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A

  • Abo reef, 1117, 1138

  • absolute open flow (AOF) potential, 840

  • acid-generating chemical, 1191

  • acoustic borehole imaging, 397–400

  • acoustic caliper, 194

  • acoustic coupling, 205

  • acoustic-data processing, 214

  • acoustic-energy propagation, 180

  • acoustic-logging, 167, 169

    • measurements, 195, 203

    • tools, 172, 175–176, 206, 228

  • acoustic receivers, 170

  • acoustic-wave

    • attenuation of, 224

    • propagation of, 214

    • propagation theory, 167

    • train, 170

    • velocity of, 169

    • waveforms, 179, 195

  • acrylamide-polymer, 1165, 1222–1223

  • -acrylamido-2-methyl-propanesulfonic acid (AMPS) monomers, 1164

  • Adaptive Implicit Method (AIM). See model formulations

  • adsorption/retention sacrificial agents, 1233

  • after federal income tax (AFIT), 1589

  • aggradational cycles, 8–9

  • AGIP. See apparent gas in place

  • air-gun wavelet, 29–31

  • air/oil ratios, 1385

  • AIT images, 138

  • AIT logs, 102, 113–114, 116–117, 119–121, 126, 131

  • Alani-Kennedy EOS method, 905

  • alkaline-surfactant-polymer (ASP) flooding, 1240

  • alluvial-fan system, 18

  • alpha-olefin sulfonates, 1227, 1236

  • alpha olefin-sulfonate-surfactant foam, 1231

  • aluminum-citrate acrylamide-polymer gels, 1190

  • aluminum-citrate colloidal dispersion gels, 1215

  • aluminum crosslinked gels, 1190

  • American Petroleum Institute (API), 79, 1079

    • data, 1491

    • gamma ray unit, 262, 269

    • gravity, 369

    • reports, 902

    • standards, 334, 426

    • units, 78, 258, 509

  • americium-beryllium (Am 241 Be) isotopic source, 269

  • Amott tests, 1041

  • amphoteric surfactants, 1227

  • AMPS polymer, 1169

  • anaerobic oil reservoirs, 1200

  • analogous reservoir, 1490, 1559

  • analytical valuation methods, 1572

  • anionic surfactant, 1226

  • anionic tracers, 654

  • anisotropic reservoirs, 835, 878–879

  • anisotropy-analysis methods, 211, 220, 335

  • annual discount rate factor, 1580

  • annular pressure, 563–566

  • annular pressure source location, problems and tools, 611

  • anticlinal reservoir, 1121

  • anticline trap, 3

  • API. See American Petroleum Institute

  • API RP 40, 81–82, 86

  • apparent gas in place, 1549

  • apparent wellbore radius, 750–751

  • appraisal, definition, 1573

  • aqueous-based foams, 1225

  • aqueous gel fluids, 1221

  • aqueous polymer gels, 1203

  • aquifer water, 1121

  • Arbuckle formation, 1213

  • Archie exponents, 454–457, 470

  • Archie method, 84

  • Archie parameters, 205

  • Archie R t -based S w equation models, 469

  • Archie water saturation equation, 145–146, 150–151, 155, 159–160

  • ARC5 phase shift, 126–127

  • areal conformance problems, 1152, 1153, 1155

  • areal sweep efficiency, 1120, 1124, 1150, 1236

  • ARI images, 137–138

  • Arps equations, 1527–1528

  • Arps-Smith method, 776, 783–785

  • FF40 array, 107, 112

  • array electrode tools, 97–99

  • array-induction tools, 113–114

  • array resistivity compensated tool (ARC5), 124–126

  • Arrhenius expressions, 1372

  • attenuation tomography, 65, 68

  • autohydrolysis, 1164, 1177, 1189

  • autoignition, 1368, 1388, 1394

  • average primary oil recovery, 902

  • average reservoir pressure, 699–700

  • average sandstone heat capacity, 1376

  • average steam zone thickness, 1315

  • azimuthal anisotropy, 220

  • azimuthal dual laterologs, 95–97

  • azimuthal measurements, 181, 193

  • Azimuthal Resistivity Imager (ARI), 95, 97, 128

B

  • Babu-Odeh method, 830, 839

  • bafflestone, 10–11

  • Baker Atlas MREX devices, 308

  • Baker Atlas Multi-Capacitance Flowmeter, 521–522

  • balanced tangential method, principles of, 384

  • barrels of oil per day (BOPD), 1309

  • basin-floor sand lobe, 3

  • basket (metal-petal) flowmeter, 523

  • before federal income tax (BFIT), 1589

    • AFIT and, 1590–1591

  • BHP. See bottomhole pressure

  • BHP, and temperature data acquisition, 692–698

    • applications and interpretation, 699–701

    • bottomhole conveyance of gauges, 694

    • drillstem testing, 694–696

    • measurement while perforating (MWP), 695–697

    • openhole wireline pressure testing, 695

    • permanent pressure measurement installations, 697–698

    • production logging, 695

    • surface readout vs. downhole recording, 693

    • surface shut-in vs. downhole shut-in, 693

  • BHP, and temperature gauges

    • accuracy, 686

    • dynamic response during pressure and temperature shock, 687

    • metrology of, 686–687

    • resolution, 686

    • sensitivity, 687

    • stability, 686–687

  • bilinear flow method, 767–768, 785, 790

  • billiard-ball-type collisions, 267, 269

  • bindstone, 10–11

  • biological stabilizers, 1177

  • biopolymer gels, 1191, 1222

  • biostratigraphy, 372

  • black-oil reservoir

    • numerical simulators, 1114

    • OOIP and, 913

    • simulation and fluid properties for, 912

  • blocking-agent conformance treatment, 1153

  • body waves and surface waves, 33–35

  • bonded wire transducers, 690

  • bond index (BI), 192

  • borehole acoustic array, 215

  • borehole-acoustic detection methods, 208

  • borehole acoustic logging, 168, 214

  • borehole-compensated (BHC) monopole devices, 167

  • borehole-corrected gamma ray log, 259

  • borehole flexural waves, 170

  • borehole fluids, 169

    • compressional velocity, 173

    • formation reflection, 183

    • ultrasonic attenuation, 183

    • velocity, 189

  • borehole-geophysical acoustic techniques, 167

  • borehole gravimetry, 408–412

  • borehole-guided modes, 182

  • borehole imaging

    • acoustic, 397–400

    • conjunctive acoustic and electrical, 406–408

    • electrical, 400–406

    • optical, 397

  • borehole televiewer (BHTV), 182

  • borehole-televiewer-type imaging devices, 210

  • Born response functions, 123

  • bottomhole conveyance, of gauges

    • coiled tubing, 694

    • electric line operations, 694

    • slickline operations, 694

    • wireless transmission, 694

  • bottomhole flowing pressures (BHFP), 840

  • bottomhole pressure, 724, 726, 759, 912

    • dynamic temperature correction and, 687

    • logging tools, 176

    • monopole-acoustic logs, 176

    • static metrological parameters, 686–687

    • and temperature data acquisition ( see BHP, and

    • temperature data acquisition)

    • and temperature gauges ( see BHP, and temperature gauges)

    • transient response variation, 687

  • bottomwater-drive, 872, 900

  • boundary conditions

    • constant flow, 730

    • no-flow, 726

  • boundary-dominated flow, 726

  • boundary effects, 723, 805

  • bounded reservoir behavior, 770–776

  • boundstone, 10–11, 13

  • Boyles-law, sum-of-fluids porosity and, 476

  • Brar and Aziz method, 864, 869

  • brine-saturation distribution, 427

  • broadband transmitters, 171

  • BTU content, of gas, 360–362

  • bubblepoint pressure, 748, 1138

  • bubble size distribution, 1228, 1230

  • Buckley-Leverett equation/method, 1108, 1123, 1125

  • Buckley-Leverett solution, 1053–1054

    • saturation profile computed from, 1056

  • bulk magnetization, 292

  • bulk relaxation, 299

  • bulk tool response, 252

  • bulk-volume-irreducible (BVI) water, 298

  • Buna rubber, 1186

  • BVI determination, 316

C

  • calcium-carbonate cementation, 15

  • calibration cycle, maximum hysteresis during, 688

  • calibration line-fitting, 444–447

  • Canadian Rapdan polymer flood, 1183

  • capacitance pressure transducer, 689

  • capillary absorption tube sampler (CATS) technology, 658–659, 669

  • capillary pressure, characteristics, 426, 1111

    • effects, 704–709

    • for intermediate wettability, 1047

    • method, depth of OWC/GWC calculation, 1505–1506

    • SCAL data, 459–460

    • of Tensleep Sandstone oil-wet rock, 1046

    • of water-wet rock, 1043

  • capillary processes control, 1225

  • capillary water, 432

  • carbonate(s)

    • buildup, 3

    • complex lithologies and, 335

    • diagenetic processes, 15

    • field, 1617–1619

    • formations, simulation of SWCT tests in, 638–639

    • layer thickness determination and, 79

    • platform, 13

    • porosity determination and, 83

    • reservoirs, 9–16, 431, 1062, 1067, 1088, 1117–1118

    • rock-fabric, facies, porosity, and permeability, 21–23

    • stratigraphy, 8

    • waterflood, with strategic well placement, 1620

  • carbonate sediments

    • classification of, 10–11

    • depositional environments, 13–14

    • diagenetic environments, 14–16

    • pore space classification, 12

    • porosity and permeability of, 10–12

    • ramp facies patterns, 13–14

    • sabkha and tidal-flat environment, 14

    • topography and ramp facies patterns, 13

    • vuggy pore space classification, 11–12

  • carbon-carbon bonds, 1160

  • carbon dioxide (CO 2 )

    • flooding, 1236, 1241

    • foams, 1236

    • injection labeling, 677

    • projects, combustion project

    • Denver unit, 1296–1297

    • Means San Andres unit, 1293–1296

    • SACROC four-pattern flood, 1292–1293

    • sweep efficiency, 1236

  • carbon/oxygen (C/O) logs, 278

  • Carr-Meiboom-Purcell-Gill (CMPG) sequence, 295–297, 301, 303, 323

    • variations in, 326

  • Cartesian coordinates, 785, 863

  • Cartesian grid, 1407–1409, 1411

  • cased-hole

    • calipers, 388–389

    • logs, 175

    • neutron porosity, 204

    • resistivity tools, 100–104

    • saturation tool, 276

    • wireline tools, 185

  • cased-hole formation resistivity (CHFR) tool, 100, 102–103

  • casing collapse part and split, problems and tools, 614

  • casing-collar locator (CCL), 501

    • well-logging and, 411

  • casing inspection logs, well-logging and

    • cased-hole calipers, 388–389

    • electromagnetic phase-shift tools, 391–392

    • flux-leakage tools, 389–391

    • ultrasonic tools, 392

  • catalytic combustion detector (CCD), 362

  • cation-exchange capacity (CEC), 18–19, 155, 457–458, 464

  • cationic acrylamide polymers, 1165

  • cationic polyacrylamides, 1165

  • cationic surfactant, 1227

  • cationic tracers, 655

  • cavern collapse, 15

  • CC/AP gel technology, 1205, 1214

  • CDR logs, 130

  • cementation sequence, 1118

  • cement-bond devices, 187–188

  • cement-bond logging, 185–186, 189

  • cement-bond logs (CBLs), 185, 191, 392, 394–396

  • cement-evaluation logs, 392–397

  • Cement Evaluation Tool (CET™), 394

  • cement-placement

    • evaluation of, 558–559

    • monitoring, 496

    • production logging and, 556–559

  • cement-to-formation

    • bonding, 189

    • interface, 185

  • cement tops detection, in temperature profiles, 714

  • centrifuge technology, 1050

  • Cesium-137, 263, 515, 518, 521

  • CGR. See condensate/gas ratio

  • chased slug approach, 571

  • chemical condensation polymerization reaction, 1241

  • chemical crosslinking reactions, 1162

  • chemical-explosive energy sources, 26

  • chemical fluid-flow shutoff material, 1153

  • chemical gas tracers, 658–659

  • chemical gel structure, 1198

  • chemical-reaction (polymerization) rates, 1241

  • chemical stabilizers, 1177

  • chemical tracer, 1174

  • chemical water tracers, 655–656

  • chemostratigraphy, 372

  • Chinese polymer floods, 1183

  • choked-fracture

    • damage, 789

    • skin factor, 789

    • type curve, 794

  • chromic triacetate (CrAc 3 ), 1194

  • chromium (III)-carboxylate/acrylamide-polymer gels, 1189

  • chromium (VI) redox gels, 1190

  • chronostratigraphic approach, 7

  • Cinco type curve, 793

  • Circumferential Acoustic Scanning Tool (CAST™), 400

  • Circumferential Acoustic Scanning Tool-Visualization version (CAST-V™), 397

  • Circumferential Borehole Imaging Log (CBIL™), 400, 406

  • classic material balance, 1519

  • clay-bound fluids, 315

  • clay-bound-water (CBW) components, 316–317, 336

  • clay minerals, 21, 431–432

  • clean-sand (Archie) model, 461–462

  • CMB. See classic material balance

  • CMPG acquisition, 341

  • coalbed reservoirs, volumetric estimate of GIP (scf), 1535

  • coarse-grid, 1408–1409

    • 2D and 3D simulation models, 1604–1605

  • collapse brecciation, 15–16

  • collar-locator log, 537, 549

  • colloidal dispersion gels, 1215

  • Combinable Magnetic Resonance (CMR) tool, 291, 316

  • combustion

    • dry, 1368

    • in-situ combustion (ISC), 1367

    • kinetics, 1371–1372

    • projects, pollution-control systems for, 1392

    • reverse, 1367–1368

    • wet, 1369–1370

  • commingled gas and water production profiling problems

    • back-scatter gamma-ray density surveys, 590, 592, 598, 604–605

    • continuous or fullbore spinner surveys, 593, 596, 599, 602, 608

    • differential-pressure density survey, 602

    • diverting-spinner flowmeter survey, 593

    • flowing spinner survey, 604–605

    • flowing survey with radioactive chemical tracer, 602

    • fluid-capacitance survey, 592, 595, 601, 605, 608

    • fluid density survey, 593

    • gradient-type density survey, 599, 604–605

    • gravel-pack surveys, 595, 598, 602, 604, 608

    • multiarm conductive and multiarm fluid capacitance surveys, 603

    • noise-logging survey, 590, 597, 599, 604–605

    • optical gas-detection surveys, 604

    • pulse-neutron surveys, 595, 599, 602, 608

    • temperature surveys, 592, 598, 601, 603, 605, 608

  • commingled-gas production, profiling, 537–539

  • commingled oil and water production profiling problems

    • gravel pack and continuous-spinner survey, 608–609

    • noise logging survey, 609

    • temperature and fluid capacitance survey, 608

  • common interpretation method, 259

  • compaction-drives, 956–961

    • material-balance analysis, 957–961

    • performance, 957

    • reservoir, 901

    • rock expansivity and compressibility, 958–961

  • compensated dual resistivity (CDR) tool, 118–121, 123–126

  • compensated neutron-porosity logging (CNL) tool, 267–268, 270

  • compensated wave-resistivity (CWR) tool, 127

  • complete-water drive reservoir, 900

  • complex faulted structural trap, 3

  • complex flow geometries, 756

  • complex seismic trace, 37–39

  • component analysis, mud logging and, 361–365

  • composite decline curves, misuse of, 1557

  • composite expansivities, 908, 917

  • compressed gas/oil, 899

  • compressional-slowness measurement, 181

  • compressional velocity, 202

  • compressional-wave(s), 169–170

    • acoustic logs, 210

    • velocity, 170

  • compressive strength, 1222

  • Compton scattering, 254–255

  • computer-aided fluid-injection control, 1221

  • computer simulation for well/reservoir performance, 1531–1532

  • computer thermal-simulation work, 1208

  • condensate/gas ratio, 1514

  • condensate reservoirs, 982

  • condensate well fluid, volumetric behavior, 990

  • condensation polymerization, 1242

  • conformance-improvement treatment systems

    • flooding operations, 1151

    • fluid system, 1149

    • foams, 1235

    • gels, 1187

    • gel treatments, 1218

    • polymer technologies, benefits of applying, 1166

    • systems for, 1149

  • coning, of well, 872–879

  • connate-brine, 1045

    • resistivity ( R w ), 453–454

  • connate-water, 908

    • expansion, 917

    • SWCT tests for, 644

  • connate water saturation ( S wc ), 615, 1048

  • consolidated rock, 1550

  • constant-composition expansion (CCE), 988–989

  • constant-pressure boundary, 827

  • constant-rate drawdown test, 772

  • constant volume depletion (CVD), 904

  • continuous and fullbore spinner flowmeters, 526–535

  • continuous/fullbore spinner and temperature survey, profiling

    • production problems, 600

  • cool hot wells, water for, 1391

  • cooling-fluid injection, 1244

  • core analysis, 78

  • core-flooding experimental testing, 1200

  • core/log calculation approaches, porosity determination and

    • calibration line-fitting, 444–447

    • density log, 447–449

  • core-plug Boyles-law porosity measurements, 442

  • core porosity ( ϕ c ), 443

  • core sampling, 78

  • Corey theory, 1128

  • correlation coefficient, 444

  • corrosion detection problems

    • magnetic flux-leakage surveys, 613–614

    • multifeeler mechanical-caliper and Eddy current wall-thickness surveys, 612

    • radial-type bond logging surveys, 614

  • corrosion-monitoring tools, 496

  • corrosive mixture, 1233

  • Council of Petroleum Accountants Socs. (COPAS) charges, 1576–1577

  • counterclockwise rotation (CCW), 532

  • coupled models, in reservoir stimulation

    • full coupling, 1449

    • iterative coupling, 1448

    • one-way coupling and loose coupling, 1447

  • coupling types, simulation of geomechanics

    • flow-properties coupling, 1445

    • pore-volume coupling, 1444–1445

  • crestal gas injection, 1119, 1135

  • critical spacing value, 172

  • crossed-dipole anisotropy analysis/logging, 211, 220, 224

  • crossflow behind casing, 563–566

  • crossflow detection behind casing, problems and tools, 611

  • crosslinked polymer gel, 1243

  • crosslinked styrene-butadiene block copolymers, 1243

  • crosslinker concentration, 1195

  • crosslinking agents, 1189

  • crosslinking chemistry, 1190–1191, 1206

  • crossplots, 280–283

  • cross-sectional gas/oil problem, 1409

  • crosswell seismic profiling, 26, 65–68

  • crude and matrix from ISC project, laboratory studies

    • chemical reactions, 1370–1371

    • combustion-tube studies, 1372–1374

    • kinetics of combustion reactions, 1371–1372

  • crude oils, 1041, 1046

    • properties, 1039

    • temperature dependence of viscosity for, 1321

  • cryogenic nitrogen rejection plant, 1135, 1143

  • crystalline carbonate, 11

  • Crystal Quartz Gauge (CQG) design, 691

  • cumulative air injected (CAI), 1385

  • cumulative incremental oil produced (CIOP), 1385

  • cumulative oil recovery and steam zone size, design

    • calculations for

    • Jones model, 1325–1326

    • Marx-Langenheim model and Mandl-Volek (M-V)

    • models, 1324–1325

  • cumulative wellhead gas, 1521

  • cutoff-BVI (CBVI) model, 316–318

  • cutoff frequency, 512

  • cuttings analysis, mud logging and

    • cuttings collection, 367

    • sample examination and description, 367–368

    • sample lagging, 365–366

  • cuttings board, mud logging and, 360

  • cuttings return, rate of, 375

  • cycle hierarchies, terminology of, 9–10

  • cyclic-steam injection, 1236, 1246

  • cyclic steam stimulation (CSS), 1324

  • cylindrical focusing technique (CFT), 103

D

  • dalmatian wetting, 1041, 1042. See also reservoir rocks

  • Darcy flow, 754, 841

  • Darcy’s law, 276, 436, 719, 721, 756, 1108, 1127

    • linear pressure dependence of flows for, 1416

  • data acquisition, 1080–1081

  • data fit—inversion, NMR and, 303–304

  • DataLatch system, 695

  • Dean-Stark water-extraction procedure, 426, 443–444, 452

  • decision tree analysis evaluation method, 1575

  • decline-trend analysis, 1556

  • deep laterolog tools, 453

  • Delaware basin, 1118

  • deliverability test

  • analysis theory, 840, 845

  • types and purposes of, 840

  • delta systems, 20

  • density and elevation survey, profiling production problem, 600

  • density log/tool, 387, 447–449

  • density/neutron log, 79, 428

  • density-porosity interpretation, 264–265

  • depositional facies model, 22

  • depth datum, of pressure, 699

  • depth-derived borehole compensation (DDBHC), 178

  • depth of investigation (DOI), 309, 335

  • derivative type curve, 743

  • deterministic cash flow evaluation method, 1574–1575

  • developed reservoirs, 704, 829, 841, 856

  • deviated well, 753

  • dewpoint pressure, 1560

  • diagenetic trap, 3–4

  • difference in gravity, A g (mGal), 409

  • differential-spectrum (DSM) method, 326–327

  • differential-vaporization (DV), 904

  • diffusion analysis (DIFAN), 329

  • diffusion-weighted mechanism. See dual- T W acquisition

  • dipole-acoustic sources, 221

  • dipole and multipole array devices, 180

  • dipole flexural shear mode, 221

  • dipole-shear

    • acoustic measurements, 214

    • dispersion, 220

    • slowness processing, 218

    • wave, 215

    • wave splitting, 221

  • dipole transmission, 170, 180

  • directional flow trends, 652

  • direct-shear velocities, 180

  • discount rate risk analysis method, 1580

  • discretization, 937, 1415, 1416, 1449

  • dispersed clay model, 156–158

  • displacement efficiency, 437, 616, 901, 921, 1024

    • macroscopic, of linear waterflood, 1052–1055

  • displacement equations, 1123

  • disproportionate permeability reduction (DPR), 1157

  • dissolved-gas-drive reservoirs, 902

  • dissolved gas/water ratio, 918

  • divalent-ion concentrations, 1206

  • diverting-spinner flowmeter, 523–526

  • DLL tools, 99

  • dolomitic carbonate reservoir, 1239

  • dolomitization, 15–16, 431, 1118

  • dolostone reservoirs, 15–16

  • domal structures, 3

  • double displacement process (DDP), 1135

  • downhole acoustic measurements, 167

  • downhole data surface acquisition, 698

  • downhole gas-fired burners, 1387

  • downhole gel, 1222

  • downhole injection pressure, 1181

  • downhole magnetics, 412–414

  • downhole NMR spectrometer, 311

  • downhole shut-in benefits, in pressure transient testing, 709

  • drainage-area geometry, 725

  • drainage P c / S w curve, 1043

  • drawdown and buildup type curves, 745

  • drawdown test analysis, 870

  • drilling engineering and operations, 372

    • connection gas, 374

    • cuttings return, rate monitoring of, 375

    • lithology and mineralogy, 373

    • mud chloride content, 373

    • mud pit level, 373

    • normal geothermal gradient, 374

    • total gas, 374

    • weight on bit and rate of penetration, 373

  • drilling fluid, 358–359, 374

  • calcium carbide and, 366

  • flow path, 359

  • hydrocarbons and, 369

  • invasion, 748

  • properties, 369–371

  • drillpipe

    • induction tools on, 117–119

    • manipulation and constriction problems, 552

  • drillstem-test data, 485–486

  • drillstem-tool (DST) tests, 86, 454, 694–696

  • dry and wet-gas reservoirs, 901

  • dry gases, 896

  • dry-gas reservoirs, 983, 1559–1560

  • Dual Dipmeter tool, 137

  • dual induction tool (DIT), 107–108, 111

  • Dual Laterolog (DLL) Resistivity ( R xo ), measurements, 93–95

  • dual-porosity, simulation model, 635

    • ethanol simulation, 641

    • ethyl formate simulation, 641

    • IPA cover tracer simulation, 635, 639–640

    • media, simulation of SWCT tests in, 636–638

    • reservoirs, 203, 785, 796, 802

    • systems, 801, 1538

  • Dual Propagation Resistivity (DPR) tool, 127

  • dual- T E acquisition, 327–329

  • dual- T W acquisition, 324–327

  • dual-water (DW) models, 158–161, 463

  • Dulang oil field, 478

  • dumpflooding, 1079

  • DV test, measurement volatilized oil, 918

  • Dykstra-Parsons coefficient, 1151

  • dynamic oscillatory viscometry, 1194

E

  • early-radial flow, 809

  • Earth resistivity, 89–90

  • echo amplitude, 194

  • echo ratio method, 329–330

  • EDCON tools, 411

  • eddy-current device, 496

  • effective date, for oil and gas reserves, 1582

  • Ei -function, 720, 722, 735, 737, 739, 743, 756

  • Ekofisk oil field (North Sea), injection- and production-well

    • locations, 1088, 1090

  • elastic-wave

    • propagation, 169

    • theory, 224

  • elastic wavefield

    • components, 33

    • imaging, 65–66

  • electrical borehole imaging, 400–406

  • Electrical Micro-Imaging tool (EMI™), 401, 407

  • electric double-layer repulsion, 1228

  • electric-line tools, advantages of, 550

  • electric log, 79

  • electrochemical component, SP logging and, 139–141

  • electrode resistivity devices

    • array electrode tools, 97–99

    • cased-hole resistivity tools, 100–104

    • laterologs, 93–97, 104

    • normal and lateral devices, 91–93

    • SFL device, 99–100

  • electrokinetic component, SP logging and, 141

  • Electromagnetic MicroImager (EMI) tool, 137

  • electromagnetic phase-shift tools, 391–392

  • electromagnetic wave resistivity (EWR) tool, 118

  • electromotive force (EMF). See membrane potential

  • El Furrial field, water and gas tracer injection in, 676

  • embar carbonate formation, 1212, 1216

  • Energy and Utilities Board, 1491

  • energy release, mechanisms of, 898

  • energy reservoir, types of, 898

  • Energy Resource Conservation Board, 1491

  • enhanced-diffusion method (EDM), 323, 329

  • enhanced oil recovery (EOR), 616

  • enriched-gas flooding, tracers for, 676

  • enriched-gas injection, tracers in, 676–677

  • enriched-hydrocarbon projects

    • Miscible Injectant Stimulation Treatment (MIST) concept, 1299–1300

    • Piercement Salt Dome field, 1300–1301

    • Prudhoe Bay field, 1297–1299

  • enthalpy, 1310, 1312

  • environmental capture sonde (ECS), 278

  • eolian system, 18

  • epoxy resins, 1240–1241

  • equation-of-state (EOS) method, 905, 983, 1114

  • equivalent drawdown time, 746

  • ERCB. See Energy Resource Conservation Board

  • ethylene diamine tetra-acetic acid (EDTA) complexes, 655

  • EUB. See Energy and Utilities Board

  • eustatic sea-level changes, 7–8

  • evaporite mineralization, 15

  • EWR-Phase 4 tool, 126

  • expansion-/compaction-drive reservoir, 900

  • expansion-drive reservoirs, 901

  • expansion of oil, rock, and water, 917

  • expectation curve (EC), 1552

  • Exxon model, 8

F

  • fair market value, 1571

  • fast-shear wave, 223

  • field application, design strategies for, 1238

  • field data interpretation, 670–675

    • analytical solutions, 674

    • levels of interpretation, 670

    • qualitative evaluation, 670–674

    • response curves, 672–675

    • sweep volume, 673–674

    • tracer-response curves with numerical simulation, 674–675

  • field-log, 114

  • field-test design, 667–668

  • filtration testing, 1199

  • finite-conductivity fractures, 785

  • fixed-gate systems, 189

  • Flagship, 522

  • flame ionization detector (FID), 361–362, 364

  • flexible-backbone polymer, 1163

  • flexural-mode propagation, 180

  • flexural waves, 215, 221

    • velocity, 171

  • floatstone, 10–11

  • flood basin deposits, 20

  • flood-front saturation, 1054–1055

  • flood plain deposits, 19

  • floodpot tests, 1049

  • flood sweep efficiency, 1151, 1157

  • flood volumetric sweep efficiency, 1247

  • Flory equation, 1168

  • flow-after-flow tests, 839, 845

  • flow barriers delineation, 652

  • flow coefficients, 842

  • flow efficiency, 751

  • flow geometries, 719

  • flowing tubing pressure, 1514

  • flow problems, origin of, 497–498

  • flow tests, 505

    • semilog methods for, 735–736

  • Flowview Plus, 522

  • flue gas, 1143

  • fluid-contacts identification

    • formation-pressure surveys, 451–452

    • log-based methods, 451

    • mud logs, 450–451

    • water-based-mud cores, 451

  • fluid-flow

    • bilinear flow, 767–768, 785

    • blocking, 1224

    • blocking agent, 1160

    • blocking treatments, 1238

    • boundary-dominated, 726

    • equations, mathematical derivation of, 1052

    • isothermal, 719

    • laminar, 721

    • linear, 730, 766–767

    • non-laminar, 761

    • pseudoradial flow, 785, 787

    • pseudosteady-state, 723–725

    • single-phase flow, 764

    • spherical flow, 769

    • steady-state, 726

    • two-state, 1110

    • unsteady-state linear, 730

  • fluid identification and characterization

    • oil-based drilling mud, 85

    • water-based drilling mud, 84–85

  • fluid(s)

    • capacitance-logging tool, 516–518, 540

    • crossflow, 1220

    • density log, 528

    • filled wellbore, 729

    • influx, 756

    • injection cycles, 652

    • injection extent determination, 568–569

    • movement/potential, 5

    • NMR properties of, 299–301

    • properties, 903–905

    • and rock interface, 171

    • sampling, 78

    • and saturated rocks, 169

    • type, mud logging and, 368–369

    • viscosities, 875, 895, 1110

  • fluid-shutoff

    • epoxy resins, 1242

    • gel, 1219

    • gel treatments, 1211

    • phenolic resins, 1241

    • plugging agent, 1243

    • resins, 1241

    • treatments, 1218, 1243

  • fluoro-surfactant foam, 1228, 1239

  • flushed-zone

    • device, 265

    • method, 150–151

  • fluvial system, 18–20

  • flux-leakage tools, 389–391, 496

  • FMV. See fair market value

  • foam(s)

    • advantages and disadvantages of, 1235

    • agents, 1226

    • ASP, 1240

    • blocking agents, 1221, 1237

    • chemicals, 1234

    • CO 2 flooding and, 1239

    • gas-blocking treatments, 1239

    • gas bubbles of, 1225, 1230

    • gels, 1221, 1238

    • general nature of, 1224

    • generation mechanisms, 1231

    • induced viscosity, 1229

    • injection mode, 1235

    • interactions of, 1234

    • lamellae films, 1229

    • for mobility control, 1235

    • mobility reduction of, 1229

    • in porous media, 1229

    • for reducing gas coning, 1237

    • steamflooding and, 1238

    • texture of, 1228

    • viscosity of, 1330

  • focused gamma-ray density-logging tool, 514–516

  • foot-by-foot log calculations, 437

  • formaldehyde, 1079, 1178

  • formation dip, 1111

  • Formation MicroImager (FMI™), 403–405, 407

  • formation permeability/porosity, mud logging and, 371

  • formation-pressure surveys, 451–452

  • formation resistivity, 89–90, 135

  • formation volume factor (FVF), 896, 898, 1113, 1490

  • formation-water salinity, 139, 141

  • four-blade propeller-type spinner element, 527

  • four focused-resistivity measurements, 102

  • four-way-closure traps, 3

  • fractional-flow, 1074

    • curves, 1110–1111

    • equation, 1108

    • theory, 1125

    • viscosity ratio effect on, 1058

    • of water, 1054, 1070

  • fracture, 15–16

    • communication, 1155

    • damage, 789

    • face damage, 789

    • orientation, 1064–1065

    • plus-matrix flow, 804

    • porosity, 23

    • problem sweep-improvement treatments, 1212

  • fractured reservoir(s), 1216

    • porosity determination and, 83

    • water and gas tracer injection in, 675

  • framestone, 10–11

  • Free Fluid Index (FFI), 298, 306, 316–317, 340

  • free-fluid (Timur-Coates or Coates) model, 321

  • free-gas saturation, 748

  • free-induction decay (FID), 294, 298

  • free-pipe acoustic signal, 190

  • free-radical

    • chemical breaker, 1222

    • chemistries, 1241

    • crosslinking agent, 1243

  • free-water level, 450, 466, 1503

    • fluid contacts, 451

  • French polymer flood, 1183

  • Frio Sandstone reservoir, 629–630

  • FTP. See flowing tubing pressure

  • fuel availability vs. crude oil gravity, 1376

  • fuel burned (FB), 1385

  • fuel geometry, 1370

  • fuels heating values, estimation of, 1374

  • Fullbore Formation MicroImager (FMI) tool, 137–138

  • fullbore-spinner log, 528

  • Fullerton Clearfork reservoir, 1066

  • furan oligomers, 1242

  • furan resin polymerization, 1242

  • furfuryl alcohol, 1242

  • FWL. See free-water level

G

  • Galerkin finite elements, 1416

  • gamma-gamma scattering density log/tools, 250, 263–264

  • gamma-ray

    • detector, 509, 515, 518

    • log cutoff, 441

    • log model, 475–476

    • tool, 118, 253, 278, 549

  • gas and oil, gravity segregation, 1511

  • gas-bearing zone, 228

  • gas-blocking agents, 1235, 1237

  • gas-blocking foam, 1234

  • gas blowout, after abandonment, 541–542

  • gas-cap drives, 920–922

    • characteristics, 921

    • dimensionless gas-cap volume, 929

    • effects on oil and gas recovery, west Texas black-oil

    • reservoir and, 923, 925

    • material-balance analysis, 928–931

    • minimization algorithms speed solution, 630

    • OOIP and OGIP, solution procedure to estimate, 929–930

    • performance, nonsegregation-drive gas caps, 922–925

    • ratio of free-gas-phase and free-oil-phase volumes, 928–931

    • reservoir, conditions at economic limit, 925

    • segregation-drive gas caps, 925–928

    • segregation mechanisms, 921

    • solution method, 931

    • total expansivity ( E t ), 929

    • Walsh’s method, 930

    • water, oil, and gas in a nonsegregating-gas-cap reservoir, 922

  • gas caps, 901

    • characteristics, 921

    • cycling project, 1298, 1614 ( see also enriched-hydrocarbon projects)

    • expansion-drive reservoir, 901

    • gas, 1513

    • injection, 1119

  • gas channeling and override reduction, 1235

  • gas chromatography (GC), 357–358, 361

    • analyses, 1132

    • catalytic combustion detector (CCD), 362

    • flame ionization detector (FID), 362

    • infrared absorption (IR) spectrometer, 364–365

    • mass spectrometer (MS) detector, 363–364

    • thermal conductivity detector (TCD), 362

  • gas-compressibility/effective-compressibility ratio, 1549

  • gas condensates, 896

  • gas coning, 1239

  • gas cycling, 902

  • gas deviation factor, 1509

  • gas-diffusivity equation, 846

  • gas-drive gravity drainage process, 1135

  • gas-drive reservoirs, 902

  • gaseous equivalent of stock-tank condensate, 1521

  • gas-expansion and rock/fluid-compression term, 1549

  • gas-expansion-drive reservoirs, 901

  • gas-filled porosity, 205

  • gas-filled reservoir, 1103

  • gas-flow equations, 740, 840

  • gas formation volume factor, 985

  • gas injection, 899

    • operations, types of, 1118–1119

    • tracers for, 676

  • gas kick, 535–537

  • gas law, 983

  • gas/oil and water profiling production problems

    • gradient-type density, continuous flowmeter surveys, 610

    • temperature and fluid capacitance surveys, 610

  • gas/oil capillary pressure, 1105, 1143

  • gas/oil compositional effects, 1113

  • gas/oil contact (GOC), 411–412, 450, 902, 1121, 1237

  • gas/oil displacement

    • efficiency, factors affecting, 1110

    • process, 1105, 1115, 1121

  • gas/oil gravity drainage, 1104

    • process, 1117

  • gas/oil linear displacement efficiency, 1107–1110

  • gas/oil problem, 1407

  • gas/oil ratio (GOR), 323, 873, 910, 912, 918, 1114, 1218, 1269, 1301

  • gas/oil relative permeability, 1107

  • gas-processing plants, 896, 1114–1115

  • gas reinjection, for improving oil recovery, 927–928

  • gas-reservoir performance and production

    • forecasting methods, 1028–1030

    • production rate-vs.-time curve for gas reservoir, decline

    • graph, 1030

    • recycling of gas aids recovery, 1031

    • reservoir deliverability, 1027–1029

    • retrograde-condensate reservoirs, 1030–1032

    • system performance, 1026–1027

    • water influx, 1030

  • gas reservoirs, 437, 1512–1514

    • determining reservoir-fluid properties, 985–988

    • forecasting, 1025–1032

    • natural gas properties, 981–994

    • natural-gas reservoirs, phase behavior of, 982–983

    • performance, 1558

    • petrophysical properties, 994–995

    • volumes and recovery, 1014–1025

    • well performance, 981, 995–1014

  • gas sampling. See gas trap

  • gas saturation ( S g ), 912

    • distributions, 1109

    • testing, SWCT tests for, 644–646

    • value, 1108

    • on waterflood oil recovery, 1050

  • gas-shutoff coning treatments, 1152, 1155, 1215

  • gas-shutoff gel squeeze treatments, 1215

  • gas trap, 359–361

  • gas/water contact (GWC), 439, 450, 466, 1487

  • gas wells, deliverability testing, 839–872

  • gas-zone porosity-correction technique, 202

  • Gates and Ramey method, oil recovery history, 1385–1386

  • GC-MS system, 363

  • GEC. See gaseous equivalent of stock-tank condensate

  • Geiger-Müeller tube, 257

  • Geiger tubes, as gamma-ray detector, 515, 518

  • gelation rate

    • acceleration, 1196

    • retardation agent, 1197

  • gel(s)

    • bottle testing, 1200

    • breakers, 1222–1223

    • chemical-liner, 1210, 1216

    • conformance treatments, 1218

    • degradation process, 1222

    • dehydration, 1202

    • fluid injection, 1219

    • forming chemical system, 1188

    • onset time, 1199

    • placement in fractures, 1202

    • shear rehealing, 1204

    • strength, 1198

    • syneresis, 1196

    • technology selection, 1207

    • treated injection well, 1212

    • treated reservoir, 1222

  • geochemical logs, 278–279

  • Geological High-Resolution Magnetic Tool (GHMT™), 414–415

  • geomagnetic polarity time scale (GPTS), 413, 415–416

  • geomechanics simulation

    • coupled model types, 1447–1449

    • coupling types, 1444–1445

    • modeling of stress-dependent flow properties, 1446–1447

    • modeling reservoir, 1446

  • geometric skin, 751–756

  • geophone, 30–31, 35

  • geopressured oil/gas, 1548

  • geopressured reservoirs, 1550, 1558

  • geosteering, 379

  • Geovision Resistivity (GVR) tool, 102, 104, 138

  • Gold’s correlation, condensate molecular weight estimation, 988

  • Gomaa model, project performance estimate for, 1329–1332

  • graben and horst block trap, 3

  • gradiomanometers, 516

  • grainstone, 11–14

  • gravel-packed wells, 1186

  • gravel-pack logs, 278

  • gravel-pack skin, 754

  • gravel placement, 568

  • gravitational energy, 898

  • gravitational forces, 875, 899

  • gravity drainage, 1120

    • gas caps, 901

    • immiscible gas/oil displacements, 1117

    • model, 1131

    • type projects, 1132

  • gravity-driven weight droppers, 26

  • gravity number, 927

  • gravity segregation, 899

  • gridding techniques, 1409

  • grid-orientation effects, 1409

  • grid properties, upscaling

    • absolute upscaling approach, 1432–1433

    • concept of, 1423

    • global, 1430–1432

    • local, 1425–1429

    • regional, 1429–1430

    • relative approach, 1433, 1435

    • schemes and techniques for absolute permeability, 1423–1425

  • grids, in simulation

    • block-center geometry, 1417–1418

    • curvilinear grid systems, 1421

    • dip-normal geometry, 1417

    • hexahedral grids, 1418–1419

    • multiple-domain hexahedral grids, 1419

    • refinement, 1419–1420

    • regular Cartesian grids, 1416–1418

    • triangular or tetrahedral grids, 1421

    • truncated regular grids, 1420–1421

    • unstructured grids, 1419–1420

    • Voronoi grid, 1420–1421

  • Gringarten type curve, 742

  • GR interactions, with formations

    • Compton scattering, 254–255

    • pair production, 255–256

    • PE absorption, 255

  • GR logs, 256, 261, 427, 433

    • API units on, 509

  • Groningen effect, 94–95, 97

  • gross bed thickness determination, 79

  • gross-count-rate gamma ray tool, 261

  • ground-force phase-locking technology, 27

  • GR spectroscopy tools, 81

  • guided waves, 168, 171, 173

  • gyroscope surveys, 381

H

  • Halliburton Gamma-Ray Backscatter Gas-Holdup Tool, 521

  • Halliburton tool (MRI-LWD), 310

  • Hall plots, 1204

  • Havlena and Odeh method, 1558–1559

  • hazardous waste injection, certification, 563–566

  • H/C atomic ratio, 1375, 1377–1380, 1383

  • health, safety, and environmental (HSE) considerations, 375

  • heat

    • balance, 1376, 1383

    • capacity, 1309–1310

    • conduction, complementary error function, 1312

    • losses, 1383

    • zone growth rate, 1313

  • heavy-oil, 1391–1393, 1544–1546

    • production, 1236

    • recovery operations, 1152

    • reservoirs, 896, 1236

    • tar sands, and tar mats, 335

  • heavy-oil-tar (HOT) layer, 475

  • He-3 detectors, 268–269

  • Heft Kel field (Iran), 1138–1139

  • height-above-the-OWC ( H owc ) basis, 429

  • hemiradial flow, 807, 811, 826

  • hem-packer, 523

  • Henry Hub gas prices, 1583

  • heptanes-plus content, 897

  • Hewlett-Packard (HP) design, for quartz pressure transducer, 690–691

  • high-angle wells, logging tools for fluid identification in, 521–523

  • high-conductivity fracture, 775

  • High-Definition Induction Log (HDIL) array, 114, 122–123

  • high-definition lateral log (HDLL) tool, 98

  • highest known water, 1498

  • high-frequency cycle (HFC), 8

  • highly resistive formations, SP and, 142–143

  • high-oil-saturation

    • flow, 1233

    • geological strata, 1221

    • matrix reservoir rock, 1188

  • high-permeability

    • anomaly, 1208

    • channels, 1157

    • geological strata, 1219

    • reservoirs, 843

  • high-pressure mercury injection (HPMI), 481–482

  • high-pressure N 2 miscible injection, 677

  • high-rate wells, 829

  • high-relief oil reservoirs, 1560

  • High-Resolution Array Induction (HRAI) tool, 116

  • High-Resolution Azimuthal Laterolog Sonde (HALS), 97–98, 102–103

  • High-Resolution Induction Tool (HRI), 111–112

  • high-resolution laterolog array (HRLA) tool, 97–99, 132

  • highstand system’s tract (HST), 8–9

  • high-temperature oxidation (HTO), chemical reactions associated with ISC, 1370

  • Hilbert transform, 37–38

  • Hill-Shirley-Klein method, 460

  • history matching water influx, 944

  • HKW. See highest known water

  • homogeneous reservoirs, 742, 1234

    • gravity effects of, 1069–1071

  • horizontal borehole, 829

  • horizontal exploration well, 825

  • horizontal wellbores, 1215

  • horizontal wells, 1064

    • analysis of, 805, 839, 1143

    • fractures intersecting, 1215

  • Horner analysis, 825

  • Horner equation, 763

  • Horner graph, 780

  • Horner plot, 763, 813

  • Horner time ratio (HTR), 738, 761

  • Houpeurt analysis technique, 846, 848

  • Houpeurt equations, 841–842, 844

  • Houpeurt flow coefficients, 867

  • HWTZ. See hydrocarbon/water transition zone

  • hydraulic seal, 191

  • hydrocarbon fluids, 899

    • spacer, 1244

    • suspensions/dispersions, 1181

  • hydrocarbon (fluid) typing, 322–324

    • dual- T E acquisition method, 327–329

    • dual- T W acquisition method, 324–327

    • echo ratio method, 329–330

    • multifluid methods, 330–331

  • hydrocarbon pore feet ( F HCP ), 434, 440

    • vs. permeability, 441

  • hydrocarbon pore volumes (HCPV), 900, 1262

  • hydrocarbon(s)

    • expansion, 917

    • formation, 2

    • gas, 1103

    • indicators, 196

    • liquids, 1559

    • miscible flooding, 1234, 1236

    • miscible IOR in-situ evaluation, SWCT tests for, 642–643

    • reservoir maps, 1494–1501

    • reservoirs, 208, 899

    • resources and primary drive mechanisms, 1602–1604

    • traps, 1–3

    • volumes and technological uncertainty, 1585

    • wash preflush, 1245

  • hydrocarbon/water contact ( H hwc ), 465

  • hydrocarbon/water transition zone, 1506

  • hydrodynamic retention, 1176

  • hydrogen index, 225

  • hydrogen-index linearmixing law, 249

  • hydrolyzed polyacrylamide (HPAM) polymer, 1162, 1173

  • hydrophones, 30, 35

  • hydrostatic gradient, 208

  • hypersaline reflux model, 15–16

I

  • ideal-gas law, 991

  • ILD-ILM-SFL logs, 107

  • illite, 17

  • imaging reservoir targets, 45–52

  • imbibition process, 1043–1044

  • immiscible displacement

    • microscopic efficiency of, 1040

    • in two dimensions, 1057–1058

  • immiscible gas displacement, 1103, 1105

    • calculation methods for, 1122–1123

    • efficiencies of oil recovery by, 1120

  • immiscible gasflood monitoring, 1132–1133

  • immiscible gas injection, 1115, 1139

    • performance calculation, 1124

    • projects, use of horizontal wells in, 1143

  • immiscible gas/oil

    • displacement, 1118, 1124

    • gravity drainage process, applications of, 1137–1138

  • immiscible water-alternating-gas (IWAG), 1093

  • impermeable lithologies, 2

  • implicit pressure explicit saturations (IMPES), 1400, 1402–1403, 1406, 1411, 1438, 1440

  • improved oil recovery (IOR)

    • operations, 615–616

    • process, 639–643

  • impulsive sources, 26

  • inaccessible pore volume (IPV), 1174

  • incremental oil production, 1212

  • Indonesia model, 462–463

  • induction logging ( see also resistivity logging)

    • array-induction tools, 113–117

    • dual-induction tools, 107–108

    • field-log examples, 114

    • induction response, 106

    • multicoil arrays, 106–107

    • phasor induction, 108–112

    • principles, 104–106

  • infill and observation wells, 1081

  • infinite-acting drainage, 735

  • infinite-acting radial flow, 743, 747, 790, 805

  • infinite-acting reservoir, 731,733, 757–758, 762, 770–772

  • inflow performance relationship (IPR), 840

  • infrared absorption (IR) spectrometer, 364–365

  • initial free-gas cap volume, 910

  • injection fluids, 899

    • relative velocities, 652

  • injection packer seal demonstration, 571

  • injection profile, 572–580

  • injection-water. See water-injection

  • injection wells, 1119, 1180

    • density, 1120

    • design, 1389

    • fracturing, 1181

    • spacing, 1120

  • inner zone mobility, 785

  • inorganic gels, 1186, 1191

  • in-place and recoverable hydrocarbons, resource classification system, 1480

  • in situ anisotropy analysis, 220

  • in situ combustion (ISC), 1367

    • combining material- and heat-balance calculations, 1374–1384

    • design considerations, 1384–1385

    • field experience, 1391–1393

    • laboratory studies, 1370–1374

    • operating practices, 1386–1391

    • predicting the performance, 1384–1385

    • process description, 1367–1370

    • production response prediction to, 1385

    • screening guidelines for, 1393–1394

  • in situ polymerization, 1191, 1204

  • instantaneous phase and instantaneous frequency calculations, 39–41

  • intercommunicating fracture system, 1134

  • interconnected vugular porosity, 1154

  • interdistributary shales, 1115

  • interdune braided-stream deposits, 19

  • interfacial-tension (IFT), 427, 429, 465, 1040, 1105, 1281

  • intermediate-hydrocarbon components, 896

  • intermediate-wet reservoir rocks, 1041. See also reservoir rocks

  • intermediate wettability, water/oil capillary pressure and, 1047.

    • See also wettability

  • Internal Revenue Service, 1574

  • interporosity flow coefficient, 797, 799–800

  • interwell interference, 1558

  • interwell permeabilities, 1118

  • intramolecular crosslinking, 1163

  • invaded-zone method, 151–152

  • invasion parameters, inversion for, 136–137

  • inversion-processing methods, 224, 228

  • IRS. See Internal Revenue Service

  • ISC, equipment for oil production

    • air-compression systems, 1386–1387

    • ignition, 1387–1388

    • safe air injection, 1389–1391

    • well design and completions, 1388–1389

  • isochronal tests, 839, 851

  • isopach maps, 1556

  • isothermal flow of fluids, 719

  • isotropic permeability, 826

  • isotropic reservoirs, 834

  • iterative methods, 1531

J

  • jet washing, 1245

  • J- function, 460

  • Joffre Viking miscible CO 2 flood, 1239

  • Jurassic-age limestone-dolomite section, 1617

K

  • kaolinite, 17

  • Kaufman-Vail principles, 100

  • Kirkuk oil field (Iraq), 1094–1095

    • areal map of reservoir sands, 1093

    • ultimate-recovery factors for, 1093–1094

  • Kozeny expression, to estimate the flow rate, 969

  • Kuparuk River oil field (Alaska North Slope), 1075, 1092–1094, 1142

    • conformance plot for, 1083–1084

    • waterflood-analysis calculations for, 1086

  • K-U-Th logging, 263

  • K -values, water-related, 1450

L

  • LaCoste-Romberg borehole gravimeter, 411

  • laminated sand/shale model, 155–156, 462

  • Langmuir isotherm, 666

  • Larmor frequency, 293, 307

  • late-linear flow, 819

  • latent heat injection rate, on strategy economics, 1319

  • latent heat of evaporation, 1310

  • late-pseudoradial flow, 818

  • lateral and normal devices, resistivity measurement and, 91–93

  • laterolog and induction logging tools, 130–132

  • laterolog device (LLd), 90

    • azimuthal dual laterologs, 95–97

    • dual laterolog resistivity measurements, 93–95

    • environmental effects on, 104

  • late-time region (LTR), 776

  • layered waterflood, surveillance-overview logic for, 1086

  • layer resistivities, 130

  • layer thickness, determination of, 78–80. See also petrophysics

  • leakoff current, 100

  • least-squares multivariate regression, 930

  • least-squares regression analysis, 848, 854, 863

  • Leduc miscible pilot, residual-oil saturation in, 677–678

  • light oil-recovery operations, 1149

  • light oils, 896, 1393

  • linear equation solver ( see also reservoir simulation)

    • combinative or CPR method, 1415

    • IMPES models in, 1415

    • Orthomin and GMRES method, 1412

    • parallel iterative solution, 1415

    • preconditioning technique, 1412–1415

  • linear flow, 730, 766–767

    • method, 791–792

    • pattern, 807

  • linear mixing law, 272, 280

  • linear no-flow boundary, 772–774

  • linear solver, Orthomin method and, 1407

  • linear waterflood, macroscopic displacement efficiency of, 1052–1054

  • liquid hydrocarbon, 1104

  • liquid-junction potential, 140–141

  • Li-6 scintillator, 268

  • listric faulted structural trap, 3

  • lithology determination, 430

    • clay-mineral properties, 431–432

    • direct, 80

    • evaluation of shale volume, 432–433

    • indirect, 80–81

    • reservoir zonation/layering, 433–434

  • lithology reservoirs, 203

  • LKG. See lowest known limit of gas

  • LKH. See lowest known hydrocarbons

  • LKO. See lowest known limit of gas and oil

  • LLd electrode array, 94

  • localized matrix reservoir rock, 1154

  • logarithmic approximation, 735, 746

  • log-data

    • conditioning, 427

    • quality, evaluation of, 424–425

  • log-formation process, 113

  • logging documentation, 175

  • logging tools

    • downhole NMR spectrometer, 311

    • LWD tools, 310–311

    • NML tool, 305–306

    • pulse NMR, 306–308

    • wireline-tool designs, 308–309

  • logging while drilling (LWD), 78

    • acoustic services, 167

    • devices, 289, 292

    • gamma ray tools, 262–264

    • logs, 423

    • measurements, 258

    • resistivity images, 138–139

  • log-inject-log measurements, for residual oil saturation, 277

  • log-inject-log tests, 1614

  • log interpretation, nuclear logging and, 270

    • advanced processing, 274–275

    • fluid effects, 273

    • macroparameters, 275

    • Monte Carlo modeling, 275

  • log presentation, 311

  • longitudinal (spin-lattice) relaxation T1 , 293–295, 298–299

  • Louisiana volatile oil

    • compositional analysis of, 909

    • material-balance calculations for, 920

    • PVT parameters for, 908

    • reservoir, pressure and producing GOR as function of

    • OOIP recovered for, 917

    • reservoir, producing history of, 916

    • selected reservoir and fluid properties for, 915

  • Love waves, 34

  • low-energy gamma ray flux, 265

  • Lower San Andres (LSA), 1295

  • lowest known hydrocarbons, 1555

  • lowest known limit of gas and oil, 1487

  • low-permeability gas reservoirs, 1556

  • low-permeability shale, 825

  • low-permeability (tight) sandstones, 335

  • lowstand system’s track (LST), 9

  • low-temperature oxidation (LTO), ISC and, 1370

  • low-temperature separators (LTS), 1514

  • LWD induction tools ( see also induction logging)

    • on drillpipe, 117–119

    • multiarray propagation tools, 124–130

    • propagation measurement principles, 119–124

  • LWD-NMR services, 310

  • LWD tools, 310–311, 358

    • nuclear logging and, 268–270

M

  • macroparameter methods, 275

  • magnetic resonance imaging (MRI), 298, 309, 1232

    • devices, 306

  • magnetic resonance imaging tool (MRIL), 308–309, 339

  • magnetic sector mass spectrometer, 365

  • magnetic survey, 380–381

  • MagTrak, LWD device, 311

  • Mandl-Volek (M-V) models, 1324–1325

  • Manning survey, 1182

  • marine air guns, 27–31

  • C marine seismic sensors, 31–32

  • marine seismic vessel with towed-cable technology, 27–28

  • Mark-Houwink equation, 1167–1168

  • Marx and Langenheim equations, 1313

  • Marx-Langenheim model, 1324–1325

  • mass conservation equations, for gridding, 1416

  • massive dissolution, 15–16

  • mass spectrometer (MS) detector, 363–364

  • mass-to-charge ratio, 363

  • mass-transfer effect, 1144

  • material- and heat-balance calculations

    • heat losses, 1383

    • initial heat balances and temperatures, 1375–1378

    • injected air and water, calculating effects of, 1381–1383

    • no combustion data available, 1374–1375

    • volume and temperature of steam plateau, 1379–1381

    • water of combustion, correction for, 1378–1379

  • material-balance, 905–910

    • analysis, 918

    • calculations, 903

    • equation, 906, 910

    • mass conservation, in reservoir, 903–910

    • method, 1519, 1558

    • object relationships, 1088

    • shell, RDBMS and, 1087

    • volatile-oil reservoir analysis, 918–920

  • matrix-block/fracture network carbonate reservoirs, 1118

  • matrix-blocks/fracture-system interaction, 1111

  • matrix-identification (MID) plot, 283

  • matrix rock, 1217

    • conformance, 1155, 1192

    • gelant, gel flow and placement in, 1201

    • oil reservoirs, 1153, 1155, 1192, 1195, 1211

    • strata, 1220

    • (unfractured) reservoirs, 1153

    • vertical conformance, 1221

  • Matthews-Brons-Hazebroek (MBH) method, 776, 778

  • maximum flooding surface (MFS), 9

  • maximum-length equation, 501

  • Maxwell’s equations, 98

  • MCFL log, 134–135, 148

  • McKelvey box, 1480–1481

  • mean- T2 model. See Schlumberger-Doll-Research (SDR) model

  • measurement while drilling (MWD)

    • devices, 78, 268

    • tools, 263, 358

  • mechanical and chemical compaction, 15

  • mechanical integrity, 277–278

  • mechanical pressure transducer, 689, 691

  • mechanical shear degradation, 1177, 1180

  • mechanical zone isolation, 1201, 1215, 1221

  • medium-temperature reactions, chemical reactions associated with ISC, 1370

  • membrane potential, 139–140

  • mercury-injection capillary pressure (MICP)

    • curves, 319

    • data, 460, 464–465

    • methods, 304, 430

  • metal-crosslinked synthetic-organic-polymer gels, 1222

  • metal crosslinking, 1190

  • metal debris, 343

  • microcylindrically focused log (MCFL) measurements, 97

  • microelectrical imaging tool, 137

  • microgas bubbles, 1225, 1229

  • microgel sweep-improvement treatments, 1215

  • Micro Laterolog (MLL), 99

  • microorganism fermentation processes, 1160

  • microresistivity imaging devices, 400

    • measurement principle of, 401, 403

  • microresistivity logs

    • MCFL device, 134–135

    • microlog, 133

  • MSFL device, 134 tools, 137

  • microresistivity-vs.-porosity crossplots, 148–150

  • microscopic fossils, mud logging and, 372

  • microseismograms, 186

  • MicroSFL (MSFL) device, 134, 148

  • Middle East carbonate matrix/fracture-system reservoirs, 1118

  • middle-time region (MTR), 744, 776

  • mineral-identification-plot (MID) techniques, 204

  • minimum degree fill (MDF), 1415

  • minimum miscibility enrichment (MME), 1265

  • minimum miscibility pressure (MMP), 1265

  • miscible flood designing

    • CO 2 -flood and enriched-gas-drive MMP, correlation for, 1268–1269

    • laboratory coreflooding studies, 1264

    • miscibility determination, 1264–1266

    • miscible project, economic viability of, 1268–1271

    • MMP and MME guidelines, 1266–1267

    • MMPs with solvents, guidelines, 1267

    • performance, factors affecting, 1263

    • in reservoir study, 1267

    • slimtube displacements, determining MMP or MME, 1265

  • miscible flood prediction, compositional reservoir simulator and

    • equations of state, phase behavior with, 1277–1280

    • injection-fluid/crude-oil systems, phase behavior of, 1271–1277

  • miscible fluids, 1124

  • miscible gas flooding, 1235–1236

  • Miscible Injectant Stimulation Treatment (MIST) concept, 1299–1300

  • miscible injection, 1261

  • miscible processes

    • compositionally enhanced solvent flood behavior, prediction of, 1281–1292

    • compositional numerical simulation, 1271–1280

    • concepts of, 1261–1264

    • miscible flood designing, 1264–1271

    • projects using CO 2 , hydrocarbon, and N 2 solvents, 1292–1302

  • miscible water-alternating-gas (MWAG), 1093

  • MIST injector 9–31C, 1300

  • mixed-wet and water-wet cores, waterflood behavior for, 1049

  • mobility-control

    • agent, 1236

    • flood, 1154

    • foams, 1224, 1234

  • mobility ratio, 1050–1052, 1062, 1068, 1107, 1151

    • on oil production for five-spot pattern, 1081–1082

  • model formulations ( see also reservoir simulation)

    • choice of formulation, 1403–1405

    • IMPES vs. implicit GOR and water cut, 1404

    • IMPES vs. implicit oil rate and cumulative oil production, 1404–1405

    • implicit and IMPES formulations, 1402–1403

    • relaxed volume, advances in, 1405–1406

    • sequential and adaptive implicit formulation, 1402–1403

    • truncation and numerical dispersion error analysis, 1403

    • variable choice and adaptive flash calculations, model

    • efficiency for, 1405–1406

  • modern and historical evaluation methods, comparison, 1591–1594

  • modified isochronal tests, 839–840

  • molecular weight (MW), 1167, 1194

  • monomer gels, 1186, 1191

  • monopole-array tool, 171, 179

  • monopole (axisymmetric) transducers, 172

  • monopole excitation, 173

  • monopole transmitters, 170, 178

  • Monte Carlo model, 249, 252, 275

  • Monte Carlo Nuclear Parameters (MCNP), 275

  • Monte Carlo simulation evaluation method, 1575–1576

  • montmorillonite, 17

  • moving-coil geophone, 30

  • MRI analysis (MRIAN), 336

  • MRIL-NMR data, 336

  • mudcake resistivity and thickness ( h mc ), 133

  • mud chloride content, 373

  • mud contamination, sources, 359–360

  • mud filtrate, 748

  • mud-log gas and oil shows, 483–484

  • mud logging, 357, 450

    • component analysis, 361–365

    • cuttings analysis, 365–368

    • data acquisition, 358–360

    • data quality, maintaining, 368

    • drilling engineering and operations, 372–375

    • formation evaluation, 368–372

    • health, safety, and environmental considerations, 375

    • total gas analysis, 360–361

  • mud pit level, 373

  • mudstone, 11–14

  • multiarray propagation tools

    • ARC5 tool, 124–126

    • geosteering with, 127–130

  • multicoil arrays, 106–107

  • multi-Darcy flow channels, 1240

  • multi-Darcy matrix rock, 1241–1242

  • multidimensional simulation models, 1127

  • multifingered caliper tool, 390

  • multifluid (forward modeling) methods, 330–331

  • multilateral wells, 1064

  • multilayer reservoir, 1215

  • multiphase flow, 1231

    • test analysis, 763

  • multiple-log interpretation

    • crossplot, visualization and, 280–283

    • multitrack log display, visualization and, 279–280

  • multiple propagation-resistivity (MPR) tool, 127, 129

  • multistage compression, conjectural economics of, 1559

  • multistage fracture placement, 568

  • multitrack log display, 279–280

  • Muskat method, 776, 783, 895

  • MWD gamma ray tools, 263

N

  • nanoTesla (nT), 413

  • natural gamma ray spectroscopy, 278

  • natural gases properties

    • depletion studies, 991

    • EOSs, 993–994

    • gas density and formation volume factor, 984–985

    • phase diagrams, retrograde-condensate gas and wet gas, 982–983

    • pressure/volume/temperature (PVT) behavior, 983–984

    • retrograde behavior, 988–993

    • retrograde-liquid volume vs. pressure, 992

    • two-phase z factor, 991

    • viscosity, 985–986

    • visual-cell depletion, retrograde gas, 990–991

  • natural-gas foams, 1234

  • natural gas from shale, 1539–1542

  • natural-gas liquids (NGLs), 896, 1115, 1300

  • naturally occurring radioactive materials (NORMs), 1040

  • natural petroleum gases, 981

  • natural reservoir boundaries, 843

  • near-critical fluids, 896

  • near-wellbore

    • conformance, 1222

    • polymer-gel treatments, 1153

    • pressure gradients, 1121

  • near-well grid refinement, effect of, 1408

  • near-well imaging, 213

  • Nested Factorization (NF), 1407, 1415

  • net/gross (N/G) ratio, 434, 436

  • net oil sand isopach of channel sand, 1498–1500

  • net-pay cutoff, 436–438

    • applications, 440–441

  • net-pay determination, 434

    • calculations, conceptual bases for, 435–437

    • gas reservoirs and, 437

    • geologic considerations in, 438–440

    • isopach maps, 1554

    • netpay-cutoff, 438, 440–441

    • oil reservoirs and, 437–438

  • neutron-density crossplot, 157, 282

  • neutron logs, 448–449, 540

    • C/O logs, 278

    • gamma ray spectroscopy tools, 278

    • geochemical logs, 278–279

    • log-inject-log measurements, for residual oil saturation, 277

    • log interpretation, 270–275

    • LWD, 268–270

    • mechanical integrity, 277–278

    • neutron-scattering porosity tools, 267–268

    • PNL devices, 276–277

  • neutron-porosity, 202, 273, 280

    • log, 253, 267, 269, 274

  • neutron-scattering porosity tools, 267–268

  • Newtonian fluid/viscosity, 1167

  • Newton’s law of motion, 170

  • New York Mercantile Exchange, 1583

  • nitrogen projects, Jay field, 1301–1302

  • nitrogen rejection plant, 1120

  • N 2 miscible injection, 677

  • NML tool, 305–306, 314

  • NMR applications, in petrophysics and formation evaluation, 289

    • anisotropy and geomechanics, 335

    • carbonates and complex lithologies, 335

    • combined, 336–338

    • heavy oil, tar sands, and tar mats, 335

    • historical development, 290–292

    • hydrocarbon (fluid) typing, 322–331

    • logging tools, 305–311

    • log presentation, 311

    • low-permeability (tight) sandstones, 335

    • NMR acoustic/density combination, 337–338

    • NMR-log job planning, 340–343

    • NMR-log quality control, 338–340

    • NMR petrophysics, 298–305

    • NMR physics, 292–298

    • NMR-resistivity combination, 336–337

    • permeability estimation, 319–322

    • porosity determination with, 311–319

    • producibility, 335–336

    • pseudocapillary-pressure curves, 335

    • residual oil ( S xo ) calculation, 331–333

    • viscosity evaluation, 333–335

  • NMR effective porosity (MPHI), 315, 322, 327

  • NMR logging

    • measurements, 289

    • and reservoir, 86

    • tools, 294, 298, 304, 327

  • NMR-log job planning, 340

    • borehole rugosity, 342

    • lithology, 341–342

    • logging speed and running average, 343

    • metal debris, 343

    • mud type, 342

    • wettability, 342

  • NMR-log quality control, 338

    • post-logging quality check, 340

    • prejob calibration and quality checks, 339–340

  • NMR petrophysics

    • data fit—inversion, 303–304

    • laboratory studies, 298

    • NMR properties of fluids, 299–301

    • properties, 298–299

    • T2 decay, 301–303

    • T2 distribution, 304–305

  • NODAL analysis, 712–713

  • no-flow boundary, 732

  • noise log, 536

    • in relief well, 541–542

  • noise-logging tool, 511–514

  • noisy SP logs, 144–145

  • non-Cartesian grids, 1407, 1411

  • noncondensable gas, 1236

  • non-Darcy flow, 754, 761, 796

    • coefficient, 842

    • effects, 722

  • nonhydrocarbon components, 1143

  • nonhydrocarbon gases, 1104

  • nonideal SWCT tests simulation

    • fluid movement, 634

    • local equilibrium time length, 635

    • nonreversing flow, 635–636

  • nonionic surfactant, 1227

  • nonionic triple-stranded polysaccharide biopolymer, 1186

  • non-laminar flow, 761. See also non-Darcy flow

  • nonlinear partial-differential equation, 757

  • nonlinear shale-volume models, 260

  • non-Newtonian viscosity, 1166, 1168

  • nonpolar hydrocarbon molecules, 1226

  • nonradioactive water tracers, 655

  • nonsegregation-drive gas caps, 901

  • nonvolumetric reservoirs, 900

  • nonzero skin, 751

  • normal geothermal gradient, 374

  • normal (pseudo-Rayleigh) waves, 168

  • Norsk Hydro tensor method, conservation of dissipation, 1428

  • North Burbank Unit Flood, 1182

  • North-Sea reservoirs, 1554

  • N th-root stack processing, 218

  • nuclear-log crossplot, 282–283

  • nuclear logging, 243

    • gamma ray transport and, 254–256

    • multiple-log interpretation, 279–283

    • neutron logs, 267–279

    • nuclear radiation transport, 245–249

    • passive gamma ray tools, 256–267

    • physics of, 244–245

    • single-log interpretation, 249–253

  • nuclear magnetic log (NML), 290, 307

  • nuclear magnetic resonance (NMR), 245, 289

    • acoustic/density combination, 337–338

    • devices, 292–293

    • echo-decay, 318–319

    • logs, 79, 86

    • physics, 292–298

    • porosity model, 308

    • resistivity combination, 336–337

    • spectroscopy methods, porosity determination and, 82

  • Nuclear Magnetic Resonance Tool (NMRT™), 309, 414

  • nuclear radial geometric functions, 251

  • nuclear radiation transport, 245–249

  • Numar’s mandrel device (MRIL), 291

  • numerical reservoir simulation model, 1121

  • numerical reservoir simulators, 1144

  • NYMEX. See New York Mercantile Exchange

O

  • OBM-core-plug Dean-Stark water-volume determinations,

    • S w calculations with, 467

  • OBM-core S w data, 429, 460–461, 469–470, 476

  • OBM-filtrate invasion, 330

  • OBM routine-core-analysis data, 426

  • ocean-bottom cable (OBC), 31–32, 34

  • Ocean Drilling Program (ODP), 414, 416

  • Odeh-Babu and Kuchuk equations, 814

  • offending injectors, 651

  • oil and gas prices, economic/political uncertainty, 1586

  • oil and gas profiling production

    • gravel pack density and fluid capacitance survey, 605

    • multiarm fluid-conductivity and capacitance survey, 606

    • temperature and back scatter gamma-ray density

    • surveys, 605

  • oil and gas property valuations, 1573–1574

  • oil and gas property ownership

    • net profits interest and production payment, 1597–1598

    • royalty interest, 1597

    • working interest, 1596

  • oil and gas reserves

    • adjustment factors for risk and uncertainty in, 1586–1589

    • asset description, 1595–1598

    • capital cost, 1584–1585

    • classification system of, 1582

    • economic evaluation, 1575

    • interest positions and prices, 1582–1583

    • reports and discounted cash flow schedules, 1578–1580

    • risk and uncertainties in, 1585–1586

    • study definition, 1572

    • taxes and operating cost, 1583–1584

  • oil and gas reservoir management

    • benefits of, 1611–1620

    • definition of

    • description of, 1601–1602

    • horizontal and multilateral wells for, 1602

    • leadership team, 1599–1600

    • models of, 1604–1605

    • performance management, 1607

    • performance survey, 1605

    • process work flow of, 1600

    • team skills of, 1600–1601

    • wellbore utilization plan for, 1603

  • oil and gas reservoirs and depletion plans, 1602–1605

  • oil and gas zone, volumetric parameters, 1508–1509

  • oil and wetting effects, 1233

  • oil-based mud (OBM), 112–114, 199, 311, 342, 424, 426

  • Oil-Base MicroImager (OBMI™), 406

  • oil classes, 895

  • oil-coated injection/film, 1244–1245

  • oilfield foams, 1223

  • oilfield furan resin treatments, 1242

  • oilfield gels, 1192, 1221

  • oil fields-Offshore Peninsular Malaysia, 478–480

    • Block A-18, gas/condensate field, Malaysia-Thailand joint

    • development area, 480–481

  • oilfield surface separators, 1115

  • oilfield tubulars, 1217

  • oil fraction in, in total fluids and cumulative oil production for typical well, 1526

  • oil, gas, and water saturation, 83–84

  • oil/gas-expansion-drive reservoirs, 901

  • oil gravity drainage, 1139

  • oil in place (OIP), 1385

  • oil-producing reservoir, 1151

  • oil production

    • mobility ratio effect on, 1081–1082

    • under WAG recovery, profiling, 539–541

    • water injection effect on, 1038

  • oil recovery

    • displacement fluid, 1151

    • drive fluid, 1151–1152, 1247

    • flood conformance, 1151

    • fluid, 1149

    • improvement, 902

    • mechanisms, 1139

    • production, 1241

    • sweep efficiency, 1153

  • oil-recovery flooding, 1224

    • operations, 1149, 1166

    • system, 1149

  • oil reservoirs, 437–438, 895, 899, 1037

    • geological aspects of, 1056

    • gravity effects on, 1065

    • structure, 1056, 1497

  • oil/water

    • fractional flow, 1155

    • profile commingled, 587–589

    • viscosity ratio, 1409

  • oil/water contacts, 426, 439, 475, 1121, 1487

  • oil-wet reservoirs, 1139, 1233

    • pressure-depth plots and capillary pressure profiles, 706, 709

  • oil-wet rocks, 1041, 1046

  • oil-zone perforations, 1104

  • oolitic limestone, 1132

  • openhole caliper logs, well-logging and, 387–388

  • openhole-imaging devices, 194

  • openhole logging, 276

  • openhole short-radius horizontal wellbores, 1210

  • openhole wireline pressure testing, 695, 697

  • OPMs. See option-pricing models

  • optical borehole imaging, 397

  • option-pricing models, 1576

  • organic crosslinking agents, 1206

  • organic-fluid-based gel, 1186

  • organic-rich shales, 211

  • original gas in place (OGIP), 421, 903, 910, 915

  • original oil in place (OOIP), 421, 615–616, 897, 903, 910, 912, 916–917, 1038, 1063, 1120, 1179, 1261, 1385

  • orthogonal Cartesian grids, 1407

  • orthosilicate monomer, 1192

  • Output Least Squares (OSL), 1430

  • overdisplacement fluids, 1211

  • OWC. See oil/water contacts

  • oxygen free-radical degradation, 1176

P

  • packer flowmeter, 524–525

  • packer probe tests, 712

  • packstone, 11–12, 14

  • parallel resistivity relationship, 155–156

  • Paroscientific design, for quartz pressure transducer, 691

  • partial-penetration skin, 821

  • passive gamma ray tools, 256–261

    • density-porosity interpretation, 264–265

    • environmental effects, 261–262

    • gamma-gamma scattering density tools, 263–264

    • LWD, 262–264

    • PE, 265–266

    • precision, 261

    • spectral gamma ray logs, 262

  • pattern gas injection, 1119–1120

  • P c -derived S w values, 470–471

  • P c /S w data, 452–453, 460

    • laboratory-measured, S w calculation and, 464–466

    • resistivity-log-derived S w and, 467

    • routine OBM core S w data with, 467–468

  • PE factor (PEF), 255

  • Peng-Robinson, EOS petroleum engineering applications, 993–994

  • perfluorocarbon (PFC) gas tracers, 658, 669

  • perfluorodimethylcyclobutane (PDMCB), 658

  • ,2-perfluorodimethylcyclohexane (1,2-PDMCH), 658

  • ,3-perfluorodimethylcyclohexane (1,3-PDMCH), 658

  • perfluoromethylcyclopentane (PMCP), 658

  • perforating depth control (PDC) log, 502

  • performance-data analysis, 1558

  • performance indicators extrapolation, 1556

  • permanent pressure measurement installations, 697–698

  • permeability

    • determination, 471–474

    • estimation, 319–322

    • matrix reservoir rock, 1235

    • reducing agents, 1188

    • reducing polymers, 1184

    • reduction, 1175

    • reduction ratio, 750

  • perpendicular bisector (PEBI) method, reservoir simulation, 1420

  • Perrine-Martin approximations, 764

  • Perrine-Martin modification, 762

  • petroleum fluids, 896–897

  • petroleum production, types of energy available for, 898

  • petroleum reserves, classification

    • proved, 1482–1483

    • unproved, 1483–1484

  • petroleum reserves estimation

    • analogy methods, 1490–1493

    • volumetric methods, 1493–1494

  • petroleum reserves status categories, 1484

  • petroleum reservoirs, 899

    • commercially productive, 900

    • fluid flow, 719

    • fluids, major classes, 982

    • pressure drop, 725

  • petroleum sulfonates, 1236

  • petrophysical applications, 421

    • case studies, 474–483

    • data sources and databases, 422–430

    • fluid-contacts identification, 450–452

    • lithology determination, 430–434

    • net-pay determination, 434–441

    • permeability determination, 471–474

    • porosity determination, 441–450

    • water-saturation determination, 452–471

  • petrophysical data sources and databases

    • acquisition of, 429–430

    • conditioning, for reservoir parameter calculations, 427–429

    • inventory of existing data, 422–423

    • quality evaluation of existing data, 423–427

  • petrophysical properties, gas reservoir

    • Forchheimer equation, 994–995

    • Klinkenberg effect, 994

    • Klinkenberg permeability correction, 995

    • non-Darcy flow, 994–995

  • petrophysics

  • absolute permeability determination, 85–86

  • definitions, 77–78

  • fluid identification and characterization, 84–85

  • and formation evaluation, NMR applications in, 289

  • fractional flow, 86–87

    • layer thickness, determining, 78–80

    • lithology and rock type, determining, 80–81

    • oil, gas, and water saturation, 83–84

    • porosity determination, 81–83

    • tools selection, 78

    • use of, 87

  • phase-alternate pairs (PAP), 297

  • phase redistribution, 796

  • phase-shift, resistivity and, 121

  • Phasor induction tool, 108–112, 115, 131

  • phenolic resins, 1241

  • photoelectric (PE) absorption, 255, 265–266

  • piercement trap, 3

  • piezoelectric crystals/transducers, 172, 511

  • pilot waterflooding, 1078

  • pipe dope, 368

  • Pixler method, 369–370

  • plastic-coated well tubulars, 1222

  • Poisson distribution, 245–246

  • Poisson’s ratio, 169, 212

  • polarization, 292–293

  • polyacrylamide (PAM), 1162

  • polyethyleneimine-crosslinked gel, 1190

  • polyhedra liquid films, 1228

  • polymer-gels, 1186, 1222

    • adsorption, 1165

    • bottle-test gel strength code, 1200

    • conformance, 1160, 1218

    • degelation, 1206

    • technologies, 1190

    • treatments, 1208, 1219, 1247

    • treatment technologies, 1155

    • water-shutoff, 1157

    • water-shutoff treatment, 1210, 1215

  • polymer(s)

    • adsorption, 1163

    • concentration grading, 1179

    • degradation, 1176

    • degrading free radicals, 1178

    • dissolution, 1180

    • enhanced foams, 1237–1239, 1248

    • filtration, 1181

    • flood biopolymers, effects of salt and hardness on, 1172

    • flooding, 1168–1169, 1176–1177

    • macromolecules, 1221

    • microgels, 1154

    • precipitation, 1176

    • retention, 1175

    • self-induced gels, 1191

    • transport, 1174

    • waterflooding, 1150, 1153, 1160, 1166, 1171

  • polymer-solution

    • injection wells, 1181

    • slug, 1179

    • viscosity, 1167, 1173

  • polysaccharide biopolymers, 1177

  • pore-fluid

    • composition and saturation, 169

    • mobility, 225

    • permeability, 224

  • pore pressure, mud logging and, 372

  • pore-to-pore interconnections, 1117

  • pore volume (PV), 1179

    • contraction, 901, 915

    • porous rocks, 1550

  • porosity determination, 441

    • calculations and uncertainty, consistency of, 449–450

    • core/log calculation approaches, 444–449

    • core porosity data and, 442

    • direct, 81–82

    • indirect, 82–83

    • total and effective porosity, 442–444

  • porosity determination, with NMR, 311

    • BVI determination, 316

    • CBVI model, 316–318

    • measurement, tool version influence on, 314–315

    • porosity-logging modes, 315–316

    • SBVI model, 318–319

  • porosity-logging modes, 315–316

  • porosity transforms, 202

  • Portland cement, 1157, 1198, 1217, 1243

  • possible petroleum reserves, 1484

  • possum belly, 358–359

  • power-law, 1170

  • prejob calibration and quality checks, logging and, 339–340

  • pressure and temperature

    • calibration points, 687

    • nonlinearity in, 688

    • optical fiber measurement of, 692

    • subsea acquisition of, 698–699

  • pressure-buildup (PBU)

    • permeability values, 473

    • test, semilog methods for, 736–739

  • pressure/depth

    • method, 1502

    • plots, 701–704, 708–709

  • pressure flow convolution and deconvolution, 708–709

  • pressure gauges

    • calibration and standard evaluation tests for, 687–688

    • nonlinearity in pressures and temperatures, 688

    • pressure calibration function, 687–688

    • pressure-temperature calibration points, 687

    • scheduled time routine for pressure gauge calibration

    • test, 688

    • temperature calibration function, 688

  • pressure-gradient

    • density log, 516

    • instrument ( see gradiomanometers)

    • method for hydrocarbon/water contact calculation, 1504–1505

  • pressure maintenance, 899

    • by gas reinjection, 902

  • pressure probes in duplex/triplex, 704

  • pressure-squared and pressure approximations, 757–759

  • pressure thermal sensitivity, 688

  • pressure transducer technology, 689–691

    • bonded wire transducer, 690

    • capacitance pressure transducer, 689

    • mechanical pressure transducer, 689

    • quartz pressure transducer, 690–691

    • sapphire transducer, 690

    • strain pressure transducer, 690

    • thin-film transducer, 690

  • pressure-transient analysis (PTA), 473

  • pressure transient testing, 693, 707–715

    • analysis, 722–723, 839

    • to characterize reservoir fluids, 713–714

    • downhole shut-in benefits, 709

    • multilayer tests, 709–711

    • NODAL analysis, 712–713

  • pressure flow convolution and deconvolution, 708–709

  • temperature profiles in production and injection wells, 714–715

  • wireline pressure transient tests, 711–712

  • pressure/volume/temperature (PVT), 1449

    • parameters, 903

    • properties, 1114

  • primary gas caps, 901

  • primary oil recovery, 895, 902–903

  • probable petroleum reserves, 1483–1484

  • producibility indexes, 202

  • producing mechanisms

    • for oil, 899–903

    • petroleum reservoirs for, 899–902

    • recovery ranges, 902–903

  • production/decline trend analysis (P/DTA), 1522–1523

  • production-log flow survey, 829

  • production logging

    • application tables ( see production-logging application tables)

    • categories of, 495–496

    • depth control, 501–502

    • flow problems, origin of, 497–498

    • misconceptions about, 496–497

    • pricing and record keeping, 502–503

    • safety and environmental tips, 498–499

    • sinker bar weight, 499–501

    • suites of, 535–542

    • tools, operating principles and performance of, 503–535

  • production-logging application tables, 549

    • classification tables, 550

    • tool-selection tables ( see tool selection tables, production logging and)

  • production-logging suite

    • commingled-gas production, profiling, 537–539

    • gas blowout after abandonment, 541–542

    • gas kick while drilling, 535–537

    • oil production under WAG recovery, profiling, 539–541

  • production-logging tools, operating principles and performance

    • continuous and fullbore spinner flowmeters, 526–535

    • diverting-spinner flowmeter, 523–526

    • fluid-capacitance-logging tool, 516–518

    • fluid identification in high-angle wells, 521–523

    • focused gamma-ray density-logging tool, 514–516

    • noise-logging tool, 511–514

    • radioactive tracer-logging tool, 508–511

    • temperature-logging tool, 503–508

    • unfocused gamma ray (gravel-pack) density logger, 518–521

  • production wells, 1078, 1083

    • and designs, 1390

  • productivity index, 724, 751

    • horizontal well, Economides et al. method and, 834–839

  • progradational cycles, 8–9

  • propagation measurement principles, 119–124

  • proved petroleum reserves, 1483

  • Prudhoe Bay field, 433, 474–477

  • Prudhoe Bay Sadlerochit reservoir, 1127

  • pseudocapillary-pressure curves, 335

  • pseudopressure, 756–757

    • equations, 842

    • transformation, 757–758

  • pseudoradial flow, 785, 792–793, 822

  • pseudo-shear measurement, 182

  • pseudosteady-state

    • equations, 719, 841, 852

    • flow, 722, 778, 798, 831, 841–843

    • matrix flow, 801

    • matrix flow model, 798

    • solution, 841

  • pseudotime transformation, 759

  • pulsed caliper tools, 387

  • pulsed neutron capture (PNC), 1301

  • pulsed-neutron-lifetime (PNL) devices, 276–277

  • pulse-echo tools, 307

  • pulse-NMR

    • logging, 299, 306–308

    • spectrometers, 298

  • pure solution-gas-drive reservoirs, 910

  • PVT treatment, of fluids in reservoir simulation

    • black-oil PVT models, 1454

    • component partitioning, 1452

    • density, 1451

    • equation-of-state models, 1454–1455

    • fluid initialization, 1456

    • gas/oil interfacial tension (IFT), 1454

    • gas viscosities, 1453

    • phases and phase type, 1450

    • surface phase behavior, 1455

    • thermal model PVT requirements, 1455

    • three-phase PVT behavior, 1455

    • two-phase flash, 1450–1451

  • pyrolisis, 1368, 1370, 1372

Q

  • QGM™ process, 369

  • quartz pressure transducer, 690–691

  • Quartztronics design, for quartz pressure transducer, 691

R

  • RAB tool, 102

  • Rachford-Rice (RR) procedure, 1450

  • radial aquifer

    • finite and infinite, 939

    • model, 936

    • OOIP, water-influx history and model parameters, 949

    • reservoir partially surrounded by, 946

  • radial-cement-evaluation devices, 193

  • radial diffusivity equation, 719

  • radial-flow, 826

    • conformance, 1220

    • diffusivity equation, 740, 840

    • injection, 1177

    • matrix-reservoir rock, 1158

    • matrix-rock reservoir, 1219

    • reservoirs, 771

  • radioactive gas tracers, 656–658

  • radioactive tracer-logging tool, 508–511

  • radioactive water tracers, 652–655

    • partition coefficients of, 653–654

    • used in oil reservoirs, 653

  • radio frequency (RF), 291, 309

  • radius of investigation, 722, 739

  • Ramey-Cobb method, 776, 781–782

  • Raoult’s law, 662

  • rate-dependent skin, 721

  • rate of penetration (ROP), 373–374

  • rate of return, 1580

  • Rawlins-Schellhardt analysis, 845, 853, 862, 864, 869

  • Rawlins-Schellhardt deliverability plot, 869

  • Rawlins-Schellhardt equation, 843, 871

  • Rayleigh waves, 34

  • Raymer-Hunt-Gardner equation, 199, 202

  • real options analysis, 1576–1577

  • Recommended Evaluation Practices, 1573

  • recovery efficiencies (REs), 1487

  • rectangular matrix-block geometry, 804

  • reduced-major-axis (RMA) line-fit, 445, 447

  • reef deposit, 1117

  • reflection coefficients, 35–37

  • regression analysis, 827

  • relative permeability, 875, 1046–1048, 1050, 1076, 1110

  • relative permeability modification (RPM), 1157

  • repeat formation tester, 1508

  • REPs. See Recommended Evaluation Practices

  • reserves and cash flow projection, 1578

  • reserves classifications

    • from areal perspective, 1518

    • basic guidelines, 1516–1517

  • reserves estimation, 1482, 1489

  • reservoir heterogeneities

    • forms of, 1055

    • by permeability variation, 1068–1072

  • Reservoir Management Leadership Team, 1606–1607

  • reservoir management team (RMT), 77. See also petrophysics

  • reservoir parameter calculations, data conditioning for

    • density and neutron logs, 428

    • gamma ray logs, 427

    • log data, 427

    • OBM Sw data, 429

    • permeability data, 429

    • porosity data, 428–429

    • resistivity logs, 428

    • routine-core-analysis and SCAL data, 428

    • sonic logs, 428

  • reservoir pressure, 683–685

    • distribution, in reservoir during fluid flow, 684–685

    • pseudosteady-state flow, 684–685

    • steady-state flow, 684

  • reservoir rocks, 1039

    • biodegradation, and tracer flow in, 665–666

    • pore geometry for, 1042

    • pore system in, 1045

    • shear failure and water-weakening of, 1089

  • reservoir(s)

    • absolute permeability determination, 85

    • architecture, 1, 7–9

    • base, 5–7

    • boundary, 723

    • carbonate reservoir, 9–16

    • drive mechanism, 1521

    • economic base of, 7

    • efficiency, 1313

    • energy, types of, 898–899

    • evaluation, by material balance, 616–617

    • external geometry of, 1–7

    • fluid flow analysis software, 846

    • fluids, 199, 206, 713–714, 839, 896, 985–988, 1175

    • geology, 1–23

    • heating, 1311–1314

    • internal geometry, 1, 7–9

    • lithology, 341–342

    • matrix rock, 1242

    • mineralogies, 1216

    • models, 21–23, 719, 1532–1533

    • oil, viscosity, 1509

    • permeability impairment, 1074

    • petrophysical properties, 1, 7–8

    • producing mechanisms, classification of, 900

    • quality, 1554

    • rock lithologies, 1185

    • sandstone layers, 1117

    • saturation tool, 522

    • sequence stratigraphy, 7–9

    • siliciclastic reservoirs, 16–23

    • simulations, 875

    • stratigraphy, 1

    • temperature, 685–686

    • traps, 1–4

    • zonation layering, 433–434

  • reservoir simulation

    • applications, 1461–1465

    • gridding in, 1415–1422

    • high-performance computing and, 1456–1461

    • linear solver, 1407, 1411–1415

    • models for application and development, 1399–1411

    • pressure/volume/temperature (PVT) treatment, 1449–1456

    • simulation of geomechanics, 1444–1449

    • streamline simulation, 1437–1444

    • upscaling of grid properties, 1422–1436

  • reservoir simulation applications

    • faults in reservoir flow model, inclusion of, 1462

    • geological model, 1461–1462

    • history matching and production forecasting, 1464–1465

    • integrated reservoir and surface facilities models, 1463–1464

    • larger model use, 1464

    • pseudofunctions for multiphase flow and gridding techniques, 1463

    • simulation of multiple reservoirs, 1464

    • simulation of nonconventional and intelligent wells, 1463

    • upscaling geological model, 1462

  • reservoir simulation high-performance computation

    • application of parallel computing, 1460

    • characteristics of, 1457

    • explosion of data and chasm of scale, 1456–1457

    • parallel computers and message-passing interface, 1459–1460

    • parallel linear-equation solver, 1458–1459

    • parallel reservoir simulator, 1457–1458

  • reservoir simulation models

    • advances in model formulations, 1405–1406

    • Cartesian grids and reservoir definition, 1407–1409

    • generalized model, 1401–1402

    • linear solver, 1407

    • model formulations, 1402–1405

    • Newton iteration method, 1043, 1402

    • Newton-Raphson method, 1401–1402

    • perpendicular bisector (PEBI) method, 1420

    • SPE Comparative Solution Project problems, 1400

    • stable timestep and switching criteria, 1406–1407

  • residual oil saturation ( S or ), 615, 1048–1050, 1081

    • in Leduc miscible pilot, 677–678

  • residual oil ( S xo ) calculation, 331–333

  • residue gas stream, 1132

  • resin(s), 1240

    • conformance fluid-shutoff treatments, 1247

    • fluid-shutoff treatments, 1244–1245

    • polymerization reaction, 1244

    • squeeze treatments, 1244

  • resistance temperature detectors (RTDs), 692

  • resistivity imaging

    • AIT images, 38

    • ARI images, 137–138

    • microresistivity images, 137

  • resistivity index ( I R ), 427, 456–457

  • resistivity logging, 428, 453

    • Earth resistivity, 89–90

    • electrode resistivity devices, 91–104

    • environment, 90–91

    • formation-resistivity determination, 135

    • induction logging, 104–117

    • laterolog and induction logging tools, 130–132

    • LWD induction tools, 117–130

    • microresistivity logs, 132–135

    • S w values, 470

    • traditional R t methods, 135–139

  • resistivity-ratio methods, 150

  • resistivity-vs.-porosity crossplots, 146–148

  • resonant-frequency analysis/measurements, 194–195

  • retrogradational cycles, 8–9

  • retrograde-condensate reservoirs, 1030–1032

  • Reverse Cuthill-McKee (RCMK), 1415

  • reverse vertical seismic profiling (RVSP), 65–66

  • Reynolds number, 759

  • RFT. See repeat formation tester

  • RF-tipping pulse, correction for, 339–340

  • RMLT. See Reservoir Management Leadership Team

  • rock-cutting samples, mud-logging services and, 372

  • rock expansivity, 907–908

  • rock-fabric facies, 22–23

  • rock-fabric reservoir model, 23

  • rock/fluid expansion/compression terms, 1550

  • rock-pore distribution, 203

  • ROR. See rate of return

  • routine-core-analysis, 425–426, 477

    • permeability data, 429

    • porosity measurements, 428

  • routine OBM core S w data

    • with P c /S w data, 467–468

    • with resistivity-log data, 468

  • R t -based S w calculations, strengths and weaknesses of, 464

  • R t methods, traditional, 135

    • invasion parameters, inversion for, 136–137

    • LWD resistivity images, 138–139

    • resistivity imaging, 137–138

  • R t / S w models, 461

  • rudstone, 10–11

  • running horizontal well tests, 828. See also horizontal wells

  • R wa comparison

    • flushed-zone method, 150–151

    • invaded-zone method, 151–152

    • resistivity-ratio methods, 150

  • R xo / R t quicklook method, 152–154

S

  • SABs. See U.S. SEC Staff Accounting Bulletins

  • Sadlerochit reservoir, 433, 474–476

  • safety and environmental tips, production logging and, 498–499

  • SAGA. See surfactant-alternating-gas-ameliorated

  • saline water, 1038

  • San Andres carbonate reservoirs, 1062, 1067

  • sands and shales, layer thickness determination and, 78–79

  • sandstone

    • deposits, 1115

    • formations, 1217, 1239

    • photomicrograph and water/oil relative permeability for, 1042–1044

    • waterflood with low permeability, 1615–1616

  • sandstone reservoirs, 1062, 1075, 1092, 1117, 1175

    • and gas and water injection, 1611–1612

    • polymer injection project, 1617

    • solution-gas drive and water- and gas-injection project, 1616

    • strong waterdrive and crestal gas injection, 1612–1613

  • sapphire transducers, 690

  • saturated oil reservoirs, 928

  • SCAL database, 441, 452, 454, 458

  • Schlumberger design, for quartz pressure transducer, 691

  • Schlumberger-Doll-Research (SDR) model, 321–322

  • Schlumberger Flowview, 522–523

  • Schlumberger NML tool, 290–291

  • Schlumberger’s tool, 310–311

    • ultrasonic transducers and, 394

  • scintillation crystal detector, 521

  • scintillator crystal, 262

  • screen factor (SF) device, 1171

  • seals, 2, 4–5

    • and flow barriers, 6

    • lithologies, 5–6

  • SEC. See U.S. Securities and Exchange Commission

  • secondary gas caps, 901

  • sedimentology, 18

  • Segmented Bond Tool (SBT™), 394

  • segregating gas cap, 902, 921, 925

  • seismic attributes, 37, 41–42

  • seismic data

    • acquisition sources

    • attribute applications, 37, 41–42

    • body waves and surface waves, 33–35

    • calibrating seismic image time to depth, 62–65

    • complex seismic trace, 37–39

    • crosswell seismic profiling, 65–68

    • 3D seismic survey design, 52–59

    • imaging reservoir targets, 45–52

    • impedance, 35–36

    • impulsive sources, 26

    • instantaneous phase and frequency calculations, 39–41

    • interpretation, 42–43

    • marine air guns, 27–31

    • reflection coefficients, 35–37

    • sensors, 30–32

    • shear wave sources, 27

    • structural interpretation, 43–45

    • uses of, 25

    • vertical seismic profiling, 59–62

    • vibrators, 26–27

    • wave propagation, 32–33

  • D-seismic data, 487

  • seismic image time to depth calibration, 62–65

  • seismic impedance, 35–36

  • seismic interpretation, 42–43

  • D seismic methods, 1504

  • seismic-reflection exploration methods, 176

  • seismic reflectivity parameters, 36

  • seismic sensors, 30–32

  • seismic surface-wave noise mode, particle motions produced by, 34

  • D-seismic surveys, 452

  • D-seismic technique, 1081–1082

  • seismic wave propagation, 32–33

  • seismic-while-drilling techniques, 208

  • selected field projects, expected incremental recovery in, 1302. See also miscible processes

  • selective dissolution, 15

  • semblance and N th-root stacking, 215

  • semilog analysis techniques, 798, 804

  • semilog coordinates, 811

  • sensitivity analysis evaluation method, 1575

  • SEOR project screening criteria, 1320

  • sequence stratigraphy

    • model, 22

    • of reservoir, 7–9

  • sequential-fluid injection mode, 1212

  • SFL device, 99–100, 104, 108, 123, 153

  • SGIP. See solution gas initially in place

  • shale-baseline shifts, 143–144

  • shale porosity, effects of pressure on, 210

  • shale volume, evaluation of, 432–433

  • shaly formations, 154

    • dispersed clay, 156–158

    • laminated sand/shale-simplified model, 155–156

    • total shale relationship, 158

  • shaly-sand models, 462

  • shear-non-rehealing gel, 1198

  • shear-thinning fluids, 1210, 1235, 1237

  • shear-thinning viscosity, 1169

  • shear-wave, 170

    • amplitudes, 191, 210

    • birefringence, 220

    • parameters, 220

    • sources, 27

    • velocity, 173

    • vibrator, 27

  • shelf systems, 20

  • shifted-spectrum method (SSM), 328

  • shore-zone systems, 20

  • shoulder-bed effect, 97, 109

  • shut-in and behind-pipe petroleum reserves, 1484

  • shut-in injection well, 513

  • shut-in logs, 540

  • shut-in time, 1211

  • shut-in tubing pressure, 1525

  • shut-in wellhead pressures, 1560

  • signal-to-noise ratio (S/N), 26–27, 180–181, 291, 296, 303, 307, 309, 327, 343

  • siliciclastic reservoir, 16–23

    • classification of siliciclastic rocks in, 16–17

    • clay habit in, 17–18

    • depositional environments, 18–20

    • diagenetic environments, 20–21

    • porosity and permeability of, 16

    • reservoir models, 21–23

    • sandstone depositional systems, 18–19

    • texture, porosity, and permeability, 22

  • siliciclastic rocks, petrophysical properties of, 23

  • siliciclastic stratigraphy, 8

  • simulation theory, 631–632, 634. See also SWCT test simulation

  • Simultaneous Acoustic and Resistivity Imager (STAR™), 137, 406

  • single-column gas chromatograph, 364

  • single-fluid

    • aqueous gel, 1223

    • injection mode, 1211

  • single-log interpretation, 249–253. See also nuclear logging

  • single-phase fluid, 728

  • single-phase sensitivity, 532

  • single-point tests, 839

  • single pressure-connected reservoir, 1554

  • single-stage acid placement, 567

  • single-stage fracture placement, 567–568

  • single-well chemical tracer (SWCT) test. See SWCT test

  • single-well data, 1524

  • single-well (one-spot) IOR pilot, 639–642

  • sinker bar weight, 499–501

  • SITP. See shut-in tubing pressure

  • skin equation, 818

  • skin factor

    • altered zone and, 720

    • deviated well, 753

    • dimensionless, 742

    • two-region reservoir model, 750

  • slickline operations, in bottomhole conveyance of gauges, 694

  • slope and basin systems, 20

  • slug tracking, 509

  • small-scale drillstem testing, 712

  • smectites, 17, 431–433, 442–444

  • Snell’s law, 168, 173

  • SNUPAR program, 275

  • Soave-Redlich-Kwong, EOS petroleum engineering applications, 993

  • Society of Petroleum Engineers/World Petroleum

    • Congress, 1480

    • classifications of reserves, 1481

    • definition of reserves, 1481–1485

    • deterministic calculation procedures of, 1489

    • significance of, 1487

  • Society of Petroleum Evaluation Engineers, 1571

  • solid-earth seismology, 220

  • solid fillers, 1240, 1243

  • solution-gas-drive reservoir, 902, 914–915

  • solution-gas drives, 910–920

    • field examples, 913–915

    • key characteristics of each stage production, 910–911

    • material-balance analysis, 915–918

    • performance, 911–913

    • production, stages of, 910–911

  • solution gas initially in place, 1511

  • solvent flood behavior prediction

    • fine-grid reference models, 1285–1287

    • full-field behavior, 1287

    • permeability relations and pseudoproperties, 1287–1288

    • segment models, 1288–1290

    • solvent trapping and solvent relative permeability

    • hysteresis, 1282–1285

    • streamtube and streamline models, 1290–1292

  • sonic logs, 428

  • sonic vibration, 172

  • SP anomalies

    • highly resistive formations, 142–143

    • invasion-related, 144

    • noisy SP logs, 144–145

    • shale-baseline shifts, 143–144

  • SP curve, shape of, 142

  • special core analysis (SCAL), 423, 426–429, 433, 441, 472, 477

  • spectral BVI (SBVI) model, 318–319

  • spectral gamma ray log, 261–262

  • spectral natural gamma ray systems, 263

  • SPEE. See Society of Petroleum Evaluation Engineers

  • SPEE FMV document, 1571

  • SPE/WPC. See 1997 Society of Petroleum Engineers/World Petroleum Congress

  • SPE/WPC and 1978 U.S. SEC definitions comparison

    • economic conditions and development status, 1487–1488

    • enhanced-recovery reserves, 1489

    • flow testing requirement and reservoir areal extent of, 1488–1489

    • reasonable certainty and known accumulations, 1487

  • spherical flow, 730, 769

  • spherically focused log (SFL), 90

  • spill point, 2–3

  • spin-echo technique, 295

  • SP log ( see also resistivity logging)

    • origin of, 139–141

    • and permeability, 141

    • static, 141–145

  • spontaneous ignition, 1387

  • spontaneous-potential (SP) log, 79, 453

  • Squirrel-sandstone, oil and water relative permeabilities for, 1048

  • stabilized C method, 866, 869

  • stacking bins, in 3D seismic survey design, 52–54

  • stacking fold, in 3D seismic survey design, 55–59

  • standard PVT parameters

    • methods to calculate, 904–905

    • of volatile and black oil determination, 904

  • standard PVT properties

    • as a function of pressure for Louisiana volatile oil, 909

    • as a function of pressure for a west Texas black oil, 905

  • Standing’s correlation, 1508

  • static bulk foam, 1231

  • static nonflowing foam, 1225

  • static pressure measurements, 699–701

    • from buildup tests, 699

    • from productivity index, 700–701

  • static SP (SSP)

    • determination of, 141–142

    • SP anomalies, 142–145

    • SP curve, shape of, 142

  • station spacings, in 3D seismic survey design, 54–55

  • statistical correlations, 1554

  • steady-shear viscometers, 1171

  • steady-state foam flow, 1232

  • steady-state radial flow equation, 720

  • steam

    • flooding, 1227, 1236

    • foams, 1236

    • plateau, 1368–1369, 1373, 1379–1383, 1394

    • saturated, properties of, 1309–1311

    • steam specific volume vs. saturation pressure, 1311

    • stimulated injection wells, 1246

    • zone shape/thickness, equation, 1315

  • steam enhanced oil recovery (SEOR), 1309

  • steamflood design, 1319–1324

    • analogy, 1321–1322

    • recovery mechanisms, 1322–1324

    • screening criteria for steamflood candidates, 1319–1321

  • steamflood injection wells, 1246

  • steam injection rates, calculations, gravity drainage models

    • Neuman method, 1326–1328

    • Vogel method, 1328–1329

  • steam zone growth

    • bypass, 1315–1317

    • combination, 1317–1319

    • viscous displacement, 1314–1315

  • steeply dipping sandstone reservoir with gravity stable miscible project, 1615

  • Stoneley wave(s), 168, 171, 173

    • amplitude, 196, 224

    • attenuation, 210

    • data, 180

    • reflection, 228

    • velocity, 224

    • velocity dispersion, 171

  • storativity ratio, 797, 800

  • strain pressure transducer, 690

  • strandplain sand, 20

  • stratal-bounded analysis window, 51–52

  • stratal-surface concept, 51–52

  • stratified systems

    • with communicating layers and assumed vertical

    • equilibrium, 1071–1072

    • with noncommunicating layers, 1067

  • stratigraphic traps, 2–3

  • streamline-based flow simulation

    • applicability of, 1437

    • applications of streamlines, 1442–1443

    • computational efficiency of, 1441–1442

    • governing IMPES equations, 1438

    • novel data produced by, 1442

    • solution to transport equation, 1438–1441

    • timestepping, 1439

  • streamtube waterflood calculations, 1059–1060, 1063–1064

  • stress-induced anisotropy, 220

  • stripping compositional effects, 1114

  • structural interpretation, 43–45

  • structural traps, 2–3

  • styrene-butadiene block copolymer resin, 1246

  • subsea acquisition, of pressure and temperature, 698–699

  • successive substitution (SS), 1451

  • sulfate-reducing bacteria, 1079

  • sum-of-fluids porosity measurements, 442

  • supercritical gas, 1225

  • superposition, principle of, 731

  • surface acquisition

    • of downhole data, 698

    • system, 172

  • surface and volume ratio (S/V), 300–303, 319

  • surface-data-acquisition system, 179

  • surface gas injection, 910

  • surface-injection equipment, 1177

  • surface mapping, 3

  • surface readout vs. downhole recording, 693

  • surface relaxation, 299–302

  • surface seismic maps, 176

  • surface seismic methods, 168

  • surface shut-in vs. downhole shut-in, 693

  • surface water injection, 910

  • surfactant adsorption/retention, 1233

  • surfactant-alternating-gas-ameliorated, 1234

  • surfactant-alternating-gas foam, 1236

  • surfactant molecule, 1226–1227

  • surfactant slug, 1236

  • Susceptibility Measurement Tool (SUMT™), 414–415

  • Swanson River Field (Alaska), 1139

  • SWCT Sor tests, 618–643

    • for connate water, 644

    • data interpretation, 629–632

    • design, 625–628

    • ester distribution, between oil and water in pore in, 623

    • features, 620–621

    • field procedures, 628–629

    • gas-saturation testing, 644–646

    • injection of ester tracer and push volume, 619

    • nonideal simulation, 634–635

    • parameters using simulator, 632–634

    • procedure, 624–625

    • production period, 620–621

    • quantitative working, 621–624

    • shut-in (reaction) period, 619–620

    • single-well IOR pilot project, 639–642

    • tracer-concentration profiles, 620, 622

    • working of, 618–620

  • SWCT Sor test design, 625–628

    • formation-water salinity, 628

    • oil cut of test well, 626

    • production rate, 627–628

    • reservoir lithology, 626–627

    • reservoir temperature, 626

    • test-interval size and average porosity, 628

  • SWCT S or test field measurements, 643–646

    • connate water saturation testing, 643–644

    • gas saturation testing, 644–646

  • SWCT test ( see also SWCT S or tests)

    • candidate, 618

    • features, 620–621

    • field setup for production step, 629

    • history, 615

    • injection step field setup, 629

    • for in-situ evaluation of hydrocarbon-miscible IOR, 642–643

    • pressure difference effects on, 635

    • S or measurement, 615–617

    • S wc measurement, 617–618

    • SWCT S or tests, 618–643

  • SWCT test simulation

    • in carbonate formation, 638–639

    • in dual-porosity media, 636–638

    • in layered formation, 635–636

    • nonideal, 634–635

    • parameters for, 632–634

  • S w data, integration of

    • adjustments to, 468–469

    • core, total, and effective systems compatibility, 469

    • P c /S w data, resistivity-log data with, 467

    • routine OBM core S w data, 467–468

  • sweep efficiency

    • methods for evaluating, 1124

    • in uniform linear systems, 1070, 1073

  • sweep-improvement treatment evaluations, 652

  • swelling compositional effects, 1113

  • swelling effect, 1114

  • S w physical-model equations, 453

  • S w techniques, applications of, 461–467

  • S w values

    • Pc -derived, 470–471

    • resistivity logs, 470

  • synthetic oil-based mud (SOBM), 311, 342

  • synthetic seismograms, 61–62, 207

  • system geometry, 797

  • system noise (ringing), 339

T

  • tank balance, performance prediction to ISC, 1385

  • taxation value, 1573

  • T2 decay, 301–303

  • T2 distribution, 304–305

  • tectonic fracture development, 825

  • tectonic processes/stresses, 220

  • televiewer-type devices, 183

  • temperature and noise-logging survey, 607

  • temperature gauges, metrology of, 688–689

  • temperature log, 535–536

  • temperature-logging tool, 503–508

  • temperature profiles

    • detecting cement tops, 714

    • in production and injection wells, 714–715

    • recommendations for, 714

    • vertical extent of fracturing and detecting lost

    • circulation, 715

  • temperature sensors, 691–692

    • mechanical transducers, 691

    • resistance temperature detectors, 692

    • thermistors, 692

  • Tensleep Sandstone oil-wet rock, 1046

  • tensor methods, cell permeability and, 1423, 1429

  • tertiary flooding oil-recovery drive fluids, 1151

  • tertiary-mode flooding, 1150

  • Texas San Andres oil reservoir, 477

  • thermal conductivity, 1313

    • gas detector, 365

  • thermal conductivity detector (TCD), 362

  • thermal cracking, 1368, 1370

  • thermal diffusivity, 1314

  • thermal enhanced oil recovery (TEOR), 1309

  • thermal stabilizers, 1177

  • thermistors, 692

  • thermosetting resins, 1244

  • thin-bed target, 49–52

  • thin-film liquid lamellae, 1248

  • thin-film transducer, 690

  • thin liquid films, 1225

  • thin oil columns, operating procedures for, 1143

  • Thomas-Stieber method, 82–83

  • three-axis magnetometer, 382

  • three-dimensional seismic survey design, 52–59

    • stacking bins, 52–54

    • stacking fold, 55–59

    • station spacings, 54–55

  • three-layer multirate test, 710–711

  • through-casing acoustic measurements, 179–180

  • Through-Casing Resistivity (TCR) tool, 102

  • thrust-fault structural trap, 3

  • tidal-dominated delta system, 20

  • tight gas reservoirs, 1542–1544

  • time-domain analysis (TDA), 323, 326

  • time-of-flight (TOF), 1438

  • time-stratigraphic unit, 8

  • Timur equation, 471

  • tool selection tables, production logging and, 550–551

    • acid, fracture-proppant and, 567–568

    • annular pressure, crossflow behind casing and, 563–566

    • casing inspection, 560–562

    • cement placement, 556–559

    • confinement demonstration, 569–571, 576, 578

    • corrosion detection, 612–614

    • crossflow detection behind pipe, 611

    • detection of holes or parting, 614

    • drillpipe manipulation and construction problems, 552

    • injection profile determination, 572–575, 577, 579–580

    • injection well, 569–575

    • with screen or slotted linear, 576–577

    • with tubing across perforations, 578–580

    • location of annular pressure source, 611

    • lost returns, 553

    • newly cased, unperforated well, 556–566

    • production wells and, 581–611

    • tracking single-phase production, 581–585, 594, 600, 607

    • tracking three-phase production, 592–593, 598–599, 605–606, 610

    • tracking two-phase production, 586–591, 595–597, 601–604, 608–609

    • underground flow, 554–555

    • well being stimulated, fractured, or gravel-packed, 567–568

    • well down for tubing or casing inspection, 612–614

    • well still being drilled, 552–555

  • tornado-chart calculations, 251

  • total and effective porosity

    • core analysis, 442–444

    • log analysis, 444

  • total-fluid-shutoff gel treatments, 1192

  • total gas analyzer (TGA), 360–361

  • total hydrocarbon analyzer (THA), 360

  • total methane equivalents (TME), 360

  • total shale relationship, 158

  • tough logging conditions (TLC) logging, 97

  • toxic heavy-metal ions, 1151

  • tracer flow, in porous reservoir rock, 659–666

    • biodegradation, 665–666

    • flow equations, 663–664

    • ion exchange, 666

    • partition coefficient, 662–663

    • residual-oil measurements, 664–665

    • retention, by partitioning between phases, 659–665

  • tracers

    • active, 651

    • analysis, sample collection for, 668–670

    • application in well-to-well test, 651–659

    • assumptions regarding, 632

    • chemical gas tracers, 658–659

    • chemical water, 655–656

    • in enriched-gas injection, 676–677

    • flow in porous reservoir rock, 659–666

    • for gas injection, 676

    • health, safety, and environment constraints, 659

    • passive, 651–653

    • program timing, 666–667

    • radioactive gas tracers, 656–658

    • radioactive water tracers, 652–655

    • types of, 651–659

  • tracer tests

    • field data interpretation, 670–675

    • field experience, 675–678

    • planning and design of, 666–670

  • tracer test planning and design, 666–670

    • field-test, 667–668

    • sample collection, 668–670

    • timing for, 666–667

  • transgression, 8–9

  • transgressive system’s track (TST), 8–9

  • transient flow equation, 841

  • transient matrix flow model, 802

  • transit-time measurements, 218

  • transmissibility value, 1416, 1418

  • transmitter-to-receiver spacing (TR), 172, 176

  • traps, 1–4. See also specific traps

  • travel-time (TT) measurements, 189

  • triangular probability distribution, 1553

  • triaxial coordinate system, 223

  • tritiated water (HTO), 653–655

  • tritium, 85, 653, 657, 659

  • true vertical depth (TVD), for geological mapping, 385

  • tube (Stoneley) waves, 168

  • turbulent flow effects, 722, 841

  • T1 -weighted mechanism. See dual- T W acquisition

  • two-coil induction array, 106

  • two-phase flow, 1110

  • two-phase gas FVF, 907

  • two-phase reservoir simulation, 1131

  • type curves, 739

    • analysis technique, 801

    • matching, 747

U

  • ultradeep perforation techniques, 1221

  • ultra low hydrolysis, 1163, 1197

  • Ultrasonic Borehole Imager (UBI™), 400–401

  • Ultrasonic Corrosion Imager (UCI™), 392

  • Ultrasonic Imager (USI™), 394

  • ultrasonic pressure pulses, 183

  • ultrasonic radial-cement-evaluation devices, 194

  • ultrasonic reflection (pulse/echo) acoustic devices, 182

  • ultrasonic tools, 392, 394

    • interpretation, 194

  • unbalanced-formation-stress components, 223

  • unconformity and buried-hill trap, 3

  • undersaturated oil reservoirs, 748, 909

  • undip sedimentary trap, 3–4

  • unfocused gamma ray (gravel-pack) density logger, 518–521

  • uniaxial compressive stress, 212

  • uniform linear systems, sweep efficiency in, 1070, 1073

  • unitization, 1574

  • Universal Transverse Mercator (UTM) geographic coordinate system, 379

  • unproved petroleum reserves

    • possible, 1484

    • probable, 1483

  • unsteady-state flow, 723

  • unsteady-state linear flow, in unbounded reservoir, 730

  • S. Acquisition Economics and federal income taxes, 1589–1591

  • S. Bureau of Mines (USBM) Amott wettability index, 1047

  • S. federal tax code, 1572

  • S. Polymer-Flood Project Production Survey, 1183

  • S. SEC Staff Accounting Bulletins, 1486

  • S. Securities and Exchange Commission, 1571

  • U.S. Securities and Exchange Commission (SEC)

    • Oil and Gas Reserves Definitions, 1485–1486

  • UV-fluorescence technique, 371

V

  • valuation, definition of, 1572

  • value allocation, 1574

  • van der Waals’ equation, 993

  • van Everdingen-Hurst (VEH) model, water drive

    • calculations, 942

    • cumulative water influx, 938

    • discretization, 937

    • geometries, radial- and linear-flow systems of, 936

    • infinite and finite, radial aquifer, 939–940

    • linear aquifer, 941–942

    • superposition theorem application, 936

  • variable density (VDL), 186, 311, 336.

  • See also microseismograms

  • VDL transmitter, 194

  • velocity approach, 571

  • velocity/porosity logging, 176

  • velocity-porosity predictive model, 203

  • velocity-shot survey, 509–511

  • velocity tomography, 65–67

  • vertical boundary, 813

  • vertical fluid communication, 1153

  • vertical gravity drainage, 1143

    • gas displacement, 1120–1122

  • vertical interference testing, packer and multiple-probe tests

    • for, 712–713

  • vertical permeability, 879, 1117

    • variation, 1067–1069

  • vertical resolution, of NMR-logging tools, 343

  • vertical seismic profiling (VSP), 25, 59–66, 207

    • based calibration of thin-bed stratigraphy, 63–64

    • depth-to-time calibration, 62–63

    • source-receiver geometry used in, 59–60

    • synthetic seismograms, 61–62

  • vertical sweep efficiency, 1124

  • vertical-to-horizontal-permeability ratio, 753

  • vibrators, 26–27

  • Vibroseis™ energy sources, 26

  • virgin reservoirs, 703–704

    • pressure gradients in well drilled in, 683–684

  • viscosity, of fluid phase, 1050–1051, 1054, 1058–1059

    • enhancing agents, 1162, 1168

    • enhancing polymers, 1247

    • evaluation, 333–335

  • voidage replacement, 1037, 1061, 1080, 1083

  • volatile- and black-oil fluid, characteristics of, 896–898

  • volatile-oil reservoirs, 897

    • material-balance analysis of, 897, 918–920

    • producing GORs, 913

  • volatile oils, 896, 1511

  • volatilized-oil/gas ratio, 896, 904, 918

  • voltage-frequency circuit, 387

  • volumes and recovery

    • determining average reservoir pressure, 1015–1017

    • gas in place, 1014–1015

    • highly compressive reservoirs, 1018–1020

    • pressure maintenance and cycling operations, 1024–1025

    • retrograde-condensate reservoirs, 1024

    • volumetric reservoirs, 1017–1018

    • waterdrive reservoirs, 1020–1024

  • volumetric heat capacity, 1313

  • volumetric reserves classification, 1515

  • volumetric sweep, 651

  • VTI anisotropy, 220

  • vugular-porosity conformance, 1155

W

  • WACC. See weighted average cost of capital

  • wackestone, 11–14

  • WAG. See water alternating gas

  • wait time ( T W ), 296

  • wall-exclusion effect, 1174

  • Walsh-Towler algorithm, characterization of volatile oil, 905

  • Warren and Root’s model, 798

  • water/air ratio, 1369

  • water alternating gas, 1107, 1215, 1262

    • flooding operation, 1239

    • injection, 1142, 1236

    • injection program, 670, 675

    • injector 939, 1300

    • process, 1617

    • ratio, 1292, 1297–1298

  • water and gas coning, 961–973

    • additional measures to control, 970

    • Chierici correlation, 965–968

    • computing critical rate and optimum perforation length, 971–972

    • critical coning rate ( q c ), 964

    • Kozeny expression, 969

    • partially penetrating wells, 968–970

    • prevent coning in bottom-water, gas-cap reservoir, 972–973

    • producing well, 961–962

    • Schols’ correlation, 964–965

    • variables affecting coning, 970

  • water and gas tracer

    • in El Furrial field, 676

    • injection in fractured reservoir, 675

  • water-based mud (WBM), 113, 333, 424, 426, 451

  • water-bearing reservoirs, 899–900

    • geological strata, 1212

    • zones, 185

  • water channeling, problem and tools, 604, 610

  • waterdrive petroleum reservoirs, 762, 900

    • alternative material-balance methods, 951–952

    • and aquifer classification, 931–932

    • aquifer performance, 945–947

    • diagnosis of, 932

    • and fluid properties, 945

    • GOR, gas saturation, oil recovery and pressure histories, 933

    • material-balance analysis, 932, 947–952

    • performance, 932–935

    • performance data, 944

    • phases of assessment, 931

    • van Everdingen-Hurst (VEH) model, 935–942

    • water-influx mechanism, 931, 933

    • water-influx effect on pressure vs. percent OOIP

    • recovered, 933

    • water-influx histories, comparison of, 949–950

    • water-influx models, 935–936, 942–944

  • water-encroachment treatments, 1246

  • water expansivity calculation, 917

  • waterflood

    • displacement, in five-spot pattern ( see waterflood pattern)

    • miscible EOR project, 1614

    • mobility ratio, 1166

    • oil recovery, 1039, 1050, 1060

    • performance, viscous and capillary forces, 1050

    • and sandstone field, 1614

  • waterflood design considerations, 1072–1074

    • injection-water-sensitivity studies, 1074–1076

    • injection wells, injectivity and allocation approaches, 1076

    • pilot waterflooding, 1078

    • produced fluids, surface facilities for, 1079–1080

    • production wells, 1078

    • water-injection surface facilities, 1079

  • waterflood field case studies, 1087

    • Ekofisk (North Sea), 1088

    • Kirkuk oil field (Iraq), 1094–1095

    • Kuparuk River oil field (Alaska North Slope), 1092–1094

    • West Texas carbonate waterfloods, 1094

    • Wilmington oil field (California), 1089–1092

  • waterflood monitoring techniques

    • data acquisition-routine-data gathering, 1080

    • infill and observation wells and 4D-seismic data, 1081

    • log(WOR) vs. cumulative-oil-production plots, and decline

    • curves, 1082–1084

    • numerical reservoir simulator, 1085

    • X -plot, 1082–1084

  • waterflood pattern, 1059–1061,1077

    • and well-spacing considerations, 1061–1063

  • waterflood technology

    • 2D-areal calculation of, 1058

    • injector/producer-pattern layout of, 1061, 1073

    • limitations of, 1040

    • production response of, 1085

    • reservoir-geology considerations in, 1055–1057

    • saturation profile during, 1040, 1052

    • in U.S., 1038

    • X-ray shadowgraphs of, 1061

  • water flow detection, underground, 555

  • water influx, 910 ( see also waterdrive petroleum reservoirs)

    • constant, 1550

    • history matching for, 944

    • material balance, estimation with, 952–953

    • predicting history for, 957, 960

    • water-influx parameters and OOIP determination, 952–956

  • water-injection

    • cooling effect of, 1077

    • in oil production, 1038

    • sensitivity studies, 1074

    • sources, 1078

    • surface facilities for, 1079

    • well fracturing, 1076

    • well bubble map, 1082–1083

  • water-intolerant epoxy resin, 1244

  • water/oil

    • mobility ratio, 1546

    • problem, 1409

    • saturation distribution, 1045–1046

  • water/oil contact (WOC) in waterdrive reservoir, 901

  • water/oil displacement process, 1040

    • gravity in, role of, 1069

    • for homogeneous linear systems, 1052

    • vertical displacement characteristics of, 1066, 1071

  • water/oil ratio (WOR), 1157, 1269

  • water production ( W p ), 910

  • water-reactive diverting agents, 1221

  • water saturation ( S w ) determination ( see also S w data,

    • integration of; S w values; S w techniques, applications of)

    • approaches for, 461–467

    • calculation techniques for, 452–453

    • clean formations, 145–146

    • data availability and data quality, 453–461

    • methods, 467–469

    • microresistivity-vs.-porosity crossplots, 148–150

    • resistivity-vs.-porosity crossplots, 146–148

    • uncertainties, 469–471

  • water-shutoff gels, 1157

    • treatment, 1211–1212

  • water-soluble polymer, 1237

  • water source location behind casing, problems

    • activated-oxygen survey, 594

    • density and gravel-pack and temperature survey, 594

    • flowing fluid-capacitance survey for oil detection, 591–592

  • water-swelling polymer, 1242

  • water-wet reservoir matrix rock, 1330

  • water-wet reservoirs, 342, 706, 708

  • water-wet rock, 1041, 1051

    • capillary pressure characteristics of, 1043, 1045

  • wave-delta system, 20

  • wave-separation processing, 224

  • Waxman-Smits relationship, 158–159

  • Waxman-Smits shaly-sand model, 481

  • Waxman-Smits-Thomas (WST) model, 454, 457–458, 463

  • WBM routine-core-analysis data, 426

  • WEC. See Well Evaluation Conference

  • weighted average cost of capital, 1589

  • Welge equation, 1108

  • Welge technique, 1106

  • well(s)

    • casing wear bend/collapse, 561–562

    • category, 549–550 ( see also production-logging application tables)

    • circulation lost returns, 553

    • damage, altered zone and skin effect, 748–750

    • drainage patterns, 1558

    • hydraulic fracture, 747, 755–756, 766, 785

    • hydraulic fracture conductivity, 721, 767

    • placement and density, 1602

    • production, economic limit, 1523–1524

    • profile production, 581–586

  • wellbore

    • geological/petrophysical information and, 372

    • hydraulics, 983

    • hydrostatic pressure, 1240

    • unloading, 728, 735

  • wellbore, geometry and integrity, 379

    • balanced tangential method and, 384

    • casing-collar locators, 388

    • casing inspection logs, 388–392

    • cement-evaluation logs, 392–397

    • gyroscope surveys, 381

    • magnetic survey, 380–381

    • minimum curvature method, 385

    • openhole caliper logs, 387–388

    • simultaneous casing inspection and cement evaluation, 397

  • wellbore storage (WBS), 727, 744, 773

    • coefficient, 742, 794

    • distortion, 759, 771

    • effects, 785, 840

  • Well Evaluation Conference, 1495

  • wellhead environments, 698–699

    • subsea acquisition of pressure and temperature, 698–699

    • surface acquisition of downhole data, 698

  • wellhead injection pressure, 1079

  • well in virgin reservoir, pressure gradients in, 683–684

  • well logging, specialized

    • borehole gravimetry, 408–412

    • borehole imaging, 397–408

    • downhole magnetics, 412–414

    • wellbore, geometry and integrity of, 379–397

  • well logs uses and interpretation

    • R wa comparison, 150–152

    • Rxo / Rt quicklook, 152–154

    • saturation determination, 145–150

  • well magnetic stratigraphy (WMS), 414–415

  • well performance

    • deliverability testing, 1008–1012

    • drainage shapes, estimation, 1007

    • effects of skin, 1014

    • gas-well deliverability relationships and, 1012–1014

    • ideal gas, steady-state radial-flow equation for, 997

    • near-wellbore phenomena, 1000

    • non-Darcy flow, 1001

    • pressure-transient testing of gas wells, 1008

    • radius of investigation, 1007–1008

    • real-gas potential, 996–998

    • skin, 1000–1001

    • steady-state radial and horizontal liquid and gas flow, basic

    • equations, 996–999

    • transient flow, 1001–1007

  • well-test analysis

    • methods of, 792, 839

    • software, 759, 770

  • well-to-well tracer tests, 624

    • tracer application in, 651–659

    • value and importance, 651

  • West Howard-Glasscock unit oil field, 477–478

  • West Texas black oil

    • compositional analysis of, 906

    • oil and gas viscosities as pressure function, 907

    • PVT parameters for, 904–905

  • West Texas carbonate waterfloods, 1094

  • West Texas Clearfork, 1062

  • West Texas intermediate sweet crude prices, 1583

  • wet-gas reservoir, 982

  • wetness method, 369, 371

  • wettability

    • mineralogy to, 1042

    • of oil/water/solid system, 1040–1042

  • wetting-phase saturation, 1231

  • Wharton’s method, 1497

  • Wheatstone Bridge circuit, 362

  • Whitney Canyon-Carter Creek Gas Field, 481–483

  • Whitson-Torp method, characterization of volatile oil, 905

  • whole-core Boyles-law porosity measurements, 442

  • Wilcox formation black oil, reservoir and aquifer properties, 955

  • Wilmington oil field (California), 1089–1092

    • injection and production wells, 1091

    • ultimate-recovery factors for, 1092

  • wireless transmission, 694

  • wireline formation testers, 86, 1503

  • wireline logging correlations, 78, 86

  • wireline pressure testing, 695, 697

  • wireline pressure transient tests, 711–713

    • packer and multiple-probe tests for vertical interference

    • testing, 712

    • packer probe tests, 712

  • wireline-tool designs, 308–309

  • WLFT. See wireline formation testers

  • world incremental oil production, by gas injection, 1303

  • worldwide polymer flood review, 1183

  • WST exponents, cation-exchange capacity and, 457–459

  • Wyllie equation, 196, 199

  • Wyllie time-average formula, 199

  • Wyoming polymer floods, 1182

  • Wyoming’s Big Horn basin, 1213

X

  • xanthan biopolymer, 1161, 1177

  • xanthan gum polymer, 1160

  • X-ray diffraction (XRD), 423, 430, 432

Y

  • y -on- x method, 445

Z

  • zero-offset VSP, 65

  • z -factor, PVT behavior of real gases, 1509

  • zones types, starting from injector, 1368

Contents

Data & Figures

References

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