating gas in place
using material balance, 98–105
in volumetric gas reservoirs, 98–100
in water-drive gas reservoirs, 100–105
calculating hydrocarbon in place, 88–98
unit recovery from gas reservoirs under water drive, 93–98
unit recovery from volumetric gas reservoirs, 91–93
gas equivalent of produced condensate and water, 105–7
limitations of equations and errors, 112–13
Sinha, Holland, Borshcel, and Schatz, 110
Slaughter field, 82
Slurries, 4
Smith, R. H., 383
Society of Petroleum Engineers (SPE), 2
Society of Petroleum Evaluation Engineers (SPEE), 2
Solution gas-oil ratio (Rso), 21, 44–47, 61–62, 477
Source rock, 477
SPE. See Society of Petroleum Engineers
Specific gravity, 25–26, 127–28
Specific weight, 477
SPEE. See Society of Petroleum Evaluation Engineers
Spencer. See Cook
Standard pressure, 477
Standard temperature, 101, 478
Standing. See Muskat
Standing and Katz, 28, 30–31, 34
STB. See Stock-tank barrel
capillaries and fractures, 244–46
definition of, 478
linear flow, 478
of compressible fluids, 238–41
of incompressible fluids, 236–37
permeability averaging in, 241–44
of slightly compressible fluids, 237–38
radial flow
of compressible fluids, 247
of incompressible fluid, 246–47
permeability averages for, 248–51
of slightly compressible fluids, 247
radii
external, 247
wellbore, 247
Stephenson. See Sclater
Stewart, Callaway, and Gladfelter, 297
St. John Oil field, 115
Stock-tank barrel (STB), 8, 478
Stock-tank conditions, 50, 478
Subsurface contour maps, 88
Summit County, Utah, 152
Supercompressibility factor, 26–27. See also Gas deviation factor
Sweep efficiency, 14, 147, 154, 165, 357, 366, 369, 406, 421–24, 433, 478
Syncline, 478
Tarner, 384, 390, 393, 397, 399, 402, 471
Tarner and Buckley, 6
Tek. See Katz
chemical flooding processes, 421–26
definition of, 478
micellar-polymer processes, 422–24
miscible flooding processes, 414–21
inert gas injection processes, 420–21
problems in applying, 421
mobilization of residual oil, 412–14
problems in applying, 426
processes, 14
in situ combustion, 430
screening criteria for, 431–33
steam-cycling or stimulation process, 428
Testing
pressure transient testing, 272–82
Thermal processes, 427–31. See also Tertiary oil recovery
in situ combustion, 430
screening criteria for, 431–33
steam-cycling or stimulation process, 428
Thompson. See Jogi
Thornton. See Muskat
Timmerman. See van Everdingen
Torchlight Tensleep reservoir, 297
Total flow capacity, 249
Tracy, 390–91. See also Carter; Kelly
line source solution, 255
radial flow, compressible fluids, 260–61
radial flow, slightly compressible fluids, 253–59
Transition zone, 362–264, 371–74, 381, 400–401
hydrocarbon, 475
Trube, 38
Truby. See Moore
Undersaturated oil reservoirs, 159–98. See also Volumetric reservoirs
calculating oil in place and oil recoveries in, 162–67
formation and water compressibilities in, 184–91
Gloyd-Mitchell Zone of the Rodessa Field, 177–84
Kelly-Snyder Field, Canyon Reef Reservoir, 171–76
Unitization, 478
University of Kansas, 443
Unsteady-state flow, 6, 302–46. See also Water influx
constant terminal pressure case, 304
constant terminal rate case, 303
Updip (“attic”) oil, 382
US Department of Energy, 433
Valko and McCain, 46
van der Knaap, 23
van Everdingen and Hurst, 303–23. See also Water influx
van Everdingen, Timmerman, and McMahon, 83
Vaporization, 9–10, 107, 159, 209–10
Velarde, Blasingame, and McCain, 46
Villena-Lanzi, 53
Viscosity, 475
of reservoir water, 63
Viscous fingering, 366, 406–7, 411, 414, 421–26, 478
Void fraction. See Porosity
Volatile oil reservoirs, 217–18. See also Saturated oil reservoirs
Volumetric method (for calculating gas in place), 112, 220
artificial gas cap, 169
bedding planes
bubble-point pressure, 5, 11, 45–47, 50–56, 210–11, 221–24
calculating gas in place in, 98–100
calculation of depletion performance, 135–40, 148, 150–54
calculation of initial oil in place
material balance studies, 162
calculation of unit recovery from, 91–93
effective fluid compressibility, 185–86
free gas phase, 11, 45, 169, 173, 190, 199
hydraulic control, 163–64, 200
material balance in, 98–100, 167–71
net cumulative produced gas-oil ratio, 169
predicted vs. actual production histories of, 143–47
Volumetric withdrawal rate, 298
WAG. See Water alternating gas injection process
Warren. See Mueller
Water alternating gas injection process (WAG), 411
Water-drive index (WDI), 80–81, 204, 205, 206
Water-drive reservoirs, 95, 100–105, 376
Waterflooding, 14, 233, 405–6, 412, 422, 478
constant, 298, 300, 302, 303, 306, 350, 352
reservoir voidage rate, 300–301
volumetric withdrawal rate, 298
water influx constant, 300–301
constant terminal pressure case, 304
constant terminal rate case, 303
Water volume, 8
Water-wet rock, 478
Wattenbarger and Ramey, 239
WDI. See Water-drive index
Weight density, 478
Welch. See Shreve
Wellhead, 4, 12, 95, 112, 114, 138, 213, 449, 478
Wendschlag. See Kleinsteiber
Wessely. See Clark
West. See Mueller
Western Overthrust Belt, 152
Wet gas, 12, 27, 144, 147, 152–57
Wichert and Aziz, 34
Wickenhauser. See Bourgoyne
Wieland and Kennedy, 82
Wildcat reservoir, 197
Wildcat well, 479
Wilde. See Coleman
Woody and Moscrip, 74
World Petroleum Council (WPC), 2
WPC. See World Petroleum Council
Wycoff and Bostet, 5
Wycoff, Botset, and Muskat, 367
Wycoff, Botset, Muskat, and Reed, 5
Yarborough. See Vogel