Subject

Subject Index

A

Abandonment pressure, 39-8, 39-10, 39-11. 39-14, 39-16, 39-23. 40-8, 40-10, 40-16, 40-24, 40-33, 40-34

Abandonment time, 41-21 to 41-23, 41-27 ABC transaction, 41-8, 57-7 Abrasion-resistant coatings, 1 l-6 Abrasive jet cleaning, 56-1 Abrasive well fluids, 6-34 Absolute open flow, 33-6 to 33-10. 34-33.

34-35 Absolute ownership.

control, 57-2 definition, 57-1 theory, 57-l

Absolute permeability, effect of temperature on. 46-37, 46-38

Absolute pipe roughness, 15-4, 34-2, 34-24, 34-27

Absolute viscosity, definition, 22-13 Absolute zero, definition, 20-l Absorbed dose, unit and definition, 58-10,

58-23, 58-36 Absorption, 26-11, 39-27 Absorptive interactions, 50-9 Abstract of API manual, 17-3 to 17-S Abstracts examination, 57-9 Acceleration head, 6-50, 6-5 1 Accelerometer, 534 Accessory equipment for liquid hydrocarbon

metering systems, 17-4 Accounting method of valuation, 41-16,

41-17, 41-19, 41-22 to 41-24 Accumulator, 18-13 to 18-15, 18-50, IS-51 Accuracy and rounding of numbers, 58-5,

58-6 Accuracy, of bubblepoint pressure

correlations, 22-8, 22-9 of Organick-Golding correlation, 21-15 vs. precision, 58-S. 58-9

Acentric factor, 20-13 Acetic acid (HAc), as sequestering agent,

54-7 in acidizing, 54-3, 54-8, 54-10

Acetylene water system, 25-24 Acid,

concentration, effect on limestone dissolved, 54-2

emulsions, 54-8 major types for acidizing, 54-l primary requirements for acidizing, 54-l solubility test, 54- 11 solution of limestone in, 54-2 strength, estimated in field, 54-3 treatment design, 54-9 to 54- 11

Acid additives, alcohols, 54-8 corrosion inhibitors, 54-6 gelling and fluid-loss agents, 54-8 iron-control agents, 54-7, 54-8 liquefied gases, 54-8 retarded acids, 54-8 sequestering agents. 54-7 silicate-control agent, 54-7 surfactants, 54-6, 54-7 thickeners, 54-8

Acid concentration. effect on acid reaction rate, 54-5

Acid fracturing, 54-8, 54-9 Acid gases removal. 14-21, 14-22

Acid-in-oil emulsion, 54-8 Acid inhibitor, 54-10 Acid number, 47-19, 47-23 Acid penetration of matrix. 54-10 Acid reaction rates, factors affecting,

acid concentration, 54-5 area/volume ratio, 54-5 flow velocity, 54-5 formation composition, 54-6 pressure and temperature, 54-4, 54-5

Acid solubility, 5416 Acid solubility tests, 54-9 Acid-soluble &ales, 54-6, 56-2 Acid solvent, 56-2 Acid strength, 54-2 Acid-swellable synthetic polymers, 54-10 Acid-thickening additives, 54-8 Acid treatment design,

fracture acidizing-carbonate formations, 54-11

matrix acidizing-carbonate formations, 54-10, 54-l 1

matrix acidizing-sandstone formations, 54-11

Acids used in acidizing!. 54-l to 54-4 Acidizing,

acid reaction rates, 54-4 to 54-6 additives, 54-6 to 54-8 critical wells, 54-l 1, 54-12 general principles, 54-l to 54-4 general references, 54-12 to 54-14 introduction, 54-l laboratory testing, 54-9 references, 54-12 solutions, 54-3 summary, 54- 12 techniques, 54-8, 54-9 treatment design, 54-9 to 54-l 1 well treatment, 6-3, 354. 56-3

Acme thread profiles, 2-1, 2-38 Acoustic array logging, 51-25 Acoustic array sonde, 51-27, 51-28 Acoustic backup system, 18-15, IS-16 Acoustic beacons, 18-2 1 Acoustic energy, 51-I. 51-11, 51-20. 51-24,

5141 Acoustic impedance, 5146, 5147 Acoustic intensity, 51-3 Acoustic log correlation, 51-30 Acoustic log vs. core analysis porosity,

51-32 Acoustic logging,

acoustic wave propagation in rocks, 514 to 51-l 1

acoustic wave propagation methods, 51-l 1 to 51-14

applications, 51-28 conclusions, 5147, 5148 elasticity, 51-l to 514 introduction, 5 l-l methods of recording acoustic data, 51-14

to 51-28 nomenclature, 5 148 references, 51-50 to 51-52 theory of elastic wave propagation in

rocks, 5149, 51-50 Acoustic logs, 41-8, 51-30 lo 51-33, 51-37.

51-38 Acoustic positioning beacons, 18- 10 Acoustic properties of rock, 514, 51-5 Acoustic signal transmission system, 18-3

Acoustic telemetry, 53-l Acoustic transit (travel) time, 5 l-16 to

51-33, 51-35, 51-39, 5140, 5145, 51-47, 53-l

Acoustic velocities, 3445, 3446, 51-29, 51-31, 5143

Acoustic velocity log, 5 l-5 Acoustic wave propagation in rock,

acoustic properties, 514, 51-5, 5143 borehole modeling, 5 l-25 fluid composition, 51-7, 51-8 introduction to, 514 porosity, 5 l-5 rock composition, 51-5 stress, 51-6, 51-7 studies, 51-34 summary of, 51-11 temperature. 5 1-7 texture, 51-S to 51-11 understanding of, 5 148

Acoustic wave propagation logging, 5 l-27 Acoustic wave propagation methods,

in fluid-filled borehole. 51-12 introduction to, 51-l 1 reflection, 51-2 transmission, 5 l-2

Acoustic wave propagation properties, 5 1- 1 Acoustic wave train analysis, 27-l Acoustic waveform, 51-12, 51-14, 51-18,

51-24. 51-26, 51-27, 5140 to 5143, 51-45, 5147, 5148

Acoustic waves, characteristics. 51-3 compressional, 5 l-2 information contained in, 5 I- 18 shear, 51-2 transit time of, 51-29, 51-30

Acoustical survey, 540, 49-l Acoustical well sounder, 30-7 Acoustics, units and conversions, 58-36 Acquisition and acquisition costs, 4 l-13,

41-15 Acre-feet diagram, 404 Acrylamide polymer, 44-39 Activated aluminas, 14-21 Activation energy, 46-12 Activation gamma ray, 50-3 Activity coefficient of water, 25-3 Activity coefficient plot, 254 Activity of radionuclide, unit and definition,

58-10, 58-23 Actuator ratio, 3-27 Actuator specifications, 3-27 Ad valorem taxes, 39-27, 41-1, 414, 41-7,

41-9, 41-12 Adapter, 3-9, 3-39 Adapter flange, 3-8, 3-9, 3-13 Adaptive implicit formulation, 48- 14 Adiabatic horsepower, 3442, 34-44, 3445 Adjustable choke, 5-54, 14-3 Adjustment factors, critical flow prover,

33-13 to 33-15 Administration and supervision costs, 41-12 Administrator of an estate, definition, 57-3 Adsorption approach, statistical mechanics

for, 25-5 Adsorption cycle, 14-10 Adsorption dehydration unit, 14-20 Adsorption ion exchange, 48-5 Adsorption rate of an emulsion, 19-5 Adsorption reaction, Darcy’s law, 26-l I

16 PETROLEUM ENGINEERING HANDBOOK

Advanced Ocean Drilling Program, 18-15 Advantages. of batch-type meters, 32-10,

32-l I of gas lift. 5-l. 5-2 of positive-displacement meters. 32. I I,

32-12 of Sl units. 58-9

Adverse moblllty ratio waterfloods, 48-1 I Adverse possession, 57-2 Aeolian dune sandstones, 36-4 Aerobic bacteria, 24-16, 24-17 After breakthrough performance, 44-20 to

44-25 Afterflow, 30-9, 30-10, 31-6 Agglomerator. 12-12 Agitation. in crude oil emulsions. 19-6 to

19-9. 19-12, 19-13, 19-27 in foaming oils, 12-7 in removing nonsolution gas, 12-13 in separation of water from oil, 12-27

Agitation of stored product, evaporation loss. I I-12

Air-balanced pumping units, IO-1 to 10.3, IO-X, IO-9

Air buoyancy, effect of, I-70. I-71 effect on mass, l-70

Air-buoyancy risers. 18-15 Air circuit breaker, IO-28 Air compressors, 46-20 Air counterbalance diagram, 10-3 Air flotation process, 15-27 Air injection, fireflood. 46-28, 46-29,

46-3 I, 46-32 Air injection rate, tireflood, 46-19. 46-28.

46-33 Air motor engine starters. IO-19 Air/oil ratio. 46-17. 46-19, 46-28 to 46-30 Air Products-Greenwich, 46-3 I A)r requirements, firefloods, 46-13. 46.16,

46-19 An-steam injection, 46-23 Air/steam ratio. 46-23 Air/water ratio, 46-33 Airy phase. 51-12, 51-13 Alabama. 24-20, 4436 Alarm-signal loops, 16-9 Alaska, 18-3, 18-38, 1X-41, 18-42, 24.20,

24-21, 27-9, 27-19, 51-8, 57-11 Alberta, characteristics of produced waters,

table, 24-8, 24-12 ptlot proJect, 44-40 Redwater D-3 reef reservoirs, 40-2, 40.20 reservoirs, water-oil displacements, 48-6 sedimentary strata in, 24-19

Alcohols, in acidizing, 54-8 in hydrate Inhibiting, 14-6 in phase environment shifts, 47-13 in removing water blocks, 56-2

Algae, 4442. 4444 Algorithms, for applicability in jet pump

performance, 6-46, 6-47 for computing dipmeter plots, 53-16 for computing relative permeability, 28-14 for screening of micellaripolymer

flooding, 48-6 Alkaline flooding 48-5, 48-7 Alkaline processes, 47-l Alkaline water breakthrough, 4440 Alkalinity, 44-44 Alkanolamine condensates, 19-10 Allowable depletion, 41-13. 41-14 Allowable gas velocity, 12.22 Allowable loading, 9-4 Allowable stress, 94, 9-8, 9-13, 12-38,

12-41 Allowable working pressure, maximum,

12-40

Allowable working pressures for piping, 15-l I

Allowables, discovery. 32-2, 32-3, 32-15 history of. 41-9 production rate. 32-l. 43-2, 43-10 Texas rule, 32-l yardstick schedule, 32-3

Allowance factor. 39.24 All-welded screens, 56-7, 56-8 Alpha emitter, SO-6 Alpha radiation, 50-2 Alternative minimum tax, 41-14, 41-15 Alternative subsea control systems, 18-49,

18-50 Alternating-direction iterative methods

(ADI), 48-16 Aluminum, 12-41, 24-9, 50-3, 50-4. 50-8,

50-18. 50-23. 50.34, 50-35 Aluminum bolted tanks. II-9 Aluminum pellets, 55-S Alundum, 26-6 Amagat’r law, 20.4 Amerada gauge temperature element, 3 I 1 Amerada pressure gauges, 30-I. 30-2, 30-4,

32-6 American Assn. of Petroleum Geologists

(AAPG). 40-2 American Gear Manufacturers’ Assn.,

10-12, IO-13 American Natl. Standard Inst. (ANSI),

piping pressure ratings, 15-14 American Petroleum Inst. (API),

API analysis of oilfield waters, 24-5, 4443

API barrel, 58-23 API casing and tubing threads, 6-2 API casing hangers. 3-39 API circumferential displacement values,

9-9 API commtttee. gamma ray calibration

standards. 50-20 API committee, standardization of steel

tanks for oil storage, I l-3 API committee, statistical study of

recovery efficiency, 44-32 API esttmation of oil and gas reserves,

40-12 API flanged or clamped wellhead equipment,

adapters. 3-9 backpressure valves. 3-8 bottomhole test adapter, 3-13 casing hangers. 3-5, 3-6 casinghead and tubing-head flanges, 3-4 Christmas-tree fittings, 3-13 clamp-type connectors, 3-5 crossover flange. 3-9 flange data, 3-18 to 3-25, 3-27 intermediate casmg hangers, 3-8 intermediate casing heads, 3-6 to 3-8 joint gaskets, 3-28 to 3-32 lowermost casing heads, 3-2 to 3-5 multiple-completion equipment, 3-13 to

3-18 physical properties, 3-2 to 34 thread limitations, 3. I tubing hangers. 3-8, 3-9 tubing-head adapter flange, 3-9 to 3-l I tubing heads, 3-8 valves, 3-11 to 3-15 wellhead assembly, 3-2 working and test pressure terminology,

3-1, 3-2 working pressure ratings, 3-2

API flanges, 3-39 API gravity, 58-24

API gravity. correction of observed value, 17-5. 17-6

API gravity of crude petroleum, 17-5 API gravity of fluid columns. 6-22. 6-23.

6-26 API gravity of light hydrocarbons, 17-5 API gravity of liquid petroleum products,

17-5 API gravity scale hydrometer test method,

17-l API horsepower rating curves. IO-17 API independently screwed wellhead

equipment, 3-39 API joint committee. proved reserve

definition. 40-2 API magnetic tape standard. 49-37 API maximum working pressure ratings,

casinghead and tubing-head flanges. 3-4 flanged-end connection, 3-4 valves, 3-l 1 wellhead assembly, 3-3 wellhead equipment, 3-3

API Midwest Research Inst., IO-7 API modified Goodman diagram, 94.

9-5, 9-8, 9-9 API oil-water separator, 15-25 API pin thread, 9-12 API piping pressure rating. 15-14 API preferred metric tutus. 17-7 API pump barrel tolerance, 8-5 API pump designation. 8-2 API recommended practice for design

calculations for sucker rod pumping systems, 8-10, 9-2. 9-3

API Research Project 25, 3 I-1 API rod grades, 9-5. 9-X API safety and pollution prevention

equipment (SPPE), 3-39 API scale, relative density, l-80 API separators, 15-23. 15-24 API spec. for bolted productton tanks,

11-l API spec. for pumping units, IO-4 API spec. for reinforced plastic sucker

rods. 9-t I API spec. for shop-welded tanks for

storage of production liquids. I l-l API spec. for sucker rods, 9-l API spec. for wellhead and Christmas-tree

equipment. 3-36 API std. for hydraulic pumps, 6-21 API study on well spacing. 40-16 API Subcommittee on Recovery

Efficiency, 40-12, 40-17 API subsurface pump bores, 8-l API subsurface pump classification. 8-3,

8-4 API subsurface pumps and fitttngs, 8-2,

83, 8-6 API sucker rod pins, 9-10 API sucker rod pumping system design

book, 9-4 API task force on performance properties,

2-54 API test method, 55-5 API threading data, 2-64 to 2-72 API torque rating, IO-5 API unit of radioactivity, 50-15, 50-20,

50-24 API valve rods, 8-2

American Sac. of Mechanical Engineers (ASME),

ASME code for unfired pressure vessels, 12-38

ASME qualification as SPPE certificate holder, 3-39

SUBJECT INDEX

American Sot. for Testing Materials (ASTM).

ASTM, API scale approved, l-80 ASTM. Committee D-19 standardizes

methods of analyzing oilfield waters. 24-S

ASTM distillation method. 26-22 ASTM RVP technique, 14-13 ASTM std. viscosity/temperature charts,

19-x ASTM viscosity charts, 6-67 ASTM wood-back or corrosion-resistant

metal cup case, 17-l American Standards Assn.. valves. 3-l I American wire gauge. 7-S Amine gas desulfurizer, 14-21 Ammeter chart record, 7-6 Ammeter spikes, 7- 14 Ammonia, 14-8, 14-9 Ammonium fluoride. 54-4 Amoco, 16-13. 46-14, 46-15, 4618, 46-30,

46-33. 47-22 Amortization, 41-5, 41-7, 41-16 to 41-18,

41.20, 41-21, 41-23, 41-24 Amount of substance, 58-7. 588, 58-23,

58-27 Amphoterics. 47-7 Amplitude attenuation, 51-14 Amplitude log, 51-45 to 51-48 Amplitude/time recording. 5 I I8 Anaerobic digestion, 25-18 Analog computer, 9-2 Analog methods for areal sweep efficiency,

44-17 Analog model, 39-22, 4418 Analogies, single-phase value to multiphase

equivalent, 35-2 Analogy technique for reserve estimation.

40-l Analysis methods, for oilfield waters. 24-S

for water drive reservoirs, 38-4 to 38-9 Analysis, of a reservoir. 42-3

of condensate liqurd and gas. 21-8 Analytic models for pump performance,

7-12 Analytical-appraisal method for fair market

value, 41-2 Analyzing crude oil emulsions, 19-6 Anchor line tension, IX-IO Angle-averaging method of calculating

directional surveys, 53-5 Angles of incidence, Sl- I2 Angles, Sl units for. 58-5 Angular velocities. conversion of, table,

I-76 Anhydrite, 50-34, 50-35, 51-31 Aniline point, 21-3 to 21-5. 21-9 Anion exchange capacity (AEC), 52-21 Anionic repulsion, 47-3 Anionics, 47-7. 47-8, 47-21 Anions, 24-9, 24-12, 24-17. 44-45 Anions conversions, 49-4 Anisotropy of strata. 49-S Annual deferment factors, 41-27, 41-30 Annuity. tables,

amount of, l-63 amountmg to a given sum (sinking fund),

l-65 present worth of an, l-66 provided for by a given capital, 1-66

Annular preventers, 18-I I, 18-12, 18-15 Annular temperature, 53-2, 534 Annular velocities, 52- I8 Annulus, effect on induction log, 49-17 Antelope field, Texas, 16-12 Anticlinal folds, 29-2 Antisludge agents. 54-7

Antoine equation, 20-13. 20-17 Appalachian area. 24. I. 24-6. 24-7 Appalachian oil fields, 44-44 Apparent convergence pressure, 39-l 1 Apparent formation resistivity factor, 26-30.

26-3 I Apparent formation thickness, 53-15, 53-16 Apparent limestone porosity. 50-21. 50-28.

50-30 Apparent liquid density, definition, 22-20

of natural gases, 22-4 Apparent mole weight. 20-14 Apparent molecular weight of gas mixtures,

20-4 Apparent viscosity, 47-S. 55-5 Apparent water-filled porosity, 49-34 Application and selection, of gas scrubbers,

12-35. 12-38 of separators, 12-35

Application of acousttc logging, cased-hole evaluation, 51-42, 5 143 cement bond quality. 5140 fracture evaluation, 51-45 to 51-47 geopressure detection. Sl-39, 51-40 hydrocarbon content. 51-35 to 51-38 introductron to, 5 l-28 lithology, 51-35 mechamcal properties, 51-43 to 51-45 permeability. 51-47 porosity, 5 l-29 to 51-35 seismic and geologrcal interpretation,

51-28. 51-29 Application of metric system,

general, 5X-3 style and usage, 58-3 units and names to be avoided, 58-5 usage for Gelected quantrties, 58-3 to 58-5

Applications, of BHP. 30-8 to 30-15 of caliper logs. 53-17 of dipmeter and directional data, 53-10 to

53-16 of ESP system, 7-1, 7-2 of fiberglass sucker rods, 9-12 of floating production facilities, 18-34,

18-35 of gas Itft. 5-l of range of jet pumps, 6-46, 6-47 of stzing of jet pump, 6-41, 642 of sucker rods, steel, 9-2 of wellhead equtpment. 3-36 to 3-39

Appraisal equations, or1 and gas reserves. 41-17, 41-18

Appraisal value: methods for computation, Intermediate interest rate, 41-8 safe interest rate, 41-3. 41-5, 41-6 speculative interest rate. 41-6 to 41-8

Approach factor, 13-2, 13-3 Approximate methods for water drive

behavior. 38-8. 38-9 Appurtenances, II-6 Aquathermal pressuring, 52-22 Aqueous phase relative permeability, 47-9 Aqueous/volatile gas systems. 25-3 Aquifer conductivity. 38-9 Aqutfer geometry, 38-1, 38-4. 38-5, 38-8 Aquifer material balance, 38-8 Aquifer permeability. 38-9 Arabian Gulf. 18-2 Aramid fiber, 6-50 Archie equation, 26-3 I, 49-5 Arctic,

drscovery, commercial, 18-3 environmental conditions, IS-38 to 18-40 production structures, 1840 to 18-42 special considerations, 18-43 transportation systems, 18-42, 18-43

I7

Arctic Marine Hydrocarbon Production project, I X-3

Arctic mobile drilling structure. 18-42 Arctic Ocean, 18.38, 18-43 Arctic oil fields, 18-43 Arctic Pilot Project, 18-3 Arctic pipelines, 18-43 Arctic polar pack, 18-39 Area equivalents, table, 1-73 Area ratio, jet pump, 6-36 to 6-43. 646 Area units, SI metric system, 58-22. 58-23 Area/volume ratio, effect on acid reaction

rate, 54-5 Area1 coverage, 44-39 Area1 coverage factor, 44-7, 448 Areal cusping. 48-10 Areal pattern efficiency. 44-S. 44-12 to

44-2s Area1 sweep, 46-14, 46-21. 46-30. 46-31 Area1 sweep efficiency. 39-15. 39-t 7 , .*,

39-18, 39-22. 39-23, 43-3, 43-7 to 4 3 44-2, 44-28. 46-24. 47-2

Area1 sweep efficiency. at breakthrough, 44-20, 44-25 by analog investigations. 4417 by mathematical analysis, 44-13 to 44. -1 by numerical models, 4417 directional permeability effects, 44-25 methods of determining, 44-13 to 44-2 mobility ratio effects, 44-17 to 44-24 reservoir dip effect, 44-25

9,

7

15

reservoir fractures effect. 4425, 44-26 Areas of circles by eighths, table, l-28,

l-29 Areas of circles by hundredths. table, l-26.

l-27 Areas of circles, sq ft. table, I-30 Argentina, 51-33. 58-20 Arithmetic average temperature. 34-8 Arkansas, 21-4, 21-7, 24-8, 24-21. 27-2,

27-3, 46-3, 46.15, 46-24 to 46-26 Arkose sediments, 29-7. 29-8 Aromatic solvents, 56-2 Arrhenius equation, 46-12 Arrhenius reaction rate, 48-5 Arrow mot. 53-10. 53-l I Arsenic, in emulsion-treating chemicals.

19-10 Arsenic inhibitors, 54- 1 Articulated loading tower. 18-30 Articulated tower, 18-34, 18-35 Artificial ignition devices, 46-20 Artificial islands, 18-40 Artificial lift, 5-l. 5-28, 6-l. 6-6, 6-7.

6-60, 6-69. 1844. 39-16. 40-4 Artificial lift system, 36-2 Artificial lifting, 30-S. 30-14. 30-15 Artificial lifting equipment. 41-3 Artificial radiation, 50-6 Asbestos-cement pipe, 15-7, 15-10 Asphalt quality. 2 l-7 Asphalt Ridge field. Utah, 46-16, 46-30,

46-31. 46-33, 46-34 Asphalt seals, 29-S Asphaltene buildup, 46-22 Asphaltenes. 19-10, 19-30 Asphaltic-based oils, 19-5 Asphaltic crudes, 6-67 Asphaltic oils, 24-18 Asphalts, 39-l Assignments hy landowner, 57-6 Assignments by lessee, 57-7 Associated/dissolved gas, 40-3 Associated gas, 40-3 Asymmetrical anticlines, 29-2 Athabasca tar sand, 46-34 Atlantic Refining Co., 38-4

PETROLEUM ENGINEERING HANDBOOK

Atomic C/O density ratio, 50-2, 50-35 Atomic densities, 50-35 Atomic H/C ratio, 46-16 Atomic number, 50-2, 50-3. 50-7 Attenuation, 51-3, 51-4. 51-11. 51-12,

51-38, 51-47 Attenuation curve, 49-34, 49-35 Attenuation factor, 49-33, 49-34 Attenuation rate, 49-32 Attic oil, 43-l. 43-2 Austin chalk, 36-l Australia, 12-39, 27-9, 27-19 Austria, 12-39 Authority for expenditure (AFE), 15-31 Automated water jets, 19-29 Automatic backwash, 16-14 Automatic casing hanger, 3-6 Automatic control, installations, 16-10

of dry-desiccant-type gas dehydrators, 16-15

of injection-pumping rate, 16-15 of water-supply wells, 16-15 valves, 164, 16-11, 16-12, 16-15

Automatic controller, 13-50 Automatic controls,

for rod-pumped wells, 16-l I of gas-lift well, 16-l I

Automatic custody transfer (ACT), 12-3, 16-2, 16-5, 16-6, 16-13

Automatic cycling of desiccant beds, 16-15 Automatic lease process control, 16-14 Automatic positive choke. 13-57 Automatic production-control equipment,

16-2 to 164 Automatic production programmers. 16-3 Automatic quantitative liquid measurement,

16-5 Automatic safety shut-in system, 18-47,

IS-48 Automatic sampler. 16-7 Automatic tank battery, 32-14 Automatic water-treating plant, 16-14 Automatic well manifolds, 16-l 1, 16-12 Automatic well testing, 16-12 Automatic wellhead controls, 16-10 Automatic wellhead safety controls, 16-10 Automatic well-testing system, 16-12 Automatically controlled valves and

accessories, 16-2. 16-3 Automation of lease equipment,

BS&W monitor, 16-7 control installations, 16-10 to 16-12 gas measurement, 16-6, 16-7 general references, 16-16 introduction, 16-1, 16-2 netail computer, 16-7, 16-8 production control equipment. 16-2 to

16-4 production safety controls, 16-4, 16-5 quantitative measurements, 16-S. 16-6 references, 16-16 sampler, 16-7 supervisory control and data transfer

(SCADA) systems, 16-S to 16-10 temperature measurement, 16-7 well testing, 16-12 IO 16-16

Autotransformer converter, 10-35, IO-36 Average annual ROR method, 41-17, 41-19,

41-21, 41-23, 41-24 Average book method of valuation, 41-22 Average deferment factor, 41-25, 41-29,

41-31 Average GOR, 32-15 Average reservoir pressure, 30-S. 30-9 Average reservoir pressure, determination,

35-16 Avogadro’s number, 50-6, 50-35

Avogadro’s principle, 5- 1 I Axial-flow pump, 6-1, 15-15 Axial-flow turbine meter, 1348 Axial load(s) or loading, 2-2. 2-20 to 2-28,

2-34, 2-35, 18-6. 18-17, 18-22, 18-24 Axial stress, 2-3, 2-34, 2-35. 246. 2-55,

2-56, 9-9 Axial stress on casing, 2-20 to 2-28, 2-32,

2-35 Azimuth,

of hole, 53-1, 53-2, 53-7, 53-10, 53-17 of hole deviation, 53-10 of reference electrode, 53-10

Azimuth angle, 53-5, 53-6, 53-8 Azimuth frequency diagrams, 53-12

B

Bachaquero field, Venezuela, 24-13 Backflow, 44-35 Backflow method, 56-5 Backpressure controller, 13-51. 13-58 Backpressure curve, 34-3. 34-31 to 34-34,

34-46 Backpressure equations, 33-5. 34-30 to

34-35 Backpressure regulation, 13-54 Backpressure test data, 39-23 Backpressure testing, 33-3 to 33-6, 33-10,

33-20 Backpressure valve mandrel. 3-9 Backpressure valves, 3-8, 3-9, 11-10, 13-56 Backsurging method, 56-5 Backup control systems offshore, 18- 15 Backwash cycle, 16-14 Backwashing, 39-26, 44-43, 4447 Bacteria, 18-30. 44-46 Bacteria control equipment, 24-2 Bactericide, 44-41 to 44-44 Baffle plates. 19-12, 19-13 Baffling, 12-7. 12-13 Bahama Islands, 29-8 Balance line valve, 3-27 Balanced tangential method of calculating

Base conditions for natural gas fluids, 17-7

directional surveys, 53-5. 53-6 Balanced-type gas lift valves, 5-39

Base

Ball bearings. 13-48 Ball joint angle, 18-17

of

Ball sealers, 55-9

crude

Ball valve seat, 5-14, 5-15

oil,

Ballasting systems, 18-7

21-1,

Ballooning effect of tubing string, 4-9, 4-10

21-3

Baltic Sea, 24-19 Bat&line-Owen field, Texas, 40-33 Barge-launched jacket, 18-25 Barge-mounted deck, IS-23 Barges, measurement and calibration, 17-3 Barium, 24-9, 44-44, 4445, SO-16 to 50-18 Barn. definition, 50-6 Barrier bar, 36-4 Barrier-island sandstones, 364 Bartlesville Energy Technology Center

(BETC), 21-9 to 21-11 Bartlesville sand, 44- 1, 444

Basic orifice factors, 33-13 Basic orifice flow factor. 13-3 to 13-11 Basic sediments and water (BS&W), 16-2,

16-7, 16-13, 17-2, 19-1, 19-6, 19-10, 19-15, 19-31, 32-6, 32-7, 32-10

BS&W monitor, 12-16 Batch treatment method, 19-l I Batch-type meters, 32-6. 32-9 to 32-11 Bathymetry. 18-16, 18-39 Battrum No. 1 field, Saskatchewan, 464 Baum& scale, relative density, l-80 Bauxite, sintered particles, 55-8 Bay Marchand field, Louisiana, 44-37,

44-38 Beal’s correlation for dead-oil viscosity.

22-14 Beam-balanced pumping units, 10-I to IO-3 Beam-type pumping unit, 10-16, IO-23 Bean, 34-45 Bearings in turbine meters, 1348 Bed detection and definition of well logs.

49-25 to 49-36 Bed thickness, effect on acoustic velocity

logging device, 51-16 Beggs and Brill correlation, 46-7 Beggs and Robinson correlation, 22-15,

22-16 Behavior index. 55-5 Bell Creek MP flood, Montana, 47-16 Bellamy field, Missouri, 46-3 Bellevue field, Louisiana, 46-4, 46-15.

46-18, 46-19, 46-34 Bellows-assembly load rate, 5-16, 5-17,

5-37 Bellows BHP element, 30-l. 30-6, 30-7 Bellows-charge pressure, 5-16, 5-17, 5-33 Bellows-charged dome pressure, 5-3. 5-6,

5-7, 5-18, 5-19, 546, 549 Bellows-charged gas lift valves, 5-6, S-12.

Binary liquid/vapor system, 23-3

5-16, 5-17, S-20, 5-21, 5-23, 5-37, S-39, 542

Bellows guide tube, 5-12

Binary

Bellows meter, 13-36. 13-37 Bellows PD meter, 32-12

uhase

Bellows protection. 5-16

diagrams.

Bellows-type chari recorder, 16-6

23-2

Bending failure, 18-39

to

Bending load fracture strength of casing,

23-6

2-61 Bending moment, Sl unit for, 58-5, 58-34 Bending stress, 18-13, 18-17 Benedict-Webb-Rubin EOS, 20-7 Benzene, 244, 24-18 Berea cores, 47-8 Berea sandstone, 28-8, 28-9, 28-11, 51-6,

51-8 Bering Sea, 1842 Berl saddles, 12-10 Bernoulli’s theorem, 15-l. 15-2 Beryllium, SO-6 Bessel factor, l-61 Beta radiation, 50-2 Bid shopping, 15-31 Bimetallic corrosion. 3-36

Base pressure, 32-14 Bino&l coefti&nts, table, l-37 Base units, SI metric system, l-69, 58-3, Binomial distribution, SO-5

58-9, 58-10, 58-21. B&ides, 47-5, 47-10 Basic data required, solution-gas-drive Biofouling, IS-51

reservoirs, Biogenesis, 25-18 OIP, 37-3 Bioherm reefs, 36-5, 36-6 pseudorelative permeability, 374, 37-5 Bioherms, 294, 29-8 PVT. 37-3 Biological degradation, 47-5 relative permeability, 37-3 Biological surveys, IS-5 saturations, initial fluid, 37-3 Biopolymers, 47-4

Basic energy equation, 34-2, 34-9 Biostrome reefs, 36-5, 36-6

SUBJECT INDEX

Biostromes, 29-4, 29-8 Biot theory, 51-8 Birdwell, 51-18, 51-27 Bi-rotor PD meter, 32-l 1, 32-12 Bit guide, 3-6 to 3-8 Bittern, 24-20 Bitumen, 19-30, 46-31 Black iron sulfide scale, 9-8 Black-oil material balance, 37-25, 37-26 Black-oil model, 484 to 48-7, 48-9, 48-14 Black-oil reservoirs, 48-2, 48-8 Black-oil rings, 39-5, 39-22 Black-oil simulator, 36-10, 45-13 Black oils, 37-22, 37-23, 37-25, 37-26,

39-17, 39-26, 40-13 Black Sea, 24-19 Blank runs, 26-21 Blanking tool, 6-48 Bleed-type sensors, 3-34 Blender iar. 52-9. 52-10 Blenders”, 55-9 Blind and test flanges, 3-25 Blind-shear ram, 18-l 1, IS-20 Blind zone on lateral curves, 49-13, 49-14 Block-and-bleed-type sensors, 3-34 Block diagram, 15-30, 51-28 Blocking agent, 56-l Blocking fluids, 56-2 Bloomer field, Kansas, 16-12 Blotter model, 39-2 1, 44 17 Blowdowns, 1 l-6 Blowout, 18-l 1, 56-3 Blowout preventer (BOP), 3-2, 3-6, 3-9,

3-38, 3-39, 7-13, 18-4, 18-6, 18-9, 18-11 to 18-21, 18-34

Blowout preventers, annular, 18-11, 18-12 hydraulic connectors, 18-12 kill and choke (K&C) valves, 18-12 ram. 18-11 unitized stack, 18-12

Blowout preventer stack, 18-11 to 18-19, 18-31, 18-34

Bluff body, 16-6 Boberg and Lantz method, 46-9 Boberg and West correlation, 46-l 1 Bodcau field, Louisiana, 46-21 Boiling point,

cubic average, 21-12, 21-15 definition of types of, 21-11, 21-12 mean average, 21-11, 21-15 molal average, 21-6, 21-11, 21-13 to

21-15, 21-17 molar distribution of SCN groups, 39-l 1 of hydrocarbons, 19-7 of six refrigerants, 14-10 volumetric average, 21-11, 21-12 vs. K-value, 39-12

Boise sandstone, 51-8. 51-9 Boll-weevil casing hanger, 3-6 Boll-weevil tubing hanger, 3-9 Bolted-steel tanks, 11-l to 11-3. 11-6, 11-9,

11-11 Bonding conditions, cement, 51-40 to 5 l-42 Bonus, oil and gas lease, 57-4, 57-7 Booster application, ESP, 7-2, 7-3 Booster pump, 15-17, 44-47 Borehole acoustic measurements, 51-28,

51-29, 51-44. 51-45, 51-47, 51-48 Borehole-compensated (BHC) acoustic log,

51-1.5 Borehole-compensated device, 50-15 Borehole-compensated sonde, 5 l- 15 Borehole-compensated sonic log, 49-15,

51-16, 51-17, 51-24, 51-26, 51-30, 51-32, 51-37

Borehole-compensated sonic tool, 49-32

Borehole-compensated sonic travel time, 5 1-22

Borehole-compensated transit time, 51-21 Borehole configuration, 53-16, 53-17 Borehole corrections, IL, 49- 18 Borehole, fluid-filled, acoustic wave

propagation in, 51-12 to 51-14 Borehole geometry, 51-19, 51-28 Borehole geometry log, 53-17 Borehole geophysical devices, 58-25 Borehole measurement of transit times,

5 1-26 Borehole reflection method, 51-46 Borehole size effects, 51-19 Borehole televiewer, 51-27 to 51-29, 5141,

51-46, 53-17 Borehole televiewer log, 51-46 to 51-48 Boron, 24-4, 24-5, 24-12, 50-6, 50-l 1,

50-12, 50-14, 50-32, 50-36 Borosilicate glass, 244 Boscan field, Venezuela, 6-24, lo-18 Bottle tests, 19-10, 19-15 Bottom discharge application, ESP, 7-2, 7-3 Bottom gas lift valve, selecting, 5-26 Bottom intake application, ESP, 7-2, 7-3 Bottom-seating holddown, 8-3 Bottom-seating stationary-barrel rod pumps,

8-8 Bottom-unloading gas lift valve, 5-51 Bottomhole assembly (BHA), 6-3 to 6-6,

6-3 1, 6-39 Bottomhole bumper spring, 5-52, 5-53 Bottomhole collar lock, 5-52 Bottomhole GOR, 37-23, 37-24 Bottomhole pressure (BHP):

gas wells, 34-3 to 34-27 gas-condensate wells, 34-27, 34-28 gas injection wells, 34-28 to 34-30 liquid injection wells, 34-28

Bottomhole pressure buildup analysis, 40-27 Bottomhole pressure calculations,

by Cullender-Smith method, 34-25, 34-26 by Sukkar-Cornell method, 34-9 to 34-24 flowing gas wells, 34-23, 34-24 gas-condensate wells, 34-27 static gas well, 34-8, 34-9

Bottomhole pressure gauge, 3 I- 1 Bottomhole pressure instruments, 30-l to

30-6, 30-15 Bottomhole pressure, steamflood, 46-17 Bottomhole pressures, 30-I to 30-15 Bottomhole test adapter. 3- 13 Bottomhole valve temperature, 5-46 Bottom-water, 24-2 Bottomwater drive, 40-15, 41-10, 48-4 Bounded reservoirs, shape factors, 35-5 Bounding additive, 46- 19 Bourdon tube, 13-38, 13-56, 16-4, 16-7.

30-1, 30-2, 304, 30-6, 30-7, 31-1 Box and pin entrance threads, extreme-line

casing joint, 2-64, 2-69, 2-70 Box and pin subcoupling, 9-4 Boyle’s law, 20-1, 20-2, 26-6, 26-7, 27-1,

30-B Boyle’s-law-type porosimeter, 26-4, 26-6 Bradford field, Pennsylvania, 24-I) 24-2,

44-1, 44-4, 47-22 Brake horsepower, 10-9, 10-17, IO-19 Brazil, 12-2, 12-21, 46-3, 46-4, 58-20 Brea field, California, 46-16, 46-18, 46-24,

46-25 Brea-Olinda field, California, 46-15, 47-22 Breakdown pressures, 44-3, 4446, 56-l Breakthrough of free gas, 40-10 Breakthrough of gas, 40-14 Breakthrough of inert gas, 39-17 Breakthrough of polymer, 44-40

19

Breakthrough of water, 40-18, 40-19, 44-4. 44-7, 44-9, 44-11, 44-12, 44-14, 44-15, 44-34

Breakthrough sweep efficiency, 44-15, 44-16, 44-25

Breast mooring system, 18-2 Breathing losses in tanks. I l-12, 1 J-13 Breccia, 29-8 Bridge plugs, 55-9 Bridging in flow channels, 54-l 1 Brightness of emulsions, 19-5 Brine displacement of product method of

solution mining, 11-13, 11-14 Brine/oil ratios, 47-14 Brine salinity, 47-3 to 47-5, 47-10, 47-l 1,

47-13, 47-21 Brinnell hardness. 2-2, 2-37, 9-5 British Commonwealth countries, l-69 British imperial gallon, l-69, l-70 British system of weights and measures,

l-69, l-70 Bromide, 19-10, 24-9, 24-12, 24-18, 24-20 Bromine, 24-5, 24-20, 24-21 Brownscombe-Collins method of water-drive

predictions, 38-9 Bubble flow, 34-36 to 34-39 Bubble Reynolds number, 34-38, 34-39 Bubble rise coefficient, 34-38, 34-39 Bubble rise velocity, 34-38, 34-39 Bubble size range of foams, 47-8 Bubblepoint c&e, 20-2 Bubblepoint equation, constants for, 22-8 Bubblepoint liquid, definition, 22-21 Bubblepoint of a system, definition, 22-20 Bubblepoint of crude, 6-21 Bubblepoint pressure, 6-39, 22-1, 22-5 to

22-9, 22-11, 22-12, 22-21, 23-3, 23-11, 24-12, 24-14, 24-15, 34-31, 34-33, 34-34, 35-2, 37-1, 37-3, 37-5, 37-6, 37-8 to 37-10, 37-15, 37-22, 39-6, 40-6, 40-7, 40-10 to 40-13, 40-19, 44-5

Bubblepoint pressure correlations, accuracy, 22-8 empirical, 21-9, 21-10 Lasater, 22-5 to 22-7 Standing, 22-5 Vasquez and Beggs, 22-7, 22-8

Bubblepoint pressure factor, 22-7 Bubblepoint viscosity, 22-16 Buckley-Leverett calculations, 48- 1 Buckley-Leverett equation, 28-3 Buckley-Leverett frontal-drive method,

40-13 Buckling,

of ice, 18-39 of pipe, 18-37 of tubing string, 4-9, 4-10

Buildup curve, 30-9 to 30-13, 30-15 Buildup test, 354, 35-14 to 35-16, 35-19 Bulk density, 50-l to 50-4. 50-7, 50-8,

50-17, 50-26 to 50-28, 50-30, 50-33, 51-14, 51-37

Bulk modulus, 6-55, 51-1, 51-2, 51-4, 51-14, 51-43, 51-44, 51-49

Bulk pore compressibilities, 51-43 Bulk volume (BV), 26-l to 26-7, 26-22.

27-1, 37-11 Bumper subs, 18-13, 18-14, 18-18 Bundle of capillary tubes model, 28-12 Buoyancy effect, 2-2, 13-51, 18-2, 18-15 to

18-17, 18-24, 18-25, 18-29, 18-37, 18-49, 24-2

Buoyancy, effect on water-drive recovery, 40-20

Buoyancy method of gravity measurements, 52-19, 52-20

Burbank unit, Oklahoma, 44-4 I

70

Bureau of Land Management, 57-12

Buried bar with shale drape. 53-12. 53-13

Burners for emulsion-treating equtpment,

19-28

Butane as IC engine fuel, IO-16

Butterfly charts, 49-28

Butterfly diagram, 24-19

Butterfly valve, 13-58

Buttress-thread casing and coupling, 2-l.

2-5, 2-7. 2-9. 2-11. 2-13, 2-15, 2-17,

2-19. 2-29 to 2-31. 2-57 to 2-61, 2-63,

2-64

Buttress thread profile, 2-38

Bypass valve. 13-59

C

Cabimas field, Venezuela, 24-13

Cable junction box. 7-13

Cable-tool cores, 26-20, 26-2 1

Cable tray, 1846

Cabled transmission system, 17-4

Cablmg systems for SCADA, 16-9

Caddo Lake field, Louisiana. 18-l

Cadiz. 58.20

Cadmium. 50-15

Caisson-retained production island, 18-40

Caisson tutus, 18-41

CAL wzllsite analysis. 49-37

Calcimeter, 52-9, 52-21

Calcite. 19-5, 5L-5. 51-6

Calcium acetate, 54-3

Calcium aluminate cement, 46. I9

Calcium carbide leg tests, 52-l I

Calcium carbonate. 194.. 24-2, 4444,

44-45

Calcium chloride, 8-9, 54-2

Calctum citrate precipitation, 54-7

Calcium fluorides, 54-4, 56-5

Calcium formate, 54-3

Calcium magnesium carbonate, 54-2

Calcium scale. 4444

Calcium sulfate, 44-44, 44-45

Calculated bottomhole pressure. 30-7, 30-S

Calculation methods. directional surveys,

53-5 to 53-7

Calculation of relative permeabihty,

automated centrifuge technique, 28-7

lnstitut Fran& du Petrole method, 28-7

Calculation procedure, Jacoby and Berry

method. 37-23 to 37-26

Calculation sequence and supplemental

equations. jet pump.

power-fluid flow through nozzle, 6-42

programming considerations. 6-46

pump performance and return flw, 6-42.

6-43. 646 sizing considerations. 6-46

worksheets, 6-44, 6-45

Calculations for sizing prime movers, IO-17

to IO-19

of standard of mass. I-70

Calculations for sucker rods. O-2 to 9-4

Calculattons: see also example problems

Calculator programs,

for HP-4 I C. 22-17

Calibrate tails, 49. I8

Calibration, of barges. 17-3

of bellows meter. 13-36

of bottomhole gauges, 30-2, 30-3. 30-5

of capacity standard, l-7 I

of conventional acoustic logs, 5 l-17

of dipmeter tool, 53-8

of gas measurement equipment, 13-l

of horizontal tanks. 17-3

of induction lop. 49-18

of spheres and spheroids. 17-3

of tank cars. 17-3

of tanks, liquid method, 17-3

of upright cylindrical tanks. 17-3

standards, 50-20. 50-29

California. 6-5, 6-24, 6-59, 17-2. 18-l to

18-3, 19-2, 19-5, 21-2, 21-4, 21-7,

24-7, 24-8, 24-20, 26-19, 26-23, 26-30,

27-4, 27-5, 29-2, 29-8. 34-41, 34-45,

40-15, 40-22, 40-23, 41-5, 44-37,

44-39, 4440, 46-3, 46-4. 46-14 to

46-16. 46-18. 46-19, 46-22 to 46-25,

46-35. 47-22. 58-20

California condensate systems, 2 l-12

California otl systems, 22-5

Californium. 50-35

Calingeart and Davis equation, 20-13. 20-17

Caliper curve and surveys, 49-1, 49-34,

49-35, 49-38, 49-39

Caliper log, 51-16. 51-19, 51-23, 51-24,

51-26, 51-33. 51-38, 51-45, 51-46

Caliper logs.

borehole configuratton. 53-16. 53-17

for casing and tubing inspection, 53-17,

53-18

interpretation and application, 53-17

introduction, 53-l. 53-16

methods of recording. 53-16

types. 53-16 to 53-18

Calorific value, 58-28

Caltex, 46-4

Calvin field. Illinois. 40-33

Canada, l-70. 12-10, 12-39, 18-2, 18-3,

18.38. 18.30, 19-2. 24-6, 24-8, 24-l I,

24-19. 24-20, 21-9. 27-20, 33-5, 44-40, 46-3. 46-4. 46.18, 46.21, 51-1, 52-12,

58-22

Canadian Arctic Islands, 18-3

Canadian Beaufon Sea, 18-3

Cap rock, 20-6. 29-7

Capacitance kilovars. IO-35

Capacitance of a process, 13-50

Capacitance probes, 16-2, 16-7, 16-8,

16-12, 19-31

Capacities of orifice well testers. 13-38 to

13-44

Capacities ot separators. 12-21 to 12-25

Capacities of spherical separators, 12-30 to

12-32

Capacitive reactance, IO-34

Capacitive transducer, 30-5, 30-6

Capacitor converter. IO-35

Capacitors, 10-25, IO-32 to IO-35

Capacity curves for separators, 12-27 to

12-32

Capacity distribution, 45-10. 45-12

Capacity-dtstribution curve. 44-8

Capacity equivalents, table, l-73

Capacity, of a process, 13-5 1

t;f API bolted steel tanks, I l-3

of API shop-welded tanks. I l-5

of eqmpment , 58-25, 58-30, 58-31

venting requirement, I l-7

Capactty. standard of. I-71

Capillary desaturetion curve (CDC), 47-9,

47-10

Capillary discontinmty, 28-3

Captllary forces, 37-l I, 44-31, 46.13. 47-9

43-6

Capillary imbibition, 48-4

Capillary number, 47-9, 47-17

Capillary pressure. as threshold pressure.

2X-6

averaging of data, 26-25 to 26-27

converting to reservoir conditions, 26-25

curves. 26-24. 26-26. 28-5

definition, 26-23, 26-27. 28.3

effect on unit dtsplacement efficiency,


end effect, 28-7

forces, 22-16, 22-17. 40-14

gradient, 40-17, 4410

laboratory measurements. 26-24 to 26-27

relative permeability calculation based on.

28-8

saturation data, 26-26

standards. 58-38

tests. 44-4

water saturation from, 26-22, 26-25,

27-8, 446

Capillary tube concepts, 47-5

Capillary tubes. bundle of, 26-10, 26-20

Capillary tubes for flow network, 26.19,

26-20

Capital expenditure. 57-l I

Capital gains. definition, 57. I 1

Capital to drill a well, 57-8

Capture cross section, 50-l I, 50-22

Capture gamma rays, 50-3, 50-4. 50-22

Carbon dioxide (CO,). 3-35 to 3-37, 4-4,

4-5, 6-4, 6-62, 8-9, 9-5, 9-8, 9-9.

10-16, 12-3, 12-X. 14-3. 14-13, 14-17.

14-20 to 14-22, 15-29. 19-29, 19-31.

20-5, 20-6. 22-5, 22-17, 23-7, 23-12,

23-13, 24-4, 24-5. 24-16, 24-17. 26-18.

28-10, 37-24, 39-2, 39-5, 39-6, 39-14.

39-16, 40-22, 42-2. 43-2. 44-42, 44-43,

45-1, 45-4 to 45-6. 45-9. 46-12, 46-22.

46-28, 48-5 to 48-11, 52-4 to 52-7, 52-Y

to 52-11. 52.13, 52-16

CO, analyzer, 19-28

CO, content, 25-5, 25-8. 25-13 to 25.15.

25-20

COJcrude oil systems. 23.10

COJdecane system, 23-9

CO, floods. 19-28

CO2 in acidizing, 54-8 to 54-10

CO, injection, 48-2, 48-7, 48-8

CO,/methane/decane system, 23-13

COhrouane system. 23-9

CO$k,k,, system, 23-9

CO, density required for miscible

displacemen;, 45-6

CO, miscible process, 45-5, 45.6

COJwater system, 25-3, 25-14. 25-15

Carbon/oxygen ratio: see C/O ratio

Carbon steel pipe, I l-2, 15.10, 15-12

Carbon steel, properties of materials. 12.41

Carbon-to-hydrogen ratto, 21-3, 2 1-5

Carbonate banks or shoals. 36-5. 36.6

Carbonate reservoirs.

bioherm reefs, 36-5

biostrome reefs, 36-5

nearshelf deposits. 36-6

shelf carbonates, 36-6

steamflood. 46-27

types. 29-8

Carbonate rocks, laboratory measurement of

porosity. 26-6, 26-7

Carbonic acid. 9-8

Carbonylsulfide (COS), 14-22

Carboxymethylhydroxyethyl cellulose

(CMHEC), 47-3

Carnot cycle. 14-10

Carr-Kobayashi-Burrows method for natural

gas viscosny, 20-9, 20-10. 20-15. 20-16

Carried interest, 41-1, 41-2. 57-10

Carrter fluid, 56-8

Carthage field. Texas, 39-3

Cartography, 58-5

Cartridge filters, 15-20, 44-47

Carved-out production payment, 4 I- 1

Case cup thermometer, 17-I

Case histories of gravity drainage,

Lakeview pool, 40- 15

Oklahoma Cny Wtlcox reservoir, 40-15

SUBJECT INDEX

Case histories. thermal recovery. Fireflood projects,

Asphalt Ridge, 46-30. 46-31. 46-33. 46-34

combination reverse/forward combustion, 46-30, 46-31. 46-33. 46-34

deepest. 46-28 to 46-30 Forest Hill, 46-3 I, 46-34 Gioriana, 46-29 10 46-32 largest, 46-28, 46-29 oxygen-enriched air, 46-3 I, 46-34 Sloss. 46-30. 46-33 Suplacu de Barcau. 46-15. 46-28, 46-29 thinnest producing reservoir. 46-29 to

46-3 1 West Heidelberg, 46-28 to 46-30 wet combustion, tertiary recovery,

46-30. 46-33 Steamflood projects,

Brea, 46-24. 46-25 carbonate reservoir, 46-27 to 46-29 distillation drive. 46-24. 46-2.5 fracture-assisted. 46-26 to 46-28 gas-cap reservoir. 46-24 to 46-26 Kern Rover, 46-23, 46-24 Lacq Sup&ieur, 46-27 to 46-29 largest. 46-23. 46-24 Slocum, 46-26. 46-27 Smackover, 46-24 to 46-26 Street Ranch. 46-26 to 46-28 watersand reservoir, 46-26. 46-27

Cased-hole completions, 56-9 Cased-hole evaluation, 5 l-42. 5 1-43 Cased-hole logging. 50-I Cash contributions to drilling well. 57-9 Cash flow, multiwell template effect on.

IS-32 Cash-flow prqjection preparation. 41-3. 41-4 Casing anchor. 8-9 Casing and tubing inspection by caliper

logs. 53-17. 53-18 Casing and tubing leaks, 33-21, 33-22 Casing,

API liners. 2-1, 2-2 API types, 2-l axial stress on, 2-20 to 2-28, 2-32, 2-35 centralizers, location of, 53-17 collapse, 53-18. 56-3 collapse pressure. 2-l IO 2-3, 2-20 to

2-28. 2-32. 2-34. 2-35. 2-46. 2-55. 2-56, 18-20

collapse pressure under axial-tension stress, 2-55

collapse resistance. 2-l to 2-4, 2-6, 2-8, 2-10, 2-12, 2-14. 2-16. 2-18. 2-32. 2-46. 2-55. 2-56

collapse resistance under axial load, 2-20 to 2-28, 2-34, 2-35

collar-locator log, 53-26 combination strings. 2-2 to 2-4 design of strings. 2-1, 2-2 dimensions, 2-28. 2-29, 2-57 to 2-59.

2-63. 2-64. 2-66 elongation, 2-2 equations for calculating performance

properties, 2-46. 2-54 to 2-56 extreme-line, 2-l. 2-4, 2-6, 2-8, 2-10.

2-12. 2-14. 2-16. 2-18. 2-29 to 2-31. 2-62 to 2-64. 2-67, 2-68

extreme-line joint, 2-5. 2-7. 2-9, 2-l 1. 2-13. 2-15, 2-17. 2-19. 2-60. 2-63. 2-67 to 2-72

flow (annular) installation design, 5-37, 5-38

gross linear footage from net footage. 2-29, 2-31

hanger, S-5. 3-6. S-X. 3-l I, 3-37, 33-39 hanger bowl. 3-2, 3-6. 3-8 hanger-seal assembly, 18-20 injection-gas pressure. 5-54 internal pressure leak resistance. 2-5, 2-7,

2-Y. 2-l I, 2-13. 2-15. 2-17, 2-19. 2-57 to 2-59, 2-64

internal pressure resistance, 2-5. 2-7, 2-9, 2-11, 2-13, 2-15. 2-17. 2-19

joint strength, 2-2. 2-5, 2-7, 2-9, 2-l I, 2-13, 2-15. 2-17. 2-19, 2-60. 2-61

leak. 31-5. 31-6 long thread, 2-S. 2-7. 2-9. 2-11, 2-13,

2-15, 2-17. 2-19, Z-31. 2-58. 2-64 minimum-ID calipers, 53-18, 53-19 multiplication factor, 2-29, 2-31 non-API steel grade. 2-5, 2-7, 2-9. 2-11,

2-13, 2-15. 2-17, 2-19 non-API weight and grades. 2-4. 2-6, 2-8.

2-10 performance properties, 2-4 to 2-19 plain-end liner. 2-32 potential profile. 53-20 profile calipers, 53-18. 53-19 range lengths, 2-3 round-thread. 2-l. 2-5. 2-7, 2-9, 2-l I,

2-13, 2-1.5. 2-17. 2-19. 2-28, 2-30, 2-57, 2-58. 2-61, 2-64

round-thread height dimensions, 2-66 safety factors, 2-l to 2-3. 2-34, 2-35 short-thread. 2-5, 2-7, 2-9, 2-11. 2-13,

2-15, 2-17. 2-19, 2-29, 2-57, 2-64 single-weight string suspended in rotary

mud. 2-37 sizes. F, values for. 34-25 special ,joint?. 2- 1 stress in, 2-36 stretch in. 2-35 to 2-37 tensile strength, 2-2 threads, 3-2 tolerance. 2-28. 2-29 travel time, Sl-41 weight. 2-28, 2-29 with helical glrakes, IX-21 yield strength, 2-2

Casing head\. 3-2 to 3-6. 3-8. 3-l I. 3-13, 3-37, 3-39

Casing inspection logs, caliper logs for, 53-17 electrical potential logs. 53-19 electromagnetic devices. 53-19, 53-20 introduction. 53-l. 53-17

Casing/tubing annulus, 3-8 Casinghead bowl. 3-5 to 3-7 Casinghead flange, 3-5, 3-6, 3-8 Casinghead gas, definition. 40-3. 57-5 Cast-iron pipe. 15-10 Cat Canyon field, California, 46-34 Catalyst poisoning. 56-2 Catalyst selection, guidelines, 15-30 Catalysts, 24-5 Catalytic combustion detector (CCD), 52-3

to 52-5, 52-l I Catalytic converters. 15-16 Catalytic ignition systems. 46-20 Catenary mooring configuration, 18-10,

18-16 Cathodic protection, 3-36. I l-6, 15-10,

18-29, 1X-33. 18-34. 53-19, 53-20 Canon exchange, 24-20, 47-20. 47-21 Cation exchange capacity (CEC), 50-15.

52-2 I Cationics. 47-7 Cations. 24-9. 24-19, 4445 Cations conversions. 49-4 Caustic Roodmg. 19-28. 44-40, 48-5, 48-7 Caustic soda. 14-22

Cavern storage application. ESP, 7-l. 7-2 Cavmgs. 33-2 1 Cavitation, 6-32 to 6-36, 6-41 to 6-43,

6-45, 6-46, 6-50. 6-60 Cavitation area, 6-37 Cavitation correction, 6-38 Cavity pumps. 19-5 Cellophane diaphragm, 26-24 Cellulose derivative thickener, 55-5. 55-6 Celsius scale. 58-5, 58-39 Celsius temperature, umt and definitmn.

58-7, 5X-10 Cement bond, 35-4, 56-4 Cement bond logging, 51-40 Cement bond quality;

bond to casing and to high velocity formation. 5 l-40. 51-4 I

bonding conditions summary. 5 l-42 free pipe. 5 I-40 good bond to casing and formation, 51-40 partial bonding, 5 I-41

Cement evaluation log. 5 l-42 Cement Evaluation Tool. 5 I-4 I Cement lining for steel pipe, IS-IO Cement sheath, 51-40. 51-41 Cement slurry, 56-4 Cementation, 26-2. 40-8. 40- 1 I, 5% I Cementation factor, 26-29 Central America, 25 18. 58-20 Central battery systems, 6-60, 6-62. 32-7 Centralized control room, 18-46 Centrifugal compressor. 14-8 Centrifugal compressor efficiencies, 14-9 Centrifugal force, 6-63. 12-7. 12-8. 12.10,

12-13, 12-14, 12-19. 12-20. 13-45. 14-3. 19-6, 19-15

Centrifugal gas scrubbers, 12-20, 12-21 Cenlrifugal (elbow) meters. 13-45, 13-49 Centrifugal pump. 6-l. 6-34. 6-49, 6-S I,

6-62. 7-2. 7-3. 15-15, 15.17. 19-S. 44-42. 4447

Centrifugal separator. 12-20 Centrifuge extraction method. 26-22 Centrifuge method for determining water

and sediment in ml, 17-1, 17-5 Centrifuge method of capillary pressure

measurement, 26-24. 26-25 Centrifuge technique for determining

relative permeability. 28-7. 28. Il. 28-12 Centrifuges, 15-20, 19-6, 26-22 Cenlripetal flow, 12-20 Cerveza platform. 18-2. 18-23 Chain drives, lo-12 Chain rule for derivatives. 37. I3 Chaining, 19-13 Chamber installations. gas lift. 5-19, 5-50 to

5-52 Chamber length equation, 5-51, 5-52 Chamber operating gas lift valves. 5-51 Channel cut and fll. S3-12. 53-13 Channeling, m acidizing, 54-8, 54-10

in cement bonding, 51-41 in emulsion treater, 19-23 in glass wool packing, 19-14 of injection water, 44-3

Channels. permeability of, 26-15. 26-16 Chanslor-Western Oil and Development

Co., 46-15, 46-19 Chapel Hill field, Texas, 39-3, 39-20 to

39-22 Characteristics of well fluids. 12-3, 12-21 Characterization factor, 21-3 to 21-l I.

21.13, 21.14. 21.21. 39-l 1 Characterization of the reservoir.

engineering, 36-6 to 36-8 geology, 36-3 to 56-6 geophysics, 36-8, 36-9


Charge pump, 6-62 Charged particle accelerators, SO-6 Charles’ law, 20-1, 20-Z Charpy impact values, 18-21 Charpy tests, 12-41 Charpy V-notch impact requirements, 3-38 Chart Rcor- I, 49-21 Chart Rcor-2, 49-21, 49-24 Chart Rcor-4, 49-18 Charts used in BHP gauges, 30-2 Chase water, 47-2, 47-11 Chatter condition, 5-16 Cheater bars, 9-10 Checklist, deck and subsea BOP testing,

18-12 Chelating agents, 44-45 Chemical absorption, 48-2 Chemical alteration of formation, 51-20 Chemical analyses, interpretation of, 24-18 Chemical analyses of produced waters, 24-2 Chemical analysis, 21-1, 21-2 Chemical and mechanical properties of

plastic sucker rods, 9-l 1 Chemical corrosion inhibitor, 8-9 Chemical degradation, 47-5, 47-22, 48-2 Chemical demulsifiers, 19-9 to 19-12, 19-32 Chemical destabilization, 19-7, 19-8 Chemical diffusion. 28-13 Chemical distributor for flowlines, 19-11 Chemical flood model, 48-4, 48-5, 48-7 Chemical flooding,

chemical agent numerical dispersion, 48-10

high-pH processes, 47-18 to 47-22 improved (enhanced) recovery, 40-4, 48-2 introduction, 47-1 low-IFT processes, 47-9 to 47-18 mobility control processes, 47-1 to 47-9 production, 46-3 ieferences, 47-24 to 47-26 summary, 47-22, 47-23

Chemical jnhibitors, 3-35, 6-55, 44-42 Chemical injection valves, 3-35 Chemical kinetics, 46-12, 46-13, 46-37 Chemical potential, 25-6, 25-9 Chemical potential sink, 47-1.5 Chemical properties of oilfield waters, 24-5 Chemical reaction kinetics, 46-1 I, 46-12 Chemical reservoirs, 29-6, 29-8 Chemical scavengers, 15-29 Chemical stain kit, 52-9 Chemical stoichiometry, 46-12 Chemicals in oil and gas separation, 12-7.

12-13 Chevron, 46-14, 46-15, 46-18, 47-22 Chevron Oil Field Research Co., 5149 Chevron packing, 18-15 Chew and Connally method, 22-14, 22-15 Chile, 58-20 Chiller, 14-8 to 14-10 China, People’s Republic of, 12-39 Chloride stress cracking, 3-35, 3-36 Chloride test, 27-l Chlorides, 24-9, 24-18, 44-44 Chlorine, 44-43, 46-20, 50-3, 50-4. 50-11.

50-12, 50-18, 50-21, 50-34 Choke capacity chart, 5-8 Choke-control operation, 5-41 to 5-44 Choke nipple, 13-56 Choke performance curve, 34-46, 34-50 Christmas-tree assembly, 3-8 to 3-l 1, 3-13,

3-17, 3-39 Christmas-tree tittings, 3-13 Christmas trees, offshore, 18-3, 18-28,

18-31, 18-32, 18-34, 18-37, 18-38 Chromatogram interpretation, 52-16

Chromatograph/thermaI conductivity detector, 52-6

Chromatography, 39-6 Chromic acid, 11-6 Chromium, 9-5 Circuit breakers, 10-28, lo-30 Circular conduits, fluid flow in, 26-10 Circular drainage area, 35-6 Circular flotation chamber, 15-27 Circumferences of circles by eighths, table,

l-28, 1-29 Circumferences of circles by hundredths,

table, l-24, 1-25 Circumferential bond image, 51-42 Circumferential displacement, 9-9, 9-10 Cities Service, 46-14, 46-15, 46-18, 46-20,

46-2 1 Citric acid as sequestering agent, 44-45,

54-7 Clamp-type connectors, 3-2, 3-5 Clamp-type permeameter, 26-18 Clamp-type riser coupling, 18-15 Clapeyron equation, 20-12, 20-13 Clarification of water produced with

emulsions, 19-28 Classification of oil and gas separators by,

application, 12-17 to 12-19 configuration. 12-16 function, 12-16 operating pressure, 12-16, 12-17 principle used to accomplish primary

separation, 12-19, 12-20 Classifications,

of hazardous areas, 10.36, lo-37 of insulation for motors, lo-26 of material balance equation, 40-7 of NEMA, for control enclosures, lo-27 of production packers, 4-1 of reservoir rocks, 29-6 to 29-8 of surfactants. 47-7

Clastic porosity, 29-8 Clastic reservoirs, 36-3, 36-4 Clastic rocks, 29-7 Clastic sedimentary deposits, 29-4 Clastic sediments, 36-3 Clathrates, 14-2 Clausius-Clapeyron equation, 20-12, 20-16,

20-17, 46-13 Clay control, 56-5, 56-6 Clay hydration, 51-19 Clay minerals, 44-2, 50-37 Clay stabilization, 56-3 Clay types, identification and quantification,

50-2 Clay yield, 58-29 Clean-sand points, 50-34 Cleaning vessels, 12-42, 19-28, 19-29 Cleanup, remedial,

abrasive jet cleaning, 56-l large-volume injection treatments, 56-2 mud removal, 56-l paraffin removal, 56-2 reperforation, 56- 1 scale deposits, 56-2 steam injection, 56-2 water blocks and emulsions, 56-2

Clearance volume, definition of. 6-21 Climatological data, 31-2, 31-3 Closed aas lift installation, 5-2, 5-3 Closed linear system, 38-9 Closed-loop control, 16-2 Closed power-fluid system, 6-4, 6-5, 6-25

to 6-28, 6-30, 6-55. 6-59, 6-60, 6-63 Closed radial system, 38-9 Closed regeneration system, 14-l 1, 14-12 Closed, rotative, gas-lift system, 5-l to 5-3,

5-11, 5-24. 5-38

Closure, 29-3, 29-8 Closure stress, 55-8 CLUSTER log analysis, 49-37 CO&O ratio in produced gas. 46-16 Coal caving, 52-19 Coal tar coating, I l-5 Coal tar epoxy internal coatings, 6-62 Coal-tar-epoxy system, 15- 10 Coalescence, 12-8, 12-10. 12-11, 12-19,

12-35, 15-22, 15-23, 19-1, 19-3 to 19-7, 19-9, 19-12 to 19-15, 19-17, 19-19. 19-21, 19-23, 19-25, 19-26, 19-28

Coalescing material, 19-14 Coalescing packs, 12-10 Coalescing-type mist extractor, 12-8, 12-l 1 Coanda effect, 12-20 Coastal interdeltaic environment, 36-3 Coatings, corrosion prevention, 18.29.

18-33, 18-34 Coatings for bolted tanks, 11-l Coatings, protective, 3-36 Code authorities for various countries,

12-39 Code vectorization, 48-17 Codes and regulatory authorities, 18-44 Coefficient, of adsorption, 51-4

of compressional wave attenuation, 5 1-4 of expansion, 26-20 of isothermal compressibility, 20-l 1,

20-16 of shear wave attenuation, 5 l-4 of thermal expansion, 58-34

Coefficients, for choke nipple, 34-45 interaction, 28-3 transport, 28-1, 28-3

COFCAW pilot or process. 46-2. 46-14, 46-33

Cogeneration of steam and electricity, 46-19 Cognac platform, 18-2, 18-23 Coherence, definition and usage SI metric,

58-8, 58-9, 58-22 Co-injection of gas and steam, 46-22, 46-23 Coke, 19-29, 46-12, 46-21 Cold drawn steel, 9-2 Cold electric grid, 19-25 Cold environment, 18-21 Cold Lake field, Alberta, Canada, 46-4.

46-34 Cold oil productivity, 46-10, 46-l 1 Cold-separation unii, 12-1 Collapse equation factors, 2-54 to 2-56 Collabse pressure equations, 2-46 Collapse pressure, of casing, 2-l to 2-3,

2-20 to 2-28, 2-32, 2-34, 2-35, 2-46, 2-55, 2-56

of line pipe, 2-48, 2-49 of tubing, 2-39, 2-41, 2-43, 246

Collapse pressure under axial load, 2-32 Collapse pressure under axial-tension stress,

2-55 Collapse resistance, of casing, 2-1 to 2-4,

2-6, 2-8, 2-10, 2-12, 2-14, 2-16, 2-18, 2-32, 2-46, 2-55, 2-56

of line pipe, 248 of tubing, 2-39, 241, 243, 246

Collapse resistance under axial load, casing, 2-20 to 2-28, 2-34, 2-35

Collapse safety factor, 2-l to 2-3, 2-32, 2-34, 2-35, 2-39, 2-45, 2-46

Collar locator, 53-26 Colombia, 21-2, 46-3, 58-20 Color of emulsions, 19-5, 19-6 Colorado, 24-8, 24-l 1, 24-20, 40-23 Colorado School of Mines, 25-9, 25- 11 Column-stabilized drilling vessel, 18-2 Combination casing strings, safety factors,

collapse, 2-2, 2-3, 2-34

SUBJECT INDEX 23

internal yield, 2-32, 2-34 joint strength, 2-32, 2-34 pipe-body yield strength, 2-32, 2-34

Combination drive reservoirs, 43-16, 45-8 Combination recovery procedures, 39-24 Combination reverse/forward combustion,

46-30, 46-31, 46-33, 46-34 Combination thermal and epithermal neutron

device, 50-37 Combination traps, 29-5 Combination valve operators, 16-3 Combustible-gas detectors, 1847 Combustion efficiency, 19-28 Combustion, in-situ,

dry forward, 46-1, 46-2 production by, 46-4 reverse, 46-2 wet, 462, 46-3

Combustion of coke, 46-12 Combustion tubes, 46-13, 46-15, 46-19 Comlith log analysis, 49-37 Common fractions of an in. to mm, table,

1-72 Common logarithms, table, 1-38 to 1-41 Common subsurface point, 53- I5 Common surface point, 53-15, 53-16 Communication adapter, 16-8 to 16-10 Communication facilities for SCADA, 16-9,

16-10 Compaction, 55-I Compaction correction factor, 5 l-33 Compaction disequilibrium, 52-21, 52-22 Compaction, effect on porosity, 26-7 Compaction of porous rocks, 26-7 to 26-10 Comparison of fluid saturation measurement

methods. averaging capillary-pressure data, 26-25 to

26-27 converting laboratory data, 26-25 introduction, 26-24, 26-25 water saturation from capillary-pressure

data. 26-25 Comparison of predicted vs. actual reservoir

performance, 37-25, 37-26 Comparison of project execution formats,

15-32 Comparison of separators, 12-21 Comparison of Tamer’s and Tracy’s

method, 37-10 Compatibility of coatings, 11-4 Compatibility tests, 19-10 Compensated density device, 50-17 Compensated Formation Density (FDP),

49-23, 49-24, 49-36, 49-38 Compensated formation density log, 46-21 Compensated Neutron Log (CNLTM), 49-36.

49-38, SO-29 Complementary error function, 46-8 Complementary metal-oxide silicon

(CMOS), 16-9 Completion costs, 41-9 Completion factor, 40-27 Completion flow efficiency, 37-21 Completion intervals in firefloods and

steamfloods, 46-17 Completion string inspection, 53-17 Completion/workover system controls,

1 B-48 Complex propagation factor, 49-33 Complexing agent, 56-3 Component parts of a pumping unit, 10-4,

IO-5 Composite reservoir, 35-7 Composition of oiltield waters,

Appalachian area, 24-6, 24-7 California, 24-7, 24-8 Canada, 24-8, 24-12

Illinois basin. 24-7, 24-9 midcontinent area, 24-8 to 24-10 Rocky Mountain area, 24-8. 24-1 I U.S. Gulf Coast, 24-7, 24-8 Venezuela, 24-9, 24-13

Composition of produced stream, GC system, 39-14

Composition ranges, GC systems, 39-2 Compositional analysis, 17-7 Compositional-balance equation, 43-6 Compositional material balance, 39-8 Compositional model, 43-2, 484, 48-6,

48-7, 48-9, 48-14 Compositional simulator, 36-10, 45-10,

45-13 Compound interest, 41-25 Compound interest factor, 41-17 Compound interest, table, l-62, l-63 Compound units, Sl metric system, 58-12 to

58-14 Compressed air, 3-3 1 Compressed vapor recovery unit, 11-13 Compressibility factor,

of ethylene, 17-7 of gas. 20-4, 20-7, 20-8, 20-10, 20-l 1,

20-14, 34-28, 40-22 of injected dry gas, 39-24 of natural gas, 5-4. 20-5, 20-6, 40-21 of nitrogen, 39-16 of pure compounds, 20-5

Compressibility factor charts, 20-5, 20-6, 40-2 1

Compressibility of CO*, 45-5 Compressibility of formation. 40-7 Compressibility of formation water, 24-12,

24-15 Compressibility of gas. 51-37 Compressibility of hydrocarbon liquids,

22-3, 22-5 Compressibility of natural gas mixtures,

17-7 Compressibility of oil, 40-7 Compressibility of pore fluid, 51-30. 51-31,

51-37 - Compressibility of porous rocks, 26-7 to

26-10 Compressibility of reservoir fluid, 58-38 Compressibility tests, 51-44 Compressibility, total, 35-2 Compression, 39-27 Compression loading, 9-13 Compression packer, 4-2 to 4-4, 4-8 Compression plant, 39- 17, 39-24 Compression ratio, 6-10, 6-21, 8-9, 8-10,

10-15. 18-14, 39-24 Compression refrigeration system, 14-9 Compression stress in pipe, 2-35 Compression stroke, lo-14 Compression system. 1 l-13 Compression-type seal, 3-6 Compressional energy, 34-28, 34-29, 39-40 Compressional forces, 29-2, 29-3 Compressional transit time curves, 5 l-29 Compressional-wave attenuations, 51-2,

51-6 Compressional-wave transit time, 51-19,

51-24 to 51-27, 51-29 to 51-31, 51-35 to 51-37, 51-39, 51-43

Compressional-wave velocities. 5 l-l. 5 1-2, 5’1-4 to 51-9. 51-12, 51-15, 51-20, 51-24. 51-25. 51-30. 51-34, 51-35. 51-37, 51-38. 5143

Compressional-wave velocity log, 51-28 Compressional waves, 51-2, 51-3, 51-12 to

51-15, 51-25, 51-27, 51-28, 51-30, 51-35, 51-46

Compressive load, 18-22

Compressive strength of cement, 5140, 51-42

Compressor, field booster, 13-57 Compressor fuel consumption, 39-24 Compressor-oil carry-over, 39-24 Compressor suction pressure, 13-58 Compton scattering, 50-6 to 50-8, 50-12 to

50-14, 50-16 Compton tail, 50-13, 50-14 Compulsory unit operations. 57-8 Comsand log analysis, 49-37 Concentration, definitions of, 48-5 Concentration, units and conversions, 58-29,

58-30 Conceptual studies, 15-30 Concrete dust, 1 l-5 Concrete (gravity) structures, IS-l, 18-2,

18-23, 18-25 Condensable vapors, 12-3, 12-8 Condensate content, 39-23 Condensate (distillate) liquids, 22-20, 39-23 Condensate-liquids recovery, 39-6 Condensate properties and correlations,

21-8, 21-10 to 21-16 Condensate well fluids, 20-7, 34-4 Condensates, 11-12. 12-3. 12-32. 14-1.

14-3, 14-5 to 14-8, 14-11, 14-14, 18-28, 39-10, 39-11. 40-3. 57-5

Condensing-gas drive. 45-l to 45-4, 45-l 1. 45-12

Conductance ratio, 44-34 Conduction, 46-25 Conductive cloth model, 44-20 Conductive solids, effect on electrical

properties of rock, 26-30, 26-31 Conductivity, 44-33 to 44-35 Conductivity log, 51-38 Conductivity units, 49-1 Conductor casing, 18-18, 18-19 Conductor strings, 3-3 Cone-bottom tanks, I l-2, 1 l-3 Configurations of separators. 12-16, 12-22,

12-31, 12-35 Confining pressure, 5 l-7 Conformance efficiency, 39-9, 43-3, 43-5 to

43-7, 43-9, 44-9, 44-32, 45-6, 45-7, 45-10, 45-13

Conformance factor, 39-18 Conformity of flood, 44-46 Congo, 46-3 Conjugate gradient, 48-17 Connate water: see also interstitial water Connate water, 24-2. 24-16, 24-18, 24-19 Connection gas indicating underbalance,

52-17, 52-18 Conoco Inc., 46-15, 46-26 Conservation, 43-l Conservation commission, 30-8 Conservation commission completion, 41-8 Conservation equations, steam injection model,

energy balance, 46-12 mass balance of coke, 46-12 mass balance of H,O. 46-12 mass balance of hydrocarbons, 46-12 mass balance of inert gases, 46-12 mass balance of oxygen, 46-12

Conservation laws, 39. I6 Conservation of mass, 34- 1 Consistency index, 55-5 Consolidated rocks, porosity of, 5 l-29 to 5 I-3 1 Constant-composition expansion, 39-7 Constant-enthalpy expansion, 14-l. 14-2 Constant-enthalpy expansion system, 14-3 to

14-8 Constant-flow control valve. 6-5 I, 6-54, 6-56 Constant percentage decline, 40-28 to

40-32, 41-9, 41-10, 41-12, 41-17


Constant-percentage-decline deferment factor, 41-24, 41-27, 41-28

Constant-pressure controller, 6-5 1, 6-54 Constant-pressure cycling, 39-23, 39-24 Constant-rate case for DCF-ROR, 41-18,

41-22, 41-23 Constant-rate deferment factor, 4 l-24,

41-25, 41-27 to 41-29 Constant-rate income, 41-18, 41-21 Constant-rate production, 41-5, 41-I 1, 41-12 Constant ratio of net profit. 41-20 Constant surface closing, gas-lift valve. 5-44 Constant-terminal-pressure case, 38-I to 38-3 Constant-terminal-rate case. 38-l. 38-2 Constant valve surface closing pressure,

5-46, 5-47 Constant-volume gas reservoirs, 40-34 Constraint equations, 48-4 Construction codes for separators,

ASME code for unfired pressure vessels, 12-38

ASME design equations for separators, 12-38

materials of construction for separators, 12-38

Construction design factor, 15-I I, 15-13 Construction materials for separator, 12-38,

12-39. 12-41 Constructton of meters, 13-37 Construction types for underground storage,

1 l-13 Contact angle, 28-10 Contact log, 443 Contact resistivity devices, 26-3 1 Containers for samples, 24-4 Containment of fracture, 55-5 Contaminants of water, IS-30 Continental sediments, 36-3 Continental shelf, 29-7, 53-12, 53-14 Continental slope and abyssal environments,

53-12, 53-14 Continuity of reservoir rock, 44-3 Continuity principles. 37-2 Continuous compounding, 41-26, 41-28,

41-30, 41-35 Continuous dipmeter surveys, 53-3 Continuous-flow gas lift,

bottom valve, selecting, 5-26 casing (annular) flow in&llation design, 5-37 depth of top valve, 5-24, 5-25 design procedures, 34-40 to 34-45 flowing pressure gradient curves, 5-25,

5-26 flowing temperature at depth. 5-26 installGion design. 5-22, 5-26 to 5-35 introduction, 5-2 I, 5-22 multiphase-flow correlations, 5-25, 5-26 operations, 5-24, 541 ortfice-check valve for the operating gas-

lift valve, 5-23, 5-24 production pressure (flurd)-operated

valves. 5-35 to 5-37 safety factors in simplified installation,

5-22, 5-23 slope of static load fluid traverse. 5-25 us& gas energy fully, 5-I

Continuous-flow installations, 5-21 to 5-26, 5-30. 5-31, s-34, 5-35, 5-37, 5-43

Contraction of pipe, lateral, 2-35 Control agent, gas regulation. 13-50 Control circuit logic, 3-27 Control curves, gas regulation, 13-52, 13-53 Control Data Corp. 1 48 I7 Control enclosures for motors. 10-26. IO-27 Control fluids, subsea control systems, 18-49 Control for odtield motors, IO-27 to lo-29 Control fuses for oilfield motors, IO-29

Control-head compression packer, 4-2, 4-3, 4-9

Control-head tension packer, 4-2, 4-9 Control lines in subsea completions, 18-33,

IS-34 Control manifolds, 6-54 Control of field compressors, 13-57 Control of subsea production facilities, IS-48 Control system, 3-31, 3-33, 3-34 Control systems offshore,

alternate approaches, 18-49, IX-50 control fluids, 18-49 direct hydraulic control. 18-50 discrete-piloted hydraulic. 18-51 drilling, 18-15. 18-16 introduction, 18-43 to 18-48 multiplexed electrohydraulic, 18-52 operational considerations, 1849 redundancy, 18-48. It-49 reliability/mamtainability, 18-48 safety systems, 18-47 sequential-piloted hydraulic, 18-51, 18-52 subsea productton facilities, IS-48 umbdtcals, 1849

Control-valve travel, 13-55 Controlled~solubility particulate solids, 54-10 Controller types, 16-3 to 16-5 Controllinginjection-pumping rate, 16-14 Controls nomenclature, 13-49, 13-50 Convection. 46-4, 46-12. 46-25 Convection heat-transfer coefficient, 46-5 Conventional acoustic logging.

calibration. 51-17, 51-18 curves recorded, 5 I - 16 cycle skipping and triggermg on the

noise, 51-16. 51-17 log presentation, 51-16 tool characteristics, 51-15, 51-16 tool span. 51-16

Conventional acoustic loas, 51-19, 51-20, 51-22 to 51-25, 51-35

Conventional coring procedures, 27-9 Conventional crank-balanced pumping units,

10-l to 10-4. 10-8. IO-9 Conventional gas-lift equipment, 5-2 Conventional lay barges. 1837, 1838. 18-43 Conventional (black-orI) material balance,

37-25. 37-26 Conventional mooring system. 18-4 Conventional mud logging. 52-1, 52-16 Conventional resistivity devices, 49-12, 49-25 Conventional resistivity logs. application, 49-14 Conventional steel pipe. 18-36, 18-37 Conventional tubing mandrel, 5-12 Conventional wireline cores. 27-9 Conventionally mined caverns, 1 l-13 Convergence pressure, 23-l 1 Conversion factors. for density units,

table, l-79 for permeabtlity. 26-14, 58-35

Conversion factors, Sl uniti, for vara, 58-20 general, 58-14. 58-22 memory joggers, 58-21 notation, 58-14 organization. 58-14 tables of, 58-15 to 58-21

Conversion of temperature-tolerance requirements, 58-7

Conversion of units in Darcy’s law, gases ar base pressure and average

tlowmg temperature. 26-13, 26-14 linear-flow liquids. 26-13 permeabtlity conversion factors. 26-14, 26-15 radial-flow liquids. 26-13

Conversion rules. 585 to 587

Conversion, tables of, angular velocity, l-76 areas, 1-74 capacities, l-74 density, 1-79 energy, l-78 heat, l-78 heat flow, l-79 lengths, I-7 1 linear velocity, l-76 masses, 1-75 power, 1-78 pressures, l-76 relative densities, l-80 thermal conductance, l-79 thermal conductivity, l-79 volumes, 1-74 work, I-78

Conveyances, tax consequences related to, 41-15, 41-16

Convolutions, 5-16 Cook Inlet, Alaska, 18-3 Cooling, creates hydrates, 14-3

cycles, 14-11 gas to condense hydrocarbon vapor, 14-5 in condensate removal, 14-1, 14-2 in gas-to-gas heat exchangers, 14-I 1 load, 14-10 with refrigerants, 14-Y

Copper electrodes, 39-21 Coquinas, 29-4, 29-8 C/O ratio, 50-l to 50-4, 50-9. 50-22,

50-24, 50-35, 50-36 Core analysis and core analysis data, 24. I,

26-l, 26-7, 26-22. 26-23. 36-3, 37-3. 39-18, 40-l. 40-3. 40-5, 40.12. 40.16, 40-19. 40-25, 41-8. 424. 446, 46-21, 50-26, 50-35 to 50.37, 51.31, 51-32, 52-26

Core analysis, average values, gravity, 27-5, 27-7, 27-l 1. 27-13, 27-15.

27-17. 27-19 interstitial water saturation. 27-3. 27-5,

27-7, 27-11, 27-13, 27-15, 27-17. 27-19, 27-20

oil saturation, 27-3, 27-5.27-7. 27-9, 27-1 I, 27-13, 27.15, 27-17. 27.19, 27-20

permeability. 27-3 to 27-6. 27-8. 27-10 to 27-17, 27-19, 27-20

permeability, 27-3 to 27-6, 27-8. 27-10 to 27-17, 27-19, 27-20

porosity, 27-3. 27-5. 27-7, 27-8, 27-l 1, 27-13, 27-15, 27-17. 27-19, 27-20

total water saturation, 27-5, 27-7. 27-I 1. 27-13, 27-15. 27-17

water saturation, reservoir. 27-20 Core analysis of different formations,

data from non-U.S. areas. 27-S data from U.S. areas, 27-9 liquid saturations, 27-8 percussion sidewall core data, 27-9 permeability, 27-l porosity, 27-l

Core-barrel sample, 56-7 Core barrels, rubber-sleeve, 56-3, 56-6 Core-sample resistivity cell, 26-28 CORIBAND log analysis, 49-37 Coring data, 4 l-8 Coring program,

core analyses, 46-2 I during and after project. 46-20 log analyses. 46-2 I microscopic studies. 46-2 1 mineral analyses of cores, 46-2 1 photographic and visual examination. 46-2 1 tracers, 46-2 I

Corner well producing cuts, 4424, 44-25

SUBJECT INDEX 25

Correction, of observed API gravity to API gravity at

60°F. 17-5, 17-6 of observed density to density at 15OC, 17-6 of observed relative density to relative

density at 60/60°F, 17-5, 17-6 of volume to 15°C against API gravity at

60”F, 17-6 of volume to 15°C against density at

WC, 17-6 of volume to 60°F against relative density

at 60/60”F, 17-5, 17-6 of volume to 15°C against thermal

expansion coefficients at 15”C, 17-6 of volume to 60°F against thermal

expansion coefficients at 6O”F, 17-6 Correction factor,

for dead-end oil IFT, 22-17 for gas flow, 33-2 for gas mixtures, 20-6

Correlation index, 21-9, 21-I 1 Correlation length, dipmeter, 53-10, 53-l 1 Correlation(s).

accuracv of, 22-89, 22-9 acot& log. 5 I-30 Baker and Swerdloff, 22-17 Beal, 22-14 to 22-16 Beggs and Brill. 46-7 Beggs and Robinson, 22-15. 22-16 between AOR and WAR, 46-19 between diaphragm and dynamic capillary

pressure methods, 26-25 between interstitnrl water and log of

permeability, 26-23 between maximum friction pressure and

maximum total flow rate, 6-19 between oil recovery and pore volume

burned, 46- 17 Boberg and West, 46-11 bubblepoint pressure, 21-9. 21-10, 22-5 to

22-9 carbon/oxygen, 50-l to 50-4, 50-9, 50-22,

50-24. 50-35, 50-36 Carr-Kobayashi-Burrows, 20-9, 20-10.

20-15. 20-16 chart, 40-22 Chew and Connolly. 22-14 to 22-16, 394 Cullender and Smith. 5-37 dead-oil viscosity. 22-14 dewpoint pressure, 21-10 to 21-15 Dykstra-Parsons, 44-9 empirical, of electrical properties, 26-29

to 26-3 I empirical. ultimate recovery, 40-13 equilibrium ratios, 39-15 flow temperature gradient, 5-26, 5-27 llutd flow. 44-20, 44-21 for approximating true vapor pressure, 14-13 for liquid and gas properties, 647 formation resistivity factor, 26-29 formatton volume, 21-15 to 21-20 gamma ray log. well-to-well. 50-2 gas-plus-liquid FVF, empirical, 6-38 Gates and Ramey. 46-15 geological, 51-29, 51-30 Hall, 26-8, 26-9 Hammerlindl’s, 26-8 K-value, 39-12 Lasater, 22-5 to 22-7, 22-9, 22-10 multiphase flow, 5-22, 5-25. 5-26. 5-38,

5-40, 34-37 to 3440 Muskat’s. 39-20 of capillary pressure data, 26-26 of solubility ratios with IFT, 47-14 of steam stimulation results, 46-11 of water saturation wtth permeability, 26-27 of well logs, 49-25. 49-26

oil formation volume factor, 22-10 to 22-13 oil systems, 22-l to 22-21 oil viscosity, 22-13 to 22-16 Organick and Gelding. 21-I 1 to 21-15 Orkiszewski, 34-37 to 34-40 permeability with tube wave data, 51-48 petrophysical, 28-13 Poettmann and Carpenter, 34-37 porosity compressibility with depth, 26-8 predicts cavitation damage, 6-36 productivtty index-permeability, 32-4 recovery factor from statistical data, 40-16 relatmg fuel content to API gravity, 46-16 resistivity index vs. saturation, 26-3 Sage and Old. 21-1 I sand-by-sand, 36-7 Showalter. 46-16 sour water stripper, 25-17, 25-18 Standing, 22-5. 22-8 to 22-1 I, 22-13, 22-14 Thodos, 20.11. 20-16 total formation volume, 21-15 to 21-20 transit time/pressure, 5 I-40 Trube. 20-I I, 20-16 undersaturated systems, oil viscositv. 22-16 Van der Knapp,. 26-8 vapor/liquid equilibrium, GC systems.

39-1 I t0 39.i3 Vasquez and Beggs, 22-7 to 22-13 velocity/porosity. 5 l-34 vertical multiphase flowing gradient, 6-43,

6-45 viscosity of gas. 20-9 water-saturated rock conductivity vs.

water conductivity, 26-30 waterflood recovery, 44-8. 4432

Correlative right. 57-2 Correlogram, dipmeter, 53-10 Corrosion, attacks, 9-l

by iron sulfide deposits. 1 I-IO cathodic protection, 19-3 1 caused by microbiological growth, 44-44 cell. 9-2 control procedures, 39-26 electrochemical, 3-36 in casing, tubing and cement jobs, 39-24 in dry desiccant dehydration, 14-21 in ethanolamine sweetening units, 14-22 in oil and gas separators. 12-3. 12-B. 12-40 in pipe. 14-17 in power oil plunger pumps. 6-33 in reverse flow systems, 6-5 in subsurface sucker-rod pumps, 8-9 in surface system and injection wells, 44-43 in water-injection systems, 24-2 increased with CO, increase, 44-42 minimized by internal coatings, 19-31 minimized by use of plastics, 44-47 on tank bottoms, 1 l-2 oxygen exclusion, 19-30 pits, 9-5, 9-8 to 9-10 problems. 6-55. 46-22 products, 6-48. 6-59 products carryover, 39-24 protection, 1 l-l. II-3 resistant alloys, 3-36 spectal metallurgy, 19-31

Corrosion of wellhead equipment, 3-35 electrochemical. 3-36 external, 3-36 internal, 3-36 material selection, 3-36 oxygen, 3-36 weight loss, 3-36 wellhead aspects, 3-35, 3-36

Corrosion inhibitors. 3-36, 6-5, 6-55, 9-I. 9-5. 9-8, 9-10, 9-13, 19-30, 19-32, 4445. 4446, 53-18. 54-6

Corrosion rates, 4441, 4442, 58-38 Corrosive fluids in separator, 12-40 Corrosive well fluids, 4-4. 4-5 Corrugated plate interceptor (CPI), 15-24 to

15-26 Cost accounting system, 19-32 Cost and profit margin relationship, 36-2 Cost/benefit analysis, 52-30 Cost comparison, production packers, 4-6 Cost-depletion allowance. 41-5, 41-13, 41-14 Cost justification, 52-29, 52-30 Cost of emulsion treating, 19-33 Cost of engine equipment. 10-16, lo-17 Cost-plus format, 15-32 Cosurfactants, 47-5, 47-11. 47-13 Cotton Valley Bodcaw reservoir, Texas,

39-19, 39-23 Cottonwood Creek field. Wyoming, 24-18 Coulter counter. 4445 Counterbalance, 10-I to 10-3, 10-6, 10-7, IO-9 Counterflow imbibition, 28-13 Counterweight, 9-2 Counting rate, gamma ray. 50-15, 50-16,

50- 19, 50.20, 50-28 Coupling failures, 9-9 Couplings and subcouplings. sucker rods,

9-3, 94 Coverage, 40-18, 44-9 Cox chart, 20-12, 20-13. 20-17 Cracked-gas/water system, 25-26 Cracking, 46-3 Crank-balanced units, 104, IO-6 Cray-IS computer, 48-17 Creep compaction, 28-l 3 Crestal-gas injection, 40-14. 43-3 Cricondenbar, 39-3 Cricondentherm, 23-6. 39-3. 45-2. 45-4 Crnerion of reservoir performance, 32-15 Critical breakthrough pressure, 44-36 Critical constants of hydrocarbons, 20.2, 20.3 Crrtical constants of solvent gases, 45-5 Critical-flow conditions. 13-53, 34-45 to 34-49 Critical-flow prover, 13-37. 13-45, 33-6.

33-7, 33-13 Critical gas mixture, 45-4 Critical gas saturation, 28-9, 34-3 I, 37-1,

37-3, 374, 48-13 Critical hydrate formation loci, 25-3 Critical locus, 23-3. 23-4. 45-3 Critical micelle concentration (CMC),

47-10, 47-l I, 47-15 Critical point, 14-2, 20-2. 23-l. 23-2, 25-1,

39-2, 39-3, 39-15 Critical pressure, 20-2, 20-3, 20.5,40-21,443 Critical ratio for flow prover, 13-37 Critical saturation, 49-30 Critical state, detimtion, 22-20 Critical temperature. 20-2, 20-3. 20-5.

22-20, 39-1, 39-4. 40-21, 45-5 Critical thickness, 49-13 Critical volume, 20-3 Critical wells m acidizing, 54-l I, 54-12 Critique of unsteady-state k, methods, 28-7 Cross imbtbitton, 48- I3 Cross plot of photoelectric factor vs.

density, 50-33 Cross rails, motor mounts, IO-19 Cross section of interactton. 50-6 Cross sections. 41-X Cross yoke, IO-2 Cross-yoke bearing, 10-3. IO-4 Crossbedding. 44-3

flow, 44-29 Crossflow, 39-19, 39-20, 447, 448, 48-10 Crossflow devices, 15-25, 15-26 Crosshead, IO-14 Crosslinked aqueous fluid. 55-6


Crosslinked gels, 55-5, 55-7, 55-8 Crossover flange, 3-7 10 3-9 Crossover seat, 5-16, 5-37 Crossover tool, 56-8 CRT screen display of fracturing data, 55-9 Crude-oil analysis, 2 l-7 to 21-9 Crude Oil Analysis System (COASYS), 21-9 Crude oil, API gravity loss vs. temperature,

19-9 Crude oil as semidiesel fuel, IO-16 Crude oil, definition, 12-3, 40-3 Crude oil, differences between natural gas, 362 Crude-oil disposal, 18-29, 18-30 Crude-oil emulsions,

description of treatment equipment. 19-16 to 19-28

economics of treating, 19-32 general references, 19-33, 19-34 introduction, 19-I methods used in treating, 19-6 to 19-15 operational considerations for treating

equipment, 19-28 to 19-32 sampling and analyzing, 19-6 theories of, 19-l to 19-6 treating equipment and systems, 19-15. 19-16

Crude oil, measuring, sampling, and testing, 17-l to 17-8

Crude-oil properties, 21-1 to 21-10 base, 21-1, 21-3 evaluation, 21-1, 21-2, 214

Crude-oil reservoirs, 39-l. 39-2 Crude oil, viscosity/temperature

relationships, 19-7, 19-8 Crude oil, volume loss vs. temperature, 19-9 Crude-oil/water emulsion, 19-6 Crude oils, temperature corrections for,

17-5. 17-6 Crude price, gross, 41-9 Crude stabilization, 40-13 Crude viscosity, effect of solution gas, 6-68 Crystalline porosity, 29-8 Crystallization temperatures, 25-19 Cuba, 58-20 Cube roots of certain fractions, table, l-18 Cube roots of whole numbers, table, l-7,

1-14 to 1-18 Cubes of numbers, table, l-7 to I-10 Cubic average boiling point, 21-12, 21-15 Cubic packing of spheres, 26-1. 26-2 Cullender and Smith correlation, 5-37 Cullender and Smith method of determining

BHP in gas wells, 34-24 to 34-26 Cumulative-gas/cumulative-oil curve, 40-32 Cumulative logarithmic diagram (S-plot),

56-6, 56-7 Cumulative oil production vs. GOR, 37-25 Cup-type plunger, 8-6 Current bedding, 53-12, 53-13 Current status of thermal recovery,

geographical distribution of projects, 46-3 major projects, 46-3 potential for incremental recovery, 46-3 production mechanisms, 46-4 reservoirs amenable to, 46-3 U.S. oil production by EOR, 46-3

Curve shapes, 49-12, 49-13 Custody transfer, 13-48 Customary units (English), 17-7, 58-2 1,

58-26 to 58-38 Cutoffs on engine installations, lo-19 Cut-out rams, 7-12 Cut test, 52-10, 52-14, 52-16 Cuttings evaluation, 52-19 Cuttings gas, 52-17 Cuttings gas analyzer, 52-1 I Cuttings, representative sample, 52-8, 52-9,

52-11

Cuttings sample geological log, 52-l Cyberdip log analysis, 49-37 Cyberlook, pass one log, 49-37, 49-38

pass two log, 43-39 Cycle efficiency of refrigerants. 14-10 Cycle frequency, maximum, 5-40 Cycle skipping, 51-16, 51-17, 51-24, 51-45 Cycles of steam stimulation, 46-9 Cyclic load,

derating factor, lO- 18 of oilwell pumping unit, lo-25

Cyclic load factor, lo-25 Cyclic steam injection, 46-21 Cyclic steam stimulation, 46-22, 48-46 Cycling operations, 39-4, 39-6, 39-15 to

39-24, 39-27 Cycling operations prediction with model

studies, 39-20 to 39-22 Cycling performance, CC reservoir,

areal sweep efficiency, 39-17 displacement efficiency, 39-18 effectiveness, 39-17 invasion efficiency, 39-17, 39-18 pattern (h&S-weighted) efficiency, 39-17 permeability distribution, 39-18 to 39-20 reservoir efficiency, 39- 17

Cycling to improve recovery, 40-4 Cyclohexanelwater system, 25-26 Cyclone separator (desander), 660 to 6-63,

12-20, 15-19 Cyclonic flow, 12-19 Cyclopropaneiwater system, 25-25, 25-27 Cylindrical shell equations, 12-38 Cylindrical tanks, 11-2

D

Daily production rate, continuous-flow gas lift, 5-54

Daily production rates, prediction of, 5-40 Dalton’s law, 20-4, 23-11 Damage,

by fluid jet, 8-7 ratio, 30-13

Damaged casing, 51-29 Damkiihler number, 47-21 Darcy head loss. 15-l Darcy’s law or equation, 26-10, 26-11,

26-13, 26-15, 26-16, 26-18, 26-19, 28-1, 28-2, 32-4, 35-10, 37-11, 39.20, 43-3, 44-9. 44-13, 44-17. 45-13, 48-2, 48-3, 56-4

Data acquisition system, 52-25, 52-27, 52-28 Data gathering and handling, 42-3 Data of varying precision, 58-6. 58-7 Data required to estimate recovery from

injection operations, 42-2 Data requirements for engineering analysis

of gas-injection operations, 43-17 Data requirements for GC cycling study,

39-22, 39-23 Data transmission schematic for MWD, 53-2 Date designation SI metric system, 58-22 Dead basins, 52-22 Dead-end oil IFT, 22-17 Dead-oil viscosity, 22-14, 22-15, 40-12 Dead oils, 45-5 Dead Sea, 24-19 Dead space of separator, 12-26, 12-30 Dead time of a process, 13-50 Dead-weight gauge, 33-6 Dead-weight regulator, 13-54 Dead-weight tester, 5-53, 13-37, 30-2 Dean-Stark extraction, 46-21 Debris or solids in well, ESP, 7-16, 7-17 Decay constant, exponential. 50-22 Decay times. 50-22

Decimal equivalents, table, 167 Decimal relation in SI metric system, 58-9,

58-22 Decimals of an in. to mm, table, 1-72 Deck drainage, skim pile sizing, 15-26 Decline-curve analysis, 40-27 Decline tables for constant-percentage

decline, 40-28 to 40-32 Decline-trend analyses, 40-l Decreasing-injection-gas-pressure installation

design method, 5-22 Deep dual laterolog (LLD), 49-19, 49-20 Deep marine sediments, 36-3 Deep Sea Drilling Project, 25-18 Deep-seated domes, 29-5, 29-6 Deepwater drilling, 18-10, 18-20, 18-21 Deerfield field, Missouri, 46-14 De-ethanizer, 14-8 Deferment-factor (weighted-average) charts,

41-23 Deferment factors, 41-5 to 41-8. 41-20,

41-21, 41-24 to 41-35 Definitions, for valuation of oil and gas

reserves, 40-3, 40-4 of fluid properties, 22-l of gas/oil ratio terms, 32-14 of petroleum reserves, 40-2, 40-3 of pump parts, 8-2 of water-drive oil reservoir terms, 38-1

Defoaming plates, 12-6 Deformations of acoustic waves, 5 l-2 Degasser boot, 19-22 Degassing, 19-18 Degassing efficiency, 52-2 Degassing elements, 12-22 Degradation of an oil accumulation, 24-17 Degrees and minutes expressed in radians,

table, l-42 Degrees of freedom, 25-1, 25-2 Dehydration by adsorption. 14-20, 14-2 1 Dehydration efficiency, 14- 19 Dehydration, storage tank used for. 19-18 Dehydration units, 14-17. 14-19 Dehydration with organic liquid desiccants,

14-17 to 14-20 Dehydrator, 14-10, 14-13, 14-18 Dehydrator pots, 13-53 Delaware-Childers field, Oklahoma, 463 Delaware effect, 49-11, 49-22 Delay rentals, 41-1, 41-13, 57-4, 57-5, 57-7 Deliverability of gas-lift well, 5-40 Deliverability of gas to compressor plant, 13-58 Deliverability of gas wells, 34-3, 34-9 Deliverability plot approach, 35-12 Deliverability testing, 35-10 Delta-bar sediments, 36-3 Delta-delta transformer, 10-30, 10-3 1 Delta-wye transformer, IO-30 Deltaic bar deposits, 36-4 Deltaic channel deposits, 36-4 Deltaic environment, 36-3 Demand-pressure regulator, 3-33 Demethanizer, 14-8 Demulsifiers, 17-2, 19-9 to 19-13. 56-5 Dendritic fingers. 45-7 Density, apparent liquid, definition of, 22-20 Density comparison method, 52-20 Density, definition of, l-80 Density difference (gravity separation).

12-8, 12-9, 12-19 Density equivalents, table, 1-79 Density gradient method, 52-20 Density in SI metric system, 58-24, 58-29 Density log, 44-3, 49-25, 49-26, 49-34,

49-38, 50-24, 51-14, 51-19, 51-31, 51-33, 51-43

SUBJECT INDEX

Density meters, installing and proving, 17-7 Density/neutron crossplot, 51-36 Density of crude petroleum, 17-5 Density of formation water, 24-14 Density of gaseous hydrocarbons, 20-3 Density of light hydrocarbons, 17-5 Density of liquid petroleum products, 17-5 Density of N&l solutions, 24-14 Density of natural gas, 20-14, 20-15 Density porosity, 50-31, 50-33 Density/pressure relationship, 26-12 Density, pseudoliquid, 22-2 to 224 Denton field, New Mexico, 6-24 Deoxygenating control equipment, 24-2 Dept. of Commerce, l-69 Dept. of Energy (DOE), 40-2, 46-16,

46-30, 46-31, 46-33, 46-34 Dept. of the Treasury, 41-15 Dept. of Transportation, 15-13 Departure curves, 49-7, 49-27 Depletion, 41-13, 41-16, 41-17, 47-21 to

47-24, 57-11 Depletion allowance, 41-13 to 41-15 Depletion-drive calculation, 43-13, 43-14,

43-16

Debletion-drive process, 42-5 Depletion-drive recoveries, 37-24

Depletion-drive performance, 37-16 to 37-18

Design standards of electric motors, 10-19, IO-20

Destabilization of emulsions. 19-6, 19-7 Desulfurization unit, 14-21, 14-22 Det norske Veritas, 1844 Detail engineering, 15-31 Detection efficiency, 50-12 to 50-14 Detection of nonhydrocarbon gases, 52-5 to

52-7 Detector resolution, 50-14 Deterministic analysis, 18-27, 18-28 Detrital, 29-6, 29-8 Detrital environment, 56-2 Detrital porosity, 29-8 Detrital reservoirs, 29-7, 29-8 Deuterium ion, SO-6 Development costs,

tangible and intangible, 41-l 1 well spacing, 4 I - 11

Development drilling, 36-2, 36-3, 36-6, 40-l Development, historical, thermal recovery,

46-3

oil and gas differences, 36-2, 36-3 prediction of performance, 36-9, 36-10

Development of waterflooding, 44-l Development plan for oil and gas reservoirs,

characterization of the reservoir, 36-3 to 36-9 introduction, 36-1, 36-2

Diesel index, 21-7 Diethanolamine (DEA), 14-21, 14-22 Diethylene glycol (DEG), 14-7, 14-18,

14-19, 25-19, 25-20 Differential compaction, 29-3 to 29-6 Differential gas liberation, definition, 22-20 Differential gas separation, 37-l Differential head loss, 13-3 Differential liberation, 40-6 Differential-opening pressure valve. 5-13,

D&&l age, 49-36 to 49-39 Digital computer program,

5-14, 5-43

14-16

Differential-pressure control valve, 6-63 Differential-pressure gradients, 34-42 Differential-pressure taps, 13-3, 13-8 Differential-pressure transducers, 16-6, 46-21 Differential process, definition, 22-20 Differential separation (vaporization), 12-32,

37-3, 45-8 Diffuser, 6-32, 6-35, 6-36, 7-3 Diffusion baffle, 19-24 Diffusion length, 50-I 1, 50-20, 50-21 Diffusion theory, 50-17 Diffusivity. 38-9, 58-34 Diffusivity equation, 35-1, 35-2, 35.10,

36-8, 38-l Digit, definition, 58-9

Depletion equation, 37-10 references. 36-10, 36-11 DigitaJ computer systems, 16-10 Depletion mechanism, 40-8, 40-10, 40-12, Development wells, 41-I 1 Digital computers, 40-10. 40-13

‘40-13, 40-15 Depletion performance, volatile oil

reservoirs, 37-22, 37-23 Depletion-recovery factors, 40-10, 40-11 Depletion technique,

dry gas reservoir, example problem, 36-3 gas reservoirs, 36-2, 36-3 oil reservoirs, 36-2

Depletion-type gas wells, 41-10 Depletion-type reservoir, 29-8, 40-8 to

40-12, 40-16, 40-32, 40-33 Depositional environment, 36-3 to 36-7 Depreciation, 41-11, 41-13, 41-21, 41-22,

57-l 1 Depression of metnstable dewpoint, 25-12,

25-14 Depth micrometer, 5-16 Depth of top gas-lift valve, 5-24 Depthoaraph, 30-7 Debating factors of motor, 10-24, 10-25, 10-31 Derivation of an orifice equation, 13-2, 13-3 Derivative response, 13-50, 13-52, 13-53 Derived units, SI metric system, l-69, l-71,

58-2. 584, 58-10, 58-11, 58-21 Derrick barges, 18-26 Desalting crude oil, 19-26, 19-27 Description needed for oilfield water

sample, 24-5 Design engineering, 15-3 1 Design features,

common to steamfloods and tirefloods, 46-17 pertaining to tirefloods only, 46-18, 46-19 pertaining to steamfloods only, 46-18

Design methods, intermittent gas lift, 542 Design of casing strings,

oil, water, and mud-weight factors, 2-1 safety factor, 2-l to 2-3, 2-34, 2-35 single-weight and -grade casing string,

2-1, 2-2 Design of gas-lift installation, 5-32 to 5-35 Design of hydraulic fracturing treatment,

55-9, 55-10 Design operating gas-lift valve depth, 5-54 Design properties for piping, 15-l 1 Design safety factors for casing, 2-l to 2-3,

2-32, 2-34, 2-35 Design slip of motor, IO-24

Developments in wellbore heat losses, 46-7 Deviation angle, 53-7 Deviation, definition, 58-9 Deviation factor, 39-7, 39-8, 39-10, 39-14,

39-23 Deviation of hole, 53-2, 53-3, 53-10, 53-17 Deviation survey computations, 53-7 Deviation surveys, 49-1, 53-1, 53-7 to 53-9 Dewatering of gas wells, 6-34, 39-15, 39-16 Dewpoint boundary, 39-3 Dewpoint chart, 25-11 Dewpoint curve, 14-l. 20-2 Dewpoint cycling, above or below, 48-7 Dewpoint depression. 12-20, 14-17, 14-18,

14-20 Dewpoint of a system, definition, 22-20 Dewpoint pressure, 22-20, 22-21, 23-3,

23-12, 39-5, 39-7 to 39-11, 39-13, 39-14, 39-16, 39-18, 39-23

Dewpoint pressure correlations, 21-10 to 21-15 Dewpoint reservoirs, 23-7 Dewpoint temperature, 14-l Dewpoint water content chart, 25-12 Dextran, 47-3 Diagenesis, 24-2, 24-20, 52-21 Diagenetic alteration, 50-37 Diagenetic history, 36-3 Diagenetic water, definition, 24-18 Dia-Log caliper tools, 53-18 Diamond cores, 27-9 Diaphragm BHP element, 30-6, 30-7 Diaphragm control valve, 16-4, 16-11 Diaphragm gas-engine starters, lo-19 Diaphragm motor oil-control valves, 12-6, 12-7 Diaphragm motor valve, 1349, 13-53 Diaphragm operators, 16-3 Diaphragm pressure, 13-54, 13-56 Diaphragm pump, 15-15 Diaphragm-&weight-loaded valve, 13-55 Diatomaceous earth filters, 15-20, 15-22,4447 Diatomic gases, 13-37 Dielectric constants, 16-7 Dielectric measurements, 5 l-19 Dielectric permittivity, 49-32 Dielectric strength, 7-3 Diesel engines, 6-1. 10-15, 10-16, 1845 Diesel fuel, IO-15

Digital signal-processing technology, 5148 Digital sonic logs comparison, 5143 Diglycolamine (DGA), 14-2 1, 14-22 Dikes, 11-l 1 Dilution caused by weighted-average

Permeability profile, 39-19 Dilution plane, 23-10 Dimensionless pressure values, 38-4 Dimensionless pressures for aquifer systems,

384 to 38-6, 38-12 to 38-19 Dimensionless water-influx values, 384 Dimensions,

definition, 58-9 of buttress-thread casing and coupling,

2-29, 2-59, 2-64 of casing long thread, 2-58 of casing round-thread height, 2-66 of casing short thread, 2-57 of chemical, electrical, and physical

quantities, 59-2 to 59-51 of external-upset tubing coupling, 243,2-66 of extra-strong threaded line pipe, 2-50 of extreme-line casing threading and

machining, 2-63 of integral-joint tubing thread, 2-65 of integral-joint tubing upset, 2-45 of line-pipe lengths, 247 of line-pipe thread, 247, 2-58, 2-62, 2-65 of line-pipe thread height, 2-62 of nonupset tubing coupling. 242, 2-66 of plain-end line pipe, 2-50 to 2-53 of round-thread casing coupling, 2-28, 2-58 of round-thread tubing coupling, 2-58 of threaded line pipe, 247, 2-58 of tubing round-thread height, 2-66

Din azimuth, 53-7. 53-9. 53-10 Dib vectors, 53-10, 53-12 Dipmeter, 49-25. 49-36, 49-37 DiPmeter logging,

application of dipmeter and directional data, 53-10 to 53-16

calibration, 53-8 computed dipmeter log, 53-9, 53-10 device, 53-6 interpretation rules, 53-12 introduction, 53-1, 53-7 oil-based muds, 53-8, 53-9


principles of TVD, TST, and TVT plots, 53-15. 53-16

survey computattons. 53-9 tools available, 53-8

Dtpmeter patterns, 53-10, 53-12 to 53-15 Dipmeter surveys. 49-I Direct-acting spring-loaded regulator, 13-55 Direct-acting weight regulator, 13-55 Direct costs (expenses), 41-11 to 41-14 Dnect-current (DC) motor, IO-21 Direct-fired heater, 19-2 I Direct hydraulic subsea control, IS-50 Direct lifting costs, 41-3 Direct line drive, 44 13 to 4416,4422,4433 Direct phase determination, 51-25 Direction of dip, 53-7 Dtrection of hole drift, 53-10 Directional drtlling, 18-30 Directional permeability effect. 44-25 Directional permeability test, 27-1 Directional surveys,

available tools, 53-3, 53-4 computation of results, 53-4 to 53-7 introduction. 53-l legal requirements, 53-4 MWD-data listing, 53-6

Directional well survey, 41-8 Directional wells, 53-l Disadvantages,

of batch-type meters, 32-10. 32-11 of positive-displacement meters. 32-11, 32-12

Discharge coefficient, 13-8 Discharge (return) gradient, 6-26, 6-29 Discharge piping, 15-17 Discharge pressure, 39-24 Discounted cash flow (DCF) method, 41-3,

41-17 to 41-22 Discounted future net cash income, 41-5 Discounted present worth, 44-5 Discovery allowable, 32-2, 32-3, 32-15 Discrete-piloted hydraulic control, subsea,

18-50 to 18-52 Discrete remote control, subsea, 18-50, 18-5 I Dispersed-gas drive, 37-I Dispersed-gas injection, 43-2, 43-8 to

43.15. 43-17 Dispersed-gas units, 15-27, 15-28 Dispersion. 15-22. 19-1, 45-6, 45-7 Dispersion curves. 51-13. 51-14 Dispersion of clay particles, 56-5 Displacement calculation procedures,

Dykstra-Parsons. 448, 449 frontal advance, 44-9 to 44-l I Stiles. 447. 448 Welge, 44-11. 44-12

Displacement efficiency, 39-9, 39- 15, 39-17. 39.18, 39-22, 39-23, 40.34, 43-3, 43-5. 43-6, 43-9, 4439. 45-6 to 45.10, 47-1. 41-2, 47-17

Displacement equations, 43-4 to 43-6, 43-8 to 43-10

Displacement fronts for different mobility ratios. 45-7

Displacement mechanisms, 36-10, 47-19, 47-20 Displacement meter systems, 17-4 Displacement of downhole pumps, 6-21,

6-24 Displacement process, 28-6, 28-7 Displacement-type controller, 13-5 I. 13-53 Displacement-type liquid-level controls, 13-53 Displacement volumes, 4423, 4424, 4428 Displacement volumes injected, 43-3, 43-7.

43-8 Disposal water. 24-5 Dissociation of water, 47- I8 Dissolved acid gases, 4447

Dissolved gas(es). 22-l. 22-20, 24-17, 40-3. 44-43

Dissolved-gas drive, 22-20. 442, 44-4 Dissolved-gas effect on oil viscosity, 22-14.

22-15 Dissolved-gas removal, 15-28, 15-29 Dissolved-gas systems, 2 l-18 Dissolved-gas units, 15-27 Dissolved salt, 24-7, 24-8 Dissolved solids, 19-1, 24-3, 24-15, 24-16,

24-18 to 24-20, 44-45 Dissolved-solids removal, 15-29 Distillates, I l-12, 12-32, 57-5 Distillation method, for water in crude oil, 17.5 Distillation, removing water from crude oil

emulsions, 19-15 Distributary channel sediments, 36-3 Distributary channels, 36-4, 36.6 Distributing piping specs., 15-12 Distribution of fluids in permeable

formations Invaded by mud filtrate, 49-5 to 49-7

Distribution system. 12-10, 12-l I Distribution transformers. types of, 10.30,

IO-31 Divalent cations. 47-13. 47-15, 47-21 Divalentihydroxide compounds, 47-20 Diverging vortex separator, 12-14, 12-20 Diverless subsea tree and running tools, 18-32 Diverting agents, 54-S. 54-10, 56-2, 56-3, 56-5 Division-order interest, 4 l-2 Dixon plates, 12-25 Dog-and-groove riser coupling, 18-15 Dogleg, 7-1, 7-9, 10-3. 10-6, 53-6 Dolomite,

acid reaction rate. pressure effect, 54-4 clays and silts in, 54-7 effect of corrosion inhibitor on acid

reaction rate. 54-6 laboratory tests for acidizing, 54-9 silica in crystal structure of, 54-4 treated with HCL, 54-2

Doiomitization, 24-18. 24-20. 26-2 Dosage, units and conversions, 58-30 Dose eqmvalent, unit and definition, 58-10 Double-acting downhole unit, 6-9, 6-20 Double-acting pump, 6-8, 6-9, 6-16, 6-18 Double-deck shaker, 52-8 Double-flanged head, 3-8 Double-port diaphragm motor valve, 13-57 Double-ported valves, 13-55, 13-58 Double-studded adapter, 3-9 Double-studded crossover flange, 3-9 Double-valve arrangements, 8-7 Double-welded butt joints. 12-40 Doughnut tubmg hanger. 3-39 Douleb oil held, Tunisia, 24-18 Dow Chemtcal Co., 54-l Downcomer pipes, 1 l-13 Downcomer/spreader, 19-19 Downdip gas flow, 43-I I Downflow filters, 15-20 Downhole assembly, MWD, 53-2 Downhole dtgitizer, 5 l-27 Downhole jet pump accessories,

dummy pumps, 6-48 pressure recorders, 6-48 safety valves, 6-48, 6-49 screens and filters. 6-48 standing valves, 6-48 swab cups (noses), 6-47. 6-48

Downhole pumps, closed power-fluid systems, 64, 6-5 displacement of, 6-21, 6-24. 6-25 handling of formation-fluid volumes, 6-67 installation. 6-2 jet free completions, 6-34

PIE ratto. 6-27 pressure recorders, 6-48 pressures and force balance in. 6-16 to 6-19 reciprocating, 6-5 I, 6-55 reverse-flow systems. 6-5 TFL installations. 6-6 types of installations, 6-2 to 6-4 with wireline-retrievable safety valve, 6-49

Downhole sensor. 53-4 Downhole sensor sub, 53. I Downhole steam generators, 46-4, 46-19 Downhole temperature profiles, 46-21 Downkickmg, 6-31 Downstream taps. 13-30 to 13-34, 13-37 Downtime analysis, 18-7, 18-8 Downtime gas. 52-17 Drag-body flowmeter, 32. I3 Drain cylinders, 12-12 Drainage area. 35-l, 35-5, 35-6, 35-13,

35-16 to 35-18, 36-8, 55-4, 56-l Drainage-area shape, 37-2 1 Drainage channels for tanks. 1 I-I I Drainage channels. mist extractor, 12-l 1, 12-12 Dramage curve, 28-5, 28.9. 28-l I, 2X-12 Drainage relative-permeability data. 28. I4 Drainage shapes. 35-4, 35-5. 35-16 Drainage tests. 26-24 Drawdown effects 39-25 Drawdown pressure. 30-10 to 30-13 Drawdown tests. 35-3, 35-4. 35-14, 35-15,

44-4 I Dresser Atlas, 49-2. 49-36, 49-37. 51-18 Drift, 13-50 Drift diameter, 3-12 to 3-14 Drill-time log, 52-l Drilling clause, 57-4. 57-5 Drilling contractor, I8- 16 Drilling data analysis. 52-28 Drilling efficiency, 52-28 Drilling engineer. 18-4 Drilling engineering services, 52-2, 52-27,

52-28 Drilling-equipment considerations offshore,

backup control systems, 18-15, IS-16 BOP. 18-11, 18-12 control systems, 18.15 extended water-depth capability. 18-16 flex joints, 18-12, 18-13 K&C systems, 18-15 marine riser. 18-14, 18-15 motion compensator, 1X-13. 18-14 reentry systems, 18-14 riser tensioner. 18-13 slip joints. 18-13

Drilling fluid, offshore, 18-12 to 18.14, 18-18, 18-41

Drilling funds, 57-l 1 Drilling, high-current, 18-21. 1X-22 Drilling models, 52.24 to 52.26 Drilling motion compensator, 18-14 Drilling mud, acoustic velocity in, 51-31 Drilling offshore,

mooring and riser analyses, 18-16, 18-17 operating manual and emergency

procedures, 18-16 planning and preparations, 18-3 to 18-5 rig selection, 18-5 to 18-16

Drilling operations, 18-28, 18-29. 18-31, 18-32. 18-39. 18-40

Drilling optimization. 52-29, 52-30 Drilling porosity, 52-26 Drilling riser, 18-16. 18-18, IX-34 Drilling vessels: see specific type Drilling wells, estimation of BHT, 31-6 Drillships, 18-3, 18-4. 18-7, 18.14. 18-15,

18-20

SUBJECT INDEX 29

Drillstem test or testing, 6-34. 18-20. 18-34, 24-3, 27-8, 30-S. 30-l 1, 30-13, 30-15. 41-8, 42-4. 48-8, 49-31

Drillstem tests, openhole, 53-17 Drillstring motion compensators, 18-13 Drip pots, 13-37, 13-53 Drip-proof motor, IO-26 Drips, 39-26 Drive mechanism, effects on recovery, 36-3 Drop method, surface-tension measurement,

24-16 Droplet size distribution. 15-23 Drowned gas wells, 39-16 Dry chambers for subsea completions, 18-31 Dry-desiccant dehydration, 14-20, 14-21 Dry-desiccant dehydrators, 13-56. 14-10, 16-15 Dry forward combustion, 46-l to 46-3,

46-14. 46-18, 46-19 Drv eas. 10.16. 39-l. 39-16. 39-18 to

-3;.20. 39-23, 39-24 Dry-gas breakthrough, 39. I7 to 39-20, 39-22 Dry-gas front, 39-17, 39-18, 39-21 to 39-23 Dry-gas injection, 39-16. 39-21 1 39-25,

.3%26 - Dry-gas reservoir, 35.3, 36-3. 39-l. 40-24,

40-25 Dry-gas/wet-gas cycling operation, 39-23 Dry-gas/wet-gas interfaces, 39-2 1, 39-22 Dry reverse combustion, 46-2 Dry vs. wet combustion, 46-18. 46-19 Dual-detector compensated-neutron device,

50-20 Dual-detector thermal device, 50-30, 50-32 Dual-element fuses, lo-28 Dual-fuel engines, IO-16 Dual induction-laterolog 8 (DIL), 49-15 to

49-20. 49-28 - Dual induction-laterolog log, 46-2 1 Dual intermittent gas-lift installations, 540,

545 Dual laterolog, 49-l I, 49-20. 49-23, 49-24,

49-28 Dual laterologigamma ray tools, 49-20 Dual-parallel-string installations, 3-l 1, 3-13 Dual-tube separator, 12-9, 12-10. 12-16. 12-18 Dual-vessel system, 6-63 Dual-water model, 49-38 Dual wells or zones, 6-7, 6-8 Dual-wing well manifold, 16-l I, 16-12 Dummy pumps, 6-48 Dummy valve, 3-35 Dump cycles, 19-30 Dump valves, 18-50, 19-20, 19-22. 19-23 Dun and Ros method, 34-37, 3440 Duplex pumps, 15-14 Dura Rod, 9-13 Duri field, Indonesia. 46-4 Dykstra-Parsons calculation. 44-8. 44-9 DykstraParsons coefficient, 47-17 Dykstra-Parsons method, 40-19, 44-7, 44-9 Dynamic amplification factor, 18-26, 18-27 Dynamic-capillary-pressure method, 26-24,

26-25 Dynamic elastic constants, 51-4 Dynamic lag, 13-51 Dynamic miscibility. 45-l. 45-2, 45-4.

45-5, 48-5 Dynamic positioning, 18-2, 18-10, 18-14,

18.20, 18-21 Dynamic stresses, 18-17 Dynamic viscosity, 24-16, 58-35 Dynamite, 56-l Dynamometer card analysis, 10-5, IO-6 Dynamometer cards, 10-6 Dynamometer test, 40-27

E

E-core transformer, 30-6 Early-time region (ETR). 35-3, 35-4, 35-6,

35-8. 35m I5 Earth resistivities, 49-l East Coalinga field, California, 46-18 East Texas area, 27-2. 27-3 East Texas field, 29-5. 29-6.40-2. 40.34,41-5 East Venezuela field, 46-16 Eccentric orifices, 13-45. 1348 Eccentricity. 6-69, 6-72 Echometer, 30-7, 32-6 Economic analyses, 39-10, 39-15, 44-32 Economic balance. 19-15 Economic considerations of stage separation,

12-33 Economic evaluation, 24-21, 44-7, 45-10 Economic justification of automation, 16-2 Economic limit, 40-12. 40-19, 40-20,

40-27. 40-32, 41-10. 41-11 Economic-limit rate. 40-25, 40-27 Economics. Impact of offshore leasing, 57-12 Economics, letter and computer symbols,

59-2 to 59-51 Economics of CC reservoir operations, 39-26 Economics of injection operations, 42-6 Economics of treating crude-oil emulsions,

19.32, 19-33 Eddy currents. 13-2. 13-36, 13-48, 19-12,

53-20, 53-22, 53-26 Edge water, 24-2 Edgewater drive, 40. I5 Edgewater encroachment, 28-4 EDTA, sequestering agent. 547 Effective annual interest rate, 41-25, 41-26 Effective decline rates, 40-27. 41-27 Effective formation permeability, 55-4 Effective gas permeability, 39-25 Effective grain volume, 26-4, 26-6 Effective hydrocarbon porosity, 40-25 Effective interest rate, 41-17. 41-20, 41-21,

41-26, 41-27 Effective isopermeability map, 39-22 Effective mobility ratto, 47-18 Effective molecular weight, 22-7 Effective permeability. 26-15, 28-l to 284,

28-6, 28-8, 28-13, 39-17, 4432, 44-33, 46-2 I

Effective porosity, 26-2 to 26-6, 28-2, 40-5, 55-4

Effective salmity. 47-13 Effective shear rate. 47-5 Effective stress, 51-30, 51-31, 51-35, 51-43 Effectiveness of cycling. 39-17 Efficiency factor in orifice equation, 13-3 Efficiency of cycling, 39-17 Efficiency of ESP system, 7-l Efficiency of gas lift, 30-14, 30-15 Efficiency of motor, IO-25 Effictency of permeability variation, 448 Effictency of separation, 12-21 Effluent fluids quality, 12-16 Effluent oil from separator, 12-15 Effluent water from’separator, 12-15 El Dorado field, Kansas, 46-14 Elastic collapse-pressure equatton. 2-55 Elasttc limit, 51-I. 51-2 Elastic limit of material, 2-46 Elastic moduli, 51-I to 51-3. 51-12, 51-30,

51-31, 51-43. 51-44, 58-34 Elasttc parameters. relationships among, 51-2 Elastic properties. 51-44 Elastic scattermg, 50-9, 50-10 Elastic transition zone, 2-55 Elastic wave propagation, 51-6, 51-8,

51-12. 51-14, 51-29. 51-49

Elastic wave velocities. 51-7 Elastictty.

characteristics of acoustic waves, 5 l-2, 5 introduction, 51-1, 51-2

Elastomeric hoses, 18-49 Elastomeric jomts, 18-13 Electric charge, unit and definition. 58-l I

58-23 Electric conductance, umt and definition,

58-l I, 58-23, 58-35 Electric dipole moment, 49-32 Electric generating systems, IO-2 I Electric inductance, unit and definition.

58-l I, 58-23 Electric-log analysis, 26-22, 26-25 Electric-motor valve operators. 16-3 Electric motors for oilwell pumping,

design standards. 10-19, IO-20 direct current (DC), IO-21 generating systems, IO-2 1 horsepower ratings of. IO-20 multiple-horsepower rated, IO-20 multiple-size rated. IO-2 1 performance factors of, IO-23 selecting size of, lo-21 single-phase type. IO-2 I ultrahigh-slip, lo-22 voltage frequency of, 10-21. IO-23

Electric porosimeter, 26-4 Electric potential difference. unit and

definition, 58-l I Electric power supply, ESP, 7-9 to 7-12 Electric pressure control, 12-39 Electric resistance, umt and definition.

l-3

58-l I, 58-23, 58-36 Electric-solenoid valves, 16-3 Electric-starter motors. lo-19 Electric submersible pumps (ESP).

application, 7-l. 7-2 general references, 7-17 handling. installation, and operation, 7-12

to 7-14 installation, 7-l. 7-2 performance curves, 6-35 references, 7- I7 selection data and methods, 7-9 to 7-12 system, 7-1. 7-2 system components. 7-3 to 7-9 troubleshooting, 7-14 to 7-17

Electric submersibles, 18-44 Electrical capacitance in electronic interface

controllers, 19-3 1 Electrtcal capacitance, unit and definition,

58-10, 58-23, 58-35 Electrtcal conductiwty in electromc interface

controllers, 19-31 Electrrcal conducttvity of flmd-saturated rocks,

fundamental concepts, 26-28, 26-29 introduction. 26-27. 26-28 resistivity measurement of rocks, 26-29

Electrical conductiwty, units and conversions, 58-35

Electrical distribution system, grounding of, 10-31, lo-32 open delta transformer, 10-30, IO-3 1 phase converters, types of, 10.35, IO-36 power factor and use of capacitors, IO-33

to IO-35 primary system and voltage, IO-29 secondary system, 10-29. IO-30 transformers, lo-30 voltage drop in, lo-32

Electrical logging, electromagnetic propagation tool, 49-32 to

49-36 focused-electrode logs, 49-18 to 49-22 fundamentals. 49-l to 49-7


general references, 49-41, 49-42 induction logging, 49-14 to 49-18 microresistivity devices, 49-22 to 49-25 nomenclature, 49-39 to 49-41 references. 49-41 resistivity logging devices, 49-l 1 to 49-14 SP log, 49-l& 49-l 1 the digital age, 49-36 to 49-39 typical log. 49-3 uses and interpretation of well logs, 49-25

to 49-32 Electrical one-line diagram, IS-45 Electrical parameters used in characterizing

porous media, 26-31 Electrical potential logs, 53-17. 53-19 Electrical properties of reservoir rocks,

empirical correlations, conductive-solids effect, 26-30, 26-31 introduction, 26-29 parameters used in characterizing, 26-31,

2632 resistivity of partially water-saturated

rocks, 26-31 Electrical resistivity measurement of rocks,

26-29 Electrical survey (ES), 49-l 1, 49-19 Electrical systems offshore,

code and regulatory authorities, 1844 distribution system, 18-4.5, IS-46 equipment enclosures, 1846 hazardous areas, 1846 introduction, 18-43, 1844 layout of facilities, 18-44 platform loads, IS-44 primary electric power, 18-44, 1845 secondary/back-up power, 18-45 wiring methods, 18-46

Electrically controlled valves, 16-3 Electrically equivalent diameter of invasion,

49-6 Electricity, units and conversions, 58-35,

58-36 Electrochemical corrosion, 3-36 Electrochemical potential, 49-8 to 49-10 Electrode array, 53-7 Electrofiltration potential, 49-10 Electrohydraulic control system, 18-l 1 Electrohydraulic subsea controls, 18-49 Electrohydraulic systems, 3-31 Electrokinetic effects, 28-1 Electrolvtic conduction. 26-28 ElectroGtic corrosion, ‘12-40 Electrolytic model, 39-20, 39-21, 44-17,

44-18, 4420, 44-21 Electromagnetic e-mode telemetry, 53-l Electromagnetic force (EMF), 53-16 Electromagnetic inspection devices, 53-17,

53-19 - . Electromagnetic propagation log, 49- 1, 49-2 Electromagnetic propagation tool (EPT)‘“,

49-32 to 49-36 Electromagnetic radiation, 50-3 Electromagnetic thickness log, 53-21 Electromagnetic thickness tools, 53-19 to

53-2 1, 53-23 Electra-mechanical timers, 164 Electromotive force, 58-11, 58-23, 58-35 Electron density, 50-16, 50-17 Electron-density index, 50-7, 50-26 to 50-28 Electron microscopy, 27-1 Electronic-casing caliper log, 53-19 Electronic chart scanners, 30-2 Electronic computers, 40-9 Electronic (solid-state) controller, 16-4 Electronic interface controllers, 19-31 Electronic model, 39-20 Electronic timers, 5-55

Electropneumatic operators, 16-3 Electrostatic coalescing, 19-13 Electrostatic coalescing treaters, 19-25, 19-26 Electrostatic emulsion treaters, 19-2, 19-10,

19-13. 19-25 to 19-27, 19-31 Elemental models, 46-1 I to 46-13 Elevated separator. 12-17 to 12-19 Elf Aquitaine, 46-27, 51-25 Elk Basin field, Wyommg, 26-23, 39-16 Ellipsoidal head equations, 12-38 Elongation,

of API body and bonnet members, 3-2, 3-3 of API casing and liner casing, 2-2 of API tubing, 2-37 of line pipe, 246 of sucker-rod types, 9-5

Embayments, 29-7 Embedment, 55-S Emergency disconnect conditions, 18-21 Emergency power, 1845 Emergency procedures offshore, 18-16 Emergency shutdown system (ESD), 3-33,

3-34, 18-47, 18-48 Emergency venting of storage tanks, 11-7 to

1 l-9 Empirical correlation factor, 27-8 Empirical equations, ice movement rate and

shape, 18-39 Emulsification of oil, IO-13 Emulsified water, 19-3 Emulsifying agent, 19-2 to 19-5, 19-9, 19-14 Emulsion breakers, 19-10, 46-22 Emulsion-breaking agents, 56-2 Emulsion conditions, ESP chart, 7-16 Emulsion, definition of, 19-l Emulsion, effect on oil viscosity, 6-27 Emulsion flood, 47-2 1 Emulsion formation, 47-19 Emulsion plugging, 6-56 Emulsion treater, I l-12, 12-3, 124, 12-13 Emulsion-treating equipment, 19-15, 19-16,

19-21. 19-27 to 19-32 Emulsion treating, overall system

performance, 19-33 Emulsion-treating system, 19-6, 19-7, 19-9,

19-11, 19-13, 19-15, 19-16, 19-30, 19-32 Emulsion viscosity, 6-67 Emulsions,

as mixed-base fracturing fluids, 55-5, 55-7 chances of forming, 8-6 decreases injection cycles/day, 5-40 effect of silicate control agents, 54-7 effect of surfactants, 54-7 gas lift can intensify, 5-2 in lirefloods and steamfloods, 46-2 1, 46-22 prevents application of gradient curves,

5-25 Emulsions, methods used in treating.

agitation, 19-12, 19-13 centrifugation, l9- I5 chemical demulsitier, 19-9 to 19-12 distillation, 19-15 electrostatic coalescing, 19- I3 fibrous packing, 19-14 filtering, 19-14 gravity settling. 19-14, 19-15 heating, 19-7 to 19-9 water washing, 19-13

Emulsions theories: See Theories of emulsions Enclosed motor, totally. lo-26 Enclosures for motors; 10-26, IO-27 End effects, 28-3, 28-5. 28-7 End-to-end flowline valves, 3-12 to 3-14 Endicott development, 18-3 Endogenetic subsurface water, definition, 24-19 Endpoint displacement data, 28-8 Endpoint mobility ratio, 47-l

Endurance limit, 9-l I Energy balance, 13-I. 34-36, 46-12 Energy-balance equation, 34-I) 34-2. 34-9 Energy, definition, 22-2 1 Energy equivalents, table, 1-77 Energy loss, 13-2, 13-3 Energy relationships for flowing fluid. 34-1,

34-2 Energy, SI unit for. 58-5. 58-l 1, 58-23,

58-24, 58-32 Engine displacement, 6-30 Engine efficiency, 6-3 1 Engine selection,

calculations for, IO-17 to lo-19 equipment life and cost, 10-16, IO-17 fuel availability, lo- 16 horsepower, IO-17 installation, lo-19 safety controls, lo-17

Engineering, analysis, 42-3 appraisal method, 41-2. 41-3 computer simulation methods, 36-7 in developing oil and gas reservoirs, 36. I,

36-6 to 36-8 interference testirg, 36-7, 36-8 material-balancp studies, 36-7 net-pay/net-connected-pay ratio, 36-7

England, 18-25 Enhanced oil recovery (EOR), 23-l. 23-7.

24-16, 25-1, 25-14, 46-3, 47-1, 47-2, 47-6, 47-7, 47-18, 47-22, 48-2, 48-4, 48-6, 48-8

Enhanced-oil-recovery (EOR) projects, 19-28 Enhanced-recovery methods, 404 Enhanced-recovery operation, 5 l-42 Enos Creek field. Wyoming, 24-18 Enriched-gas drive, 45-2, 45-3, 45-5 Environment, 11-4, 13-1 Environmental conditions (forces), 1 l-6,

18-1, 18-3, 18-4, 18-7 to 18-10, 18.17, 18-21, 18-25, 18-31, 18-36, 18-44, 1847

Environmental conditions, ice characteristics, 18-38, 18-39 ice loading, 18-39 permafrost, 18-39 waves, 18-39

Environmental corrections, gas effect, 50-30, 50-31 matrix effect, 50-28 to 50-30 shale effect, 50-31 to 50-33

Environmental criteria, 18-26 Environmental factor, 1 l-8 Environmental impact, 24-9 Environmental load predictions, 18-22 Environmental regulations, 44-41 Environments, wellhead equipment, 3-36 to

3-39 Epigenetic interstitial water, definition, 24-18 EPILOG log analysis, 49-37 Epipressure contours, 44-15, 44-16 Epithermal counting rate, 50-20, 50-29 Epithermal detector, 50-19, 50-20, 50-2 1 Epithermal diffusion coefficient, 50- 19 Epithermal matrix effect, 50-30 Epithermal neutron flux, 50-15, 50-20 Epithermal neutrons. 50-S. 50-9. 50-14,

50-17, 50-19, 50-30 Epithermal porosity device, 50-28, 50-32 Epoxy resin coating, 11-6 Epoxy thermoset resin, 9-12 Equal-payment-series present-worth factor,

41-25 Equalizer for tank battery, I l-9 Equalizing valves, 3-29 Equation factors for collapse pressure

equations, 2-54 to 2-56

SUBJECT INDEX 31

Equation, general for critical-flow prover, 13-45

Equations for computing subsurface pressures, 33-15

Equations for jet pumps, 6-36, 6-37 Equations for oil and gas separator,

gas capacity, 12-23 sizing for &IS capacity, 12-23 to 12-25

Equations for valuation methods, 41-18.41-19

density, 1-79 energy, 1-11 length, l-7 1 mass, 1-75 power. 1-78 pressure, 1-77 velocity, 1-76 volum& l-73 work, 1-77

Equations for water-drive reservoirs, 38-I to Erection of pumping units, 10-7, 10-12 38-4 Erosion, pump cavitation damage, 6-36

Equations

to 20-8, 23-10, 23-12, 23-13, 25-8, 25-16, 39-16, 48-4, 48-5, 48-9

in

Equilibrium behavior, GC systems, 39-2 to

Sl metric system, 58-13

39-4

Equations of state (EOS), 14-16, 20-4, 20-6

Equilibrium constants, 14-16, 23-l I, 37-23 Equilibrium data sources, 25-l to 25-4 Equilibrium dewpoint, 14-18 Equilibrium dewpoint locus, 25-1, 25-2 Equilibrium dewpoint water content, 25-2 Equilibrium flash calculations, 12-33, 12-34,

Erythorbic acid, reducing agent, 54-7 Escalation clauses, 41-3, 41-9 Esso. 46-4, 46-14

Error anaiysis,

Estimating reserves. 40-l Ethanelwater system, 25-17, 25-18, 25-24,

- 50-28 Errors in basic data, 38-7, 38-8

14-16 Equilibrium flash separation, 14-16 Equilibrium gas. 39-7, 39-8, 39-14 E&libriumg&saturation,40-11,40-12,43-11 Equilibrium phase diagrams, 23-1, 45-2 Equilibrium ratios, 21-11, 21-16, 23-1 I,

25-5, 39-6, 39-9, 39-11 to 39-13, 39-15 Equilibrium vaporization constants, 46-12,

46-37, 46-39 Equilibrium vaporization ratios. 37-23 Equilibrium water dewpoint, 14-18 Equipment coordination, surface/downhole, 4-1 Equipment enclosures offshore, 18-46 Equipment for control of oiltield motors,

handoff-auto switch, lo-27 line disconnect switch, lo-27 local remote switch, lo-27 motor starter contactor, IO-28 programmer, 10-27, IO-28 sequence-restart timer, IO-27

Equipment selection, reciprocating pumps, 628 Equipment used in emulsion treating,

clarification of water produced, 19-28 desalting crude oil. 19-26, 19-27 electrostatic coalescing treaters, 19-25,

19-26 EOR projects, 19-28 free-water knockouts, 19-17, 19-18 horizontal treaters, 19-23 to 19-25 reverse emulsions, 19-27 settling tanks, 19-18 to 19-22 storage tanks, 19- 18 vertical treaters, 19-22, 19-23

Equivalent circular pipe, 34-27 Equivalent conductivity, 49-34 Equivalent formation-water resistivity, 49-l 1 Equivalent hydraulic gradient. 26-l 1 Equivalent length of &es and fittings, 15-4 Equivalent limestone porosity, 50-28, 50-30 Equivalent linear permeability. 26-18 Equivalent liquid permeability, 26-18, 27-1,

27-8 Equivalent methane in air (EMA), 52-3 to

52-5 Equivalent molecular weights. modified

weight average. 21-12 to 21-15 Equivalent mud density (EMD), 52-25 Equivalent proton masses (EPM). 24- 19 Equivalent slowing-down length, 50-29 Equivalent water conductivity. 49-39 Equivalent wellbore radius, 35-4 Equivalents, tables,

areas, 1-73 capacity, 1-73

25-27 Ethanolamine, 14-21 Ethylene density, 17-6 Ethylene glycol (EG), 14-7, 14-18, 14-19 Ethylene glycol, hydrate inhibition, 25-19,

25-20 Ethylene glycol monobutyl ether, 54-7, 56-5 Ethylene/water system, 25-24, 25-27 Ethylenediaminet&raacetic acid (EDTA), 56-2 European countries, concrete gravity

structures, 18-23 Evaluation of fracturing prospects, 5 l-45 Evaporation method of capillary-pressure

measurement, 26-24 Evaporation, preventing, 11-12, 11-13 Evaporites. 49-25 Evinper-Muskat equation, 34-3 I Example problems:

casing, tubing, and line pipe. 2-36. 2-37. 2-55, 2-56 -

. .

cmde-oil properties and condensate properties and correlations, 21-15 to 21-20

electric submersible pumps, 7-17 estimation of oil and’gas’reserves, 40-8,

40-9, 40-12 to 40-14, 40-16, 40-17, 40-3 1

gas-condensate reservoirs, 39-10, 39-11, 39-23, 39-24

gas lift, 5-4 to 5-8, 5-10 to 5-12, 5-15, 5-20, 5-25, 5-26, 5-29 to 5-37. 546. 5-47, S-49, 5-50, 5-52

gas measurement and regulation, 13-8 gas properties and correlations, 20-13 to

20-17 hydraulic pumping, 6-20, 6-21, 6-24,

6-29. 6-30, 6-44 to 6-46 miscible displacement. 45-10 to 45-13 mud logging, 52-29 phase behavior of water/hydrocarbon

systems, 25-13. 25-14 properties of reservoir rocks, 26-3, 26-5,

26-6, 26-14, 26-15, 26-17, 26-26, 26-27 pumping units and prime movers for

pumping unit, IO-8 to 10-11, 10-18, io-14. io-21 to 10-24, IO-31

solution-gas-drive oil reservoirs, 37-24, 37-25

subsurface sucker-rod pumps, 8-5 sucker rods, 9-4 water-drive oil reservoirs, 38-5 to 38-7 well-performance equations. 35-7 to 35-9,

35-13. 35-14, 35-19, 35-20 wellbore hydraulics. 34-8, 34-9, 34-23 to

34-26. 34-30, 34-32 to 34-35, 34-41 to 3445

Excelsior packs, 19-23, 19-31, 19-32 Excess-flow valves, 3-29 Excitation, BHP gauges, 30-5, 30-6 Executor, definition. 57-3

Exhaust-gas turbocharger, 15-16 Exhaust power fluid, 6-25 Exogenehc subsurface water, definition, 24-19 Exothermic reaction, 31-6 Exotic metals for pipe, 15-l 1 Expander, 14-8 Expansion-drive gas reservoirs, 40-26 Expansion factor, 13-2, 13-8, 13-26 to 13-34 Expansion separator or vessel, 12-1 Expansivity, 24- I5 Experimental procedure,

steady-state k, methods, 28-3 to 28-7 unsteady-state k, methods, 28-7

Exploration geologists, 18-3 Exploration hazards, 46-22 Exploratory well, 4 I-I 1 Explosion proof, 3-34 Explosion-proof motors, 10-27, 1@36, IS-46 Exponent of backpressure curve, 33-5 to

33-13 Exponential-integral solution, 35-3, 35-4 Exponentials, table, l-55 Extended flanged outlets, 3-3 Extended flanges, 3-8 Extended water-depth capability, 18-16 Extension nipple, 8-1, 8-4 Extensive properties. definition, 22-21 External boundary conditions, definitions, 38-I External coatings, Il.6 External corrosion, 3-36, 18-33 External gas-injection pressure maintenance,

43-16 External-upset tubing, 2-38 to 245,2-64. 2-66 Externally adjustable secondary seal, 3-6 Extra-strong threaded line pipe, Z-46, 2-50 Extracting-liquid drive, 45-5, 45-6 Extraction method for determining sediment

in oil, 17-5 Extraction methods for determining water

saturation, 26-22 Extraction of minerals, 24-20 Extraneous materials in well fluids. 12-3 Extreme-line casing, 2-1, 2-4, 2-6, 2-8,

2-10, 2-12, 2-14, 2-16, 2-18, 2-29 to 2-31, 2-62 to 2-64, 2-67, 2-68

Extreme-line casing joint, 2-5, 2-7, 2-9, 2-11, 2-13, 2-15, 2-17, 2-19, 2-60, 2-63, 2-67 to 2-72

Extruded-plastic system, 15-10 Exxon Co. U.S.A., 16-13, 47-22 Exxon Corp., 20-S

F

“F” Pairs log analysis Facies, 29-5, 29-8 Facilities,

for fireflood, 46-20 for steamflood, 46-19, 46-20

Facility throughput, 58-25, 58-30, 58-31 Factor analysis, 24-20 Factor, gas-pressure-at-depth, 5-5, 5-6 Factors affecting oil viscosity, 22-14 Factors affecting permeability

measurements, gas slippage. 26-18 overburden pressure, 26-19 reactive fluids, 26-18, 26-19

Factors contributing to vapor and gravity losses in tanks,

agitation, 1 l- 12 breathing, 11-12 filling, 11-12 storage size, 1 l-12 surface area, 11-12 tank pressures, 11-12

37 PI:1 IN,1 I:lIM I:N(;INI:I.HINf, IIASl,l!r,~,K

temperature. I I- I2 vapor prewlre, I I I2

Factors for test-preshurc cquationh. 2-63 Factors in design of injection opcratlons. 42-2 Factor> in evaluation oI permeability l’rom

other parameter.\. 26-19. 26-20 Factory-baked coatmgh. I I-I Fail-safe hydraulic actuatow 18-3 Fail-safe valves. 3. IX Failure diagram. 9-4 Failure5 of sucker rods, 9-8. 9-9. 9- I3 Faw market value. 40-I Fair-market-value determination, 41-2. 4 l-3.

41-S. 41-S Fanning friction factor, 34-24 Fanning‘s equation. 26-10 Farmouts. 57-9. 57-10 Fathometer. 18-5 Fatigue analysis, IX-27 Fatigue cracks or cracking. 9-l. IS-16 Fatigue damage, 18-27 Fatigue failure. 9-9. IS-21 Fatigue life. 9-l I Fatty amine compounds. 44-45 Fault traps. 29-3 Feasibility analysis, 39. I7 FED DDL wellsite analysis. 49-37 Federal excise taxes. 41-l. 41-3, 41-4,

41-9. 41-12 Federal income taxeb. 41-5. 41-6. 41-S. 41-12 Federal Power Commission (FPC) approval

certificates. 4 l-9 Federal Register, 57-12 Federal taxes. 41-5. 41-7, 41-12 to 41-16,

44-5 Fee ownership,

control, 57-2 definition, 57-l

Fee simple interest, 41-I Fence diagram, 45-8, 45-9 Ferric hydroxide, 56-3 Ferrous sulfide precipitation, 54-7 6FF28 IES tool. 49-15 6FF40 IES logs and tool, 49-15.49-17, 49-18 Fiber-reinforced plastic pipe, 15-10 Fiberglass casing and tubing, 4446 Fiberglass filaments, 12-12 Fiberglass-lined steel tanks, 19-31 Fiberglass-reinforced polyesters (FRP’s), 11-9 Fiberglass/steel rod string, 9-12 Fiberglass sucker rods,

application, 9-12, 9-13 body. 9-12 care, handling. and storage, 9-13, 9-14 chemical and mechanical properties, 9-l I end-fitting grades, 9-12 expected life, 9- I3 failures, 9-13 general dimensions, 9-l 1 introduction, 9-10 manufacture of. 9-12 physical dimensions, 9-l 1 rod-body-to-steel connector-joint design, 9-12 stress-range diagram, 9- 13

Fibrous filters. 39-26 Fibrous packing, 19-14 Fibrous-type nust extractors, 12-12 Field behavior vs. predicted performance,

waterfloodmg, 44-31 Field capillary number, 47-17 Field compressors, control of, 13-57 Field development, 36-1, 46-l 1 Field development plan offshore, I S-25, IS-26 Field engineers, 39-l Field examples, deviation survey, 53-7, 53-8 Field facilities.

tireflood.

pencratlon and inlcclion. 4h-IY water trcatnacnt. 40-20

Field-fil~crcd hampIe. 24-4 Field flltcring cqulpmcnt, 24-4 Field instrumentation l’or SCADA. 16-9 Field operations ol’fshorc.

drillstem testing, IX-20 introduction. 18-17 locatwn, establishing. I& I8 plug and abandonment, IS-20 running BOP, IS-18 to IS-20 running ZO-in. casing. IX-18 running 30.in. casing. IS-18 spudding the well, IS-18

Fieid performance, 48-6. 48-7 Field-performance data. 37-7 Field &lot tests, 48-13 Field pilots, 46-I I Field projects. thermal recovery,

dry vs. wet combustion, 46-18, 46-19 reservw performance, 46-14 to 46-17 screening guides, 46-13

Field response, MP ilooding, 47-16 Field results,

chemical flooding, 47-21, 47-22 foam injection, 47-9 high-pH processes, 47-21. 47-22 polymer floods, 47-6

Field sampling. CC reservoir, 39-5 Field separation conditions, optimum, 39-5 Field titration kit, 54-3 Field-welded tanks, 11-2. 1 l-9 Filing losses, storage tanks, I I-I 1 to 1 l-13 Fill-up, 44-9. 44-34, 44-39. 4441, 44-46 Film thickness of coatings, II-4 Filter/separator. 12-l. 12-2 Filter-type mist extractor, 12-l I Filtering, 12-8, 12-11. 19-7, 19-14, 19-28 Filters, 15-20, 15-21 Filtration, 15-20 Finger in gas displacement, 43-7 Fingering of miscible slug, 45-6 Finite-closed aquifer, 38-5, 38-6, 38-8,

38-13. 38-18 Finite-closed boundary, 38-1 Finite-difference equations, 48-l, 48-2, 48-13 Finite-difference method, 43-13 to 43-15 Finite-difference simulator, 45-10 Finite-element simulator, 45-10 Finite linear aquifers, 38-2 Finite-outcropping aquifer, 38-5, 38-8,

38-10, 38-11. 38-14 to 38-19 Finite-outcropping boundary, definition, 38-l Fire detectors and detection systems, 18-47 Fire hazard. IS-46 Fire tests for valves, 3-38 Fire tubes. 19-28 Fireflood, 46-1, 46-3. 46-4, 46-13 to 46-28 Fireflood pots, 46-13 Firewall, 11-9, 11-11 First-contact miscible flooding, 45-1, 45-2,

45-5 First law of thermodynamics, 34-I First-stage separator gas, 39-6, 39-10 Fishing characteristics of packers, 4-6 Fissility, 52-20 Fitting factor, 38-7 Five-point difference scheme. 48- 1 I Five-spot pattern, 43-2, 43-8, 44-1, 448,

4413 to 44-20, 44-22. 4423, 4425, 44-26 to 4429, 4433. 44-34, 44-37, 44-38. 4440, 45-7, 46-13, 46-17, 46.18, 46-23. 46-25. 46-26, 46-28. 46-30. 47-10

l,lVC V‘IIYL. milnlll~ltl, 11 17 l,~xctl choke, 5 S4 Fixed drilling platlorrn\, l&2, IX-24 Fixed-pad Kingsbury Ihrwt bcarmg, 7-3 Fixed platli)rm drilling, ?-3X, 3.3Y Fixed pump mstallation. 6-2. h-3 Fixed-roof tanks. I l-2 Flagging the bottom valve, gas IlIt, 5-44 Flame arrcstcrs, I l-6, I I-X to I l-10. 19-2X Flame ionization detector (FID). 52-4. 52-5.

52. IO, 52. I I Flammable gases, IO-36 Flammable liquids, IO-36 Flange data, 3-16 to 3-25, 3-27 Flange taps, 13-3 to 13-8, 13-14 to 13.19,

13-26, 13-27. 13-30, 13-31, 13-33, 13-34 Flank waterflood, 4% I3 Flare boom, IS-20 Flash calculations for separators, 12-33.

12-36, 12-37 Flash calculations. multlcomponent. 40. I3 Flash chamber. trap or vessel, 12-l Flash distillation system. 19-15, 19. I6 Flash gas liberation. definition, 22-20 Flash gas separation. 37-l Flash liberation process. 32-7 Flash point, I l-7 to I l-9 Flash process, definition. 22-20 Flash separation (vaporization), 12-32. 21-4,

37-3. 45-8 Flat-bottom tanks, I l-2 Flat-plate orifice, 13-2 Flat-sided tanks (non-API), 1 l-2 Flex joints. 18-12. 18-13. 18-19, 18-25 Flexible pipe. 18-36, 18-37 Flexural failure, 18-39 Float-actuated pilot-operated valve. 13.53 Float-and-sink (density) method, 52-20 Float cages, 13-54 Float-operated controller, 13-54 Float-operated controls, 12-18 Float-operated mechanical oil valves. 13-53 Float-operated pilot, 12-5, 12-39 Float-operated trap, 13-58 Float traps. 13-53. 13-54 Floating barges, IS-34 Floating drilling operation or system. 18-3,

18-11, 18-14, IS-16 Floating drilling rigs or vessels, 18-2, 18-6.

18-10, 18-13, 18-17. 18-20, 18-31, 18-34 Floating drilling, subsea systems. IS-19

Floating platforms. 3-38 Floating drilling vessels, 3-39 Floating production facilities (FPF).

applications, 18-34, IS-35 disposal of oil, gas, and water, 18-36 semisubmersibles vs. tankers, 18.35, 18-36 under Coast Guard jurisdiction, 18-44

Floating-roof tanks, 11-2. I l-6 Floatless level controller, 13-53 Floatless level controls, 13-54 Flocculation, 19-9, 19-10, 19-28. 44-46 Flood coverage, 39-18, 44-18 Flood efficiency. 39-18, 44-46 Flood fronts, 4416 Flood pot tests, 40-16. 40-17 Florida, 24-20. 24-21, 29-7, 29-8, 44-36 Flotation, 15-20, 19-28 Flow-after-flow, 33-4 Flow channels, 26-10. 55-l Flow coefficient, 34-3 I Flow computer. 5-53 Flow conductivity. 28-2 Flow-control devices, safety shut-in systems.

control systems, 3-31. 3-33. 3-34 introduction. 3- I8 production platform, 3- I9

SUBJECT INDEX

regulations, 3-34 sensors, 3-34 subsurface safety valves, 3-26, 3-27,

3-29, 3-31 surface safety valves. 3-21 with hydra&c and pneumatic valves, 3-20

Flow-control valve, 16-l 1 Flow-direction change to remove oil from

gas, 12-9 Flow m annulus. 41-42 Flow in tubing. gas, 34-9 to 34-27 Flow-measurement pulsed-data transmission

systems, 174 Flow nozzle flowmeter, 32-13 Flow provers. 32-14 Flow rate, eqmvalent total, 35-2 Flow rate. units and conversions, 58-31 Flow regimes. 34-36 to 34-38, 34-40 Flow-strmg sizes, table, 34-23 Flow-string weights, table. 34-23 Flow surges, 12-20 Flow systems of combinations of beds,

26.14, 26-15 Flow systems of simple geometry,

horizontal flow. 26. I I, 26-12 radial flow, 26-13 vertical flow, 26-12. 26-13

Flow-temperature gradient correlation, 5-26, 5-21

Flow-test data on a well, 30-l I 10 30-13 Flow through chokes. 34-45. 3446 Flow through pores of various sizes. 54-10 Flow velocities for pumps, 15-17 Flow velocity change to remove oil from

gas, 12-9 Flow velocity. effect on acid reaction rate, 54-5 Flowing BHP. gas, calculation of, 34-9 to

34-27 Flowmg gas column, 34-9 Flowing gas wells, 34-23, 34-29 Flowing-pressure-at-depth traverse. 5-23, 5-26 Flowing pressure gradient, 5-l. 5-32, 5-43.

44-33 Flowing pressure gradient curves, 5-25,

S-26, 5-30, 5-43 Flowing pressure surveys, 5-43 Flowing pressure traverses, 5-21, 5-23 Flowing production pressure at depth, 5-45 Flowing production pressure. gas-lifl valve.

5-17 to 5-19, 5-21, 5-23, S-24, 5-26 to 5-28, 5-30 to 5-33. 5-35. 5-36. 5-41 to 543, 545, 546, 5-48

Flowing production transfer pressure, 5-33, 5-34, 5-36

Flowing temperature adjustment factor. 33-15 Flowing temperature factor, 13-3. 13-13 Flowing wellhead backpressure, 5-54 Flowing wellhead production pressure, 5-53 Flowlme backpressure, 6-25 Flowline breaks. I6- 11 Flowlme choke. 5-53, 5-54 Flowline headers, 3-21 Flowlme pressure, 6-25, 6-43 Flowline-pressure term, 6-28 Flowline sampling. 24-3, 24-4 Flowline temperature, 52-22 lo 52-24 Flowlines m subsea completions, 18-33.

18.34, 18-36 to 18.38 Flowmeters, 32-6. 32-10, 32-13 Flue gas, 45-1, 45-4, 45-6, 46-21 Fluid channel gradient, 3 l-5 Fluid coefficient, 55-2 to 55-4 Fluid columns, specific gravities and unit

pressure of, 6-22, 6-23 Fluid composition. 51-7. 51-8 Fluid conductivity. 26-10. 26-28 Fluid-content investigation, 49-26, 49-27

Fluid-controlled valves, 16-3. 16-4 Fluid controls, 6-51 Fluid data, ESP, 7-9 Fluid distributions. 442 to 44-4, 44-l 1 Fluid-electric-controlled valves, 16-3 Fluid-flow effects on waterflooding. 44-29 Fluid-flow model, 4420, 4421 Fluid/fluid interstitial configurations. 28-3 Fluid friction in hydraulic pumps, 6-19, 6-20 Fluid friction in sandstone reservoirs, 56-2 Fluid friction in tubular and annular flow

passages, 6-26 Fluid-friction losses, 6-5, 6-25, 6-47, 6-49

to 6-5 I, 6-67. 6-69 Fluid-gradient calculations, 6-26 Fluid identification. 50-2, 50-3 Fluid incompressibility, 51-49 Fluid-inventory equations, 43-9 Fluid jet, 8-7 Fluid level in well, 30-7, 30-8, 30-15 Fluid-loss additives, 55-4 Fluid-loss agents, 54-8 Fluid-loss characteristics of fracturing

fluids, 55-2, 55-7, 55-8 Fluid-loss-controlled fluids, 55-4 Fluid mapper, 44-20 Fluid mobility. 39-20. 44-7, 51-47, 52-14 Fluid pound, 10-5, IO-6 Fluid power, 6-15 Fluid pressure differences, 56-2 Fluid pressure regulator, 13-54 Fluid properties,

data, 37-16 gas and liquid FVF, 6-67 to 6-69 gravity, 6-67 introduction. 6-66 oil systems. 22-l viscosity, 6-67

Fluid pumpoff chart, ESP, 7-15 Fluid sample analysis, 41-8 Fluid saturation configurations. 28-2 Fluid saturation distributions. 28-2, 46-2 Fluid saturations,

comparison of methods of measurement, 26-24 to 26-27

determination from rock samples. 26-2 I, 26-22

interstitial water, 26-22 to 26-24 laboratory measurement of capillary

pressure, 26-24 of cores, factors affectmg, 26-20, 26-21 of reservoir for waterflooding, 46-3, 46-4

Fluid viscosrty, 6-27 Fluids in motion,

energy relatlonships, 34-1, 34-2 irreversibility losses, 34-2, 34-3

Flume pope. 19-21 Fluoboric acid system, 54-4, 54-l 1 Fluorescence X-ray, 50-7 Fluoride, 19-10, 56-I Fluoride mtensitier, 54-4 Fluosilicates, 54-4, 56-4 Flushing agent, lo- 13 Flushing efficiency. 39-18 Flux-gate magnetometer, 5 l-28 Flux leakage. 53-20 to 53-23, 53-26 Flywheel, 10-15. IO-19 Foam, 18-47. 19-23. 32-7. 45-8 Foam flooding, 47. I, 47-6 to 47-9 Foam quality. 55-6 Foam separator, 12-18 Foam stability. 47-7 Foaming agents. 39-16. 55-6 Foaming in desulfurizer. 14-22 Foaming oil, 12-3. 12-6, 12-7, 12-13,

12.17. 12-19 to 12.22, 12.32, 12-35

33

Focused electrical-resistivity devices, 26-31 Focused-electrode devices, 49-l I. 49-18 Focused-electrode logs, 49-18 to 49-22 Folded structure, 53-12 Force balance equations, 5-13 Force balance m downhole 6-16 to 6- 19 pumps, Force of gravity, 58-3 Force summing devices, 30-1, 30-2, 30-6 Force, unit and definition, 58- 1 I, 58-23,

58-24, 58-34 Forced-circulation heating. 19-22 Forced-draft burners, 19-28 Forchheimer equation, 35. I I Fordoche field, Louisiana, 39-16 Forecast of future rate of production,

constant percentage decline, 41-9, 41-10 declining production, 41-9 harmonic decline, 41-10 hyperbolic decline, 41-10 part constant rate-part declining

production, 41-10, 41-11 produced product prices, 41-I 1 proration of market curtailment. 41-I I

Foreign objects in flow string, 33-20, 33-22 Forest Hill field, Texas, 46-3 1, 46-34 Formation.

analysis, in sand control, 56-3 damage, 56-4, 56-8 properties, in sand control, 56-2 sampling, in sand control. 56-3

Formation alteration, effect on log measurements, 51-20 to 5 l-23

Formation balance gradient, 52-25, 52.26 Formation compaction, 26-8 Formation composition, effect on acid

reaction rate, 54-6 Formation compressibility, 40-34 Formation compressibihty vs. depth, 26-7 Formation conductivity. 54-8, 54-9 Formation damage, 4-9. 30-8, 35-4, 39-25,

51-21, 54-8 to 54-10 Formation density log. 52-20 Formation drillability exponent, 52-24 Formation evaluation, 5 l-l, 5148 Formation evaluation letter and computer

symbols, 59-2 to 59-51 Formation evaluation services, 52-2 to 52-l 1 Formation factor,

dependence on porosity and lithology, 49-4 evaluation, 49-14, 49-26, 49-30

Formation fluid pressure, 51-39 Formation fracturing,

fluid-loss-controlled fluids, 55-4 formations fractured, 55-2 fracture area, 55-2, 55-3 fracture planes, 55-2 fracturing equipment. 55-9 fracturing materials. 55-5 to 55-8 fracturing techniques, 55-8, 55-9 general references, 55-10 to 55-12 hydraulic fracturmg theory, 55-l. 55-2 introduction, 55-l multiple-zone fracturing, 55-9 operations. 8-8 references. 55-10 reservoir-controlled fluids, 55-2, 55-4

, stimulation results, 55-4. 55-5 treatment planning, 55-9. 55-10 viscosity-controlled tluids, 55-4

Formation of an emulsion, 19-2. 19.3 Formation permeability. 50-2 Formation pore pressure, 52-17 Formation pressure gradient, 5 l-39 Formation resistivity factor, 26-28 to 26-31,

49-4 Formation shear-wave velocity, 51.25

Foams as fracturing fluids, 55-6. 55-7, 55-9 Formation tests. 40-3


Formation transit time, 51-19, 51-20 Formation volume,

of gas plus liquid phases, 21-19 of well production at reservoir conditions,

21-20 total. gas-condensate system, 21-16, 21-18 total by Standing’s correlation, 21-19

Formation volume correlations, 21-15 to 21-20 Formation volume factor (FVF) of gas,

6-67, 20-11, 20-16. 22-13, 22-20. 37-16, 39-14, 39-23, 40-5, 40-7, 40-9, 40-22 to 40-24

FVF of gas plus liquid phase, 6-47 FVF of oil, 6-67. 22-l. 22-10 to 22-13,

22-20, 37-16, 40-6, 40-8, 40-9, 40-l 1, 40-16

FVF of water, 24-15, 24-16 FVF, total (two-phase), 6-47, 6-68, 22-l.

22-13, 22-14; 22-20 FVF’s vs. pressure, 37-16 Formation water, definition, 24-18 Formation water density, 24-14 Formation water resistivity, 24-14, 24.16,494 Formation water sample, 24-3 Formation water viscosity. 24-16, 24-17 Formations fractured, 55-2 Formazin polymer, 44-44 Formazin turbidity units (FTU), 44-44 Formic acid (HCOOH) in acidizing, 54-3,

54-8, 54-10 Forms of meter, 13-2 Formulation sequential. 48-14 FORTRAN IV, 17-6, 17-7 FORTRAN card deck, 17-5 FORTRAN source code listing, 9-3 Fossil water. 24-2 Foster field, Texas. 44-30 Foundations for pump and prime mover, 15-18 Foundations of pumping units, IO-7 Four-arm caliper, 53- I7 Four-arm dipmeter tools, 53-8, 53-10 Four-cycle engine, IO-14 to 10-16, IO-19 Four-stage separation, 12-34 Four-way engine valves, 6-9 Fourier heat equation, 26-16 F, values for various annuli, 33-17 F, values for various flow strings, 33-16 Fractional analyses, 39-2 Fractional-flow curve, 40-14, 43-10, 43-l I,

44-12 Fractional-flow equation, 40-17, 43-3, 43-5,

43-10, 44-4, 44-9, ‘M-10 Fractional flow of gas. 40-14, 43-6, 43-8 Fractional horsepower motors, 18-46 Fractional oil recovery, 44-9 Fractional water cut, 44-8 Fractionation, 39-27 Fractionation equipment, 39-5 Fracture acid&g: 54-9, 54-l 1 Fracture area, 55-2, 55-3 Fracture-assisted steamflood, 46-26 Fracture conductivity, 54-8, 54-9. 55-4,

55-8. 55-9 Fracture conductivity ratio, 55-4 Fracture evaluation, 5145 to 51-47 Fracture flow capacity, 55-8 Fracture-fluid efficiency, 55-4 Fracture geometry, 55-5, 55-9 Fracture gradient, 55-2 Fracture of pipe, 2-60 Fracture penetration, 55-4, 55-9 Fracture planes. 55-2 Fracture porosity. 44-2 Fracture pressures, 44-3, 44-46, 5 1-44 Fracture strength of casing, 2-61 Fractured-matrix imbibition. 48-9 Fractured matrix model. 48-5

Fractured porosity, 29-8 Fractures, ‘perme&ility of, 26- I6 Fracturing: See Formation fracturing Fracturing, 26-2. 40-23, 40-24. 51-44, 56-l Fracturing efficiency, 55-9 Fracturing equipment, 55-9 Fracturing fluids, comparative efficiency, 55-9

early treatments with, 55-l effective volume of, 55-2 foams, 55-6. 55-7 gelled-oil, 55-7 heavy oil-in-water emulsions, 55-7 high-viscosity, 55-8 leakoff, 55-4 mixed-base, 55-7 oil-base, 55-5 oil-in-water dispersion, 55-7 rate of leakoff controlled by viscosity, 55-4 viscosity of, 55-2 viscous emulsion, 55-8 volume of, 55-3 water-base, 55-5 to 55-7

Fracturing materials, fluids, 55-5 to 55-8 propping agents, 55-8 selection, 55-9

Fracturing pressure, 54-10, 54-l 1, 56-5 Fracturing pressure gradients, 55-2 Fracturing techniques, 55-8, 55-9 France, l-68, 12-39, 46-3, 46-27 to 46-29 Frangible-roof tanks, I l-2 Frax log analysis, 49-37 Free condensate, 14-5 Free gas, 6-2, 6-38, 6-39, 6-47, 6-50, 6-57,

6-62, 8-10. 12-3, 22-1, 22-9, 37-1, 37-2, 37-5, 40-5, 40-8, 40-13, 40-22 to 40-24, 40-33, 44-4

Free-gas cap, 40-6 to 40-8, 40-10 Free-gas production, 37-2 Free-gas production rate, 37-11 Free-gas saturation, 37-22, 40-19, 44-4,

44-5 Free pump cycle, 6-3, 6-6 Free pump installations, 6-3, 6-4 Free-standing risers, 18-15 Free-stretch factor of casing, 2-35 Free water. 14-3, 14-5, 14-6, 14-17, 14-20,

19-9, 19-17, 19-24. 19-25 Free water knockout (FWKO), 12-3, 12-4,

12-13, 15-21, 18-28, 19-9, 19-17 to 19-19, 19-22, 19-32

Freezing point, 14-2, 14-6. 14-10, 14-19, 21-19, 25-19

Freezing problem, 13-53 French design, concrete structures, 18-23 French Nat]. Assembly, l-68 Freon 12. 14-9 Frequency of wave, 51-14 Frequent; response. 30-5, 30-6 Frequency, unit and definition, 58-11.

J8-23; 58-36 Fresh core techniques, 44-5 Fresh mud, 49-20, 49-25, 49-27 Fresh water, 44-41, 44-42 Freshwater buffer, MP flooding, 47-10 Freshwater recharge, 24-20 Friction coefficient, 9-9 Friction factor, 15-l to 15-3. 15-5 to 15-7,

15-10, 34-2, 34-3, 34-24, 34-38, 34-39, 39-25

Friction in downhole pumps, 6-21 Friction loss, 13-2 Friction loss curves, 55-6, 55-7 Friction loss gradient, 34-36, 34-38 to

34-40 Friction losses, 46-29 Friction pressure, 55-5, 55-6

Friction pressure-drop curves, 6-26, 6-70,6-7 1 Friction relationships,

annular sections-flow between tubing and casing, 6-69 to 6-72

circular sections-tubing, 6-69 pressure drop in tubing annular flow,

6-70, 6-71 Friction wheel engine starters, IO-19 Frictional horsepower, 10-18, lo-19 Frictional press&e drop or loss, 6-1, 6-18

to 6-20, 6-25, 6-35, 46-7 Fritted glass, 26-6, 26-24 Front displacement models,

Mandl-Volek’s refinement of Marx- Langenheim method, 46-8

Marx-Langenheim method, 46-7, 46-8 Ramey’s generalization of Marx-

Langenheim method, 46-8 Frontal-advance applications, 43-16 Frontal-advance calculation, 43-12, 44-9 to

44-11 Frontal-advance equation, 40- 14, 40- 17,

40-18, 4410 Frontal-advance performance, 43-12 Frontal advance theory, 44-7 Frontal-drive method, for oil reservoir with

gas-cap drive, 40-13, 40-14 for oil reservoir with water drive, 40-17,

40-18 Frost heaving, 18-41 Frost point, 25-5 Fry pool, Texas, 44-1 Fuel availability for engines, lo-16 Fuel consumption, 10-17, 58-33 Fuel content as performance indicator,

tirefloods, 46-16 Fuel-gas scrubbers, 19-28 Fugacity coefficient, 25- 11 Fugacity of hydrate, 25-l 1 Full-bore flowline valves, 3-12 to 3-14 Full-capacitv relief valves, 12-40 Full-dime&r core analysis, 27-1, 27-8 Full-diameter core method, 26-17 Full diesels, lo-15 Full-interest wells, 57-9 Full-line injection-gas pressure, 5-53 Full-load rating of motor, 10-26, 10-28,

IO-30 - Full-load slip, lo-24 Fullerton-Clearfolk unit, California. 36-7 Fully implicit formulation. 48-14 Fungi, 44-43, 44-44 Funicular distribution, 26-24 Fuses for motors, lo-28 Fusible plugs for fire detection, 18-47 Future inflow performance, 34-34, 34-35 Future net cash income, 41-5, 41-6 Future performance calculations, 43-10 to 43-16 Future performance, water-drive reservoirs,

pressure gradient between new and original front positions, 38-13, 38-14

reservoir above bubblepoint pressure, 38-14 reservoir below bubblepoint pressure,

38-14 to 38-16 reservoir simulation models, 38-16

G

Galling, 6-50 Galvanic anodes, 19-3 1 Galvanic corrosion, 3-36 Galvanized coating, 1 l-6 Galvanized wire armor, 18-49 Gamma-gamma density devices, 50-7, 50-15

to 50-17, 50-26 to 50-28, 50-37 Gamma probability function, 39-l 1 Gamma radiation, 50-3

SUBJECT INDEX 3.5

Gamma ray absorption, 50-2, 50-13 Gamma ray attenuation, 50-2, 504 Gamma ray curve and log, 364, 46-27,

49-15, 49-19, 49-20, 49-25, 49-38, 49-39, 50-15, 50-24 to 50-27, 51-16, 51-17, 51-19, 51-23, 51-26, 51-27, 51-33, 51-38, 5145, 53-2, 534, 53-26

Gamma ray detection, 50-14, 50-23 Gamma ray devices, 50-15, 50-16 Gamma ray emission spectra, 50-15, 50-17 Gamma ray energy, 50-7, 50-13, SO-15 Gamma ray flux, geometry for, 50-16 Gamma ray index, 50-24 Gamma ray interactions, 50-6 to 50-8,

50-12, 50-14 Gamma ray measurements, 50-24 to 50-26 Gamma ray spectroscopy, 50-2, 50-3,

50-12, 50-13, 50-22, 50-24, 50-35 Garden Banks platform, 18-2 Gas analysis, 52-17, 52-18 Gas analysis system, 52-3 Gas anchors, 8-9, S-10 Gas and oil differences, 36-2 Gas backpressure valve, 124, 12-5, 12-9 Gas boot, 6-33, 6-57 to 6-59, 19-13, 19-18,

19-21 Gas break-out, 16-14 Gas breakthrough, 43-3, 43-5, 43-8, 43-9 Gas cap, 37-2, 37-3, 37-5 to 37-8, 37-13 to

37-17, 39-5, 40-5 Gas-cap drive, 36-2, 37-1,40-g, 40-13, 40-14 Gas-cap-drive reservoirs, 43-9, 42-5 Gas-cap encroachment, 36-2 Gas-cap expansion, 43-12, 43-15, 43-16 Gas-cap gas expansion. 37-5 Gas-cap gas production, 37-5 Gas cap in vessel, 6-62 Gas-cap injection, 43-3 Gas cap/oil production, 37-10 Gas-cap reservoir, 46-24 to 46-26 Gas capacity chart, 5-8 Gas capacity of separators, 12-23 to 12-25,

12-27 to 12-29, 12-31, 12-32 Gas chromatography, 27-1, 52-5 Gas compressibility, 36-2 Gas compressibility factor, 5-8, 5-l 1,

12-22, 12-23, 12-25, 12-26, 12-29, 12-30, 20-4, 20-7, 20-8, 20-10, 20-11, 20-14, 22-13, 4645

Gas/condensate ratio, 39-5 Gas-condensate recovery, 39-13 Gas-condensate reservoirs,

economics of operation, 39-26, 39-27 formation and fluid data for, 39- 11 general operating problems, 39-24 to

39-26 introduction, 39-1 nomenclature, 39-27 operation by pressure depletion, 39-10 to

39-15 operation by pressure maintenance or

cycling, 39-15 to 39-24 properties and behavior, 39-l to 394 references, 39-27, 39-28 sample collection and evaluation, 39-6 to

39-10 well tests and sampling, 394 to 39-6

Gas condensate systems. 20-4. 21-16 to 21-20, 22-l -

Gas-condensate wells, 3-36, 3-37, 334. 34-37, 34-28, 34-36

Gas condensates, 20- 11, 40- 13, 40-24 Gas coning, 32-3, 37-2, 37-13, 48-6 Gas cushion, 19-17, 19-18 Gas cutting, 1847 Gas cycling, 34-28, 45-13, 45-14 Gas cyclone, 12-20

Gas deliverability approach, 35-12 Gas-depletion drive, 29-7 Gas de&ion factor, definition, 22-20 Gas-discharge counters, 50-12 Gas discharge radiation detector, 50-12 Gas displacement, 43-3 to 43-6, 43-8, 43-16 Gas disposal, 18-30 Gas distribution system, 12-38 Gas drive, 46-3, 46-5 Gas effect, on acoustic log, 51-37

on velocity ratio, 51-38 Gas effect on neutron porosity, 50-30,

50-31 Gas eliminators, 15-14 Gas evolution, 37-22, 37-23 Gas expansion, 37-6 Gas expansion factor, 39-l 1, 40-7 Gas-expansion method of determining

porosity, 26-6 Gas-expansion porosimeter, 26-6 Gas exsolution, 52-14 Gas extraction methods. 52-2 Gas filter, 12-1, 12-2 Gas-tired crude oil heating unit, 19-28 Gas flaring, 18-30 Gas flotation units, 15-27 Gas-flow computers, 16-6, 16-12 Gas flow, Weymouth formula, chart, 15-8,

15-9 Gas formation volume factor (FVF), 6-67,

20-l 1, 20-16, 22-13, 22-20, 37-16, 39-14, 39-23, 40-5, 40-7, 40-9, 40-22 to 40-24

Gas-free hydraulic loop, 18-34 Gas-free viscosity, 22-14. 22-15 Gas fuel consumption, 39-24 Gas fundamentals as applied to gas lift,

gas pressure at depth, 5-3 to 5-6 gas volume stored in conduit, 5-11, 5-12 introduction. 5-3 temperature effect on confined bellows-

charged dome pressure, 5-6 to 5-8 volumetric gas throughput of a choke or

gas lift valve port, 5-8 to 5-10 Gas/gas interface, 39-21 Gas-gathering facilities, 5-53 Gas-gathering system, 12-10, 12-11, 12-33 Gas gravities of natural gases, table, 25-6 Gas-gravity/condensate-gas ratio, 34-28 Gas gravity, definition, 22-20 Gas handling, approximation for, 6-38, 6-39 Gas-hydrate equilibrium locus, 25-2 Gas hydrate region, oil and gas reservoirs

that exist in, 25-18, 25-19 Gas in effluent oil, 12-15, 12-16 Gas in place,

by material balance, 40-6, 40-7 by volumetric method, 40-5, 40-6 in reservoir containing nonassociated gas

and interstitial water but no residual oil, 40-23

Gas injection, 42-5, 43-16 Gas injection, BHP calculation, 34-28 to

34-30 Gas injection data, 39-23 Gas-injection operations, 43-2, 43-3, 43-7,

43-9, 43-17 Gas-injection performation, 43-5, 43-16 Gas injection pressure maintenance in oil

reservoirs, calculation of performance. 43-8 to 43-10 efficiencies of oil recovery by gas

displacement, 43-3 example calculations of future

performance, 43-10 to 43-16 introduction, 43-I. 43-2

methods of evaluating areal sweep efficiency, 43-7, 43-8

methods of evaluating conformance efficiency. 43-6, 43-7

methods of evaluating displacement efficiency, 43-3 to 43-6

nomenclature, 43- 18 optimal time to initiate, 43-3 references, 43-16, 43-17, 43-19 types of gas-injection operations, 43-2,43-3

Gas interference, 6-21, 6-22, 6-24 Gas law constants, 20-2 Gas liberation, 37-3 Gas lift, charts, 643

continuous flow, 5-21 to 5-38, 3440 to 3445 design procedures, 3440. 34-41 designing installations, 34-28 gas fundamentals as applied to, 5-3 to 5-12 intermittent flow, 5-38 to 5-53 introduction, 5-l to 5-3 nomenclature, 5-55 operations, description of. 5-I performance, 34-44 references, 5-57 unloading procedures and proper

adjustment of injection gas, 5-53 to 5-55 valve mechanics, 5-12 to 5-21 valves, 6-2, 6-6, 18-28, 18-34 well control, 16-11 wells, energy losses, 34-37 wells, tubing profile caliper, 53-17

Gas-lifting methods, 44-42 Gas/liquid/hydrate equilibrium, 25-5 Gas/liquid ratio (GLR), 5-23, 5-25, 5-26,

5-34, 5-36, 5-38, 543, 6-27, 6-29, 6-30, 6-35, 641, 642, 644, 12-21, 12-22, 39-2 to 39-6, 39-10

Gas/liquid relative permeability data, 39-7 Gas lock, 7-4, 7-6, 7-10, 7-15, 7-16 Gas lock breakers, 6-21 Gas lock chart, ESP, 7-15 Gas locking, 6-10, 6-21, 8-9 Gas measurement, automatic. of lease

equipment, 16-6, 16-7 flow nipple and pitot tube for, 33-2 general references, 13-59 instruments, 33-13 introduction, 13-l metering systems, 13-37 orifice constants, 13-3 to 13-35 physical setup of system for, 13-36, 13-37 references, 13-59 velocity meters, 13-l to 13-3

Gas mobility, 37-3, 39-25, 43-7 Gas motor engine starters, IO-19 Gas/oil contact, 26-25, 404, 40-14, 40-15.

41-9, 46-26 Gas/oil flow through chokes, 34-47 to 3449 Gas/oil interface, 1847, 50-36 Gas/oil interfacial tension (IFT), 22-16, 22-17 Gas/oil ratio (GOR). 5-25, 5-26, 6-24,

6-25, 6-29, 6-30, 6-38, 6-39, 6-44, 6-47, 12-35, 22-20, 34-41 to 3443, 3447 to 3449, 38-16, 39-1, 39-2, 40-33, 41-8, 44-39, 58-38

Gas/oil relative permeability, 28-9 Gas/oil relative permeability ratio, 37-1,

37-2, 39-13 Gas/oil separator, 22-20 Gas override, 48-12 Gas passage charts, 5-8 to 5-10 Gas payment, definition. 41-l Gas permeability, 39-13, 39-25, 47-9 Gas-plus-liquid FVF, 6-38 Gas pressure at depth,

charts, 5-3, 5-6 factors for approximating, 5-5, 5-6, 5-l I

36

injectton curves. 5-S static injection calculations, 5-3 to 5-6

Gas-pressure-at-depth factor, 5-5, 5-6, 5-49 Gas pressure function. 37-8 to 37-10 Gas pressuremaintenance performance. 43-8

to 43- 10 Gas price. gross, 41-9 Gas processing plants. 40-3 Gas Processors Assn. (CPA), 20-8, 25-9 Gas Processors Suppliers Assn. (GPSA), 20-S Gas-producing intervals, location of, 31-4,

31-6 Gas properties and correlations,

Amagat’s law, 20-4 Calingeart and Davis equation, 20-13 coeffictent of isothermal compressibility.

20-11 Cox chart, 20-12, 20-13 critical temperature and pressure, 20-2.

20-3 Dalton’s law, 20-4 equations of state, 20-6, 20-7 example problems, 20-13 to 20-17 formation volume factor, 20. I 1 ideal gas, 20-l. 20-2 Lee-Kessler equation, 20- 13 mole fraction and apparent MW of gas

mixtures. 20-4 molecular weight, 20-I. 20-3 natural gasoline content of gas, 20-10,

20-11 principles of corresponding states, 20-4 real gases. 20-4 IO 20-6 references. 20-18 van der Waals’ equation, 20-7 to 20-9 specific gravity (relative density), 20-4 specific gravity of gas mixtures, 20-4 vapor pressure, 20-3, 20-l I . 20- I2 viscosity, 20-9 viscosity correlations, 20-9, 20-10

Gas properties, effect on gas well performance. 35-10

Gas property ownershtp, 41-1, 41-2 Gas-purchase contracts, 41-3, 41-9 Gas quality from scrubbers, 12-15 Gas recoveries by natural water drive or gas

Injection, 39-16 Gas regulation,

definitions, 1349. 13-50 field compressors, control of, 13-57 to

13-59 high-pressure service, 13-55, 13-56 liquid-level control, 13-53, 13-54 lowpressure service, 13-55 principles of control. I349 process characteristics, 13-50 to 13-53 references, 13-59 regulators. types of, 13-54 to 13-57

Gas regulator, IO-19 Gas relative permeability, 28-8 to 28-12,

40-25, 40-26 Gas relative permeability vs. total wetting-

thud saturation, 28-8 Gas reserves: See also Reserves Gas reservoir,

development plan for, 36-l to 36-l 1 infinite acting, 35-l 1, 35-12

Gas reservoirs, depletion technique, 36-2, 36-3 free gas in, 40-5 in gas hydrate region. 25-18, 25-19 nonassociated, material balance recovery

estimates. 40-33, 40-34 nonassociated, volumetric recovery

estimates, 40-2 1 to 40-26 with water drive, 40-7, 40-26 without water drive, 40-24, 40-25, 40-33

Gas richness indicator, 524


Gas sales contract, 12-33, 14-l Gelled-oil fracturing fluid, 55-7 Gas sales Ime. 3-19 Gelled water in acidizing. 54-12 Gas-saturated crude oil. 22-15 Gelling agents, 54-8 Gas scrubbers, 12-l. 12-10. 12-I 1, 12-20 to Gels as fracturing fluids, 55-5, 55-6

12-22, 12-35. 12-38. 1828 General Conference on Weights and Gas separator to remedy gas locking. 7-16 Measures. l-69 Gas shows. total, 52-13 to 52-16, 52-18 General crude. 46-16. 46-18. 46-21 Gas sizing of separator. 12-30 General flow equations, 13-I Gas slippage. effect on permeability General overhead (GO), 41-14

measurements. 26-18, 26-19 General Petroleum Co.. 46-14 to 46-15 Gas-slippage effects, study required, 28-13 General principles of acidizing, Gas solubility. 40-9 acetic and formic acids, 54-3 Gas solubility in oil, 22-21 hydrochloric acid, 54-l to 54-3 Gas stripping, 15-29 hydrofluoric acid, 54-3. 544 Gas sweeteners. 12-35 General references: See also References. Gas throughput performance, 5-22 acidizing, 54-12 to 54-14 Gas-to-gas heat exchanger, 14-5 to 14-8,

14.il. 14-14, 14-15, 14-20 automation of lease equipment. 16.16. 16.17 crude oil emulsions, 19-33. 19-34

Gas-transmission-line pressure, 14- 15 electric submersible pumps, 7.17 Gas transmission lines, 12-38 electrical logging, 49-4 1, 49-42 Gas transmission piping specs., 15-12 estimation of oil and gas reserves, 40.38 Gas trap, 52-2 formation fracturing, 55-10 to 55-12 Gas-treating systems, 14-17 IO 14-22 gas-injection pressure maintenance in oil Gas turbine meters, 16-6 reservoirs, 43-16, 43-17 Gas turbines. 15-16, 15-17, 46-19 gas measurement and regulation, 13.59 Gas-vent string, 6-4 hydrate/volatile-gas systems, 2527. 25-28 Gas venting passage, 6-2. 6-5 miscible displacement, 45-15 Gas viscosity. 40-9, 44-6 mud logging, 52-30 Gas volume stored. in casing annulus. oil and gas leases, 57-12

within a conduit. 5-l I. 5-12, petroleum reservoir traps. 29-9 Gas/water contact, 39-2 I phase behavior of water/hydrocarbon Gas/water flow. 34-27 systems, 25-24 to 25-28 Gas/water interface. 39-21. 39-22 relative permeability. 28-16 Gas well inflow equation, 33-5 to 33-7 reservoir simulation, 48-20 Gas well performance, sucker rods. 9-14

deterioration causes. 33-20 to 33-22 temperature in welis. 31-7 gas properties, effect of, 35-10 thermal recovery. 46-45. 4646 Infinite-acting gas reservoir, 35-l 1. 35-12 valuation of oil and gas reserves, 41-37 long-term forecast, 35-12 water-drive oil reservoirs. 38-20 non-Darcy flow. 35-10. 35-l I water-injection pressure maintenance and pseudosteady-state solutions. 35-12 waterflood processes. 44-52

Gas wells. water/volatile-gas systems. 25-24 to 25-27 Bow through tubing-casing annulus, 34-27 wellhead equipment and flow-control flowing BHP calculation, 34-9 to 34-27 devices, 3-40 not suitable for TFL servtce, IS-34 Generator voltage, IO-2 I openflow, 33-l to 33-23 Geochemical analysis, 52. I, 52-2 static BHP calculation, 34-3 to 34-9 Geochemical model, 24-20

Gasoline as four-cycle engine fuel, lo-15 Geochemical parameters. 50-37 Gasoline content, 39-1, 39-5 Geochemical water analyses, 24-5 Gasoline-driven engine starters, IO-19 Geochemistry. 50-36, 50-37 Gasoline-plant recovery effictency, 45- 12 to Geochronology, 58-25

45-15 Geodetic surveys, l-69 Gasoline plants, 11-13, 40-13, 41-3, 57-5 GEODIP log analysis. 49-37 Gasoline/water system, 25-27 Geographical distribution of thermal Gassmann-Blot theory, 5 l-36 recovery projects, 46-3 Gassmann’s theory, 51-8 Geological analysis, 52-2, 52-7 to 52-9, 52-28 Gassy conditions. ESP chart. 7-16 GeologIcal correlation, 5 l-29, 5 I-30 Gassy fluid, 6-21 Geological interpretation. 51-28. 51-29 Gassy wells, 6-28. 6-34 Geological map, 40-4 Gate valves, 3-l 1 to 3-13, 3-21 Geologists, 57-8 Gathering systems, I I-13. 40-l Geology, in oil and gas reservoirs Gauge cocks. 12-42 development, Gauge glasses, 12-42 carbonate reservoirs, 36-5, 36-6 Gauge location factor, 13-8. 13-35 elastic reservoirs, 36-3, 36-4 Gauge tables, correcting for incrustation, 17-3 paleo-environments, interpretanon of, 36-3 Gauging petroleum and petroleum products, shale stringers. extent of, 36-6

17-3 Geology in sand control. 56-2 Gaussian elimination. 48-16 Geometric-mean air permeabilities. 4437 Gear pump, 19-5 Geometric progression, 6-39 Gear reducer, IO-2 to 10-6, 10.12, lo-13 Geometric series. 40-30 Gear reduction units, 6-50 Geometric spread of energy, 5 l-3 Gearhart, 49-2. 49-36. 49-37 Geometric spreading, 51-12. 51-13 Geiger-Mtiller tube. 50-16 Geometrical factor, 49. I6 to 49. I8 1 49-22 Gel or gelatin model, 39.21, 4417. 44-18. Geometrical spreading factor. 5 1~ I3

4420, 4421 Geometrical spreading loss. 49-34 Gel slugs. 54-10 Geophysics, in characterizmg reservoirs, Gel strength. 58-34 3b-8. 36-Y

SUBJECT INDEX 37

Geopressure detection, 5 l-39 Geopressure evaluation, 52.2, 52-16 to 52-26 Geopressure gradient, 52-25 Geopressure transition zone, 52-24 Geopreasured shales, 52-22 Geopressured zone, 52-22 to 52-24 Geoiechnical analysis, 18-41 Geothermal gradient,

assumed to estimate BHT, 31-6 basis for pressure-at-depth curves, 5-5 definition of, 52-22 in sedimentary basins, 31-2 in southwest U.S.. 31-3 increased, 5-23 linear, 46-5 temperature protile, 4-6

Geothermal temperature. 5-26 Geothermal temperature gradient, 5-6 Geothermics, 58-33 Germanium (Ge) detector, 50-14. 50-23 Germany. 12-39. 46-3 Getting ;he well drilled, 57-8 Gettv Oil Co.. 46-4, 46-14, 46-15, 46-18,

46-20, 46-23. 46-24 Gibbs theory, 47-8, 47-l I Gilbert’s equation. 34-45. 34-46 Gippsland basin. Australia, 27-19 Clash wool. 19-14 Glauconite. 46-21 Glen Hummel field. Texas, 46-15, 46-18 Glenpool field. Oklahoma, 54-l GLOBAL log analysis. 49-37 Gloriana field, Texas. 46-15, 46-29 to 46-32 Glossary of terms, reserves estimation.

crude oil, 40-3

Gravity drainage, 28-l I, 29-7, 37-1, 37-2, 37-5, 37-7, 37-17. 40-14, 40-15, 40-29, 41-l 1. 43-l to 43-3. 43-5 to 43-7, 43-16, 44-36, 44-39. 47-8, 484. 48-12

Gravity dump piprng, 6-62 Gravity faults, 29-3 Gravity forces, 37-l I. 44-31 Gravity losses, preventing, 1 l-12. I l-13 Gravity platform construction, 18-23, 18-24 Gravity segregation, 12-3, 37-2, 37-4, 40-8,

43-5, 43-7. 43-16. 45-7, 45-8, 48-8 Gravity separation, 6-56 to 6-59, 12-8,

improved recovery, 40-4 natural gas, 40-3 natural gas liquids, 40-3 possible reserves, 40-4 probable reserves, 40-4 reservoir, 40-3

12-19, 12-21, 12-23, 15-21, 19-6, 19-7, 19-13

Gravity separation devices, 15-23 Gravity settling, 15-18, 19-14, 19-15, 19-28 Gravity stabilization, 45-8 Gravity structures. 18-2, 18-3, 18-23,

Glossary of terms, petroleum reservoir 18-4 I, 18-42 traps, 29-8, 29-9

Glossary of terms. reservoir engineering phase behavior, 22-20, 22-21

Glucan. 47-3

Gravity systems ID piping design, 15-14, 15. I5 Graywacke sediments, 29-7 Great Britain. l-70 Great Lakes. 18-l

Gluconic acid, 44-45 Glycol absorbers. 13-54. 14-18 Glycol-condensate separator, 14-7 Glycol dehydrators, 12-35. 14-18 Glycol foaming, 14-20 Glycol injection LTS system. 14-6 to 14-8,

Great Salt Lake, 24-19 Grid network, 44-17 Grid orientation effects, 48-10 to 48-13 Grid spacmga. 48-8 Gridblocks, 37-2. 48-2 to 48-8, 48-10 to

14.14. 14-15 48-12. 48-14. 48-15, 48-17

Gridded multiphase reservoir simulators. Glycol rcboiler, 14-6. 14-7. 14-15 Glycol/water mixture, 39-5 Glycols, 12-35. 13-36, 14-6 IO 14-E. 14-15,

37-11. 37-13, 37-14

14-18 to 14-20 Government authorities or agencies, 12-39,

18-44 Governmental regulations. 3-34 Governors. IO-14 Graben. 29-3, 29-8 Gradlent curves. 5-25. 5-36. 5-37 Gradienr flmd tlow, 31-4 Gradlent gas flow, 31-4 Gradient of power tluid, 6-25. 6-26, 6-29.

Gridded reservoir models. 37-2, 37-5 Gridded simularor equations, 37-l I, 37-22 Gridded SLmulator studies. 37-2 Groningen gas field. Netherlands, 51-47 Grooved pin-end plunger, 8-4 Grounding of electrical system, 10-31, IO-32 Guar as thickening agent, 55-5 to 55-7 Guard-electrode device, 49-20 Guarding of pumping units. IO- I2 Guatemala. 25. I8 Guide posts, 18-19, 18-32 Guide, to number of digits to retain, 58-6

6-43. 6-44 Gradient of return Huid. 6-43 Gradient of well servicing fluid, 4-7 Grain density, 50-28, 50-33 Grain density test. 27-l Grain roundness factor. 55-8 Grain-bize distribution, 56-3, 56-7 Grain size of proppants. 55-X Grain size test. 27-l Grain volume: See Sand grain volume Granting clause. 57-3. 57-4

to style for metric usage. 58-l 1 Guidebase, ocean floor, 18-18. IS-19 Guidecones, 18-14 Guided wave, 51-13 Guideline tensioning systems, 18-l I, 18-13 Guidelineless drilling systems, 3-39 Guidelineless re-entry systems, 18-14 Guidelines,

for marine cargo Inspection, 17-8 for offshore structure selection. 18-25 for running down BOP stack. 18-16

Graphic plots. Introduction, 24-18 Reistle diagram, 24-19 Stiff diagram. 24-19 Tickell diagram, 24-19

Graphic relationships for SI units, 58-23 Graphical correlations, 22-5, 22-7. 22-8 Grabhite. 12-41 Graphite impregnated cloth model, 39-2 I G&e-tlow’pack, 46-19 Gravel-pack completions, 47-6 Gravel-pack failure, 56-6 Gravel-pack permeabdlty improvement, 56-6 Gravel packing, 56-3. 56-5 to 56-9 Gravel quality. 56-6. 56-7 Gravel selection. 56-6. 56-7 Gravel sizes available. 56-6 Gravimetric determination of BV, 26-3 Gravimetric system, 58-3 Gravitational forces. 26-12. 26-24, 29-3 Gravitational units. 58-5 Gravity conservation with storage tanks,

II-12 to II-14

for selection of storage tanks, 1 I-l for use of SI units, 17-7 for wire-rope, spudding offshore wells. 18-18 susbsea system, 18-19 to BOP testing procedures, 18-12 to surveys to be performed and analyzed

for offshore drilling permit, 18-5 Guides for using metric units. 58-8 Guides to acid fracture treatment design, 54-l I Gulf BHP gauge, 30-l Gulf coast. 18-2. 24-7, 24-8, 29-3, 33-21.

41-5, 47-3. 51-38, 51-39 Gulf of Mexico, 18-2, 18-3, 18-7, 18-24.

19-5, 19-15, 25-18. 29-7. 51-34, 57-l 1. 57-12

Gulf of Thailand. 36-9 Gulf Oil Corp.. 16-12, 46-15, 46-16, 46-18,

46-28 to 46-30 Gunbarrel tank, 19-20 to 19-22 Gunbarrels. 19-7, 19-18, 19-32 Guyed towers, 18-2, 18-3, 18-24. 18-25 Guyline system, 18-24, 18-25 Gypsum (gyp), 56-I. 56-2 Gyroscopes for dxectional surveys, 53-3 Gyroscopic orientation, 53-7

H

h-mode telemetry, 53-I Habendum clause, 57-4 Halite, 24-20 Hall-Yarborough equation, 20-8 Hammer lugs, 3-39 Hand-held calculator, 20-7, 20-9, 20-13,

40.30 Hand-off-auto switch, IO-27 Handling ESP equipment, 7-12 Hard-wired logic, 16-1, 16-8 Hardness. 4444, 47-5, 47-10, 47-l I. 47-13 Harmonic decline. 40-29, 40-3 I, 40-32,

41-l 1, 41-12 Harmonic-decline deferment factor, 41-29.

41-31, 41-35 Harmonic voltages, 10-30. IO-32 Harrisburg field, Nebraska, 44-40, 47-22 Hassler method, 28-3, 28-5 to 28-7 Hastalloym . 7-3 Havlena and Odeh‘a method for OIP. 37-3.

38-12 Hazardous area classification, 10-36, IO-37 Hazardous areas, electrIcal syslems

offshore, 18-46 Hazen-Williams equation, 15-2 HCI: See Hydrochloric acid Head, definition, 34-2 Head loss due to friction, 15-l Head meters, 13-2 Heading, in separators, 12-22. 12-31, 12-35 Heading conditions, 5-22. 5-24. 5-25, 6-60 Heading of wells. 34-46, 34-50 Heads of well fluids, 12-1, 12-32 Heal of fracture. 55-2 Healing, 47-8 Heat capacity.

of rock. 46-7 of steam. 46-5 of water. 46-2 Sl units. 58-28 volumetric. 46-7. 46-10

Heat conduction, 46-4. 46-12. 48-5 Heat conductiun. transient. 46-6 Heat content. of petroleum fractions. 2 l-6

of natural gas. 14-17 Heat exchange rate. 58-38 Heat exchangers, I I-12. 1 I-13, 12-13, 14-5

to 14-8. 14-11. 14-14, 14-18. 14-21. 14-22. 19-8. 19-21, 19-23, 19-28


Heat flow, conversion of units, table, 1-79 Heat flow distortion, 52-22 Heat flow rate, 58-23 Heat in oil and gas separation, 12-7, 12-13 Heat injection rate, 46-8 Heat losses, factor in pattern selection,

46- 17 higher steam rate required in steamfloods,

48- 18 surface lines, 46-4 wellbore, 46-5. 46-19 with thermal stresses, 46-19

Heat of reaction, 46-12 Heat of vaporization, 14-21 Heat transfer. 9-1. 14-1, 14-3, 14-20, 28-13 Heat tra,.sfer coefficient, 58-35 Heat treating, 9-1, 9-2 Heated gunbarrel emulsion treater, 19-22 Heat treater, 15-21, 16-3 to 16-5, 16-12 Heating capacity, 19-29 Heating efficiency, 19-28 Heating in treating emulsions, 19-7, 19-11 Heating value, gross, of natural gas

mixtures, 11-7 Heats of combustion, 52-3 Heavy oil-in-water emulsion-type fracturing

fluid, 55-7 Heavy viscous oil, 12-17 Heidelberg field, Mississippi, 46-15, 46-18 Helical spring BHP element, 30-l Helium, 14-17, 50-14, 52-5, 52-6, 52-10,

52-13 Hemispherical head equations, 12-38 Hempel distillation, 21-3 Hencky-van Mises theory of yielding, 2-55 Henry’s law constants, 25-17 Hercules wellhead, 7-7 Heterogeneity effects on waterflooding,

44-29 Heterogeneous system, definition, 22-21 Hewitt field, Oklahoma, 44-35, 44-36 Hewlett Packard BHP gauge, 30-4, 30-7 HF: See Hydrofluoric acid Hibernia development, 18-3 Higgins-Leighton method, 44-28, 44-30,

44-31 High-capacity operation of separator, 12-42 High-frequency phase analysis, 27-1 High injection-gas cycle frequency, 5-5 1 High-liquid-level control, 12-39 High-pH chemistry in chemical flooding,

47-18. 47-19 High-pH field tests, 47-21 to 47-23 High-pH processes,

consumption, 47-22 displacement mechanisms, 47-19, 47-20 high-pH chemistry, 47-18, 47-19 rock/‘fluid interaciions, 47-20, 47-21

High porosity presentation, 49-40 High-pressure gas engine starters, IO-19 High-pressure gas injection, 45-4, 45-l 1,

45-12 - High-pressure gas wells, 33-4 High-pressure models, 46-13 High-pressure seals, 3-36 High-pressure service regulators, 13-55 High-bressure steamfloo&, 25-4 High-resolution spectroscopy, 50-4, 50-35,

-50-37 -- High-slip motors, 9-3 High-speed engines, lo-14 to lo-19 High-voltage megger, 7-13 High yield strength pipe, 15-12 Hirask-Lawson theory, 47-9 Histogram of acid numbers, 47- 19 Historical background of relative

permeability, 28-2

Historical performance of reservoir, 36-10 Historical review of offshore operations,

18-1 to 18-3 History matching, 48-9, 48-13 History of reservoir simulation, 48-1 Holddown, 8-2, 8-3 Hole azimuth, 53-1, 53-2, 53-7, 53-8,

53-10, 53-17 Hole casing programs, 1841 Hole deviation, 52-13, 53-2, 534, 53-10,

53-17 Hole deviation, angle of, 53-3 Hole direction, 534 Hole enlargement, effect on acoustic

velocity logging tools response, 51-15 Hole rugosity. X-19 Homestead statutes, 57-3 Homogeneous system, definition, 22-21 Hondo platform, 18-2, 18-23 Honduras, 58-20 Hooke’s law, 51-1, 51-2 Horizontal emulsion treater, 19-21, 19-23,

19-25, 19-26 Horizontal flow system, 26-11, 26-12 Horizontal force vs. displacement curve, 18-10 Horizontal fractures, 44-26, 44-28, 55-2 Horizontal FWKO, 19-18 Horizontal gas flow, 43-10, 43-11 Horizontal permeability, 39-17 to 39-19 Horizontal pressure vessel sizing, 15-24 Horizontal scrubber, 12-38 Horizontal separator, 12-1, 12-6, 12-7,

12-10, 12-16 to 12-18, 12-20 to 12-31, 12-35, 12-40, 16-15, 18-28

Horizontal separator sizing, 12-30 Horizontal stresses, 55-l Horizontal three-phase separator, 19-17 Horizontal three-phase oil/gas/water

separator. 12-4 Horizbntal vessels, 13-53 Homer plot, 30-9, 35-15, 35-16, 35-19 Homer-type analysis of static BHT, 3 l-6 Horsehead, 10-2 to 10-4, lo-12 Horsepower at prime mover, lo-18 Horseuower, definition, 6-14, 58-24 Horsepower of engines, lo-17 to 10-19,

10-32, 10-33, lo-35 Horsepower of pumping unit, 9-11 Horsepower-rated motors, lo-21 Horsepower rating of motors, 10-17, 10-19,

10-20 Horsepower requirements, 34-41, 34-42,

3444, 34-45

Hot-water stimulation,

Horsepower vs. injection pressure, 34-44 Horst, 29-3, 29-8

48-2

Hoskold method, 41-16,41-18,41-20 to 41-22 Hot-dip process, 1 l-l, 11-6 “Hot” dolomites, 50-16

Hot waterflood. 46-4,

Hot electric grid, 19-25 Hot oil prodiction, 46-9, 46-10

46-5,

Hot oil productivity, 46-11

46-13,

Hot

46-23,

oil treatments, 46-21, 56-2 Hot-rolled steel, 9-l Hot spots, 7-1 Hot water, cooling of, 46-6 Hot-water iniection, 46-I

Hydraulic ivcompressibility method, 26-8 Hydraulic radius, 34-27, 34-39 Hydraulic-set packer, 4-3, 4-5, 4-6

Hidraulic

Hydraulic subsea controls, 1849

transmission’system,

Hydraulic surface safety valves, 3-20,

18-3

3-21 Hydraulic transformer, 6-19 Hvdraulic transformer orocess. 6- 16

Hydraulic turbine, 6-1

Huntington Beach field, California, 19-5, 46-22, 46-23

Husky Oil Co., 46-22, 46-23 Hutton platform, 18-24 Hydrate depression, 25-19 Hydrate dissociation model, 25-9 Hydrate dissociation predictions, 2.5-5 to 25-9 Hydrate dissociation pressure, 25-6 Hydrate formation, 12-3, 14-1, 14-2, 144

to 14-7, 14-17 Hydrate formation, condition of methanol

propane mixture, 25-20 conditions, effect of GOR, 25-19 conditions for paraffin hydrocarbons, 25-4 on expansion of gas, 25-l 1 pressure, procedure for determining, 25-8,

25-9 temperature, 12-40

Hydrate inhibition, 25-19, 25-20 Hydrate inhibitors, 14-3, 14-5 to 14-8, 14-17 Hydrate problem, 13-53 Hydrate stability conditions, 254 to 25-9 Hydrate temperature, 14-2, 14-3, 14-5 to

14-7, 14-17 Hydrate/volatile-gas systems, 25-3 Hydrated iron oxide, 14-22 Hydrates, 5-12, 5-24, 14-2, 14-3, 14-5,

14-6, 33-20, 33-21, 39-24, 39-25 Hydration of cementation material, 26-18 Hydraulic actuators, 3-2 1, 18-28 Hydraulic BOP control system, 18-21 Hydraulic connectors, 18-12. 18-18. 18-34 Hidraulic control circuit, 3-33 Hydraulic control system, 18-l 1, 18-15 Hydraulic currents,-24-2 Hydraulic forces, 4446 Hydraulic fracturing theory, 55-1, 55-2 Hydraulic head, 26-10, 26-12 Hydraulic horsepower, 6-45, 10-17, lo-18 Hydraulic installations, system pressures and

losses, in calculation of fluid gradients, 6-26 in closed power-fluid system, 6-26 in fluid friction in tubular and annular

flow passages, 6-26, 6-27 in open power-fluid system, 6-25

Hydraulic power transmission, 6- 1, 6- 15 Hydraulic pressure, 55-I Hydraulic-pumped-well control, 16-11 Hydraulic pumping,

downhole pumps, 6-2 to 6-7 fluid properties, 6-66 to 6-69 frictional relationships, 6-69 to 6-72 introduction, 6-1, 6-2 jet pumps, 6-34 to 649 principles of operation-reciprocating

pumps, 6-8 to 6-33 references, 6-72 surface equipment, 6-49 to 6-63

46-24 Hot-wire detector, 52-3 Huff’n’puff method, 46-1. 47-10, 56-2 Hugoton field, Texas, 33-1, 33-7, 33-9,

33-22, 34-46 Humble formula (relation), 26-29, 26-31,

494, 49-32 Humble gauge temperature element, 31-1 Humble 30-l pressure gauge,

Hidrocarbon analyses, crude oil and gas condensates, 39-2

formation evaluation service, 52-2 to 52-7, 52-13

of produced well stream, 39-7 of separator products and calculated well

stream, 39-7 used in pressure depletion predictions,

39-10, 39-11

SUBJECT 1NDEX 39

Hydrocarbon chromatogram, 52-16 Hydrocarbon content of samples, 52-9, 52-10 Hydrocarbon content from logs, 5 l-35 to 5 1-38 Hvdrocarbon gas viscositv. 15-6 H;drocarbon/cquid conddnsation, 39-13 Hvdrocarbon liquid recovery, 37-22, 37-23 Hidrocarbon liquid recove; calculations,

14-16 Hydrocarbon liquid recovery system, 14-8 Hydrocarbon liquid saturations, 39- 10 Hydrocarbon mixtures, 39-2, 394, 39-12 Hydrocarbon pore space, 39-8, 39-9, 39-l 1,

39-18 Hydrocarbon recovery systems, lease-

operated, gas treating for removal of water vapor,

CO, and H,S, 14-17 to 14-22 lOW-temperature separation (LTS), 14-l to

14-17 references, 14-22

Hydrocarbon recovery unit, 14-10, 14-11 Hydrocarbon reservoir, definition, 39-l Hvdrccarbon-rich phase at three-phase

critical conditi&, 25-5 _ Hydrocarbon saturation, 49-27, 50-2 Hidrocarbon stabilization, 14-13 to 14-17 Hydrocarbon/water phase diagrams, 25-l to

25-4 Hydrocarbon/water systems, 25-3, 25-27 Hydrocarbon Well Log Standards

Committee, 52-30 Hydrocarbons in place, ownership of, 57-1 Hydrocarbons presence detection, 50-1, 50-3 Hydrocarbons, removing from solids, 15-30 Hydrocarbons, treating from water, 15-2 1 Hydrochloric acid (HCL),

acidizing treatments, 54-1, 54-2 as synthetic polymer gel, 55-5 channeling and wormhole effect, 54-8 combined with HF. dissolving action. 54-9 density at 6O”F, 54-2 dissolution of concentrated, 54-3 dissolving limestone, 54-2 in acidizing, 54-l to 54-3 in matrix acid stimulation, 56-5 inhibited, as mud-dissolving acid, 56-l inhibitors used with, 54-1, 54-6 matrix treatment of carbonates, 54-10 organic inhibitors in, 54-6

reaction rate, effect of, acid concentration, 54-5 area/volume ratio, 54-5 flow velocity, 54-5 formation composition, 54-6 pressure, 54-4 retardation of, 54-8 rubber lining protection from, 11-6 temperature, 54-4, 54-5 to acidize pH, 24-4 to clean tubing, 56-3 to dissolve corrosion products, 39-26 to remove scale, 56-2 used in combination with HF, 54-3,54-9

Hydrocyclone, 6-62 Hydrocyclone operation, 15-19, 15-30 Hydrodynamic forces, 18-17, IS-25 Hydroelectric valve operators, 16-3 Hydrofluoric acid (HF) in acidizing, 54-3,

54-4, 54-9, 54-l 1 Hvdrofluoriclhvdrochloric acid (HF/HCl)

mixNreS in-acidizing, 54-11 Hydrogen, l-80, 26-18, 50-1, 50-3, 50-4,

50-9, 50-13, 50-17, 50-18, 50-20, 50-26, 50-31, 50-34, 51-31

Hydrogen density, 50-32 Hydrogen embrittlement, 3-36 Hydrogen flame detector, 52-4

Hydrogen sulfide (H,S), 3-36, 3-37, 4-4, 4-5. 6-4, 6-54, 7-11, 7-14. 8-9, 9-1, 9-5, 9-8, 11-6, 12-3, 12-8, 14-3, 14-13, 14-17. 14-20 to 14-22. 15-28. 15-29. 18-20. 18-47, 20-5, 20-6, 22-5, 24-5, 24-17, 39-5, 39-6, 40-22, 44-36. 44-42 to 4444, 45-5, 52-4 to 52-7, 52-13, 547

Hydrogen sulfide content, 25-5, 25-8, 25-13, 25-20

Hydrogen sulfide fumes, lo-13 Hydrogen sulfide gas detectors, IS-47 Hydrogen sulfide/water system, 25-27 Hydrolysis of methyl formate, 54-4 Hydrolyzed polyacrylamide (HPAM), 47-3

to 47-6 Hydrometer, l-80, 54-3 Hvdrometer test method, 17-5 Hidrophile, 47-7 Hydrophobe/hydrophile balance, 19-10 Hidrobhobic surface, 47-8 Hydropneumatic tensioning units, 18-13,

18-14 Hydrostatic equilibrium, 26-l 1 Hydrostatic gradient, 58-25 Hydrostatic head, 6-25, 6-28, 6-51, 55-7,

55-8 Hydrostatic pressure, 3-29, 3-31, 18-17,

29-1, 51-39, 5144 Hydrostatic PV compressibility technique,

26-8, 26-9 Hydrostatic test pressure, 2-62, 3-1,3-2, 3-13 Hydroxyethyl cellulose (HEC), 47-3 Hydroxyfluoboric acid, 54-4 Hydroxyl reactions, 47-21 Hydroxypropyl guar as thickening agent,

55-5, 55-6 Hyperbolic cosines, table, l-59 Hyperbolic decline, 40-28, 40-29. 40-31,

40-32, 41-10, 41-11, 41-29 Hyperbolic-decline deferment factor, 41-29

‘to 41-31 Hyperbolic sines. table, l-58 Hyperbolic tangents, table, l-60 HypercleanTM technique, 46-2 1 Hysteresis, 28-2, 28-3. 28-6, 28-10, 28-13,

30-3, 30-6, 30-7, 33-6

I

I-wire, 7-5 Ice characteristics, 18-38 Ice-class rigs, 18-2 1 Ice impact, 1843 Ice islands, 18-39 Ice loading, 18-39 Ice management. 18-43 Ice point, 25-l to 25-3, 25-5 Icebergs, 18-39 Icebreaker assistance vessels. 1843 Ideal equilibrium ratios, 23-l 1 Ideal gas, 20-l to 20-3, 26-12 Ideal-gas law, 13-8, 20-2, 204, 20-6, 20-7,

39-8, 40-21, 47-13 Ideal productivity index (PI), 32-3 Ideal solution principles. density from, 22-2,

22-5 Idealized pore models, 26-28 IFP-ICPP, 46-4, 46-15. 46-18, 46-28, 46-29 Igneous rock, 29-3, 29-8 Ignition devices, 46-20 Illinois, 40-16, 40-32, 40-33. 44-41, 44-42,

46-3, 46-4, 46-15 Illinois basin, 24-6, 24-7, 24-9, 4444 Illite, 46-21,50-21,50-32,50-34,50-37,52-21 Illuminance, unit and definition, 58-l 1,

58-23, 58-36 Imbibition curves, 26-24, 28-5, 28-9 to 28-12

Imbibition effect, 40-20 lmbibition of water, 40-20 Imbibition without relative permeability

data, 28-4 Immiscibility of methane gas and oil, 45-2 Immiscible disulacement. 42-2 Immiscible d&lacement fluid, 40-4 Immiscible fluids. 28-2. 28-12. 28-13 Immiscible gas drive, 45-4 Immiscible gas injection, 43-1, 43-2 Immiscible liquids, 19-1, 19-2, 19-14 Immiscible processes, 39-18 Impact energy, 58-32 Impact kinetic energy, 13-l Impact loading or loads, 3-1, 18-5 Impact pressure, 13-45 to 13-48, 33-l to 33-4 Impact requirement, wellhead equipment, 3-38 Impedances, IO-30 Impingement, 12-S to 12-11, 12-13, 12-19 Implicit-pressure/explicit-saturation

formulation (IMPES), 48-14, 48-15 Implied covenant, 57-6 Impressed-current system, 11-6 Improved recovery reserves, 40-3, 40-34 Impurities in well fluids. 12-3 In-transit deck-load capability. 18-8 Inaccessible pore volume (IPV), 47-5 Inbreathing (vacuum relien of storage tanks.

11-6, 11-7 Incident flux, 50-5 to 50-7 Incident gamma ray, 50-7, 50-12. 50-13 Inclination angle, 53-5, 53-6 Inclinometer, 53-8 Inclinometer section, 53-7 InconelO, 7-3, 15-21 Incremental gas production, 37-10 Incremental oil production, 37-9, 37-17 Incremental oil recovery (IOR), 47-6, 47-2 1

to 47-23 Incremental recovery, potential for, 46-3 Incrustation, 17-3 Independent oil company, 57-8 Independent screwed wellhead, 3-39 Indian Petroleum Corp., 18-1 Indiana, 24-7 Indirect beater, 14-3, 14-5, 14-6 Indirect-fired heaters, 19-2 1 Indonesia, 12-39, 46-3, 46-4 Induced-gamma-ray spectroscopy, 50-4,

50-34, 50-35, 50-37 Induced hydraulic fractures, 54-l 1 Induced porosity, 26- 1, 26-2 Induced radiation, 50-6 Induction conductivity curve, 49-15 Induction device, deep-reading (ID), 49-15,

49-17, 49-20 Induction device, medium-reading (IM).

49-15, 49-17, 49-18 Induction-electrical log (IEL), 49-27. 49-29

to 49-3 1 Induction-electrical surveys (IES), 49-11,

49-15 Induction log (IL), 49-l, 49-2, 49-5, 49-6,

49-14 to 49-18, 49-25 to 49-27, 49-29, 49-30

Induction log resistivity, 51-17, 51-26, 51-37, 51-38, 5146

Induction motors, lo-19 to 10-21, lo-23 to 10-25, 10-30, 10-32, lo-36

Induction motor poles vs. synchronous speeds, lo-23

Induction spherically focused log (ISF), 49-15, 49-16, 49-19. 49-20. 49-34, 49-36

Inductive couplers, 18-52 Inelastic gamma-ray spectroscopy, 50-35 Inelastic neutron reactions, 50-13 Inelastic scattering, 50-9, 50-23


Inelastic spectrometry. 50-22 Inert-gas injection. 39-16 Inertial effects, 35-10 Inerttal forces, 35-l I Industrial multitube boilers, 46-19 Inferential meters, 16-5 Infiltration by permeation, 24-18 Infinite-acting pressure solution, 35-3, 35-4.

35-7. 35-12. 35-14 Infinite aquifer. 38-3, 38-6. 38-9 Infinite boundary, definition, 38-l Infinite linear aquifers, 38-2, 38-8 Infinite radial aquifer, 38-3. 38-5 to 3X-8 Inflation factor. 41-15 Inflow performance relationship (IPR), 6-4,

6-25, 6-41 to 6-43, 6-46, 6-47. 34-30 to 34-35, 34-46. 34-50. 37-17 to 37-21

Inflow well performance, 5-22 Influence-function curves, 38-3 Infrared (IR) absorbance, 12-16 Infrared absorption detector, 52-5 to 52-7 Infrared absorption method, 46-21 Infrared detectors, 3-34 Infrared fire sensors. 18-47 Inglewood field, California, 46-14 Initial fluid saturations, 37-3 Initial gas saturation, 446, 4438 Initial hydrate formation conditions, 25-l. 25-2,

25-5, 25-6. 25-l I. 25-12. 25-15, 25-19 Initial hydrate formation, estimating, 25-5 Initial oil saturation. 44-4 Initial saturation conditions. 43-5 Initial saturations. effect of, 44-6 Initial water distribution. 44-l I, 44-37 Injection application, ESP, 7-2 Injection, BHP calculation, 34-28 to 34-30 InjectIon fluids, 42-2, 42-5 Injection-gas breakthrough, 5-52 Injection gas cycle, 5-12, 5-43, 5-48, 5-52 Injection-gas-cycle frequency, 5-55 Injection-gas cycles per day, 5-40 to 5-42,

s-54. 5-55 Injection gas-line pressure, 5-48, 5-54. 5-55 Injection-gas/oil ratio (GOR), 3441 to 3443 Injection-gas opening pressure, 5-18 to

S-20, 5-26, S-28, S-29, S-33, 5-39. 5-40, 5-51

Injection-gas operating pressure, 5-48, 5-53 Injection-gas pressure, 5-20, 5-2 I, S-24,

5-26, 5-28. 5-31. 5-32, 5-35. 5-37. 5-39 to 5-41, 5-44, S-46, 5-48 to 5-54

Injection-gas-pressure-at-depth Curves, 5-5 Injection-gas-pressure-at-depth traverse, S-36 Injection-gas rate, proper adjustment, 5-53

to 5-55 Injection-gas requirement for intermittent

lift, S-40 to 5-42 Injection-gas throughput. maximum, 536,543 Injection-gas volume per cycle, S-S 1 Injection-gas volumetric rate, 5-3, 5-54 Injection-gas volumetric throughput, 5-37, 540 Injection-gas volumetric throughput profiles,

5-20 Injection operations. 42-1 to 42-6 Injection pressure effect on horsepower,

3442 InJeCtiOn-preSSUre-Operated gas lift Valve,

5-13, 5-14, 5-16 to 5-24, 5-27, 5-32. 5-33, S-36, 5-40, 5-54

Injection profile, foam, 47-9 Injection profiles, 4-6 to 4-8 Injection-pumping rate, controlling, 16-14 Injection quill, 19-I 1 Injection treatments, large-volume, 56-2 Injection water, 24-5 Injection well plugging, 39-26

Injection wells. gas. 34-28 to 34-30 liquid. 34-28

lnlectivity. 44-29. 44-33 to 44-35. 44-43. 46-22

Injectwy, effect of damage on, 54-8, 54-9 Injectivity index. 4434, 44-35 lnjectivityiproductiwty ratio, 46-17 Injectivity profile. of water-injection well,

31-4 Injectivity testing. 39-25. 39-26, 44-46 Inner-valve assembly. 13-49 Inorganic constituents.

anions, 24-9, 24-12 cations. 24-9

Inorganic solids. 19-5 Input safety valves (ISV’s), 3-35 Insert pump. 8-l In-situ analyses, IX-26 In-situ combustion, 19-28, 48-2. 48-5 to

48-7 In-situ combustion models, 46-12 In-situ combustion processes.

chemical reactions. 46-37 dry forward combustion, 46-1, 46-2 production by, 46-4 reverse combustion, 46-2 wet combustion, 46-2, 46-3

In-situ “static” analysis, 18-27 Insoluble reaction products, 54-1 Inspection of tubing and casing by caliper

logs. 53-17. 53-18 Installation design calculations, gas lift, 5-29

to s-32 Installation design considerations. gas lift,

5-22 Installation design. contmuous flow gas lift,

calculation of test rack-set opening pressure, 5-29. 5-33

determmation of valve depths, 5-28, 5-29, 5-32. 5-33

example calculations. 5-29 to 5-35 selection of port size. 5-28

Installation design, intermittent gas lift, calculation of test rack-set opening

pressure, 5-46. 5-49 determination of valve depths, 5-45, 5-46,

5-48, 5-49 example calculations, 5-46. 5-47, 5-49,

5-50, 5-52 lift chamber application. 5-50 to 5-52 percent tubing load, 5-48 selection of port size. 544

Installation design methods, gas lift, 5-22 Installationimamtenance system controls, 1848 Installation of ESP equipment, 7-12 to 7-14 Installation of prime mover, IO-19 Installation of pumping units, 10-7, IO-12 Installation of safety devices, 12-40 Institut Franqais du P&role method, 28-7 Instrument-adjustment factor, 13-52 Instrumentation for liquid hydrocarbon

metering systems, 17-4 Instrumentation systems offshore, 18-43 to

1 a-47 Insulating additive. 46-19 Insulation classification, IO-26 lnsulatlon for oilwell pumping motors,

classification of. IO-26 winding materials for, IO-26

Insulation materials, winding of, to-26 Intangible drilling costs, 57-I 1 Intangibles and intangible cost, 41-l I.

41-13, 41-14, 41-15 Integral flange, 3-16, 3-22, 3-24 Integral joint tubmg, 2-38 to 2-45, 2-64,

2-65

Integral \,aluCs, tabulated. 34-5 to 34-7, 34-10 to 34-22

Intensified acid, 54-3, 54-S Intensity/time recording. 51-18 Intensive properties. 22-2 I. 39-2 Interaction coefficient. 28-3 Interest,

carried, 57-10 landowner’s, 57-1. 57-2 mineral, 57-6 net profits. 57-10 royalty, 57-5 to 57-8 working. 57-5. 57-7, 57-9, 57-10

Interest tables, 4 l-25 to 4 I-34 Interface level controller. 19-23 Interfacial buildup, 19-30 Interfacial sludge, 19-32 Interfacial tension (IFT)

deadend oil, 22-17 defimtlon. 22-l. 24-16 effects on relative permeability. 28-10,

28-l 1 gas/oil. 45-4. 45-6 liquid/gas, 22-16 of acid solutions, 54-6 of condensate and water, 34-50 oil/water, 47. I, 47-9. 48-5 reduced by surface-active agents, 44-39 results in spherlcal form of water

droplets. 19-I units and conversion factors, 58.38

Interfacial tension reducer. 56-5 Interfacial tension reduction. 44.40, 48-2 Interference, 44-33 Interference effects, 38-1, 38-3 Interference tests and testing, 30-S. 36-7,

36-8, 42-4 Intergranular porosity. 26-1, 26-3, 5 I-3 I Intermediate domes, 29-5. 29-6 Intermediate packers, 4-11 Intermittent controller. 16-4 Intermittent flow, skim pde. 15-26 Intermittent gas lift.

comparison of time cycle to choke control of injection gas, 5-41. 5-42

cycle of operation, 5-38 daily production rates, 5-40 disadvantages of, 5-38, 5-39 gas-lift valves, 5-42, 5-43 heads or slugs in, 12-32, 12-35 injection gas requirement. 5-40, 5-41 installation design methods, 5-39, S-42.

5-44 to 5-50 introduction, 5-38 lift chamber application and installation

design, 5-50 to 5-52 operation, 5-1, 5-3, 5-l 1, 5-13, 5-19.

5-37 to 5-53 percent tubing load installation designs, 548 plunger applications, 5-52 pressure-gradient spacing factors. 5-43, 5-44 surface closing pressure of valves, 5-44 types of installations. 5-39, 5-40 unloading Injection-gas pressure. effect of

installation design methods, 5-39 valve port size, 5-44

Intermittent pressure-gradient spacmg factor, 5-42, S-43

Intermittent spacing factor, 5-45 Intermittent spacing factor gradient, 5-44,

s-45, s-47 Intermittent spacing factor traverse, 5-46, 5-47 Internal coatings, 11-4. II-5 Internal-combustion-engine driven

generators, 18-45 Internal-combustion engmes.

diesel, 10.15, IO-16 four-stroke cycle, IO-15

SUBJECT INDEX 41

in inert gas injection, 39-16 installation, IO-19 multiplex pumps analogous, 6-49 oil engine, 10-15. IO-16 selection of, IO-16 to IO-19 two-stroke cycle. 10-14. IO-15

Internal corrosion, 3-36 Internal energy. 13-I Internal floating roofs, I l-2, 1 l-6 Internal flushing efficiency, 39-18 Internal gas drive. 37-1, 40-E Internal gas-driven reservoir, 32-15, 32-16 Internal injection, 43-2 Internal pressure leak resistance, of casing,

2-5. 2-7, 2-9, 2-l I, 2-13, 2-15. 2-17, 2-19. 2-57. 2-58, 2-64

Internal pressure, of casing, 2-1, 2-61 of pipe, 2-59 of line pipe, 2-56, 2-63

Internal pressure resistance of. casing, 2-5, 2-7, 2-9, 2-11, 2-13, 2-15,

2-17, 2-19 line pipe. 2-56 tubing, 2-46

Internal rate of return (ROR) method, 41-17 Internal Revenue Code, 41-14. 41-15 Internal Revenue Service, 41-2 Internal spiral element, 12-19 Internal water weir, 12-35 Internal yield pressure of pipe and

couplings, 2-5, 2-7, 2-9, 2-l 1, 2-13, 2-15, 2-17, 2-19, 2-32, 2-56, 2-57, 2-63, 3-l

Internal yield pressure safety factor, 2-2, 2-32, 2-34, 2-35, 2-45, 2-46

Internally coated pipe, 39-26 Internally plastic-lined tubing, 44-46 International atomic weight table, 20-l Intl. Bureau of Weight and Measures, l-69

to l-71 Intl. Commission on Radiological

Protection, 58-10 International foot, l-69 Intl. Metric Convention. l-68, 1-69 Intl. prototype kilogram, l-69, I-70 Intl. Standards Organization (ISO). IO-12 Intl. system of units, guidelines for use, 17-7 Interpretation.

chart for Rocky Mountain method, 49-3 I, 49-32

chart for R,,IR, and shaly sand method, 49-28

IEL method, 49-30, 49-31 of caliper logs, 53-17 of casing inspection log, 53-23 to 53-26 of chemical analyses, 24-18, 24-19 of EPT log, 49-34 to 49-36 of rmcrolog, 49-23 of paleo-environments, 36-3 of pipe analysis log, 53-13 to 53-26 of rules of dipmeter, 53-10, 53-12 of well logs, 49-25 to 49-36 quantitative, of hydrocarbon saturation,

49-21 stratigraphic, 53-13, 53-14

Interpretation of nuclear logs, gamma ray measurements, SO-24 to SO-26 introduction, 50-23, 50-24 lithology determination, 50-33 to 50-35 porosity determination, 50-26 to 50-33 saturation determination, 50-35 to 50-37

Interstate Oil Compact Commission, 33-15 Interstitial clay, effect on formation

resistivity factors, 26-30 Interstitial water, 24-2, 24-3, 24-16, 24-18.

26-30, 27-8, 40-8, 40-10, 40-13, 40-16, 40- 19. 40-23

lnterstltlal water content, 39-17, 39-18, 39-21 to 39-23. 40-12

Interstltlal water saturation. 26-26. 28-4, 28-14, 37-3, 37-4, 37-15, 37-17, 39-10, 40-5 lo 40-10, 40-12. 40-15. 40-16, 40.19. 40.24. 42-4, 43-5, 44-4, 446, 449, 4436

Interstitial water saturations, capillary pressure, 26-23. 26-24 oil-based mud. 26-22, 26-23

Interval transit (travel) time, 51-15, 51-17. 51-19, 51-23. 51-24, 51-27, 51-43, 58-25, 58-33, 58-36

Interzonal hydrostatic head, 7-2 Intrawell continuity, 36-l. 36-6, 36-7 Invaded-zone correction, 49-22 Invariant point, 47-12 Invasion effects on IL. 49-17 Invasion efficiency, 39-15, 39-17, 39-18,

39-22, 39-23. 40-34, 47-l Inverse emulsion, 19-l Inverse lever rule. 23-3. 23-8 Inverse simulation, 48-9 Inverted bucket traps, 13-53 Inverted nine-spot well patlern. 45-10,

46.17, 46.18, 46-28 Investors method, 41-17 Involute element, 12-19 Iodide. 19-10, 24-9 Iodine, 24-5. 24-20, 24-21 Ion diffusion, 24-19 Ion exchange, 24-19, 24-20 Ion-exchange conduction, 49-4 Ion-exchange reactions, 52-21 Ion-exchange resins. 15-29 Ionization, 50-3 Ionized-gas counter, 50-12 Iran, 29-6 lron bacteria, 44-43 Iron chelating agents, 56-l Iron-control agents, 54-7, 54-8 Iron sponge sweetening. 14-22 Iron sultide, 14-22, 19-4, 19-9, 44-44 Iron sulfide deposits, 1 l-10 Irreducible saturation, 28-5, 28-8 Irreducible water saturation, 44-6, 44-l I,

44-12, 46-34. 46-37, 46-38, 47-9 lrreversibihty losses, 34-2 Isobaric contour maps, 39-23 Isobutaneiwater system, 25-25, 25-27 Isochronal backpressure test, 34-31 lsochronal test data, 39-25 Isochronal testing, 33-4 to 33-6, 33-10 to

33-13 Isoelectric point, 54-7 Isolation packer, 4-2, 4-3 Isometric of fractures, 51-28, 51-29 Isopachous maps. 39-2 I, 40-5, 41-8, 46-30,

46-31 Isopentaneiwater system, 25-26 Isoporosity map, 39-22 Isoporosity maps, 44-3 Isopotential lines, 4415 to 4417 Isopropyl alcohol in acidizing, 54-E Isothalic thermoset resin, 9-12 Isothermal coefficient of compressibility, 55-4 Isothermal compositional model, 48-5 Isothermal model, 48-4 lsovol map, 39-17 Italy. 12-39 Iterative method or solution. 37-8, 37-9,

37-11. 48-l. 48-13

J

J function, definition, 26-25, 26-26 Kerosene/water system, 25-27 J-lay first-end connection, 18-38 Kettleman Hills field, California. 6-24, 29-2

Jackson candle units (JCU). 44-44 Jackup rig, 3-38 Jackups, 1X-2 to IX-6 Japan. 12-39 Jay/Little Escambla Creek field. 44-36, 44-37 Jefferson limestone. Kentucky, 54. I Jet pump, 6-l. 6-2. 6-4, 6-7

application range, 6-46, 6-47 application sizing, 6-41. 6-42 approximation for handling gas, 6-38, 6-39 calculation sequence and supplemental

equations, 6-42 cavitation in, 6-35, 6-36 downhole pump accessories, 6-47 to 6-49 hydraulic, 6-6 installation. 6-43 mathematical presentation, 6-36 to 6-38 nomenclature. 6-35 nozzle and throat annulus area, 6-4 I nozzle and throat size. 6-39, 6-41 performance characteristics. 6-34 to 6-37 production unit performance. 6-42 ratios and throat annulus areas, 6-40 reverse-flow casing type, 6-5 single seal, 635 subsurface. 6-32, 6-47 worksheet and summary of equations,

6-44, 6-45 Jetting wells. 32-15 Jobo field, 46-4 Johnson pressure gauge, 30-2 Johnston-MaccoiSchlumberger BHP gauges,

30-4 Joint efficxncy. 12.38. 12-40 Joint-interest owner, 4 l-2 Joint-operating agreements, 57-9 Joint strength of.

casing, 2-2. 2-5, 2-7. 2-9. 2-l I, 2-13, 2-15, 2-17, 2-19. 2-60. 2-61

line pipe, 2-48, 2-61 to 2-64 tubing, 2-39. 2-41, 2-43, 2-61

Joint strength safety factor, 2-2. 2-32, 2-34, 2-35, 2-45, 2-46

Jostling decrement. 5 l-47 Joule-Thomson effect, 12-17, 14-2 Jug heater, 19-21 Jumpout load of casing. 2-61 Junction box, ESP, 7-7. 7-8 Jurassic, 36-2 Juvenile water. 24-2

K

K&C systems, 18-15 K-MonelO , 4-4. 4-5, 7-3. 7-6 K-value correlation, 39-12 K-values. 23-10. 23-l I. 25-5, 39.12, 48-4,

48-5 Kalman filtering, 50-S Kalrez@, 4-5 Kansas, 16-12, 16-13. 19-3. 21.2, 24.8,

24-9. 27-8, 27-10 to 27-13, 33-1, 39-25. 40.23, 44-42, 46-4, 46-14

Kansas Corp. Commission, 33-15 Kaolinite, 46-2 I, SO-2 I, 50.32, 50.34.

50-37 Karma” vortex trail, 13-49 Kay’s rule, 20-5 Kentucky, 24-6, 24-7. 41-l 1, 46-16, 54-l Kern River field, California, 46-4, 46-14,

46-15, 46-18, 46-20, 46-23. 46-24, 46-34, 46-39

Kerogen, 52-16 Kerosene, 19-4

PETROLEUM ENGINEERING HANDBOOK 42

Kick-off injection-gas pressure, 5-24. 5-25, 5-28, 5-33

Kickover tool, 5-2 Kihara potential, 25-5, 25-8, 25-9 Kill and choke (K&C) valves, 18-12 Kill fluid, S-24, IS-33 Killed steel, 12-41 Kilogram, definition of, I-69 Kilogram of the Archives, 1-69 Kilovoltamp reactive (WAR), 10-31, lo-33

to IO-35 Kilovoltamps (WA) rating of transformers,

IO-30 to 10-35 Kinematic viscosity, 6-67, 669, 19-8,

22-13, 24-16, 58-35 Kinetic energy, 6-34, 13-1, 1345, 20-1,

20-2, 34-9, 34-29, 34-36, 50-3, 50-8, SO-13

Kinetic mixer, 19-l 1, 19-12 Klinkenberg corrections, 27-1 Knife-edge blade electrodes, 53-8, 53-9 Knitted-wire-mesh coalescing pack, 12-10,

12-11 Knitted-wire-mesh fibrous packs, 12-12 Knitted-wire-mesh mist extractor, 12-7,

12-8, 12-10 Knocking, 6-33, 6-50 Knockout drum, trap or vessel, 12-1, 12-4 Kobe porosimeter, 26-4, 26-6 Kozeny equation. 26-20 Krypton-85, 46-21 Krypton-86, l-69, l-70 Kuparuk field, Alaska, 18-3 Kuster pressure gauges, 30-2 Kyrock field, Kentucky, 46-!6

L

La Concepcidn field, Venezuela, 24-13 La Paz field, Venezuela, 24-13 Laboratoty coreflood, 47-17, 47-21 Laboratory curves,

for lateral sonde, 49-13 for normal sonde, 49-12

Laboratory depletion recovery, 39-14 Laboratory-derived data, 39-10, 39-l 1 Laboratory displacement tests, 4440 Laboratory experimentation,

elemental models, 46-12, 46-13 fuel content, tirefloods, 46-16 of AOR and WAR, 46-17 partially scaled models, 46-13 use of water in firefloods, 46-18, 46-19

Laboratory layout for performing routine core analysis, 26-22

Laboratory-measured relative-permeability data, 374

Laboratory measurement of capillary pressure,

centrifuge method, 26-Z dynamic method, 26-24 evaporation method, 26-24 mercury-injection method, 2624 porous-diaphragm method, 26-24

Laboratory measurement of porosity, bulk volume, 26-3 carbonate rocks, 26-6, 26-7 pore volume, 26-5, 26-6 precision of measurement, 26-6 sand-grain volume, 26-3 to 26-5

Laboratory measurement of transit times, 5 l-26

Laboratorv pressure-depletion studv. 39-13 Laboratory PVT analysis, 39-13 . Laboratorv PVT data. 37-3 L.aborato~ restored-state floods, 444 Laboratory solubility tester, 54-10

Laboratory testing of formation rock for acidizing, 54-9

Labyrinth path design, 7-4 Labyrinth path protector, 74, 7-5, 7-11 Lacq Superieur field, France. 46-27 to

46-29 LACT systems or units, 11-13, 15-14, 174 Lactic acid as sequestering agent, 54-7 Lag, 13-50 Lag stroke, 52-8 Lag time, 52-8, 52-14, 52-18, 52-22 Lagoonal clays, 364 Lagoven, 46- 14 Lagunillas field, Venezuela, 24-13, 464 Lake Maracaibo field, Venezuela, 18-l Lakeview pool, California, 40-15 Laminar-flow regime, 28-13 Laminar-flow region, 34-3 Landman, 57-8 Landowner’s interest, 57-1, 57-2 Landowner’s royalty, 41-1 Langmuir constants, 25-9 Laplacian interblock flow terms, 48-15 LaSalle anticline, 24-7 Lasater correlation, 22-5 to 22-7, 22-9,

22-10 Laser liquid particle spectrometer, 12-15,

12-16 Last-chance hydraulic stab system, 18-15,

18-16 Last-stroke method, hydraulic pumping,

6-28 Latched packers, 4-3 Late-time region (LTR), 35-3, 35-6 to 35-8,

35-11, 35-12 Latent heat, factor in refrigeration cooling

load, 14-10 Latent heat from sensible heat, 19-15 Latent heat of steam. 46-5 Latent heat of vaporization, 46-2 Lateral device, 49-12, 49-19, 49-31 Lateral loading or loads, 18-S. 18-6 Lateral-sweep factor, 40-16, 40-17 Lateral wave loading or loads, 18-23, 18-26 Laterals in hard formations, 49-13 LaterologTM (LL). 49-1, 49-5, 49-6, 49.11,

49-18, 49-21, 49-23, 49-25, 49-27 Laterolog 3 (LL3), 49-18 to 49-22 Laterolog 7 (LL7), 49-18 to 49-22 Laterolog 8 (LLS), 49-15, 49-17. 49-20,

49-27 Layout drawings, 15-30 Layout of electrical offshore facilities, 1844 Leaching, 24-20, 26-2 Lead acetate, 52-6 Leak resistance, casing joints, 2-l Leak resistance limit, 2-59 Leakage,

fluid, 6-21 fluid-seal plunger, 6-33 in downhole unit, 6-55 in pump plungers, 84, 8-5 of field gas-condensate samples, 39-5 of pump, 6-24 of tubing pressure, 6-3 pressure-relief valve, 6-33

Leakoff of fluids, 54-8, 55-2, 554, 55-8 Leaky modes of acoustic waveforms, 51-12,

51-13 Leap-frog formulations, 48-14 Lease, and assignment provisions, 41-9

automatic custody transfer (LACT), 16-1, 16-7, 16-12, 16-13

bonus, 41-1, 41-13 broker, 57-8 facilities, 4 l-9 location data, 41-8

problems, 57-10 purchases, 57-8 tank battery installation, 1 I-10

Lease-operated hydrocarbon-recovery systems,

gas treating for removal of water vapor, -CO,, andH,S, 14-17 to 14-22 . low-temperature separation (LTS), 14-1 to

14-17 - references, 14-22

Leasehold costs, capitalized, 41-13 Leases, oil and gas, 57-1 to 57-12 Least-squares fit, 38-10 Lee-Kesler equation, 20-13, 20-17 Legal requirements, directional surveys,

53-4 Lena platform, 18-24 Length equivalents, table, 1-71 Length, standard of, l-70 Lenticular deposits, 49-25 Lessor, in the oil and gas lease, 57-3 LETC field site, Utah, 4633 Letter subscripts, SPE std., 59-52 to 59-70 Letter symbols for mathematical equations,

58-3 Letter symbols in alphabetical order, SPE

std., 59-2 to 59-17 Leutert pressure gauge, 30-2 Level controllers and gauges, 19-31 Lever-operated dump valves. 19-22 Lever rule, 23-5 Lever-type valve, 12-6, 12-18 Leverage, 41-8 Life of engine equipment, 10-16, lo-17 Lift equipment, effectiveness of, 40-27,

41-9 value of BHP measurements, 30-14

Lifting potential concept, 34-50 Lifting surface flowmeter, 32-13 Light, units and conversions. 58-36 Lightning arresters, 10-28 to IO-32 Lignites, 49-25 Liguera platform, 18-2 Limestone sonde, 49-14, 49-26, 49-27 Limit switches, 16-3, 16-13 Limitations of gas lift, 5-1, 5-2 Limited character sets, 58-l 1 Limited Entry@ technique, 55-9 Limiting tie line, 45-3 to 45-5 Line disconnect switch, lo-27 Line drive pattern, 44-1, 44-20, 44-25,

46-17, 46-18 Line pioe,

and- coupling, schematic, 2-54 axial stress, 2-48. 2-49 collapse pressure, 2-48, 249 collapse pressure under axial-tension

stress, 2-55 collapse resistance, 248 collapse resistance under axial load, 248,

249 dimensions, 2-47, 2-50 to 2-53 elongation, 246 equations for calculating performance.

246, 2-54 to 2-56 hydrostatic test pressure, 2-62, 2-63 internal-pressure leak resistance, 2-57 to

2-59 internal-pressure resistance, 2-56 internal yield pressure, 2-56 joint strength, 248 plain-end, 2-50 to 2-53 safety factors, 2-32 tensile strength, 246 test pressure, 247, 2-50 to 2-53, 2-62 thread dimensions, 2-58, 2-65 thread form, 2-62

SUBJECT INDEX 43

thread height dimensions, 2-62 threaded or threads, 2-47, 2-48, 3-2 tolerance on lengths, 247 weight, 247, 2-50 yield strength, 246

Line scale, 12-2 Line sink, 39-20 Line source, 39-20 Line-source solution. 35-4 Line tension, maximum, 18-10 Linear-absorption coefficient, 50-7 Linear aquifers, 38-2, 38-4, 38-18 Linear diffraction analysis, 18-39 Linear dimensions, conversion of, 58-7

units applied to, 58-5 Linear-flow system, 26-13 to 26-15 Linear frontal advance, 38-13 Linear gels, 55-5, 55-6 Linear geometry, definition, 38-l Linear parabolic difference equations, 48-15 Linear partial differential equation, 35-1,

35-10 Linear variable differential transformer,

51-5 Linear velocities, conversion of, table, 1-76 Lined pipe, 39-26 Liners in steel pipe, 15-10 Lipophiles, 47-7, 47-11, 47-19 Liquefaction, 12-3 Liquefied gases in acidizing, 54-8 Liquefied petroleum gas (LPC), as

injection fluid, 42-2, 45-1 to 45-3, 45-6 to 45-9, 45-12, 45-13

Liquefied petroleum products, density of, 17-5

Liquid block or blocking, 39-26, 46-1, 46-3 Liquid (oil) capacity of separators, 12-28,

12-29, 12-31 Liquid carryover, from compressor, 39-26

in mist extractor, 12-40 in separator, 12-42

Liquid contents of GC systems, 39-4 Liquid desiccants, 14-17 Liquid-discharge control valves, 12-42 Liquid-distribution coefficient, 34-39. 34-40 Liquid entrainment, 34-36 Liquid fallback, 5-40, 5-43, 5-44, 5-48,

5-52 Liquid/gas ratio, 12-35, 39-2, 39-5 Liquid holdup, 34-36, 34-37, 34-46 Liquid hydrocarbon, 12-33, 12-35 Liquid-hydrocarbon content, 12-15 Liquid-hydrocarbon recovery, 11-13 Liquid injection, BHP calculation, 34-28 Liquid knockout, 12-l Liquid-level control, 3-19, 13-51, 13-53,

13-54 Liquid-level controller. 12-2, 12-5 to 12-7,

12-9, 12-18, 12-35, 12-39, 14-3, 14-14, 14.18, 19-17 to 19-20, 19-31, 32-7

Liquid-level controls, 16-4, 16-5 Liquid/liquid equilibria, 23-l Liquid loading in wells, 34-46, 34-50 Liquid measurement, 16-S Liquid mist, 12-8 to 12-12, 12-20, 12-22 Liquid natural gas (LNG), 17-4, 17-7 Liquid petroleum, calculation of quantities

measured by turbine or displacement meters, 17-7

Liquid petroleum (LP) gas, 10-15, 10-16, 17-4

Liquid-phase distribution, 39-25 Liquid-phase shrinkage, 39-4 Liquid production per cycle, 5-52 Liquid recovery, maximum, 5-51, 12-32 Liquid recovery per cycle, 5-40 Liquid-saturation data, 27-8

Liquid saturations, 27-8 Liquid seal in separator, 12-5 Liquid slug process, 45-l Liquid slugs, 5-1, 5-11, 5-19, 5-38 to 544,

5-51, 5-52, 5-54 Liquid-storage facilities, 12-33 Liquid surges, 12-2, 12-20 Liquid turbine meters, 1348 Liquid/vapor equilibrium, 23-1, 23-5 Liter, definition of, l-69 Lithium, 24-9, 24-20, 24-21, 50-6, 50-14 Lithological log, 52-14, 52-19 Lithology determination,

direct measurement, 50-37 induced-gamma-ray spectrometry, 50-34,

50-35 introduction, 50-2 neutron/density combination, 50-33 photoelectric factor, 50-33, 50-34

Lithology, effect on formation factor, 49-4 effect on water-injection efficiency, 44-2 estimation from logs, 51-35 parameters, 50-18

Lithostatic pressure, 26-8 Lloydminster field, Canada, 46-34 Lloyds of London, 18-44 Load analyses, offshore facilities, 1844 Load capacity, ultrahigh-slip motor, lo-22 Load fluid gradient, 5-25, 5-28, 5-33, 545,

546 Load fluid production rate, 5-53 Load fluid traverse, 5-25 Load production pressure, 549 Loading or load up of wells, 32-15, 34-46,

34-50. 39-16 Loan payout calculation factors, 4 l-32 to

41-35 Loan payout, calculation of, 41-31 to 41-36 Local control loops, 1847 Local remote switch, lo-27 Location surveys offshore, 18-5 Lock screws, 3-3, 3-5, 3-6, 3-8, 3-9 Lockout cap, 3-27 Log analyses, company computer centers,

49-37 in coring program, thermal recovery, 46-21

Log-linear grid, 49- 15 Log mean temperature, 34-8, 34-9 Log-normal permeability distribution, 44-8 Log presentation, acoustic logging, 51-16 Log (electric) presentation and scales,

49-15, 49-16, 49-22, 49-23 Log-probability graph paper, 40-18 Logarithmic decrement, 514, 51-47 Logarithmic energy decrement, average,

50- 10, 50-l I, 50-22 Logarithmic probability diagram, 56-6, 56-7 Logarithmic sensitivity scale, 49-27 Logarithms of equivalents, l-73, l-75, 1-77 Logging engineer, 52-30 Logging geologist, 52-9, 52-18, 52-30 Logging-system schematic, MWD, 53-2,

53-3 Logging umt systems, 52-25, 52-26 Logistics considerations offshore, 18-4, 18-5 Long Beach crude oil, 47-20 Long, gross, or shipper’s ton, l-70 Long-range planning, 42-1 Long-spaced acoustic logging,

borehole-size effects, 5 I-19, 51-20 formation-alteration effect, 51-20, 5 l-21 introduction to, 51-19 summary of. 51-23, 51-24 tool, 51-21 to 51-23, 51-47

Long-spaced acoustic logs. 51-22 Long Spacing SonicTM tool, 51-21

Long-term forecast, gas-well performance, 35-13

Long-thread casing, 2-5, 2-7, 2-9, 2-l 1, 2-13, 2-15, 2-17, 2-19, 2-31, 2-58, 2-64

Longitudinal capillary imbibition, 28-12 Longitudinal dispersion, 45-6 Longitudinal waves, 51-2 Looped networks in gathering and

distribution systems, 15-14 Lorenz coefficient, 44-36 Los Angeles, 46-24 Loss-free propagation time. 49-32 to 49-34 Loss-ratio method, 40-32 Louisiana, 18-1, 18-2, 214, 24-7, 24-8,

24-20, 26-7, 26-23, 27-6 to 27-8, 29-3, 32-1, 36-4, 37-25, 39-16, 40-23, 41-1, 44-37, 46-3, 46-4, 46-15, 46-18, 46-19, 49-29, 574, 57-10, 57-l 1

Louisiana Dept. of Conservation, 32- 1 Louisiana gulf coast, 27-6 to 27-8, 44-37,

51-22, 51-23 Louvered baffles, 19-23 Low-alloy steel, 12-41 Low-interfacial-tension (IFT) processes,

lowering ROS, 47-9, 47-10 MP flooding, 47-10 to 47-18

Low-liquid-level control, 12-39 Low-pressure service regulators, 13-55 Low-pressure waterflooding, 42-2 Low-temperature fractional distillation, 39-6 Low-temperature operation of separator,

12-40 Low-temperature separation (LTS),

temperature, 14-17 with hydrate inhibitor, 14-6 to 14-8 without hydrate inhibitor, 14-3 to 14-6

Low-temperature separation (LTS) systems, compression refrigeration, 14-9, 14-10 constant-enthalpy expansion, 14-3 to 14-8 cooling, 14-1, 14-2 hydrate formation, 14-2, 14-3 hydrocarbon stabilization, 14-13 to 14-17 mechanical refrigeration, 14-8, 14-9 retrograde condensation, 14-l selective absorption, 14-10 to 14-13 theoretical considerations, 14-1 to 14-3 turbine expansion, 14-8

Low-temperature separation (LTS) unit, 12-1, 13-57, 18-46

Low-temperature separator, 12-17. 14-5 Low-temperature stabilization, 14-7 Low-tension ignition, lo-17 Lower explosive limit (LEL), 1847 Lower marine riser package (LMRP),

18-12, 18-15, 18-17, 18-19 Lubricating oils, temperature correction for,

17-6 Lubrication of pumping units, lo-12 Lubricator, 648, 6-54, 6-57 Luminous flux, unit and definition. 58-11,

58-23, 58-37 Lump-sum deferment factors, 41-20, 41.21,

41-24, 41-25 Lump-sum payment, 41-25 Lynes BHP gauges, 30-4

M

Machining details, extreme-line casing joint, 2-64, 2-67, 2-68

Macrodevices, 49-7, 49-14 Macroresistivity curves, 49-26 Macroscopic anisotropy, 49-5 Macroscopic convective dispersion, 45-6 Macroscopic cross section, 50-10, 50-21,

50-23, 50-36 Macroscopic fluid velocity, 35-10


Macroscopic photoelectric cross sectton. 50-17. 50-33. so-34

Macroscoptc thermal absorption cross section, 50-10 to 50-12, 50-21, 50-30, 50-33

Magnelog. 53-19 Magnesium, 24-5, 24-6, 24-8 to 24-13,

24-18. 24-20. 24-21, 4444, 4445. 47-13

Magnesium chloride, 8-9, 19-29, 54-l Magnetic collar locator, S3- 18 Magnetic compass for hole deviation, 53-3,

53-4 Magnetic flux, 53-21 to 53-23 Magnetic flux density, unit and deftnmon.

58-l I, 58-23. 58-36 Magnettc flux, untt and definition, 58-l I,

58-23. 58-36 Magnetic induction, unit and detinitton.

SE- I I, SE-36 Magnetic permeability, 49-33. 53-23 Magnetic relative permeability, 53-20 Magnetic sensor, 13-48 Magnetic tape recordings. 49-36, 49-37 Magnetic trip capability of circuit breakers,

IO-28 Magnetic valve operators, 16-3 Magnetism, units and conversions, 58-36 Magnetometer. 18-S Magnetos. IO- I7 Magnolia Petroleum Co.. 46-14, 46-16 Main Reservoir field, Louisiana. 37-25 Maintenance and operation of tank batteries,

II-IO. II-11 Maintenance cost, emulsion treating, 19-33 Major thermal recovery projects, 46-3. 46-4 Makeup gas, 39-23, 39-24, 4441 Mandl-Volek model, 46-15 Mandl-Volek refinement of Marx-

Langenheim method, 46-8, 46-9 Mandrel and boll-weevil tubing hangers,

3-16 Mandrel hanger, 3-39 Manganese, 3-3. 24-4, 24-S. 24-9, 4444,

50-12, 50-18, SO-35 Manifolds, high-pressure. 55-9 Mamfolds in subsea completions, 18-32 Mamtoba, Canada, 24-8 Manometer factor. 13-8. 13-35 Manual adjustable positive choke, 13-57 Manual casing hanger, 3-6 Manual emergency shut-down valve, 3-19 Manufacture. of fiberglass sucker rods. 9- 12

of steel sucker rods. 9-l. 9-2 Manufacturer’s field representative, 7-13 Manufacturers’ pumps,

multiplex-plunger type, 6-52 to 6-55 nozzle and throat stzes. 6-39 nozzle vs. throat annulus area, 6-41 throat annulus areas and area ratios. 6-40 types of. 6-10 to 6-17

Manufacturers’ rated capacities for separators, 12-32

Manways, 1 l-6. 12-42 Marathon Oil Co.. 46-15 Maraven. 46-4. 46-15 Marginal well tests, 12-17 Maricopa field, Califorma. 6-24 Marine bulk carriers. metering systems for

loading and unloading. 17-4 Marine cargo inspection, guidelines for,

17-E Marine environment. 56-2 Marine measurement, 17-E Marine pipelines, 18-43 Marme risers. 18-14 to 18-16. 18-19 Marine terminals. 18-43

Marine water. 24-19, 24-20 Mark II crank-balanced pumping units, 10-t

to 10-4, 10-6, 10-E. IO-9 Market capacity. 32-l Market value. 41-3, 41-5, 41-6 Market-value yardstick, 41-5 Marx-Langenheim method, 46-7 to 46-9 Mass-absorption coefficient, 50-8 Mass-balance equations, 48-3 Mass balance of hydrocarbons, 46-11 Mass balance of oxygen, 46-12 Mass balance of water. 46-11 Mass-conservatton equation, 48-3. 48-S Mass equivalents, table, l-75 Mass flowmeter, 32-13 Mass flow ratio, 6-36 to 6-38, 6-45 Mass or force as weight quantity, 58-3,

58-S Mass, special terms and quantities

involving, 58-7, SE-8 Mass spectrometry, 27-l Mass, standard of. I-70 Mass, unit and definition, 58-3, 58-5,

58-23. 58-27 Mass vs. weight, I-70 Massachusetts Inst. of Technoloav, 51-49 Material balance, 14-16, 38-4, 38-S Material-balance calculations, 22-13, 28-t I,

35-16, 37-13. 40-1, 40-13, 40-24, 42-3, 43.12, 43-16. 48-l. 48-14

Material-balance equation, 35-8, 37-2, 37-5 to 37-7, 37.10. 37-13 to 37.17, 38-4, 38-8. 38-9, 38-12 to 38-14, 40-6, 40-7, 40-9, 40.10, 40.12, 40-33, 40.44, 43-4, 43-6. 43-X. 43-12, 43-13

Material-balance method, for average reservoir pressure, 3.5-3

for nonassociated gas reservoirs, 40-33 for oil in place, 40-2, 40-6 to 40-E

Material-balance studies, 36-7 Materials of construction for separators,

12-38, 12-39 Materials of construction for storage tanks,

1 l-9 Mathematical analysis of areal pattern

efficiency, 44-13 to 4417 Mathematical analysis. water-drive oil

reservoirs, 38-i to 3X-17 Mathematical modeling, 28-7, 28-10 Mathematical models.9.3, 36-10. 39-17,

39-18, 48-l Mathematical reservoir simulatton, 39-24,

45-10 Mathematical reservoir simulators, 39-22 Mathematical-simulation models, 38-16 Mathematical simulators. 39-17, 45-13 Mathematical iables, 1-2 to 1-67 Matrix acid stimulation, 56-5 Matrix acidizing.

A/V ratio high. 54-5 carbonate formations, 54-10, 54-l 1 definition of. 54-8 overflush. 54-t 1 sandstone formattons. 54-l 1 with surfactants. 54-6

Matrtx blocks. 48-5 Matrix compactron. 26-7 Matrix correctton chart. SO-29 Matrix, definition, 26-2 Matrix density. 50-l. 50-27, 50-28 Matrix effect on neutron porosny, 50-28 to

50-30 Matrix identification chart, 50-19 Matrix permeability, 26-15. 27-18 Matrix porosity, 26-7. 44-2 Matrix steam injection. 46-27, 4628 Matrix transit time. 51-30, 51-35

Matrix treatment with acid, 56-5 Maximum efficient rate (MER), 32-2, 41-9 Maximum-indicating pressure gauge, 30-4 Maximum present worth, 42-2 Maximum producible oil index, 49-28 Maximum theoretical valve spread, 542 Maximum transfer pressure, 5-32 Maxwell’s equation, 49-33 May Libby field, Lomsiana, 46-15 Mean average boiling point, 21-l 1, 21-12.

21-15 Mean free path. 50-10. SO-22 Mean hydrauhc radius, 26-31 Means field. Texas, 36-5, 36-7 Measured phase compositions, 23-12 Measurement,

of barges, 17-3 of horizontal tanks, 17-3 of liquid hydrocarbons by displacement

meter systems, 17-4 of petroleum by weight, 17-7, 17-8 of petroleum liquid hydrocarbons by

positive-displacement meter, 17-4, 17-5 of spheres and spherotds. 17-3 of tank cats, 17-3 of upright cylindrical tanks, 17-3

Measurement control charts 17-7 Measurement methodologies of relative

permeability, - calculation methods, 28-7 capillary-pressure and endpoint-

displacement method, 28-8 critique of methods, 28-7 stationary-fluids methods. 28-8 stead-,-state methods. 28-3 to 28-7 unsteady-state methods, 28-7

Measurement tickets, 17-7 Measurement-while-drilling (MWD),

data listing for, 53-6 data-transmission schematic. 53-2 directional vs. multishot directional, 53-S downhole assembly, 53-2 log, 53-2, 53-4 logging system, 53-3 measuring systems, 53-l rotary-drilling log, 53-4 services, 52-1, 52-28

Measuring crude oil. 17-I to 17-8 Measuring natural-gas fluids, 17-7 Measuring quality of separated fluids,

12-15, 12-16 Measuring temperature of petroleum and

petroleum products, 17-5 to 17-7 Mechanical damage, 5 I-20 Mechanical data, electric submersible pump

(ESP), 7-9 Mechanical degradation. 47-S Mechanical energy, 22-21, 51-2, 51-3 Mechanical-energy gradients, 28-13. 28-14 Mechanical fail&, -39-25 Mechanical flow sheets, IS-31 Mechanical lock holddown, 8-8 Mechanical losses in hydraulic pumps, 6-19.

6-20, 6-21 Mechanical power. 6- I5 Mechanical pressure control, 12-39 Mechanical properties.

elasttc module, 5 I-43 fracturing. 51-44 sand control, 5 145

Mechanical recording BHP gauges, 30-2 Mechanical refrigeration. I I-13 Mechanical-refrigeration systems, 14-8 to

14-10 Mechamcal trmers, 164 Mechanical wave propagation. 5 l-2 Mechamcally operated valve. 13-53

SUBJECT INDEX 45

Mechanically set packer, 4-3, 4-4, 4-6 Mechanics, units and conversions, 58-33,

58-34 Mediterranean Sea, 24-19 Medium-slip motors. 9-3 Melcher-Nutting grain-volume method, 26-3 Melting curve, 23.l( 23-2 Membrane-filterability tests, 4443 Membrane filtration, 24-18 to 24-20 Memory jogger, metric units, 58-21 Mene Grande field, 24-13 Mene Grande Oil Co.. 46-16 Mene Grande tar sand, Venezuela, 46-3 Mercaptans, 14-17 Mercury. 26-3, 26-4, 26-24. 39-8 Merc&njection method of capillary-

pressure measurement, 26-24, 26-25 Mercury manometers, 13-3, 13-36 Mercury method of calculating directional

surveys. 53-6 Mercury porosimeter, 26-22 Mercury-pump method, 52-19 Mercury-pump porosimeter, 26-6 Mercury test site, Nevada, 53-5 Mercury-type meters, 13-8, 13-35 to 13-37 Mercury valve switch, 16-3 Metal-on-metal seal ring, 18-18 Metal spray coupling, 9-9 Metal-to-metal plungers, 8-4 Metallic storage tanks, 1 l-9 Metamorphosed rock, 29-3, 29-8 Metastable dewpoint locus, 25-1, 25-2 Metastable equilibrium, 14-4 Metastable-equilibrium locus, 25-2 Metastable liquid water, 25-10 Meteoric water, 24-2 Meter, definition, 1-69 Meter factor or multipliers, 32-10, 32-12,

32-13 Meter loops, 6-54 Meter model. 474 Meter proving, 16-6. 16-14, 17-4 Meter-tank-type LACT system, 16-12,

16-13 Meter tube, 5-53 Metering and metering assemblies, 17-4,

17-5 Metermg separator, 12-17 to 12-19, 32-13,

32. I4 Metering systems,

critical flow provers, 13-37. 13-45 orifice well tester. 13-37 pitot tube, 13-2, 13-45 velocity, other meters using, 13-45,

13-48. 13-49 Metering trim. 13-53 Meters using velocity,

centrifugal (elbow) meters, 13-45 eccentric orifices, 13-45 rotameter, 13-45 segmental orifices, 13-45 sonic meters, 13-48 turbine meters, 1345 vortex shedding meter. 13-48

Methaneibutaneldecane system, 23-5 Methane/butane system, 23-6 Methaneidecane system. 23-6 Methane hydrates, 25 10 Methane/propane hydrates, 25-10 Methane/propane system, 25-9 Methane/propane/water system, 25-10 Methane-rich gas, 25-13 Methane/water system. 25-l. 25-2. 25-17.

25-18 Methanol, as hydrate inhibitor. 25-19. 25-20

for freezing and corrosion protection, 3-3.5

Method of least squares. 26-3 1. 40-6

Methyl alcohol, in acidizing, 54-8 in in-situ formation of hydrofluoric acid,

54-4 Methyl orange end point, 54-3 Methyldiethanolamine (MDEA), 14-21,

14-22 Metric Conversion Act of 1975, l-69 Metric standard for orifice equations and

constants, 13-3 Metric system,

definition. origin, and development, l-68, l-69

Intl. Bureau of Weights and Measures, I-69

present status in U.S., l-69 units and standards of, 1-69

Metric ton, l-70 Mexico, 12-39, 21-2. 58-20 Micellar floods, 19-28, 48-5. 48-7 Micellar fluids, 28-l 1 Micellarlpolymer (MP) flooding, 47- 1, 47-9

to 47-22, 48-6 formulation, 47-13, 47-15 phase behavior, 47-l 1, 47-13, 47-20 slug, 47-10, 47-15 to 47-17 surfactants, 47-7, 47-17

Micelles, 47-10, 47-1 1 Microannulus, 51-41 Microbiological growth, 44-44 Microcaliper curve. 49-1, 49-l I, 49-22,

49-25, 49-26, 49-29, 49-31 Microcaliper log, 53-16 Microcomputers, 16-1, 16-6, 16-8 Microdevices, 49-7, 49-14 Microemulsion, 28-1 I, 45-l Microemulsion flooding, 47-10 Microemulsion phase, 47-l 1 to 47-14 Microfiche, 17-5 Microfilm, 17-S Microinverse, 49-23 Microlaterolog (MLL), 49-22, 49-24 to

49-26. 49-28 Microlog (ML), 26-31, 443, 49-22 to

49-29, 49.31. 49-32 Microlog shaly-sand method. 49-28 Micrometer screw, 26-3, 26-4 Micronormal. 49-23 Microprocessor-based instrument system,

18-47 Microprocessors, 16-l Microresistivtty. 51-19 Microresistivity devices, 49-1, 49-22 to

49-25, 49-26 Microresistivity survey, 49-11 Microscopic anisotropy, 49-5 Microscopic convective dispersion, 45-6 Microscopic cross section, 50-6 Microscopic displacement of fluids, 39- I8 Microscopic efficiency, 40-34 Microscopic pore volumes, 39-17 Microscopic studies, 46-2 1 Microscopic sweep efficiency, 47-2 Microseismogram, 5 l-24, 51-35, 51-45,

51-46 Micro-Seismogram LogTM. 51-18 MJCROSFL (MSFL), 49-20, 49-22, 49-24,

49-25 Microswitch valve switch, 16-3 Mid-American trench, 25-18 Mid-Continent, 21-4, 21-6, 24-8 to 24-10,

29-3. 40-19, 41-5, 44-4 Middle East, 27-9, 27-20. 52-22 Middle-time region (MTR). 35-3, 35-4,

35-6. 35-8, 35-10 to 35-12, 35-14. 35-15

Midway field, California, 29-2

Midway Sunset field, California, 4614, 46-15, 46-18, 46-19

Midwest Research Inst., 8-10 Midyear compound-interest factor, 4 1 17 Midyear lump-sum deferment factor, 41-6 to

41-8, 41-27 to 41-29 Miga field, Venezuela. 46-15, 46-18 Migration length, 50-12, 50-20, 50-21,

50-29, 50-30, 50-32 Migration of clay particles, 56-5 Migration of oil and gas, 24-l Migration of oil, 24-17

of water, 24-18 Mile Six Pool, Peru, 40-14 Mill scale, I l-5 Mill varnish, 51-41, 56-3 Miller-Dyes-Hutchinson (MDH) plot, 35-15,

35-17 to 35-20 MilliporerM filter test, 44-45 Mineral,

analyses of cores, 46-2 1 deeds, 57-6 dissolution, 47-20 interests, 41-1, 41-15, 57-6 owner, 57-1, 57-6 severance, 57-2

Mineral Management Service, 3-34 Mineralogy, 56-3 Minerals, in water, 4444, 44-45

in a lease or a conveyance, definition, 57-2

recovery from brines, 24-20, 24-21 Miner’s rule, 18-27 Minicomputer, 5 l-4 Minifrac job, 55-9 Minimum hydrodynamic potential, 29-3.

29-B Minimum miscibility pressure (MMP), 45-6.

45-8, 45-9 Minimum pump intake pressure, 7-10 Minor isostatic adjustment, 29-7, 29-8 Miscibility, definition, 45. I, 45-6

development, 45-4, 45-5 maintaining, 45-7 of methane gas and propane liquid, 45-2 of propane liquid and oil, 45-2 of refrigerants with water. 14-10 pressure, 22- 17 providing to improve recovery, 39-15

Miscible displacement, engineering examples, 45-10 to 45-13 engineering study, 45-8 to 45-10 factors affecting displacement efficiency,

45-6 to 45-8 fluids, 40-4 general references, 45-15 introduction, 45-1 methods. 44-19 nomenclature, 45-13 numerical dispersion effect in, 48-10 processes, 23-7 references, 40-13 to 40-15 theoretical aspects, 45-l to 45-6

Miscible-drive projects, 42-5 Miscible flood, 39-23, 48-2, 48-10 Miscible-fluid displacement. 43-7 Miscible-phase displacement, 39-16 Miscible processes, 39-18 Miscible slug process, 42-2. 45-l to 45-3,

45-6 to 45-9, 45-12, 45-13 Mississippi, 24-20, 24-21, 26-19, 40-23,

46-3, 46-4, 46-15. 46-18, 46-28 to 46-30, 54. I

Mississippi River, 36-4 Missour), 24-B, 46-3, 46-14 Mist eliminators, 12-12, 39-26


Mist extractors. 12-l to 12-5, 12-7 to 12-9, Lasater, 22-5 to 22-7, 22-9, 22-10 Mooring analysis, 18-9, 18-16, 18-17, 12-11, 12-12. 12-1.5, 12-19, 12-21. Mandl-Volek. 46-15 18-21 12-23 to 12-26, 12-31, 12-40, 19-22. 19-24, 19-25, 39-26

Mist flow, 34-27, 34-36, 34-37, 3440 Mix-based fracturing fluids, 55-7, 55-8 Mixed-lithology rocks, 51-35 Mixing efficiency, 19-27 mm to decimals of an in., table, l-72 Mobil Corp., 46-4, 46-15, 46-18 Mobile analyzer, 24-4 Mobility, 58-38 Mobility-buffer drives, 47-l Mobility buffer, MP flooding, 47-10, 47-17 Mobility-buffer salinity, 47-15 Mobility-control processes,

effect of low mobility on oil recovery, 47-1, 47-2

foam floodine, 47-6 to 47-9 polymer flooding, 47-2 to 47-6

Mobility improvement, 44-39, 44-40 Mobility of hisplacing fluid, 44-17 Mobility of foams, 47-8, 47-9 Mobility ratio, 39-15, 39-18, 39-21, 40-18,

40-19, 43-7, 43-8, 44-4, 44-8 to 44-10, 4415, 44-17 to 4425, 4427, 44-29, 4433 to 44-40, 45-4, 45-7, 45-9, 45-l 1, 47-1, 47-2, 47-20

Mobility-ratio effects, 44-17 to 44-24, 44-34, 4436

Mobility. total, 35-2 Model assumptions, 48-9 Model basin,’ 18-7 Mode1 formulation, 48-14 to 48-16 Model grid selection, 48-7 Model input data, 48-6 Model, radial flow, 35-6 Model(s).

analog, 39-22, 44 18 analytical for pump performance, 7-12 analytical for steam injection, 46-7 to

46-l 1 assumptions, 48-9 black oil, 48-4 to 48-7, 48-9, 48-14 blotter, 44 17 bundle of capillary tubes, 28-12 chemical flood, 48-4, 48-5, 48-7 composItional, 43-2, 48-4, 48-6, 48-7,

48-9, 48m 14 computer, 39-4, 44-38 conductive cloth, 44-20 dispersed clay, 5 1-34 drilling, 52-24 10 52-26 dual-water, 49-38 electrolytic, 39-20, 39-21, 4417, 4418,

44-20, 44-2 1 electronic. 39-20 elemental, 46-11 to 46-13 fluid flow, 44-20. 44-21 fluid mapper, 4420 fractured matrix, 48-5 framewood structural. 5 l-34 frontal displacement, 46-7 to 46-9 future interpretation, 50-36 gel or gelatin, 39-2, 44-17, 44-18, 44-20,

44-2 1 geochemical, 24-20 grain boundary structural, 51-34 graphical, 22-5, 22-7, 22-8 graphite-impregnated cloth. 39-2 1 aridded reservoir, 37-2. 37-5. 37-l I high-pressure. 46-13 hydrate dissociation, 25-9 idealized pore, 26-28 in-situ combustion, 46-12 isothermal, 48-4 Kuster-Toksdz. 5 1-34 laminated. 5 1-34

mathematical, 9-3, 36-10, 39-17, 39-18, 48-1, 48-16, 48-17

mathematical simulation, 38-16 meter, 47-4 numerical, 44-17. 44-20, 46-l 1, 46-20 numerical simulation, 40-2 partially scaled, 46-l 1 to 46-13 perforation prediction, 37-19 physical, 46-1 1 to 46-13 porous reservoir, 44-17 positive seal double-bag, 7-l 1 potentiometric, 39-21, 39-22, 4417,

44-19, 44-34 power law, 47-4, 55-5 process, 28-3 randomized network, 28-12 reservoir simulation, 38-16, 40-34, 43-2,

43-17, 48-1 to 48-6 resistance network, 44-20 rock flow, 44-20 sand, for fluid flow, 26-l 1 to 26-13 scaled physical, 45-10 scaled porous, 44-17, 44-34 shalv sand, 51-34 simple two-mineral, 50-33 simulation, 44-31, 44-32, 48-7 to 48-9 steam chest, 46-9 steam injection, 46-l I, 46-12 streamtube, 45-10 tandem labyrinth path, 7-11 tank-type, 37-2, 37-4, 37-5, 37-l 1, 37-14,

37-17 theoretical, 5 l-8 thermal, 48-4 to 48-7, 48-14 thermal numerical, 46-12 vacuum, 46. I3

Modems, 16-10 Modified black-oil simulator, 45-10 Modified Griffith and Wallis method, 34-37 Modified Stiles permeability-block method,

40-20 Modified turnkey format, 15-32 Modulus of elasticity, 9-3, 9-l 1, 9-12 Moisture-resistant coatings. I l-6 Molal average boiling point. 21-6, 21-11,

21-13 to 21-15 Mole, definition, 22-21 Mole fraction gas mixtures, 20-4 Mole, unit and definition, 58-25 Molecular diffusion, 45-6 Molecular sieves, 14-21 Molecular weight, 20-1, 20-3, 204, 20-9,

20-10 Molecular weight, effect on water content in

vapor phase, 25-16 Molybdenum, 9-5 Moment of inertia, 58-34 Monatonic gases, 13-37 Monel@ , 3-36, 7-5, 15-21, 30-4 Monel bellows, 5-16. 5-17 Monitor log, 53-8. 53-l 1 Monitoring programs, thermal recovery,

46-20, 46-2 I Monoethanolamine (MEA), 14-2 1, 14-22 Monotube separator, 12-16, 12-21, 12-22 Monovalent cation. 47-15 Monovalent/divalent ratios, 47-13 Montana, 24-8. 24-l 1. 24-20, 40-23 Montmorillonite, 442, 47-2 1, 52-2 I, 52-22 Moody diagram, 15-2, 15-3. 15-7 Moody friction factor, 34-24, 34-38 Moonpool, 18-2, 18-23, 18-42 Moored buoy, 18-30 Moored positioning, 18.2, 18.9

Mooring systems, 18-4, 18-8 to 18.10, 18-16, 18-18, 18-21, 18-24

Morkill method, 41-16. 41-19, 41-22 Mother Hubbard clause, 57-6 Motion characteristics, drilling vessels, 18-7 Motion compensators, 18-2 Motion-response curves, 18-l Motor control centers (MCC’s), 18-44,

1846 Motor, control for, IO-27 to lo-29

cyclic load factor of, lo-25 derating factors for. IO-25 direct current. IO-21 drip-proof, 10-26, 18-46 efficiency of, IO-25 electric, for oilwell pumping, lo-19 to

10-37 enclosures for, lo-26 explosion-proof, 10-27, 18-46 fr&tional horsepower, 18-46 fuses for, IO-28 horsepower ratings of, IO-20 induction, lo-19 to 10-21, IO-23 to lo-25 insulation for, IO-26 multiple-horsepower rated, lo-20 multiple-size rated, IO-21 oiltield, control for and protection of,

lo-27 to lo-29 performance factors of, IO-23 to IO-26 power factor of, IO-25 power triangle for, lo-33 rated voltage, 10-2 1 selecting size of, lo-21 service factor of. 10-25. lo-26 single-phase, 10-2 I slip of, 10-23, IO-24 speed variations of, 10-24, IO-25 splash-prmf, IO-26 starter contactor for, lo-28 temperature rise of, lo-26 torque of, IO-25 totally enclosed, 10-26, 18-46 ultra-slip, IO-24 voltage frequency of, IO-2 I, IO-23 winding temperature sensors, lo-29

Motor flat cable, ESP, 7-5 Motor horsepower, IO-36 Motor load transducers, 46-2 I Motor rated voltage, IO-21 Motor torque, IO-24 Motor valve diaphragm pressure, 13-54 Motor winding temperature sensor, lo-29 Motor windings. lo-26 Mount Poso field, California, 46-4, 46-15,

46-18 Movable oil, 46-8 Mud acid, 56-5 Mud acid preflush, 54-4 Mud acid system, 54-4, 54-l 1 Mud contamination, 56-l. 56-3 Mud damage, 35-4 Mud-dispersing agents. 56-l Mud log, 49-23 Mud-log data, 52-26 Mud-log format, 52-l I to 52-16 Mud-log services, 52-1, 52-2 Mud logger, 52-30 Mud logging, 52-l to 52-30 Mud logging contractor services, 52-28 Mud removal, 56-l Mud-removal acid, 54-3, 54-4, 54-l I Mud transit time, 51-20, 51-23 Mud weight, 30-15 Mud-weight factors, 2-1 I 2-3, 2-33, 2-38

SUBJECT INDEX 47

Multicomponent Rash method, 37-23 to 37-26

Multicylinder diesel engines, lo-17 Multicylinder gas engine. 6-l Multicylinder pump, 4447 Multifingered caliper logs, 53- I7 Multilayer prediction method, 44-31 Multiphase displacement experiments. 28-3 Multiphase flow, Buckley-Leverett

description of, 28-6 continuous-flow gas-lift design, 3440 to

34-45, 34-50 correlations, 5-22, 5-25, 5-26, 5-38, 5-40,

34-37, 37-40 gas plus liquid, hydraulic pumping, 6-27 immiscible fluids, no gravity forces, 28-2 in heterogeneous porous media, 48-1,

48-2 introduction, 34-35, 34-36 modeling of, 28-12 pseudosteady-state behavior. 35-6 theoretical considerations, 34-36, 34-37 well-performance equation, 35-2

Multiphase flowing gradient calculations, 6-72

Multiphase flowing pressure-gradient curves, 5-2 1

Multiphase inflow performance relationship

Natl. Electric Code (NEC), IO-26 Natl. Electrical Code, 18-46 Natl. Electrical Manufacturers Assn.

(NEMA), classification for control enclosures, 7-5, 7-6, IO-27

D-electric motors, 10-17, lo-18 rated motors. IO-24 specifications for motors, IO-20

Natl. Science Foundation. IX-15 Natural cosecants, table, l-48, l-49 Natural cosines, table, l-44, l-45, l-50 to

I-54 (IPR) equation, 34-32

Multiphase pressure-drop correlations, 34-37 Multipiece structure, 18-23 Multiple-bore mandrel tubing hanger, 3-14,

Natural cotangents, table, l-46, l-47, l-50 to l-54

3-16 Multiple-bore riser, 18-35 Multiple-completion equipment, 3-13 Multiple completions, 56-5 Multiple-contact miscibility, 39-16, 45-1,

45-5, 45-6. 48-5, 48-10 Multiple-cylinder engines, IO-15 Multiple-horsepower-rated motors, lo-20 Multiple-motor installation, IO-36 Multiple-parallel tubing strings, 3-14 Multiple-regression equation, 2-60 Multiple-seal pumps, 6-39 Multiple-segment tubing hanger, 3-16 Multiple-size-rated motors, lo-21 Multiple-stage separation, 12-16, 12-32,

Natural gamma ray activity, 50-2, 50-15 Natural-gas container, 36-2 Natural-gas. definition, 12-3, 40-3 Natural-gas engineering letter and computer

symbols. 59-2 to 59-51 Natural-gas engines, 15-16 Natural-gas fluids measurement, 17-7 Natural-gas fuel. lo-15 Natural-aas liquids (NGL). 40-3. 40-4 Natural-gas m;xtures. 17-7 Natural Gas Policy Act, 43-2 Natural-gas/water-system, 25-3 Natural gases. compositions and gas

gravities. 25-6 Natural gasoline, 40-3 Natural gasoline content of gas, 20-10,

20-11

12-33

to 6-59, 6-62

Multiple thrusters, 18-10 Multiple tubing strings, 3-8 Multiple-zone fracturing, 55-9 Multtples of 0.4343, table, l-60 Multiples of 2.3026, table, l-60 Multiplex BOP control system, 18-21 Multiplex pumps, 6-28, 6-49 to 6-55. 6-57

Natural gasoline plants, 4 I- I 1 Natural gums in acidizing, 54-8 Natural logarithms, table. I-56, 1-57 Natural secants, table, l-48, 149 Natural sines, table, l-44, l-45, l-50 to

l-54 Natural tangents, table. l-46, l-47, l-50 to

1-54

442 Natural water drive, 39-15 to 39-17, 39-26,

Multiplex transmission systems, 18-3 Nearshore carbonate deposits, 36-6 Multiplexed electrohydraulic control, Nebraska, 24-8, 24-20, 40-23, 44-40,

subsea, 18-52 Multiplication factor,

46-14, 46-15, 46-18, 46-21, 46-30, 4633, 47-22

for casing joint length, 2-29. 2-3 1 for tubing joint length. 2-45

Multipoint backpressure test, 34-31 Multipoint gas injection, 5-32, 5-36 Multipoint testing, 334 to 33-13, 33-22 Multipool aquifers, 38-16 Multishot survey, 53-3 Multistage centrifugal pumps, 6-l Multistage emulsion, 19-2. 19-3 Multiwell templates, 18-32 Multiyear ice, 18-39 Muskat material balance, 37-13 Muskat method, 37-10 to 37-13, 37-21 Muskat’s correlations, 39-20 Muskat’s method, 40-9

Nederlandse Oil Co., 46-14 Negative gas show, 52-14 Negotiated turnkey format, 15-32 Neopentane/water system, 25-26 Neothene, 52-20 Nephelometer, 4444 Nephelometric turbidity units (NTU). 4444 Net cash flow, 41-3, 41-5 to 41-8 Net-oil computers, 16-2, 16-7, 16-8, 16-12 Net-pay/net-connected-pay ratio, 36-7 Net positive suction head (NPSH), 15-17 Net-profit/initial-investment ratio, 41-22 Net-profit/unreturned-investment-balance

ratio, 41-22 Net-profits interest, 41-1, 41-2, 57-10 Netherlands, 12-39, 46-3, 46.14, 51-47

N

n-Butane/water system, 25-26 nDecane/water system, 25-26 n-Hexaneiwater system, 25-26 n-Pentane/water system, 25-26 Naphtha, 26-22 Naphtha/water system, 25-26 Naphthenic base. 19-27 Napierian logarithms, l-56, 1-57 Natl. Assn. of Corrosion Engineers

(NACE), 4-4 Natl. Bureau of Standards (NBS), 1-68 to

l-71, 17-4 Natl. Conference of Weights and Measures,

17-7, 17-8

Neuquen basin, Argentina, 51-33 Neutron absorption. 50-2 Neutron cross section, total, 50-9 Neutron/density combination, 50-30, 50-31,

50-33 Neutron-density crossplot, 50-30, 50-33 Neutron detectors. 50-14. 50-I 5 Neutron energy, 50-8 to 50-10, 50-23 Neutron/gamma-ray tool, 49- 19 Neutron interactions, 50-E to 50-12 Neutron log, 44-3. 49-26. 49-34. 49-38,

51-31, 51-33 Neutron porosity, 50-24. 50-31, 51-20,

51-33 Neutron-porosity devices, 50-17 to 50-21.

50-28 to 50-33 Neutron-slowing-down properties, 50-2,

50-4, 50-l I Nevada, 24-2 I, 53-6 New England, 29-7 New Hampshire, 51-45 New Mexico, 6-24, 21-4. 24-8, 24.20,

27-16, 27-17, 36-8, 39-25, 40-23, 44-40 New Mexico Conservation Commission.

33-15 New York, 24-l, 44.1 Newton-Raphson iteration procedure, 23-l I,

48-14, 48-15 Newtonian fluid, 22-13 NEXUS log analysis, 49-37 Ni-Resist, 7-3 Ni-Span C@ , 30-3 Nickel, 9-5 Nigeria, 50-26 Nigerian reservoirs, offshore, 48-6 Nikurodse friction-factor equation. 34-24 Nine-point difference scheme, 48-l I Nine-spot grids. 48- 11 1 48-12 Nine-spot pattern or network, 43-2, 44-13,

44-14, 44-21, 44-23 to 44-25, 4434, 46-17, 46-25, 46-28

Nipple-up operations, 3-6 Niralloy. 7-3 Nitric acid (HNO,). 24-4 NitrileO , 4-5 Nitrogen (NJ I-70, 5-6, 5-7, 12-3, 14.13,

14-17, 16-3, 20-5, 22-5, 22-17, 23-7, 25-14, 26-18, 37-24, 39-2, 39-6, 39-14, 39-16, 40-22, 43-2, 45-1, 45-4, 45-6, 45-12, 48-5, 48-6, 48-9, 52-6, 55-6, 55-9, 56-5

Nitrogen-charged dome pressure, 5-7 Nitrogen-charged gas-lift valves, 5-16, 5-17.

5-26 Nitrogen in acidizing. 54-8 Nitrogen/water system, 25-3 Nitroglycerin, 24-1, 56 I Nitrox solution, 46-22 Nominal decline rate, 40-27 to 40-29 Nominal interest rate, 41-25 to 41-35 Nominal rate-of-return (ROR), 41-18 Nominal value. definition. 58-9 Nomograph, 22-5, 22-6. 22-10, 22-13 Non-API, pumps, 8-9

steel-grade casing, 2-5, 2-7, 2-9, 2. I I, 2-13, 2-15. 2-17, 2-19

weights and grades of casing, 2-4. 2-6, 2-8, 2-10, 2-12. 2-14. 2-16, 2-18

Non-Darcy flow, 34-31, 34-32. 34-34, 35-10, 35-11

Non-Darcy flow factor, 33-5 Non-Newtonian effects, polymers, 47-4 Non-Newtonian rheology, 28-13 Non-S1 metric units, 58-10, 58-21 Non-upset tubing, 2-38 to 2-44, 2-64, 2-66 Non-US. areas, core analysis data from,

27-9


Nonassociated dry gas reservoir. 40-24 Nonassociated gas. 40-3. 40-23, 40-33,

40-34 Noncircular drainage area, 32-S Noncollinear flow, 28-12 Nonequilibrium gas displacement, 43-16 Nonideal effects, micellaripolymer (MP)

flooding, 47-13 Noninjection gas requirements in cycling,

39-23 Noninteractive scattering theory, 51-8. 51-9 Nonionics, 47-7, 47-8 Nonlinear partial differential equation, 35-2 Nonmetallic storage tanks, I l-9 Nonmetric units, 58-S Nonownership theory, 57-l Nonsymmetrical aquifers, 38-3 Nonsymmetrical geometry, definition, 38-l Nonwetting immiscible fluids, 28-3, 28-5,

28-6 Nonwettine phase. 26-24, 40-26, 47-9 Normal ammeter chart, electric submersible

pump (ESP), 7-14, 7-16 Normal boiling point, 20-I I Normal brass standards, I-71 Normal compaction trend line, 51-39 Normal device, 49-12, 49-19, 49-20 Normal fault with drag, 53-12 Normal faults, 29-3, 29-8 Normal-flow installations, 6-6 Normal startup chart, electric submersible

pump (ESP), 7-14 Normal venting capacity of tanks, 1 l-7 Normalized total gas. 52-18 Normals in hard formations. 49-13 North America, 24-6, 29-3 North Anderson Ranch field, New Mexico,

36-8 North Atlantic, 18-38 North Burbank unit, Oklahoma, 47-6 North Dakota, 24-20, 57-10 North Louisiana area, 27-4, 27-5 North Sea, 18-2, 18-3, 18-18, 18-23 to

18-26, 18-36, 18-41. 1844. 27-9, 27.20, 36-2, 44-37, 44-46, 50.24, 50-25, 51-39, 51-40. 52-16, 52-26

North Slope, 18-3 North Tisdale field. Wyoming, 46-15 Northward-Estes field, Texas. 47-22 Northwest Atkinson field, Texas, 29-4 Norway, 12-39, 18-25, 21-9 Norwegian fields, 18-23 Nozzle flow gradient, 6-37 Nozzle of jet-pump, 6-32, 6-34 to 6-39,

6-411 6-42, 6-46, 6-62, 6-63 Nozzle loss coefficient, 6-37 Nozzle size, jet pumps, 6-35 to 6-39, 6-43,

6-44 Nozzle/throat-area ratio, jet pumps, 6-35 Nuclear counting rates. SO-5 Nuclear log, 53-26 Nuclear logging techmques,

interpretation of nuclear logs, 50-23 to 50-37

introduction, 50-l to 50-3 nomenclature, 50-37. 50-38 nuclear physics for logging applications,

50-3 to so-15 nuclear radiation logging devices, 50-15

to SO-23 references, 50-38

Nuclear magnetic logging (NML), 52-26 Nuclear magnetic relaxation analysis, 27-l Nuclear magnetic resonance (NMR), 28-10,

50-2 Nuclear measurements, 50-24

Nuclear physics for logging applications, fundamentals of gamma ray interactions,

50-6 to SO-8 fundamentals of neutron interactions, SO-8

to 50-12 nuclear radiation, SO-3 to SO-6 nuclear radiation detectors, SO-12 to 50-15

Nuclear radiation, in wireline logging, 50-l introduction, 50-2 to 50-5 nuclear reactions. 50-6 particle reactions, 50-S. 50-6

Nuclear-radiation detectors, gamma ray, 50-12 to 50-14 neutron, 50-14, SO-15

Nuclear-radiation logging devices, gamma-gamma density, 50-16, SO-17 gamma ray, 50-15, SO-16 inelastic and capture gamma ray

spectrometry, 50-22, 50-23 neutron porosity, 50-17 to 50-21 pulsed-neutron logging, 50-21. 50-22

Nuclear reactions, 50-6 Nuclear spectrometry. 49. I Nucleonic densitometer, 12-16 Number groupings, Sl metric system, 58-12 Numerical dispersion, 48-10 to 48-12 Numerical models, 44-17. 44-20 Numerical simulation, in-situ combustion

models, 46-12 models. 40-2 of chemical flood performance, 48-6 of thermal recovery processes, 46-l I,

46-12 steam injection models, 46-l I. 46-12

Numertcal simulators, 3D and 3-phase, 46-7, 46-I 1

Nutating disk positive displacement (PD) meter. 32-11, 32-12

NuTriTM, 46-22

0

Obigbo field, Nigeria, 36-7, 36-8 Obsidian, 19-S Obstruction in tubing, 33-21 Occurrence, origin, and evolution of oilfield

waters, introduction, 24-19, 24-20 membrane filtration, 24-20 quantities of produced water, 24-20 shale compaction, 24-20

Ocean enuineers. 18-3 Ocean sahwater, 44-42 Oceanographer, 18.4, 18-26 Octane number, 21-4, 21-7 Off-lap deoosition, 29-8 Offset: 41:11, 41-15 Offset-drilling rule, 57-2 Offset of controller, 13-52 Offshore bars, 36-3 Offshore field operations.

drillstem testing, IS-20 establishing location, 18-18 introduction, 18-17 plug and abandonment, 18-20 running

20-m. casing, 18-18 30-m. casing, 18-l 8 BOP, 18-18 to 18-20

spudding well, IS-18 Offshore installations, 6-5 to 6-7, I l-6 Offshore leasing,

economic impact, 57-12 jurisdiction, 57-l I procedure, 57-11 producing history. 57-l I

Offshore operations, arctic. 18-38 to 1843 drilling, 18-3 to IS-17 electrical, instrumentation, and control

systems, 18-43 to 18-52 field, 18.17 to 18-20 historical review, 18-l to 18-3 introduction. 18-I production, 18-27 to 18-38 references, 18-52 special considerations. 18-20 to 18-22 structures, 1822 to 18-27

Offshore pipelines. expensive element, 18-29 flowlines for subsea wells, IS-36 to 18-38 larger lines, 18-38

Offshore platforms, rigs, or structures, 5-2, 6-55, 6-59, 6-63. 7-l. 7-2. 12.16, 12-18, 12-20, 12-21, 12-35. 12-39, 18-l to 18-7, 18-22 to 18.25. 18-28 to 18-30. 18-40 to 18-42, 18-44

Offshore production operations, floating production facilities, 18-34 to

1836 introduction. IS-27 pipelines, 18-36 to 18-38 platform production, 18-28 to 18-30 subsea completions, IS-30 to 18-34

Offshore, special considerations, cold environment, 18-2 I deepwater drilling. 18-20, IS-2 I high-current drilling, 18-2 I, 18-22

Offshore structure classification, concrete gravity, IS-23 gravity platform construction, 18-23,

18-24 template/jacket, 18-22 template/jacket construction, 18-22. 18-23

Offshore Technology Conference, 18-38 Oficina field, Venezuela, 24-13 Ohio, 24-6, 24-7, 26-23, 43-l Ohmtc potential drop. 49-13 Ohm’s law, 26-16, 26-29. 39-20, 4417.

49-14 Oil and gas differences,

best depletion techniques, 36-2, 36-3 sales method, 36-2

Oil and Gas Inst., 41-7 Oil and gas leases, 57-I to 57-12 Oil and gas separators,

accessories, 12-39, 12-40 capacity curves, 12-27 to 12-32 centrifugal gas scrubbers, 12.20, 12-21 centrifugal separators, 12-20, 12-21 classification, 12-16 to 12-20 comparison of horizontal, spherical, and

vertical types, 12-2 I computer sizing, 12-25 to 12-27 construction codes, 12-38. 12-39, 12-41 controls, 12-39, 1240 estimated quality of separated fluids.

12-13 to 12-16 estimating sizes and capacities, 12-21 to

12-25 general references, 12-43 illustrations of, 12-2 I introduction, 12-l to 12-3 measuring quality of separated fluids,

12-15, 12-16 methods used to remove gas from oil,

12-13 methods used to remove oil from gas,

12-8 to 12-l 1 mist extractors for, 12-11. 12-12 nomenclature, 1242, 1243 operation and maintenance considerations.

12-40

SUBJECT INDEX 49

practical consideratton in sizing, 12-32 primary functions of, 12-3, 12-4 references, 12-43 safety features. 12-39, 1240 secondary functions of, 124, 12-5 selection and application of separators and

scrubbers, 12-35 to 12-38 special problems in. 12-6 to 12-8 stabilization of separated liquid

hydrocarbons, 12-33. 12-35 stage separation of oil and gas, 12-32 to

12-35 summary, 12-l valves, 12-39, 1240 well fluids and their characteristtcs, 12-3

Oil bank, 44-l 1, 4433 Oil-base (based) muds, 26-21 to 26-23.

40.19, 444. 53-8, 53-9 Oil-based fluids, 18-49, 18-52 O&based fracturing fluids, 55-5 Oil-bucket construction. 12-35 Oil carrying agent, 56-2 Oil changing in pumping units, lo-13 Oil collectors. 19-20 Oil coning, 48-9 Oil cut, 47-18 Oil density, definition, 22-1 Oil-density determination from ideal-solution

principles, composition known, 22-2 to 22-4 composition unknown, 224, 22-5

Oil-discharge control valve, 12-5, 12-6, 12-9, 12-39

Oil-displacement efficiencies, 4439 Oil-displacement rate, 46-8 Oil engines, IO-15 Oil equivalent volumes, 41-13 Oil-external microemulsion. 47-12. 47-15 Oil foam. 12-6 Oil formation volume factor (FVF) 6-67,

22-1, 22-10 to 22-13, 22-20, 37-16, 40-6, 40-8, 40-9, 40. I 1, 40-16

Oil FVF, constants for, 22-l 1 Oil FVF correlations,

saturated systems, 22-10 Standing. 22-10 undersaturated systems, 22-l I to 22-13 Vasquez and Beggs, 22-10, 22-11

Oil/gas/water separator, 12-4, 12-5, 12-21 Oil gravity,

effect on air requirements, 4616, 46-17 effect on fuel cc&nt, 46-16, 46-17 test, 27-l

Oil in effluent gas. 12-15, 12-16 Oil in effluent water, 12-15, 12-16 Oil-in-place (OIP), 37-2 to 374, 37-6, 40-5

IO 40-8 Oil-in-water dispersion-type fracturing fluid.

55-7 Oil-in-water emulsions, 6-27, 19-l to 19-3,

19-11, 19-27, 24-2, 55-7 Oil isoperms. 28-7 Oil isothermal compressibility,

Ttube method, 22-11, 22-12 Vasquez and Beggs method. 22-12, 22-13

Oil mist, 12-19. 44-4 Oil mobility, 43-7 Oil mobilization, 28-12, 484 Oil payments, 41-1, 445 Oil power fluid, 6-27, 6-29, 6-44, 6-47,

6-55, 6-56, 6-60. 6-61. 6-63 Oil pressure function, 37-8 to 37-10 Oil production above bubble point, 37-6 Oil production, time required for, 37-21 Oil property changes, steamfloods, 46-15 Oil property ownership, 41-l. 41-2 Oil-rate-vs.-time plot, calculation of, 47-17

Oil recovery. by chemical flooding. 47-13. 47-16,

47-17. 47-19. 47-20 by gas displacement, 43-3 by solution-gas drive. 37-2, 37-5, 37-6,

37-10, 37-11, 37-13 to 37-1s. 37-17, 37-19, 37-21, 40-18. 40-20, 444

by water injection, predtcting, areal sweep and pattern efficiency.

44- I2 to 44-25 dtsplacement calculation procedures,

44-7 to 44-12 reservoir fractures, effect of, 4425,

44-26 waterflood performance method

selection, 44-3 1, 44-32 waterflood performance prediction

methods, 44-26 to 44-3 1 by waterflood. 445. 44-S effect of low mobility, 47-1, 47-2 efficiency. 4430, 4432, 47-16 estimation, 48-l process, 48-3. 48-4. 48-12 thermal, 46-14, 46-15 vs. volume of fuel burned, 46-15

Oil relative permeability, 28-6, 28-8 to 28-13, 44-12, 46-37, 46-38

Oil-removal efficiency, 15-28 Oil reserves: see reserves Oil reservoir, development plan for, 36-I IO

36-l I Oil reservoir volume factor, 37-10 Oil reservoir with gas cap, 40-7 Oil reservoirs, depletion technique, 36-2 Oil reservoirs in gas-hydrate region, 25-18,

25-19 Oil reservoirs under gravity drainage,

case histories after pressure depletion, 40-15

occurrence of, 40-14, 40-15 Oil reservoirs with gas-cap drive, 40-13,

40-14 Oil reservoirs with water drive,

average recovery factor, 40-16. 40-17 buoyancy and inhibition effect, 40-20 general discussion, 40-15. 40-16 permeability distribution effect, 40-18 to

40-20 recovery-efficiency factor. 40. I6 unit recovery computed by frontal-drive

method, 40-17, 40-18 unit-recovery equation, 40-16

Oil retention time, separator, 12-3, 12-15, 12-25 to 12-30

Oil saturation, 26-22, 37-9. 37-10 Oil Show AnalyzerTM (OSA), 52-10, 52-l 1 Oil shrinkage, 37-l. 37-6, 37-22, 37-23,

40-S Oil sizing of separator. 12-30 Oil-soluble coating. 9-10 Oil-soluble paint, 9-2 Oil-soluble resins, 54-8 Oil specific gravity, 6-67 Oil stainmg. 52-9. 52-10 Oil/steam ratio, 46-9, 46-15. 46-23 Oil storage,

appurtenances, I l-6 capacity, 18-30, 18-36 general references, 1 ll14 gravity conservation, 11-12, II-13 gravity structure, 18-41 materials of construction, I l-9 production equipment. 1 l-9 to 1 l-l I references, 1 I - 14 tank corrosion protection, I I-4 to II-6 tank types, 11-l to 11-4 tanks, 11-6, 11-7, 18-43

temporary. 18-2 underground storage, 1 l-13. 1 I-14 vapor control, 11-12, II-13 vapor losses, 11-11, II-12 vapor-recovery system, 11.12. 11-13 venting atmospheric and low-pressure

storage tanks. I1 -6 to 1 l-9 Oil surge chamber. 19-23, 19-24 Oil system correlations,

bubblepoint pressure, 22-5 to 22-9 density determination, 22-2 to 22-5 empirical, 22-7 FVF, 22-10 to 22-13 gas/oil IFT. 22-16. 22-17 general references, 22-22 glossary, 22-20, 22-21 graphical, 22-5, 22-7. 22-8 introduction, 22- 1 pseudoliquid density. 22-2 references, 22.21, 22-22 oil FVF, 22-10 to 22-13 solution GOR for saturated oils, 22-9.

22-10 total FVF’s, 22-13 viscosity, 22-13 to 22-16

Oil viscosities, 22-1, 22-13 to 22-16, 37.12, 37-16, 40-9, 40-17, 40-32, 46-31. 46-34, 46-35

Oil-viscosity correlations, factors affecting, 22-14 introduction, 22-13 saturated systems, 22-14 to 22-16 undersaturated systems, 22-16

Oil/water capillary pressure, 26-29 Oil/water contact (OWC). 41-9, 44-39 Oil/water interface. 12-39. 18-47. 19-4,

19-5, 19-9, 19-11, 19-18 10 19-20, 19-22, 19-23, 19-30, 19-31. 40-15

Oil/water interfacial tension. 4440, 47-9 Oil/water mobility ratio, 48-5 Oil/water relative-permeability curve, 47-18 Oil/water separator. 24-3 Oil/water system, 25-27. 25-28, 39-20 Oil/water viscosity ratio, 40-19, 44-6. 44-9 Oil-weight factors, 2-l. 2-33. 2-38 Oil wells,

computing inflow rates, 34-32 future inflow performance, 34-34, 34-35 inflow performance, 34-30 to 34-33 single- and two-phase 1PR equation.

34-33, 34-34 Oil-wet, 19-9, 44-6 Oilfield brines, 24-5 Oiltield motors,

equipment for control of, 10-27, lo-28 protection equipment for, 10-28, IO-29

Oilfield steam generators, 46-19 Oilfield waters,

analysis methods, 24-5 chemical properties, 24-5 to 24-13 composition, 24-6 definition, 24-18 evolution, 24-19. 24-20 occurrence, 24- 19, 24-20 origin, 24-19, 24-20 pH, 24-16 physical properties, 24-12 to 24-l 8 sample description, 24-5

Oilwell performance, infinite-acting pressure solution, 35-3,

35-4 production rate variation (superposition),

35-8, 35-9 pseudosteady-state behavior, 35-6 to 35-8 skin effect. 35-4 superposition, example problem, 35-9

so PETROLEUM ENGINEERING HANDBOOK

transient and pseudosteady state, example problem, 35-7, 35-8

well pressure performance-closed reservoir. 35-2, 35-3

wellbore storage effect, 35-4 to 35-6 Oilwell production-meter installation. 32-13 Oilwell Research porosimeter, 26-6 Oklahoma, 6-24, 16-13, 21-2, 21-4, 21-10,

24-8. 24-10. 24-21, 27-8, 27-9 to 27-12. 33-1, 33-7. 33-9, 33-12, 40-15, 40-23, 441, 444, 4436, 4441, 44-44, 46-3, 46-14, 46-16, 47-6, 57-10

Oklahoma City field, 6-24, 40-2 Oklahoma City Wilcox reservoir, 4s 15 Oleic phase, 47-l I, 47. I5 Olympic pool. Oklahoma, 44-41 On-lap deposition. 29-8 Oolicast, 29-9 Oolicastic porosity, 29-8. 29-9 Oolith. 29-9 Oolitic porosity, 26-l Open-cycle selective hydrocarbon adsorption

system, 14-12 Open delta transformer, 10-30, IO-31 Open-flow capacity, 30-10, 33-3 Open flow of gas wells. 33-l to 33-23 Open-flow potential, 33-5 to 33-S. 33-10,

33-11 Open-flow testing of gas wells, 13-45 Open-flow tests, 33-3, 41-9 Open gas-lift installation, 5-2, 5-3 Open-loop control, 16-2 Open power-fluid system, 6-17, 6-18, 6-25

to 6-28. 6-30, 6-57 to 6-59, 6-63 Open regeneration system, 14-l 1, 14-12 Openhole completions, 47-6, 56-8, 56-9 Openhole logging, 50-I Operating agreements, 41-9 Operating costs, emulsion treating, 19-33 Operating downtime offshore, 18-8 Operating equipment, BHP gauges, 30-3,

30-4 Operating expenses,

ad valorem taxes, 41-12 average cost per barrel, 41-l 1, 41-12 breakeven, 40-32 check list item for evaluation, 41-9 cost per well-month, 41-l 1 direct, 41-l 1 direct lifting, 41-l 1 field or district, 41-12 range of, 41-12 recompletion, 41- 12 stimulation, 41-12 trucking charges, 4 I 12

Operating gas-lift valve, 5-39 to 5-42, 5-44, 5-51 to 5-53, 5-55

Operating injection-gas pressure, 5-23, 5-26 to 5-28, 5-30, 5-32, 5-35. 5-36, 5-38, 5-39, 5-44. 5-48, 5-49, 5-53, 5-54

Operating interest, 41-2, 41-13 Operating limits,

drilling vessels, table, 18-E riser, table, 18-18

Operating manuals, offshore. 18-16 Operating pressures, of separators, 12-16

of wellhead equipment, 3-l Operating problems, gas condensate (GC)

reservoir, number of wells required, 39-26 well injectivity, 39-25. 39-26 well productivity and testing, 39-24,

39-25 Operation and maintenance considerations

for separators. cleaning of vessels, 12-42 corrosive fluids, 1240

gauge cocks and glasses. 12-42 high-capacity operation, 12-42 insulation of safety devices, 12-40 low temperatures, 12-40 mist extractors. 12-40 paraffin, 12-42 periodic inspection. 12-40 pressure gauges, 12-42 pressure shock loads, 1242 safety heads (rupture disks), 12-40 throttling discharge of liquid, 12-40

Operation factor, 12-22 Operation of ESP equipment, 7-12 Operational considerations for emulsion

treating equipment, burners and fire tubes, 19-28 cleaning vessels, 19-28, 19-29 corrosion, 19-30. 19-31 excelsior packs, changing of, 19-31,

19-32 interfacIal buildup, 19-30 level controllers and gauges, 19-3 I removing sand and other settled solids,

19-29, 19-30 safety features for electrostatic treaters,

19-3 I water-in-oil detectors (BS&W monitors),

19-3 I Operational considerations, subsea control

systems, 18-49 Operational problems and remedies,

problems common to steam and tirefloods, emulsions, 46-21, 46-22 sanding, 46-2 1 well productivity, 46-21

problems plaguing ftrefloods only, corrosion, 46-22 exploration hazards, 46-22 poor injectivity, 46-22

problems plaguing steamfloods only, steam placement, 46-22 steam splitting, 46-22

Operational well modes, 4-6 to 4-8 Optical emission spectrographic analysis,

56-3 Optimal conditions, generating for

micellar/polymer (MP) flood. 47.14, 47-15

Optimal economic recovery, 42-l. 42-2 Optimal time to waterflood, 44-5 Optimization, of injection operations, 42.1,

42-3 Optimization studies, 48-7 Optimum efficiency of fracturing, 55-9 Optimum pressure on separator, 124 Orcutt Hill field. California, 47-22 Organic constituents of oiltield water,

24-17, 24-18 Organic inhibitors, 54-6 Organic liquid desiccants. 14-17 to 14-20 Organic phosphates, 44-45 Organic solvents, 56-2 Orgamck and Golding correlation, 21-I 1 to

21-15 Orgamsms, 44-43 Orientation curves, 53-9 Orifice check valve, 5-10, 5-22 to 5-24,

5-26, 5-28, 5-31. 5-35, 5-36 Orifice coefficient for provers, 13-45 Orifice constants.

basic ordice factor, 13-3 expansion factor, 13-8 flowing-temperature factor, 13-3 gauge-location factor. 13-8 manometer factor, 13-8 pressure-base factor, 13-3

Reynolds-number factor. 13-8 specific-gravity factor, 13-3 supercompressibility factor, 13-8 temperature-base factor, 13-3 thermal-expansion factor. 13-S

Orifice equations, 13-3 Orifice location, 13-36 Orifice meter, 5-53, 13-8, 13-36, 13-45,

1348, 16-6, 16-S. 33-6, 33-13 Orifice metering of natural gas, 17-7 Orifice-plate flowmeter. 32-l 3 Orifice plates, 14-2. 17-7 Orifice well tester, 13-37 to 13-44, 32-6.

32-14 Original oil in place (OOIP). 38-9 to 38-13 Orkiszewski correlation, 34-37 to 34-40 Orogenic movements, 29-7 Orthogonal-wave equation migrations, 36-8 Onhomin technique, 48-17 Oscillating piston PD meter, 32-l I Oscilloscope, 51-3, 51-12 Osmotic effects, 24-19 Ossum field, Louisiana. 26-7 Otto cycle, IO-15 Outbreathing (pressure relief) of storage

tanks, 11-6, 11-7 Outer continental shelf (OCS). 3-34, 57-l I,

57-12 Oval gear positive displacement (PD) meter,

32-l I Overall displacement efficiency, 39-18 Overall economic analysis, 39-27 Overall efficiency of miscible displacement,

45-7 Overall efficiency of pumping system, lo-25 Overall heat-transfer coefficient. 46-4 to

46-7 Overall instantaneous cycling efficiency,

39-18 Overall oil recovery, 46-14 Overall particle-removal efficiency, 15-27 Overall recovery efficiency, 43-3, 45-8 Overall recovery factor, 40-23 Overall reservoir recovery efficiency, 40-34 Overbalance condition, 52-l 8 Overburden heat loss, 48-5 Overburden pressure. 26-9. 26-19, 5 l-4 to

51-7, 51-25, 51-44, 51.47, 52-26. 55-8, 56-2, 56-3

Overburden stress, 28-4, 28-13, 514, 51-30, 5143

Overflow connections for tank, 1 l-9 Overflush agent, 56-5 Overflush in acidizing. 54. I 1 Overhead, 41-12, 41-13 Overhead allocation, 41-9 Overhead costs, 36-2 Overload shutdown conditions, ESP chart.

7-16, 7-17 Overloading separators with liquid. 12-10 Overpressure, of storage tanks. I l-4 Overpressured formations, 35- 1 Overpressured gas reservoir, 40-34 Overpressuring of separator, 13-58 Overriding royalty interest, definition. 41-l

to 41-3 Overtemperature lockout circuit, IO-29 Overtensioning of pipe, 18-37 Overtorquing, 9-9 Overtravel of fiberglass rods, 9-l I, 9-12 Overturned anticlines. 29-2 Ownership maps, 41-8 Ownership of hydrocarbons in place, 57- 1 Oxidation potential, 24-16 Oxyalkylated phenols, 19-10

SUBJECT INDEX 51

Oxygen (O,), 6-55, 9-8, 14-3, 14-17, 14-20, i4-22, 15-28, 15-29, 19-30, 19-31, 24-4. 24-5, 24-16, 24.17, 24.20, 39-16, 44-42, 4443, 44-47, 46-12, 46.22, 46-34, 48-5, 50-1, 50-13, 50-18, 50-35

Oxveen analvzer. 19-28 Ox$gen corrosion, 3-36 Onvaen-enriched air fireflood, 46-31, 46-34 Oxygen injection, 42-6 Oxygen scavengers, 15-29, 47-5, 47-10 Oxygen utilization efficiency, 46-15, 46-2 I

P

p-x diagrams for mixtures of CO,, 23-10 P-wave critical angle, 51-12 P-wave modulus for drv rock. 51-49 P-wave modulus for rock frame, 51-49 P-wave velocity, 51-l I, 51-37 P-waves, 51-2to 51-5, 51-11, 51-36, 5147 Pack gravel, 56-4 Packer mechanics, 44 Packer operations, modes of, 4-1 Packer seats, location of, 53-17 Packer selection, considerations for,

corrosive well fluids, 4-4 fishing characteristics, 4-6 packer mechanics, 44 purchase price, 4-6 retrievability, 4-5 sealing elements, 4-5 surface/downhole equipment coordination,

4-4 through-tubing operations, 4-6

Packer utiltzation, 4-1 to 4-3, 4-6 permanent packers, 4-3 retrievable packers, 4-2, 4-3 success, 4-6

Packing of uniform spheres, 26-l Packoff element. 3-6 Painter field. Wyoming, 39- 16 Pair production, 50-6 to 50-8, 50-13, 50-14,

56-16 Paleo-environments, interpretation of, 36-3,

36-7 Paleontologists, 57-8 Paloma field, California, 26-30 Paluxy gas-condensate reservoir, Texas,

39-20, 39-2 I Pan AmericaniCasper Oil Co., 46-14, 46-18 Panama Canal, 18-7 Panhandle equation, 15-7 Panhandle field, Texas. 44-30 Paper-tape-type H,S detector, 52-7 Parachor, definition, 22-16 Parachors,

for hvdrocarbons. 22-18 for pure substances, 22-17

Paraffin, 5-25, 5-52, 5-53, 6-31 to 6-33. 7.13. 11-13. 12-3. 12-7, 12-8. 12-10. 12-li. 12-40, 12-42, 19-4, 19-5. 19-9, 19-10, 19.30. 26-3. 32-l I, 44-4

Paraffin hvdrocarbons. 20-13. 39-2 Paraffin inhibitors, 56-2 Paraffin problem, 3-27 Paraffin removal. 56- 1. 56-2 Paraffin scrapers, 18-33 Paraffintc hydrocarbon series, 20-5 Paraffinic o&. 6-67. 24-18 Paraguay, 58-20 Parallel-bore valves. 3-15 Parallel-plate interceptor (PPD. 15-24, 15-25 Paris Academy of Science, l-68 Paris Valley field, California. 46-22, 46-23 Paroscientitic digiquartz. 30-7 Parrish and Prausnitz development, 25-5 to

25-9 Partial buildup curve. 30-9

Partial cement bonding, 51-41, 51-42 Partial differential equations, 48-2 Partial penetration, 35-4 Pantal pressure maintenance, 42-3, 43-9 to

43-17 Partial pressure of gas, 20-4 Partial water drive, 39-24 Partial water-drive reservoir, 40-6 Partially scaled models,

high-pressure, 46. I3 physical types. 46-11, 46-12 vacuum, 46-13

Particle reactions, 50-5, 50-6 Particle-size distribution, 26-2, 4445 Partition, 57-2 Past performance analysis, gas pressure

maintenance, 43-9 Pattern effects on waterflooding, 4429 Pattern efficiency, 44-15, 44-18, 45-6, 45-8

to 45-10 Pattern (h@weighted) efficiency, 39-15,

39-17, 39-18, 39-20 to 39-23, 39-26 Pattern floods, 46-l Pattern injection, 43-2 Pattern selection, thermal recovery, 46-17 Pattern types in firefloods and steamfloods,

46-18 Payout, 41-3, 41-35, 41-36 Payout schedule, 41-31 Peace River field, 46-34 Peak crank torque, 9-2, 9-3 Peak polished-rod load, 9-2 Peak torque, IO-26 Pendular rings, 26-24 Penetration of acid, 54-8 Peng-Robinson equation, 20-8, 23-13 Penn State arrangement, 28-5 Pennsylvania, 18-l. 21-2, 24-1, 24-2, 24-6,

24-l. 44-1, 444, 47-22 Pennsylvania Oil Producers, 17-1 Penultimate layer, 364 Percent factor, assigned spacing

design line, 5-33 Percent-load design method, 5-42 Percent-load intermittent-gas-lift

installation designs, 544 Percent-load production pressure, 548 Percent-tubing-load installation design, 548 Percentage depletion, 57. I I Percentage-depletion allowance, 41-5,

41-13, 41-14 Percentage factor, gas lift, 5-32 Percentage-time controller, I64 Percentage timer. LO-28 Percussion-sampling techniques, 27-9 Percussion sidewall core data, 27-9 Perforated-interval completion, 5-5 I Perforating gun, 53-26 Perforating operations, 5 I40 Perforating pipe. 56-l Perforation ball sealers, 54-10 Perforation cleaning methods,

backflow, 56-5 backsurging. 56-5 HCI preflush, 56-5 matrix acid stimulatton, 56-5 matrix treatment with acid, 56-5 overflush, 56-5 perforation washing, 56-5 underbalance, 56-5-

Perforation, sand control, 564, 56-5 Perforation tunnels. 56-l. 564, 56-5, 56-8 Perforation washing. 56-5 Perforations. locating. 53-26 Performance calculations, reciprocating

pumps, 6-28 to 6-30 Performance characteristics, jet pumps, 6-34

Performance coefficient, of backpressure equation, 33-5 to 33-10, 33-12

of refrigerants, 14-l I Performance curves,

abandonment contour vs. cumulative oil, 40-34

cumulative gas vs. cumulative oil, 40-32, 40-33

improved recovery reserves, 40-34 material balance method for nonassociated

gas reservoirs, 40-33, 40-34 of jet pump, 6-35, 6-36, 6-38, 641 to

6-43, 646, 6-47 of tubing and choke, 34-5 oil percentage in total fluid vs. cumulative

oil, 40-32 water/oil contact (WOC), 40-34

Performance evaluation of rigs, 18-7, 18-8 Performance factors for mot&s.

cyclic load, lo-25 efftciency, IO-25 power, IO-25 service, 10-25, IO-26 slip, 10-23, lo-24 speed variation, 10-24, IO-25 temperature rise, IO-26 torque, IO-25

Performance indicators, common to both steamfloods and

firefloods, changes in oil property, 46-15 oil recovery, 46-14, 46-15 sweet efftciencv , 46- 14

p&a&g to firefloods only, air/oil ratio (AOR), 46-17 air requirements. 46-16 fuel content, 46-16

pertaining to steamfloods only, steam/oil ratio (SOR), 46-15

Performance of solution-gas-drive reservoirs, 37-1, 37-2

Performance predictions, models, 37-19 of micellar-polymer flooding, 47-17 of oil and gas reservoirs, 36-9, 36-10 of solution-gas drive, 37-14 to 39-18 of volatile oil reservoir, 37-22 to 37-26

Performance uroiiles, 5-20, 5-2 I Performance properties,

of casing, 2-l, 2-4 to 2-19. 2-32 of pipe,-2-46, 2-54 to 2-56 of tubing, 2-38 to 2-43

Performance technique for reserve estimation, 40-I

Performance-time predictions, 43-9, 43-10 Performax plate pack, l9- 13 Periodic inspection of separators, 12-40 Periodic production tests, 12-17 Peripheral flood, 44-2, 44-13, 44-17. 44-36 Permafrost, 18-38, 1X-39, 18-41 to 18-43 Permafrost cement, 18-4 1 Permafrost problem, 3-27 Permanent packers, 4-l to 4-6, 4-8 Permeability-block method, 40-19. 40-20.

40-24, 40-26 Permeability, calculations, 26-16

changes, effect on radial flow, 54-9 consideration in waterflooding, 442 conversion of units in Darcy’s law, 26-13

to 26-15 correlation with tube-wave data, 51-48 damage. 30-13, 30-14 definition of, 27-l. 28-l. 55-1 distribution. 26-26, 36-3, 36-7, 39-16,

39-18 to 39-20, 40-12, 40-18 to 40-20, 40-24. 40-25, 44-8. 44-15, 45-11. 45-12

distribution factor. 40-16. 40-17

52

effective, 26-15, 28-l to 28-4, 28-6, 28-8. 28-13, 39-17, 44-32, 44-33, 46-21

factors affecting measurement, 26-18, 26-19

factors in evaluation of, 26-19, 26-20 tlow systems of simple geometry, 26-t 1

to 26-13 from pressure-buildup curve, 30-12 in acoustic logging, 51-47 interstitial-water relationships, 26-23 introductory theory, 26-10, 26-11 limits of formations, 55-2 measurement of, 26-17, 26-18 net thickness product, 39-21 of channels and fractures, 26-15, 26-16 of matrix, 55-9 of uack, 55-8 of propping agents, 55-2, 55-8 of reservoir rocks, 30-I 1, 39-13. 44-3 physical analogies to Darcy’s law, 26-16 pinchout, 4439 prediction, 50-2 profile, 314, 364, 39-19, 44-3, 45-10.

51-47 ratio, 37-14, 37-15 reduction, 47-3 to 47-5, 55-8 reduction factor. 35-5 relative, 28-1 to 28-3, 28-6, 28-8 to

28-14, 28-16, 30-11, 39-13, 44-2, 44-4. 44-5, 44-9, 55-X

SPE preferred unit, 58-24, 58-25 stratification, 39-18, 39-20 transforms, 50-37 unit in SI metric system, 58-24. 58-35,

58-36 variation, 39-19, 39-20, 39-23, 39-26.

40-18, 40-19, 443, 448 to 4410, 4436, 45-7

viscosity ratio, 47-8 Perm-plug method of permeability

measurement. 26-17 Permeameter, 26-17, 26-18 Permian Basin. 49. I 1 Persian Gulf, 4437 Personal computer, 39-l I, 39-12 Personal property, definition, 57-l Personnel protectton at wellsite, lo-31 Peru, 40-14. 58-20 Peters factor, l-61 Petrographic analysis. 56-3 Petroleum engineering servtces, 52-2, 52-16

to 52-27 Petroleum engineers, 22-1, 22-14 Petroleum Engineers Club of Dallas, 41-5 Petroleum liquid, acoustic velocity in, 51-3 I Petroleum measurement subsidiary, 17-6 Petroleum reserves-definmons and

nomenclature, possible, 40-2 probable, 40-2 proved, 40-2. 40-3 proved developed, 40-3 proved undeveloped, 40-3

Petroleum reservoir engineering, 42-l Petroleum reservoir engineering letter and

computer symbols, 59-2 to 59-51 Petroleum reservoir traps, 29-l to 29-9 Petroleum sulfonates, 47-7 Petrophysical and physical parameters,

relationship to nuclear logging, clay types, 50-2 fluid identification, 50-2 hydrocarbon saturation, 50-2 lithology, 50-2 permeability. 50-2 porosity. 50-1, 50-2 presence of hydrocarbons, 50. I

Petrophysical correlations. 28-12 Petrophysical descriptors, 50-2, 50-3 Petrophysical measurements, 52-2, 52-26,

52-27 Petrophysical properties, 28-8, 47-20 Petrophysical work, 48-8, 48-9 pH, 244, 24-5, 24.16, 24.17, 4444 pH control, 4440, 4442 Phase analysis, high-frequency, 27-l Phase behavior, and interfacial tension,

47-14, 47-15 definition. 22-2 I, 23-I of COJC,IC,, mixture, 23-9 of gas/condensate system, 39-2 to 39-4,

39-12, 39-13 of pure component, 23-2 of surfactantlbrineioil system, 47-11 to

47- 13 of water/hydrocarbon systems, 25-l to

25-28 Phase-boundary curves, 45-3, 45-4 Phase compositions, calculation of, 23-10 to

23-13 Phase converters, types of, IO-35 Phase diagrams, by measuring liquid

volumes at several temperatures, 39-7 of Eilert’s fluids, 39-3 of gas condensate fluids, 394 of reservoir-fluid systems, 23-6, 23-7 of single component, 23-1, 23-2 of surfactant/brine/oil system, 47.11,

47-12 ternary, 23-5, 23-6 types of, 23-2 to 23-10

Phase equilibrium, 12-2 1 Phase equilibrium calculations, 20-10 Phase lag, 53-20 Phase loss relay, lo-28 Phase rotation, 7- I3 Phase rule, 23-2, 23-8, 25-t Phase shift angle. 53-20 Phenolic-resin gravel packing, 46-21 Philippine Islands, 58-20 Phillips Petroleum Co., 16-13, 45-15,

46-24, 46-26 Phosphoric acid. 11-6 Photoelectric absorption, 50-4, 50-7, 50-12

to 50-14, 50-17 Photoelectric absorption factor, 50-7, 50-17,

50-24, 50-33, 50-34 Photoelectric effect. 50-6 to 50-S Photographic history of injection-fluid

fronts, 44-18 Photographs and visual examination of

cores. 46-2 I Photometry. I-69 Photomicrographs, 19-2 to 19-5 Photomultiplier. 50-12 to 50-14 Physical analogies to Darcy’s law, 26-16,

26-17 Physical dimension of fiberglass sucker

rods, 9-l I Physical models, 46-1 I to 46-13 Physical parameters and nuclear radiation,

50-2, JO-3 Physical-properties data of liquid

hydrocarbons, 17-5 Physical properties of foams, 47-8, 47-9 Physical properties of oil, 21-3 to 21-8 Physical properties of oil systems, 22-l Physical properties of produced waters,

compressibility, 24-12 to 24-14 density, 24-14, 24-15 dissolved gas, 24-17 formation volume factor (FVF), 24-15,

24-16 organic constituents, 24-17, 24-18


pH, 24-16 redox potential (Eh), 24-16, 24-17 resistivity, 24-16 surface (interfacial) tension, 24-16 viscosity, 24-16

Phystcal properties of wellhead equipment, 3-2, 3-3

Phystcal setup of metering system, orifice location, 13-36 recorder, 13-36 size of orifice and metering run, 13-36 straightening vanes. 13-36

Physico-chemical changes, 46-12, 46-13 Piercement domes, 29-5. 29-7 Piezoelectric element, 5 l-3 Piezoelectric transducer, 30-5, 30-6 Pig launcher, 15-14 Pig trap, 15-14, 15-16 Pigging, 18-29 Pile hammers, 18-23 Pile jacking, 18-41 Piled structures, 18-42, 1843 Pilings, 3-3 Pilot floods, 4437 to 44-39 Pilot-gas-control manifold, 16-15. 16-16 Pilot-loaded regulators, 13-55 Pilot-loaded valves, 13-55 Pilot LPG flood, 45-14 Pilot-operated control valve. 13-53 Pilot-operated diaphragm motor valve,

13-55 Pilot-operated dump valves, 16-5 Pilot-operated gas-lift valve, 5- 13, 5-43,

5-44, 5-51 Pilot-operated relief valve, I l-8, 12.40 Pilot operation, 45-10, 42-6 Pilot plug, 13-54 Pilot project, 40-3 Pilot relay, 13-50 Pilot valve, 3-34 Pilot valve diaphragm failure, 11-S Piloted union-type rise coupling, 18-15 Pin-and-socket connectors, 18-52 Pinchouts, 29-8 Pinnacle reefs, 36-5 Pipe analysis log (PAL), 53-20, 53-24,

53-25. - Pipe analysis tool, 53-23 Pipe body safety factor, 2-2, 2-32. 2-34,

2-35 Pipe-body yield strength, 2-2, 2-4, 2-6, 2-8,

2-10, 2-12, 2-14, 2-16, 2-18, 2-32, 2-56 Pipe coils, 19-21 Pipe diameters,

choosing in gas lutes, 15-7 choosing in liquid lines, 15-2

Pipe dope as formation contaminant, 56-3, 564

Pipe-laying reels, 18-37 Pipe rams, 18-11, 18-15, 18-20 Pipe storage, 11-2, I l-4 Pipe taps, 13-3, 13-8 to 13-11, 13-20 to

13-25, 13-28, 13-29, 13-32 Pipe-wall thickness, 15. I 1 Pipeline, gas, 36-2 Pipeline metering systems, 17-4 Pipeline run statements, 41-9 Pipeline trunk lines, 16-2 Pipeline valve, 1 I-l I Pipeline valve switches, 16-3 Piper diagram, 24-19 Piping,

design considerations, 15-13 drawings, 15-31 on offshore platforms, 15-l 1 pressure breaks, 15-13 pressure rating classes, 15-13

SUBJECT INDEX 53

pressure/temperature ratings, 15-13 system design, IS-1 to 15-14 system materials, 15-7 to 15-l 1

Pisolith. 29-9 Plsolitic limestone, 29-8

32-13,

Piston-and-valve assembly, 6-5 I

32-14, 33-l

F’lston BHP element, 30-I

to 33-4

Piston effect of tubing string, 4-9, 4-10 Piston gauge, 33-6 Piston-like displacement, 447, 44-9

Plain-end,

Piston pneumatic/hydraulic pump ratio, 3 Piston/stem area ratio, 3-21

liner casing,

Piston-type actuators. 3-2 1

2-32

Pitcher niaule. 18-14. 18-15 Pitman siie members, 10-3, 10-4, IO-12 Pitot tube. 13-2. 13-37, 13-45 to 13-48,

Pneumatic actuators, 3-2 I, 3-27, 18-28 Pneumatic control valves. 16-3 Pneumatic controls, 13-49 Pneumatic/hydraulic relay, 3-33 Pneumatic pilots, 13-56 Pneumatic/pneumatic relay, 3-33 Pneumatic pressure control, 12-39 Pneumatic surface safety valve, 3-20, 3-21 Poettmann and Carpenter correlation, 34-37 Poettmann’s method, 34-9

-33 Point bars, 36-6 Poiseuille’s equation, 26-10, 26-15. 26.19,

26-20 Poisonous-gas sensors, 18-47 Poisson distribution, 50-5 Poisson’s ratio, 51-2, 51-4, 51-13, 51-37,

51-43, 5144, 51-50 Polar packs, 18-39

Pore-size distribuhon, 26-19, 26-24. 4427. 47-5. 47-10, 51-30, 54-6

Pore structure of rock, 26-10 Pore-throat-blocking effect, 47-9 Pore throats, 47-21 Pore volume (PV), 26-l to 26-7. 26-22 Pore-volume compressibility, 26-7 to 26-10,

47-37, 47-38 Pore volume, laboratory measurement, 26-5

to 26-7

by electromagnetic-propagation tool,

Porosimeter, 26-4 to 26-6

49-36

Porosity, apparent water filled, 49-34 balance check, 49-30 by density log, 49-26, 49-34, 49-36,

49-38

line pipe, 2-46, 2-G to 2-53 Plait point, 23-5, 23-8 to 23-10, 47-l 1 to

47-13 Planar view. directional data presentation,

53-6 Planning and preparations offshore, 18-3 to

18-5 Plant costs, 39-l Plant products, 39-9 to 39-l 1, 39-23 Plastic blanket, 9-14 Plastic-coated sand grains, 55-8 Plastic-collapse pressure equation, 2-54,

2-55 Plastic lining for steel pipe, 15-10 Plastic-packed secondary seal, 3-6 Plastic-packed-type seal, 3-9 Plastic pipe, 15-10 Plasticity, 52-20 Plate coalescers, 15-23 to 15-26 Plate-count method, 44-44 Plate heat exchanger, 19-23 Plate-type heating elements, 19-21 Platform deck layout for process facilities,

18-30 Platform jacket, 18-28, 18-34 Platform loads. 18-44 Platform production.

crude oil disposal, 18-29, 18-30 gas disposal, 18-30 process equipment, 18-28 water disposal, 18-30 well completion, 18-28 well servicing, 18-28, 18-29 well workovers, 18-28, 18-29

Platform rigs, 36-2 Platform vibration, 12-23 Platform well bay, 18-29 Platinum-iridium standard, l-70 Plot of buildup with afterflow, 30-10 Plot of water FVF vs. pressure, 24-15 Plow steel, 304 Plug and abandonment of well, 18-20 Plug valves, 3-l 1 to 3-14 Plugback operations, 33-2 1 Plugging, 5-16, 5-23, 5-53, 14-2, 19-15,

19-30, 24-2, 39-25, 39-26, 44-36, 44-42 to 44-45, 56-6

Plugging agents, 29-5, 39-26 Plugging materials, 54-10 Plunger application for intermittent gas lift,

5-52, 5-53 Plunger-arrival detector, 5-52 Plunger clearances, 8-6 Plunger/engine (P/E) area ratio, 6-l 1 to

6-13. 6-15, 6-16, 6-18, 6-27, 6-28, 6-30 Plunger lift, 5-38 Plunger overtravel, IO-25 Plunger pumps, 6-50, 6-52 to 6-55, 8-5 Plunger stroke, 9-2

Polar blots, 53-12 Polished-joint tubing hanger, 3-9 Polished rod, 8-10, 9-1, 10-1, 10-2, 10-5,

10-7 Polished-rod coupling, 9-4 Polished-rod horsepower, 9-2, 9-3, IO-18 Polished-rod velocities and acceleration,

1 o-7 Polished-sealbore packer. 4-3, 4-8. 4-9 Polyacrylamide (P’AM), 47-3 Polyacrylamide polymer, 44-39, 44-40 Polyamine derivatives, 19-10 Polyemulsions, 55-8 Pol;ethylene. 1 l-9, 24-4, 24-5 Polyethylene bedding jacket, 18-49 Polyethylene line pipe, 15-10 Polyethyleneoxide (PEO), 47-3 Polyglycol esters, 19-10 Polymer-driven flood, 47-2 1 Polymer-flood statistics, 47-6 Polymer flooding, 19-28, 47-l to 47-6,

47-10, 47-18. 47-22, 48-7 Polymer gels. 55-5 Polymer properties,

biological degradation, 47-5 chemical degradation, 47-5 mechanical degradation, 47-5, 47-6 non-Newtonian effects, 47-4, 47-5 permeability reduction, 47-5 polymer retention, 47-5 viscosity relations, 47-4, 47-5

Polymer retention, 47-5 Polymer-solution viscosity, 47-4 Polymerisurfactant incompatibility, 47-13 Polymer types, 47-3 Polymer waterflooding, 48-5 Polymerized oils, 19-10 Polyphosphates, 44-15 Polypropylene, I l-9. 12-12 Polysaccharides, 47-3 Polyvinyl alcohol (PA), 47-3 Polyvinyl chloride, 1 l-9 Polvvinvl chloride (PVC) &tic, 18-46 Pony rids, 9-l. 9-3, 9-11’ Pooling clause, 57-5, 57-6 Poorly consolidated rocks, 51-33, 51-34 Pop-off safety release valve, 5-53 POP-Off valve, 13-59 Porcelain diaphragm, 26-24 Pore aspect ratio, 51-9, 51-12 Pore compressibility, 26-7 Pore configuration, 26-2 Pore-fluid compressibility, 5 l-4 Pore-fluid pressure, 28-4, 51-4, 51-5, 51-7,

51-8, 51-25. 51-30, 51-39, 51-44 Pore geometry, 28-2, 54-6 Pore liquid saturation, 27-9 Pore pressure, 52-18, 52-21, 52-22, 52-24

to 52-27

by neutron log, 49-26, 49-34, 49-36. 49-38

by sonic log. 49-26, 49-27 compaction and compressibility of porous

rock, 26-7 to 26-10 compressibility, 26-8 definition of, 27-l distribution, carbnate reservoirs, 36-6 effect on formation factor. 49-4 estimating, 51-5, 51-33 evaluation from acoustic log. 5 l-30 factor to consider in waterflooding, 44-2,

44-3 index, 49-38 introduction, 26-1, 26-2 investigation, 49-26 laboratory measurement of, 26-3 to 26-7 logs, 49-11, 51-29, 51-31, 51-32 measurement comparisons, 26-6 methods of determining, 26-4, 26-5 of consolidated rocks, 51-29 to 51-32 of poorly consohdated rocks, 51-33,

51-34 of secondary porosity. 51-31. 51-33 of shaly sand, 51-34, S 1-35 profile, 36-4 Rocky Mountain method, 49-31, 49-32 velocity relationship, 5 l-5

Porosity determination, bulk-density measurement, 50-l. 50-2 gamma-gamma density devices, 50-26 to

50-28 neutron-porosity devices, 50-28 to 50-33

Porous-diaphragm method of capillary- pressure measurement, 26-24, 26-2.5

Porous diaphragm or membrane, 26-24 Porous reservoir models, 44-17 Port configurations, gas-lift valve, 5-15 Port size, selection for gas-lift valves, 5-28 Port-to-bellows area ratio, 5-15 Portable well testers, 32-6 to 32-8 Portland cement, 46- 19 Portugal, 58-20 Position-sensing valve switch, 16-3 Positive-death indicator, 56-5 Positive-displacement meter, 12-6, 12-18.

12-19, 16-2, 16-5 to 16-7, 16.12. 17-4 to 17-6, 32-6 to 32-8, 32-10 to 32-12

Positive-displacement meter, measurement of petroleum liquid hydrocarbons by, 17-4

Positive-displacement-meter prover tanks, tables, 17-6

Positive-displacement-meter-type LACT system, 16-13

Positive-displacement pumps. 6- 1, 6-34, 6-49 to 6-51, 6-62, 13-54, 15-14, 15-17, 28-4, 44-47

Positive-seal double-bag model, 7-11 Positive-seal protector. 7-4, 7-5

54

Positive-volume dump meters, 16-13 Positive-volume meters, 16-2, 16-5, 16-7 Possible reserves, definition, 404 Posted barges, 18-2 Potassium, 24-5, 24-9. 24-18. 24-20. 50-2

to 50-4, 50-16, 50-18, 50-24 to 50-27, 50-34, 50-35

Potassium chloride for control of clay swelling, 46-20

Potential distribution, 39-20 Potential energy, 6-1, 6-34, 13-1, 13-2,

34-28, 34-29, 34-36 Potential function, 26-l I Potential gradient, 26-I I, 39-2 1 Potential of a process, 13-50 Potential tests, 12-17, 41-19 Potential tests of oil wells, 32-l to 32-16 Potentiometric model, 39.21, 39-22, 44.17,

4419, 4434 Potentiometric model studies, 39-20, 39-21 Potentiometric transducer, 30-5, 30-6 Poth “A” sand, 46-29 to 46-32 Pothead, 7-5 Pounding, 6-33, 6-34 Pour point, 21-7, 21-9, 21-10, 46-27,

46-3 1, 46-33 Power cable, ESP, 7-5, 7-6 Power control manifold module, 6-54, 6-56 Power, definition of, 6-14 Power-distribution system, offshore, 18-45 Power equivalents, table, 1-78 Power-factor correction, lo-35 Power factor of motor, 10-25, IO-33 to

IO-35 Power fluctuations, ESP, 7-14 Power fluid, 6-l to 6-5, 6-9, 6-10, 6-20,

6-21, 6-24 to 6-30, 6-34, 6-37, 6-38, 6-41, 6-42, 648, 6-51, 6-60, 6-62

Power-fluid discharge-pressure friction, 6-27 Power-fluid flow thyough nozzle, 6-42 Power-fluid friction, 6-30 Power-fluid friction pressure, 6-27 Power-fluid gradient, 6-25, 6-26, 6-29, 6-30 Power-fluid pressure, 6-7, 6-9, 6-16 to

6-18, 6-25, 6-27, 6-28, 641 to 6-43 Power-fluid systems, 6-54 to 6-57 Power-fluid tubing friction pressure, 6-42 Power-fluid tubing string, 6-2, 6-3 Power-law coefficient, 47-4, 47-9 Power-law model, 47-4, 55-5 Power method for parameter determination,

48-16 Power-oil emulsion, 6-31 Power-oil plunger pumps, 6-33 Power-oil tank and accessories,

closed system, 6-59 open system, 6-57 to 6-59

Power stroke. IO-14 Power supplies, uninterruptable (UPS’s),

1845 Power triangle of motor, lo-33 to IO-35 Power, unit and detinmon, 58-11, 58-23,

58-24, 58-32 Powers of numbers, three-halves table,

l-19, l-20 Powers of numbers, two-thirds table, I-20 Powers of SI units, 58-12 Pozzolan, 46-19 Precision of gas meter, 13-l Precision vs. accuracy, 58-8, 58-9 Predicted reservoir performance. 42-5. 42-6 Pre-exponential factor, 46-12 Preferred metric unit, 58-21, 58-26 to 58-38 Preflush,

hydrochloric acid, 56-5 micellar/polymer flooding, 47-10, 47-15 systems, 56-3


PREOS. 25-R. 25-9, Z-16 Preparation of well for testing, 33-6 Present value or present worth, 41-3 to

41-8, 41-12, 41-16, 41-17, 41-23. 41-25, 41-27, 41-29, 42-6

Present-worth factor, 41-25 Present worth of an annuity, table, l-66 Pressure and force m static plunger and

cylinder assembly. 6-18 Pressure, average drainage-region, 35-19,

35-20

Pressure-gradient traverse, 5-25 Pressure-hydrometer test method, 17-J Pressure hysteresis, 48-10 Pressure-loaded balanced diaphragm valve,

13-56

Pressure-balanced valves, 13-55 Pressure-base factor, 13-3, 13-12 Pressure behavior, constant rate in closed

reservoir, 35-2, 35-3 Pressure bombs, 304 Pressure-buildup analysis, 39-18, 39-19 Pressure-buildup behavior, 30-14 Pressure-buildup data, 6-48 Pressure-buildup tests, 42-3, 424, 48-8 Pressure changes in wellbore, calculations

including, 46-6

Pressure log, 52-1, 52-26 Pressure maintenance. 23-1, 40.4, 40.14.

43-11 to 43-16, 48-2, 48-4 Pressure-maintenance operations, 18-44,

34-28, 43-l to 43-3. 43-8 Pressure maintenance or cycling of GC

reservoirs. choosing between, 39-26 combination recovery procedures, 39-24 reservoir cycling, gas injection, 39-16 to

39-24 water drive and water inJection, 39-15,

39-16

Pressure-composition phase diagram, 23-2, 23-3, 23-6, 23-8, 23-9

Pressure control for high-pressure well, 13-56

Pressure controls, separators, 12-39 Pressure conversions. 58-7, 58-28. 58.29 Pressure correction for gas viscosities, 20-9 Pressure decline, rapid, 37-1, 37-2 Pressure dependence,

of compressional- and shear-wave attenuation, 51-6

of compressional- and shear-wave velocities, 51-5

of porosity, 5 l-6

Pressure-multiplier pump, 55-9 Pressure-operated gas-lift valve, 5-24 Pressure, optimum of separator, 12-4 Pressure/permeability data, 44-3 Pressure prlot, 13-56 Pressure/production history, 37-3, 37-6 Pressure profiles, 4-6, 35-4 Pressure pulses, 53-l Pressure radius, 4433 Pressure range, GC reservoirs, 39-2 Pressure rating classes of fittings, 15-13 Pressure ratings for steel pipe, 15-l 1 Pressure ratio, 6-36, 6-37, 6-45 Pressure recorders, 6-48 Pressure-recording charts, two-pen, 5-18,

5-23, 5-39, 5-41

Pressure depletion, 26-21, 39-7 to 39.16, 39-23, 39-24, 39-26, 44-l

Pressure-depletion behavior, 39-4 Pressure-depletion operation of GC

reservoir, hydrocarbon/liquid-condensation effect,

39-13 prediction with laboratory-derived data

and hydrocarbon analysis, 39-10, 39-l 1 prediction with vapor/liquid equilibrium

calculation and correlation, 39-l 1 to 39-13

Pressure-reducing regulator, 5-13. 12-39 Pressure-reducing valve, 13-55 Pressure reduction in gas analysis, 52-17 Pressure-reduction regulation, 13.54 Pressure regulators, 13-54 Pressure relationships used to estimate

producing BHP, 6-28 Pressure relief of storage tanks, 1 l-7 Pressure-relief valve, 6-5 1, 1 l-8, 1 l-9,

12-39, 19-28

pressure drawdown at wells, effect on productivity and recovery, 39-13

relative merits of measured vs. calculated behavior, 39-13, 39-15

Pressure-depth diagram, 5-21 Pressure distribution, 35-6, 4417, 44-30 Pressure drawdown, 6-48, 34-31, 34-34,

35-6, 37-2, 37-19 to 37-21, 48-10 Pressure drop, across sand-tilled

perforations, 564 in flowing gas column, 34-9 in gas lines, 15-5, 15-7 in liquid lines, 15-2, 15-3 in tubing, 6-70, 6-71

Pressure, effect on acid-reaction rate, 544, 54-5

effect on gas-saturated crude oils, 22-16 effect on tubing string. 4-9

Pressure equivalents, table, l-77 Pressure evaluation, 52-26 to 52-28 Pressure filters, 4447 Pressure for hydrate formation, 25-8 Pressure, force and flow in dynamic plunger

and cylinder assembly, 6-18 Pressure function, 34-35, 37-8 Pressure gauges, 1242 Pressure gradient, 2-39, 34-29, 38-13,

39-21, 44-3, 44-6, 44-15 Pressure-gradient curves, 34-36

Pressure ridges, 18-39 Pressure-sensing instrument (PSI), 7-7, 7-8 Pressure shock loads, 12-42 Pressure, SI unit for, 58-5, 58.11, 58-23 to

58-25, 58-28, 58-29 Pressure storage of products, 1 I - I2 Pressure, surface closing, gas-lift valves,

5-44 to 5-46 Pressure surveys, 5-2 Pressure switches, 16-4 Pressure/temperature diagram, 14-2 Pressure/temperature phase diagram, 23-6 Pressure/temperature rating of steel, 3-38 Pressure-transducer technology, 30-6 to 30-E Pressure transducers, 46-21 Pressure-transient behavior, 354 Pressure-transient tests, 5-3 Pressure transition zone, 52-2 I Pressure traverses, 34-36, 34-41 to 34-44,

41-41 to 41-44

cell, 39-13

Pressure/vacuum relieving system, 11-13 Pressure/vacuum valves, 1 l-8, 11-9 Pressure/volume (PV), compressibility,

51-49 diagram for pure components, 20-2 equilibrium cell, 204 method for waterflood water

requirements, 44-41 relation, 20-2, 20-6, 39-7

Pressure-volume-temperature (PVT), analysis, 22-1, 22-5, 22-10, 22-13, 40-21

SUBJECT INDEX 55

data, 7-9, 37-3, 37-22, 40-6 properties, 44-37, 48-2, 48-13

Pressure waves, 51-2 Pressures and forces in reciprocating

pumps. 6-10, 6-14 to 6-16 Pressures and losses.

in closed power-fluid installation, 6-26 in open power-fluid installation, 6-25

Pressures, forces and flows m hydraulic transformer, 6- 19

Pressures in downhole pumps. 6-16 to 6-19 Pressurized ball joints. 18-12, 18-13 Preventton of emulsions, 19-5 Primary cementing, 56-4 Primary depletion, 37. I, 42-2 Primary drainage, 28-12 Prtmary electric power, 1X-44, I X-45 Prrmary electrical system, IO-29 Primary functions of 011 and gas separators,

removal of gas from oil, 12-3 removal of oil from gas, 12-3 separation of water from oil, 12-3, 12-4

Primary oil recovery, 24-3, 40-33 Primary performance, injection operations,

42-3. 42-4 Primary-performance predictions, volatile oil

reservoirs, 37-23 Primary porosity, 26-l, 29-3. 36-6 Primary production. 41-12 Primary recovery. 42-l. 45-9 Primary-recovery methods and operations.

44-1. 44-2, 445, 44-36 Primary separation m separator, 12-19,

12-20 Primary separator gas, 39-6, 39-9. 39-10.

39. I4 Primary stratigraphic traps, 29-4, 29-5 Primary term. habendum clause, 57-4. 57-5 Primary waves. 5 l-2 Prime movers for pumping units,

electric motors, IO-19 to IO-37 internal-combustion engines, IO-14 to

IO-19 Principal amounting to a given sum, table,

l-64. l-65 Principle of additive volume, 20-l I Principle of corresponding states, 20-4,

20-5. 20-9. 20-13 Principle of flux-leakage tool, 53-22, 53-23 Principle of operation. reciprocating pumps.

6-8 to 6-32 Principle of superposttion, 38-l to 38-3 Principles of regulation control.

derivative response, 13-52. 13-53 nomenclature of process controls, 13-49,

13-50 process characteristics, 13-50 proportional control, 13-5 I, 13-52 reset, 13-52

Principles of TVD. TST, and TVT plots. 53-15, 53-16

Prism diagram, 47-12, 47-13 Probabrhty theory, 26-28 Probable error. factors for computing, table,

l-61 Probable reserves, 40-4 Problem examples: see Example problems Problems.

common to steamfloods and firefloods, 46-2 I. 46-22

plaguing tirefloods only, 46-22 plaguing steamfloods only, 46-22

Problems, special in or1 and gas separators, corrosion, 12-S paraffin, 12-7. 12-8 sand. silt, mud, salt. etc. 12-8 separating foaming crude oil, 12-6, 12-7

Process characteristics, 13-50 to 13-53 Process control computer. 16-10 Process equipment and facilities offshore,

18-28. 18-30, 18-32, 18-42 Process flow for expansion process. 14-8 Process flow sheets, 15-31 Process model, 28-3 Process selection, 15-30 to 15-32 Processing plant, 11-13 Procurement, an engineering effort, 15-31 Pro-Dip log and wellsite analysis, 49-37 Produced-fluid gradient, 6-25, 6-26, 6-29,

6-44 Produced-product prices. 41. I I Produced water, 12-3. 24-5 Producer BHP, steamfloods, 46-17 Producibdity of well, 39-5, 39-6 Producing efticrency, 30-15 Producing gas/oil ratio (GOR), 6-27, 37-l

to 37-3, 37-5, 37-7. 37-9 to 37-14, 37-22. 37-23, 37-26, 39-2

Producing properties. check list of data required for oil and gas, 41-8, 41-9

Producing wells, gas, 34-3 to 34-27 gas-condensate, 34-27, 34-28 gas/water flow, 34-27

Product thread form, extreme-line casing joint, 2-64, 2-71. 2-72

Production casing string, 3-S Production data, ESP. 7-9 Production decline, 41-9 to 41-l 1 Production decline curves, constant-

percentage, 40-28 to 40-32 decline tables for constant-percentage

decline, 40-30 to 40-32 economic limit. 40-27 general principles, 40-26, 40-27 harmonic, 40-29, 4 L 10 hyperbolic, 40-28 loss-ratio method. 40-32 nominal and effective decline, 40-27 relatronship between effective and nominal

decline. 40-29 reserves and decline relationship, 40-32 straightening curves, 40-3 I to evaluate pilot flood performance, 44-39 types of, 40-28. 40-29 types of plots. 40-3 1

Production discharge friction pressure, 6-27 Production equipment,

tank battery, I l-9 to 1 l-l I tank grades, I l-l 1

Production fluid gradient, 5-40 Production history. 41-9 Production loans, 44-5 Productton logging, 53-17 Production mechanisms, 46-4 Production packers,

classification and objectives, 4-l combination tubing/packer systems, 4-l I considerations for packer selection, 4-4 to

4-6 in production packing, 56-8, 56-9 referencea, 4-I 1 tubmg/packer forces on intermediate

packers. 4-I 1 tubing/packer systems, 4-6 to 4-9 tubing response characteristics, 4-8 to

4-l 1 tubing-to-packer connections. 4-1 utilzation and constraints, 4-I to 4-3

Production payments. 41-1, 41-2, 41-t. 41-9. 41-15. 57-7

Production-pressure effect. 5-18, 5-30 Production-pressure factors, 5-14, 5- I7 to

5-22. 5-24. 5-26. 5-27. 5-32. 5-33, S-35, S-39, S-40. 5-42. 5-44, 5-48, 5-54

Production-pressure-operated gas-lift valve. 5-13, 5-16, 5-17. 5-21. 5-32, 5-33. 5-35 to 5-37, 540, 5-54

Production profile, 40-l Production-rate allowables. 32-1, 43-2,

43-10 Production-rate and time calculations,

solution-gas-drive. introduction, 37-17 rates based on IPR, 37-19 to 37-21 rates based on PI, 37-19 time required for oil production, 37-21.

37-22 Production rate of gas wells, 33-20 Production rate variation (superposition),

35-8, 35-9 Production response from high-pH flood,

47-22 Production safety controls, 16-4 Production separator, 12-17 Production string, 3-39 Production structures offshore,

artificial islands, 18-40, 18-41 gravity type, 18-41, 18-42 piled, 18-42

Production taxes, 41-l. 41-3, 41-4, 41-12 Production tests, 18-34 Production-transfer-pressure traverse, 5-36 Productive stringer. 36-7 Productivity, decline or loss, 39-25 Productivity, effect of damage on, 54-8,

54-9 Productivity, from drawdown tests. 4442 Productivity index (PI), 5-38, 5.39, 5.45,

641, 6-46, 30-10 to 30-13, 30-15, 32-2 to 32-6, 34-30 to 34-36, 35-6. 35-10. 37-19 to 37-21, 40-27, 42-4. 46.10. 58-14, 58-38

Productivity index for different GOR’s, 32-5 Productivity-index/permeability correlation,

32-4 Productivity ratio, 30-13. 30-14 Productivity test, 24. I, 39-25 Products of crude oils, temperature

correction for, 17-5, 17-6 Profile calipers, 53-17. 53-18 Profile of a gravity system, 15-15 Profiles, injection-gas volumetric

throughput. 5-20 Profit margin. 41-6 Profit margin and cost relatronship, 36-2 Profit-to-investment ratio, 41-7 Profitability, 39-17 Programmable calculators, 6-34, 6-38, 6-4 I,

6-46, 20-7, 20-9 Programmable controllers, 16-4, 18-47 Programmable logic controllers, 19-29 Programmer for oilfield motors, lo-27 Project control, 15-32, 15-33 Project definition, 15-30 Project design, thermal recovery.

features common to both steamfloods and firefloods, completion intervals, 46. I7 pattern selection, 46-17 producer BHP, 46-17

features pertaining to firefloods only. air injection rate, 46-19 dry vs. wet gas combustion, 46-18 WAR, 46-19

features pertaining to steamfloods only, steam injection rate. 46-18 steam quality, 46- 18

Project execution format. 15-31, 15-32 Project inspection and expediting, 15-31 Project management, 15-30 to 15-32 Projected oil recovery. 42-2. 42-3


Prolog wellsite analysis, 49-37 Pronunciation of metrjc terms, 58-13 Propagarion time, 49-32, 49-34 Propane as IC engine fuel, IO-16 Propane as refrigerant, 14-9 Propane compressibiliiy table, 17-7 Propane critical pressure, 25-3 Propane/water system. 25-2. 25-3. 25-17,

25-25. 25-21 Properties and behavior of gas condensate

tluids, composition ranges, 39-2 gas/liquid ratios, 39-4 introduction, 39-l liquid contents, 39-4 phase and equilibrium behavior, 39-2 to

39-4 pressure and temperarure ranges. 39-2 properties of separated phases, 39-4 viscosities, 39-4

Properties of construction materials for pressure vessels, 12-41

Properties of crude oils and gas condensates, 39-2

Properties of produced waters, analysis methods for oilfield water, 24-5 chemical properties of oilfield waters,

24-5 to 24-13 morgamc constituents, 24-9, 24-12 interpretation of chemical analyses, 24-18,

24-19 introduction and history, 24-I to 24-3 nomenclature, 24-20 occurrence. origin. and evolution of

oilfield waters, 24-19. 24-20 physical properties of oilfield waters.

24-12 to 24-18 recovery of minerals from brmes. 24-20.

24-2 1 references, 24-21, 24-22 sampling, 24-3 to 24-5

Properties of separated phases, CC streams, 39-4

Properties of ternary diagrams, 23-4 Proportional action of controller, 13-52 Proportional control, 13-49, 13-51 to 13-53,

13-56 Proportional counter, 50- 14 Proportional pilot for pneumatic service,

13-56 Proportional/reset controller, 13-52 Proportionality constant for rock, 26. II Proppant,

density, 55-8 grain roundness factor. 55-8 grain size, 55-8 grain-size distribution. 55-8 grain strength, 55-8 permeability. 55-8 placement, 55-8 quality, 55-8 transport. 55-7, 55-9

Proppant-transport properties, 55-5 Propping agent,

amounts used. 55-l definition of, 55-2 grain size of, 55-8 grain strength of, 55-8 permeability, 55-4 placement of, 55-8

Propylene. 14-9 Propylene compreasdxlity table, 17-7 Propylene/water system. 25-25 Propyneiwater system, 25-25 Proration, 41-3, 41-10, 41-11 Proration records, 13-3 Protected~slope production island, 1X-40

Protectmn equipment for oilfield motors. air circuit breaker, lo-28 control fuses, IO-29 lightning arresters, IO-28 motor fuses, IO-28 motor-winding temperature sensors, 10-29 over-temperature lockout circuit, 10.29 phase loss relay. 10-28, IO-29 pumping-unit vibratmn switch, lo-29 thermal-overload relay, lo-29 under-voltage relay, lo-28

Protective coatings, 9-10 Proved developed reserves, definitmn, 40-3 Proved reserves definitmns, 40-2 Proved undeveloped reserves, definition,

40-3 Proving systems, 17-4 Proximity log (PL), 49-22 to 49-25, 49-27 Prudhoe Bay field. Alaska. 18-3, 18-39,

18-41, 48-17 Pseudo-Rayleigh waves. 51-12 to 51-14.

51-25. 51-27 Pseudobinary diagram, 23-9 Pseudocomponenta, 47-I 1 Pseudocritical calculations,

from gas analysis, 40-21 from specific gravity, 40-22

Pseudocritical constants, corrected, 20-5 Pseudocritical density, 20-10, 20-15 Pseudocritical pressure, 20-5. 20-7, 20-10,

20-16. 22-12, 40-21, 40-22 Pseudocritical properties, 22-2 I, 34-4 PseudocrItical properties of C, + , 20. IO Pseudocritical temperature, 20-S, 20-7,

20-10. 2I)-16. 22-12, 40-20, 40-21 Pbeudocrltical-temperature gradient factor.

20-7 Pseudocriticals. for heptanes and heavier,

21-17 of gases and condensate well fluids, 21-19

Pseudogeometrical factors, 49-22, 49-25 Pseudoliquid density, 22.2 to 22.4 Pseudophase theory, 47-13 Pseudoreduced compressibility, 20-I 1,

20-12, 22-12, 22-13 Pseudoreduced pressure, 20.5. 20-9, 20-l 1,

20-12. 22-13, 22-21. 40-21 Pseudoreduced properties, 22-21, 34-5 to

34-7, 34-10 to 34-22. 34-24 Pseudoreduced temperature, 20.5. 20.9,

20-11. 20-12, 22-13, 40-21 Pseudorelative-permeability curves, 37-4,

48-8 to 48-10, 48-12 Pseudorelative-permeability data, 37-4, 37.5 Pseudostatic SP. 49-9, 49-10. 49-28 Pseudosteady state, 35-2, 35-3, 35-7, 35-8,

35-10. 35-12 to 35-14. 35-16 Pseudosteady-state aquifer productivity

index. 38-8 Pseudosteady-state behawor. 35-6 to 35.8,

35. I5 Pseudosteady-state flow. 5.25. 32.3 to 32-6,

33-5 to 33-7, 34-30, 34-31, 37-19, 37-2 I

Pseudoternary diagram, 45-2. 45-3, 45-5 Public Law 93-380, Aug. 21, 1974, 1-69 Public Law 94-168. Dec. 23, 1975, 1-69 Puffer, 52-6 Pull bar. 7-12 Pull curves. casing-hanger. 3-6, 3-7 Pull-m procedure, IS-37 Pull sheet, 53-17 Pull tube, 8-4 Pulling and running sucker rods, 9-10 Pullout strength of line-pipe joint, 2-62 Pulsation dampers, 6-50. 6-51, 6-61. 15-17 Pulse testing or testa, 36-7. 36-8, 48-8

Pulsed-data transmission systems, 17-4 Pulsed nuclear magnetic resonance analyzer,

52-26 Pulsed-neutron logging. 50-36 Pulsed-neutron logging devices, 50-2 1,

50-22 hltrusion process, 9- 12 Pump discharge pressure, 6-17, 6-25 to

6-21, 6-28, 6-41 to 6-43, 6-47, 6.49, 6-5 1

Pump displacement, 6-I 1 10 6-13, 6-15, 6-16. 6-21, 6-24. 6-29, 6-30, 6-52 to 6-55, 8-5. 8-9, 9-2

Pump drivers, 15-15, 15-16 pump efficiency, 6-24. 6-3 1, 6-37, 6-38,

6-49, 46-2 1 Pump-efficiency equations, 6-68 Pump-end volumetric efficiency, 6-2 I, 6-22 Pump intake, 7-4, 7-5 Pump-out method of solution mming, I l-13,

II-14 Pump performance curve, 7-10, 7-l 1 Pump piping and installation, 15.17 Pump-protector motor unit, 7-2 Pump selection, 8-2 to 8-4 Pump-selection table. 7-10 Pump speed, maximum rated, 6-I I to 6.13.

6-15, 6-16, 6-21 Pump submergence. 6-25. 6-26 Pump suction gradient, 6-42, 6-44 Pump-suction (intake) pressure, 6-4, 6-17.

6-25, 6-26, 6-38, 6-43. 6-47 Pump terminology, 8-2. 8-6 to 8-9 Pumpdown pressure recorders, 6-34 Pumped-off well, definition of, 10-27 Pumping equipment for fracturing, 55-9 Pumping speed factor. IO-6 Pumping speed, maximum practical. 9-4,

9-5 Pumping-unit bearings, IO-5 Pumping-unit design calculations, IO-8 to

10-l I Pumping-unit geometry, 9-2. IO-2 Pumping-unit loading, IO-5 Pumping units, 10-I to IO-13 Pumpoff, 7-6. 7-10, 7-16 Pumpoff controls, lo-27 Pumpstroke counter, 52-I I Pure Oil Co., 54. I Purging offshore distribution system, IS-46 Pycnometer, 26-3 Pycnometer method, 52-19 Pyo&type thermocouple, 16-7 Pyramidal rule, 40-5 Pyrenees Mts., 46-27 Pyroanalyzers, 52-28 Pyrolysis. 52-l

Q Quadruple point. 25-15 Quality control. 12-38 Quality factor. 5 l-4 Quality of foams, 47-8 Quality of separated fluids. 12-13, 12-15 Quality power oil, 6.55 Quantities (chemical, electrical, and

physical) in alphabetical order, 59.18 to 59-5 I

Quantity, definition. 58-9 Quartzose sediments. 29-7 Quaternary compounds. 44-45 Quaternary diagrams. 24-19 Quench water. 46-2 I, 46-22 Quick-cycle units, 14-10, 14.13 Quintaplex pump, 55-9 Quintiplex positive-displacement pump, 6-I.

6-49. 6-5 1

SUBJECT INDEX 57

R

Rabbiting, 56-3 Radial aquifers, 38-2 to 38-4, 38-8 to 38-19 Radial differential temperature log, 31-7 Radial-flow equation, 30-12 Radial-flow pumps, 15-15 Radial-flow system, 26-13 to 26-15 Radial frontal advance, 38-13 Radial geometry, definition, 38-l Radial gridded simulator, 37-21 Radial pseudogeometrical factors, 49-20 Radians expressed in degrees, table, 1-43 Radiation, 46-4 Radiation detector. 50-14 Radiation heat-transfer coefficient, 46-5 Radiation log. 49-25 Radiation, units and conversions, 58-37 Radio frequency, 19-3 I Radio-frequency preheater, 9-12 Radio triangulation systems, 18. I8 Radioactive capture, 50-9 Radioactive decay, 50-4, 50-6, 50-21 Radioactive isotopes, 50. I5 Radioactive rocks. 58-33 Radioactive tracers. 284, 46-2 I Radioactivity logging and logs, 41-8, 5142 Radioactivity surveys, 49-l Radiograph, of areal sweepout efficiency.

44-18 of welded pipe, 1241

Radioisotopes, 46-2 I Radionuclide. 58-10 Radium. 50-4. 50-6, 50-15 Radius of circumscribed circle, equation,

I-36 Radius of curvature method of calculating

directional surveys, 53-5 Radius of inscribed circle. equation. l-36 Ram preventera. 18-l I, 18-12, 18-15 Ramey’s equation for wellbore heat

transmission, 46-5. 46-6 Ramey’s generalization of Marx-

Langenheim method, 46-8 Random flood pattern or network, 44-13,

44-14. 44-17 Randomized network model, 28-12 Range lengths. API casing and liner casing,

2-3 API tubing, 2-37 line pipe, 2-47

Rangeability of gas meter, 13-I. 13-45, 13-48

Rangely field. Colorado, 23-9. 23-10. 26-23, 48-6

Raoult’s law. 23-l 1 Rarefactions, 51-2 Rasching rings, 12-10 Rate/cumulative curve or relationship,

40-25. 40-27 to 40.29, 40.31, 40-32 Rate-dependent skin factor, 35-10 Rate of frontal advance, 39-17 Rate-of-penetration (ROP). 52-l I, 52-13.

52-18. 52-24. 52-25. 52-27 to 52-29 Rate-of-penetration log. 52-1 Rate of return (ROR), 41-6 to 41-8. 41-16

to 41-24, 442 Rate/pressure curves. 44-36 Rate/time curve or relationshlp, 40-27 to

40.29, 40.31, 40.32, 41-10 Ratio(s).

air/water, 46-33 compression, 6-10, 6-21, 8-9, 8-10.

10-15, 18-14, 39-24 conductance, 4434 damage. 30-13

equihbrium, 21-1 I, 21-16. 23-11, 25-5, 39-6, 39-9. 39-1 I to 39-13, 39-15

equilibrium vaporization, 37-23 gas-gravity/condensate-gas, 34-28 gas/oil, 5-25, 5-26. 6-24, 6-25, 6-29,

6-30, 6-38, 6-39, 6-44. 6-47, 12-35, 22.20, 3441 to 34-43, 34-47 to 34-44, 38-16, 39-l, 39-2. 40-33, 41-8, 4439, 58-38

injectivity/productivity, 46-17 liquid/gas, 12-35, 39-2, 39-5 methods. 49-28 net-pay/net-connected-pay, 36-17 net-profit/initial-investment, 41-22 net-profit/unreturned-investment balance,

41-22 of differential pressure to absolute

pressure, 13-8 of epithermal counting rates, 50-20, SO-29 of gas-cap/oil-zone volume, 37-5, 37-6,

37.13, 37-14 of net profit. constant, 41-20 of nozzle area to throat area, 6-34 of orifice to pipe diameter, 13-36 of pump displacement to engine

displacement, 6-18 oil/steam, 46-9. 46-15, 46-23 permeability. 37-14, 37-15 permeability/viscosity, 47-8 piston/engine (P/E), 6-l I to 6-13, 6-15,

6-16. 6-18. 6-27, 6-28, 6-30 piston pneumatic/hydraulic pump, 3-33 pore aspect. 51-9. 51-12 pressure. 6-36. 6-37. 6-45 producing gas/oil, 6-27, 37-l to 37-3,

37-5, 37-l. 37-9 to 37-14, 37-22, 37-23, 37-26, 39-2

productivity, 30-13, 30-14 profit-to-investment, 41-7 sand. 36-4 solubilizatlon, 47-13, 47-14, 47-20 stage compression, 39-24 stage pressure, 12-33 steam/oil. 46-8, 46-14, 46-15, 46-23,

46-24. 46-27 steam/tar. 46-27, 46-28 sulfur/oxide. 52-7 surface~gas~gravity/weKtluid~gravity,

21-17 tube amplitude, 51-47, 5148 velocity. 51-38 viscosity, 43-5, 43-6, 45-7, 45-l I viscosity vs. pseudoreduced temperature,

20-9 viscous/gravity forces. 44-25 volumetric, 55-6 water/oil, 19-17, 24-20, 28-5, 34-41,

40-18 to 40.20, 447, 44-9. 441 I. 44-3 I, 44-32. 44-39. 46-33

water/oil mobility. 43-7. 448, 47-6 water/oil viscosity, 40-18, 44-10

Reaction kinetics, 48-2 Reaction-rate equation. 46-12 Reaction rate of acids, factors affecting,

acid concentration. 54-5 area/volume ratio, 54-5 corrosion inhibitors. 54-6 flow velocity, 54-5 formation composition, 54-6 pressure, 54-4 temperature. 54-4. 54-5

Reactive tluids. effect on permeability measurements. 26-18. 26-19

Reactive power rating of transformers (kVAR). 10-31, lo-33 to IO-35

Real-gas law, 20-4. 20-I I Real-gas pseudopressure, 35-10

Real gases. 20-4 Real property, definition. 57-l Receipt and delivery tickets, 17-7 Receiver of sonic meter, 13-49 Reciprocal gas formation volume factor,

40-22, 40-23, 40-33, 40-34 Reciprocal mobility ratio, 44-19. 4422,

44-23 Reciprocal of numbers. table, I-21 to 1-23 Reciprocated induction curve, 49-15 Reciprocating oilwell pumps, 8-l Reciprocating piston positive-displacement

meter, 32-l I Reciprocating pump,

displacement of downhole pumps, 6-2 1, 6-24

equipment selection and performance calculations, 6-28

fluid friction and mechanical losses in hydraulic pumps. 6-19 to 6-21

for waterfloods, 15.14. 15.15, 15.17, 15-18

gas/liquid ratio in vented systems, 6-27 in closed power-fluid systems. 6-4 in reverse-flow systems, 6-5 manufacturer speciticatlons, 6-l 1 to 6-13,

6-15, 6-16 multiphase flow and pump discharge

pressure, 6-27 pressure and force balance in downhole

pumps, 6-16 to 6-19 pressure and forces in, 6-10, 6-14 to 6-16 pressure relationships used to estimate

producing BHP, 6-28 principle of operation, 6-8 to 6-10 subsurface troubleshooting guide, 6-3 I system pressures and losses in hydraulic

installations, 6-24 to 6-27 turbulence in, 19-5 worksheets and summary of equations,

6-29, 6-30 Recoil electron ejection, 50-12 Recombined separator samples, 39-5 Recommended practices before unloading,

5-53 Recompletion costs. 41-9, 4 I 12 Recompletions. 41-9, 44-7 Recorder for metering system, 13-36. 13-37 Recording acoustic data. methods of.

acoustic-array logging, 5 l-25 to 5 I-27 amplitude/time recording, 51-18 conventional acoustic logging, 5 I I5 to

51-18 intensity/time recordmg. 51. I8 introduction, 5 I I4 long-spaced acoustic logging, 5 I- I9 to

51-24 reflection, 51-27. 51-28 shear-wave logging, 5 l-24, 5 1-25

Recording ammeter, 7-14 Recording caliper logs, 53-16 Recoverable gas reserves, 40-24, 40-27 Recoverable gasoline content. 20-I I Recoverable hydrocarbon reserves, 4 l-3 Recoverable hydrocarbons, 39-26 Recoverable oil, 40-27, 44-32, 4437. 44-38 Recovery by miscible displacement, 45-9.

45. IO Recovery by pressure maintenance, 39-9 Recovery efficiency, 39-l I, 39-15. 42-5.

43-2, 43-6, 43-9. 44-3. 45-B. 45.12. 45-13, 46-14, 46-27. 47-16, 47-17

Recovery-efficiency factor, 40-16. 40-17 Recovery estimates. 40. I Recovery factor, 40-l. 40-I 1. 40-19. 40-20.

40-23, 40-25 to 40-27


Recovery factor, average from correlation of statistical data, 40-16, 40-17

Recovery factor vs. reserv~lr pressure, 37-14, 37-15

Recovery from gas reservoirs with water drive, 40-26, 40-27

Recovery of LPG products, 45-12 Rectangular tanks, 1 l-2 Rectilinear flow of compressible fluids,

26-11 Red Sea, 24-19 RedalertTM motor controller, 7-6, 7-16 Redlich and Kwong equation, 20-7, 20-8,

23-12, 23-13 Redox potential (Eh), 24-4, 24-5, 24-9,

24-16, 24-17 Reduced properties, definition, 22-2 1 Reduced-state relationships, 22-2 1 Reduced vapor pressure, 20-13 Reducing agents, 54-7, 56-3 Reduction factor or ratio, 6-50, 49-9 Redundancy, subsea production facilities,

1848 Redwater D-3 pool, Alberta, Canada, 40-20 Redwater field, Alberta, Canada, 40-Z Reel barges, 18-37, 1X-38 Re-entry systems, 18-14 References (see also General References),

acidizmg, 54-12 acoustic well logging, 51-50 to 5 l-52 automation of lease equipment. 16-16 bottomhole pressures, 30.16. 30-17 casing, tubing, and line pipe, 2-74 chemical floodmg, 47-24 to 47-26 crude-oil properties and condensate

properties and correlations, 2 i-20 development planning for oil wells,

36.10, 36-l 1 electric submersible pumps, 7-17 electrical logging, 49-41 estimation of oil and gas reservoirs,

40.37. 40-38 formation fracturmg. 55-10 gas-condensate reservoirs, 39-27. 39-28 gas-injection pressure maintenance in oil

reservoirs, 43-19 gas lift, 5-57 gas measurement and regulation, 13-59 gas properties and correlations, 20-18 hydraulic pumping, 6-72 lease-operated hydrocarbon-recovery

systems, 14-22 measuring, sampling and testing crude oil.

17-8 mixable displacement, 45. I3 to 4% 15 mud logging, 52-30 nuclear logging techniques, 50-38 offshore operations, 18-52 oil and gas separators. 12-43 oil storage, 1 I- 14 oil-system correlations, 22-21, 22-22 open flow of oil wells, 33-23 other well logs. 53-26 petroleum reservoir traps. 29-9 phase behavior of water-hydrocarbon

systems. 25-20 to 25-24 phase diagrams, 23-13 potential tests of 011 wells, 32-16 production packers, 4-l I properties of produced water, 24-21 to

24-23 propertles of reservoir rocks, 26-33 pumping units and prime movers for

pumpmg units. IO-37 relative permeability, 28-15. 28-16 remedial cleanup and other stimulation

treatments. 56-9

reservoir simulation, 48-17 to 48-20 solution-gas-drive oil reservoirs, 37-27 subsurface sucker-rod pumps, S-10 sucker rods. 9-14 surface facilities for waterflooding and

saltwater disposal, 15-33, 15-34 temperature in wells, 31-7 thermal recovery, 46-43 to 46-45 typical core analysis of different

formations, 27-9 valuation of od and gas reserves, 41-37 water-drive oil reservoirs, 38-20 water-Injection pressure maintenance and

waterflood processes, 44-49 to 4452 well-performance equations, 35-21 wellbore hydraulics, 34-55, 34-56 wellhead equipment and flow-control

devices, 3-40 Reflected conical wave, 51-12 Reflection method, acoustic-wave-

propagation logging. 51-I I, 51-27. 51-28

Reflection peak, 49-13 Refrigerants, comparison of common types,

14-9 Refrigerants, properties of six types. 14-10 Refrigerated storage, 1 l-12 Refrigeration process, 14-9 Regeneration cycle, 14-10 Regeneration gas, 14-l 1 to 14-14, 14-20,

14-21 Regeneration-rate controller, 16-15 Regeneration system, 14-6, 14-7, 14-l 1,

14-12 Regression equations, 46- 15 to 46-17 Regular polygons, table, 1-36 Regulator types, 13-54 to 13-57 Regulatory agencies, 16-1, 16-2, 18-12,

19-28. 32-1, 32-2, 32-15. 33-5, 40-1, 40-3, 40-4. 41-3. 43-2

Regulatory agency form, 32-2 Regulatory codes. 18-44 Reid vapor pressure (RVP), 12-33, 14-13.

17-3, 21.1Y Reiatel diagram, 24-19 Relationship,

between bending and curvature radius of casing, 2-61

between total and external load of casing, 2-6 1

Relative atomic mass, 58-24 Relative bearing, dipmeter. 53-10 Relative density, correction of observed

value, 17-5, 17-6 definition of, l-80, 58-24 hydrometer test method, 17-5 of C,+ fraction. 20-10 of crude petroleum, 17-5 of liquid petroleum products, 17-5 of natural gas, 20- I3

Relative dielectric permittivity. 49-32 Relative molecular mass, 58-24 Relative oil volume, definition, 22-21 Relative permeability,

calculating cumulative gas production, 31-10

conclusions, 28-13, 28-14 critique of recent work. 28-10 to 28-12 curves, 28-6, 28-8 to 28-13 definition. 2X-l effect of GOR or WOR changes, 30-l I factor in waterflooding, 44-2 framework ideas, 28-2, 28-3 general references, 28-16 historxal background, 28-2 in determining mobdity in a layer, 44-9 in two-phase fluid flow, 55-8

introduction, 28-1, 28-2 measurement methodologies, 28-3 to 28-9 nomenclature, 28-14 of reservoir rock, 44-4, 44-5 ramifications needing attention, 28.12,

28-13 recent literature, 28-9, 28-10 references, 28-15, 28-16

Relative-permeability characteristics, 37-2, 37-19, 44-27

Relative-permeability curves, 28-6, 28-8 to 28-13, 34-31, 39-13, 44-6, 46-13, 46-34, 46-37

Relative-permeability data, 37-3, 37-4, 37-10, 39-9, 40-13, 43-11, 46-12

Relative-permeability-ratio data, 37-23 Relative-permeability ratios, 40-8 to 40.12,

40-14, 43-5 to 43-7. 43-12 Relative pipe roughness, 15-2. 15-3, 15-7 Relative-roughness factor, 34-2, 34-3,

34-38, 34-40 Relaxation pressure, 40-34 Relays for motors, IO-28 Reliability/maintainability, subsea production

facilities, 18-48 Reliability of gas meter, 13-l Reliability of sensors. 3-3 1 Remedial operations, 4-9, 33-22 Remedial work, 41-8 Remedial workover operations, 39-24 Remote, closed-loop controls, 18-46 Remote control of subsea equipment, 18-48 Remote-control valves, 18-3 Remote-controlled SSV system. 3-34 Remote terminal umt (RTU), 16-4, 16-6,

16-8 to 16-l 1 Removal of acid gases, 14-21, 14-22 Removal of CO,, 14.17, 14.21, 14-22 Removal of gas from oil, 12-3 Removal of gas from oil in separators,

methods used, agitation, 12.13 baffling, 12-13 centrifugal force, 12-13 chemicals, 12-13 heat, 12-13 settling, 12-13

Removal of HZS, 14.17, 14.21, 14-22 Removal of oil from gas, 12-3 Removal of oil from gas in separators,

methods used, centrifugal force, 12-9, 12-10 coalescence, 12-10, 12-l I density difference (gravity separation),

12-8 filtering, 12-l 1 flow-direction change, 12-9 flow-velocity change, 12-9 impingement, 12-9

Removal of water vapor, 14-17 to 14-21 Repeatability of BHP gauges, 30-4. 30-6 Repeatability of meters, 13-48 Reperforation, 56-l Representative-element simulation, 48-7 Reproducibility, 13-50 Reserve SPE letter symbols, 59-2 to 59-51 Reserve SPE subscripts. 59-52 to 59-70 Reserved production payment, 4 I - 1 Reserves.

and decline relationship, 40-32 cost of developing. 42-1, 42-2 possible, 36-l. 40-4 probable, 36-1, 40-4 proved, 36-l. 40-2. 40-3 proved developed, 40-3 proved undeveloped, 40-3 ultimate depletion of. 42-2

SUBJECT INDEX 59

Reserves, oil and gas, definition and nomenclature, 40-2, 40-3 estimating, 40-1, 40-2, 40-12 general references, 40-38 glossary of terms, 40-3, 40-4 nomenclature, 40-35 to 40-37 nonassociated-gas reservoirs. 40-2 1 to

40-26 oil- or gas-in-place computation, 40-5 to

40-S oil reservoirs under gravity drainage,

40-14. 40-15 oil reservoirs with gas-cap drove, 40-13.

40- 14 oil reservoirs with water drive, 40-15 to

40-2 I performance curves, 40-32 production-decline curves, 40-26 to 40-32 references, 40-37, 40-38 reservoir-volume computation, 40-4, 40-5 saturated depletton-type oil reservoirs,

40-8 to 40-12 undersaturated oil reservoirs without water

drive. 40-12 volatile 011 reservoirs, 40-13

Reservoir above bubblepoint pressure. 38-13 Reservoir anisotropy, 36-8 Reservoir below bubblepoint pressure, 38-13 Reservoir continuity, 36-6 to 36-8 Reservoir-controlled fluids, 55-2, 55-4 Reservoir coverage. 39. I8 Reservoir cycling efticlency, 39-17, 39-18,

39-22, 39-23 Reservoir cycling, gas injection,

calculation of cycling performance, 39-17 to 39-20

dry-gas injection, 39-16 inet--gas injection, 39-16. 39-17 noninjection-gas requirements, 39-23,

39-24 prediction of operations with mathematical

reservoir simulator, 39-22, 39-23 prediction of operations with model

studies. 39-20 to 39-22 ultimate recovery, 39-23

Reservoir cycling operations, efficiency terms, 39-l 8

Reservoir, definition, 40-3 Reservoir deliverability, 5-23 Reservoir depth, 442, 443 Reservoir description, uncertain data, 48-12 Reservoir-dip effect, 4425 Reservoir discontinuities, 36-4, 36-5 Reservoir engineer, 22-10, 26-7, 36-10,

39-3, 39-24, 44-7, 4.431 Reservoir-fluid characteristics, 36-1, 36-2,

424, 42-5 Reservoir-fluid compositions, 37-24 Reservoir-fluid properties, 43-10 Reservoir-fluid recovery. 39-23 Reservoir-fluid samples, 424 Reservoir-fluid systems, phase diagrams,

23-6, 23-7 Reservoir-fracture effect, 4425. 4426 Reservoir geometry, 44-2 Reservoir-geometry factor, 38-13 Reservoir heterogeneities, 28-l 1, 30-14 Reservoir identification from mud log,

52-15 Reservoir interference, 38-3, 38-4 Reservoir limit tests, 32-5 Reservoir performance, calculating under

steam stimulation, 46-9 indicator pertaining to steamfloods, 46-15 indicators common to both steamfloods

and firefloods, 46-14, 46-15

Indicators pertaming to firefloods. 46-16 prediction of. 36-9, 36-10

Reservoir performance data, 37-7 Reservoir productivity guide, 52-16 Reservoir-rock characteristics, 36-l. 36-2.

42-4, 42-S Reservoir-rock heterogeneity, 28-l 1 Reservoir-rock properties,

continuity of, factor in waterflooding, 44-2. 44-3

electrical conductivtty of fluid-saturated rocks, 26-27 to 26-29

empirical correlatton of electrical properties. 26-29 to 26-32

fluid saturations, 26-20 to 26-27 nomenclature, 26-32 permeabihty, 26-10 to 26-20 porosity, 26-l to 26-10 references, 26-33

Reservoir simulation, as extension of material-balance technique, 36-7

general references, 48-20 htstory of, 48-1. 48-2 introduction, 48-1 mathematical models for, 43-17 models, 38.16, 40-34, 43-2, 43-17, 48-l

to 48-9 nomenclature, 48-17 purpose of. 48-6, 48-7 references, 48- 17 to 48-20 studies of gas-condensate reservoirs,

39-22 technology, 48-13 to 48-17 validity of results, 48-9 to 48-13

Reservoir-simulation models, 38-16, 40-34, 43-2, 43-17, 48-1 to 48-9

Reservoir simulators, 28-14, 36-7, 36-10, 46-11

Reservoir traps, 29-1 to 29-9 Reservoir volume, computation of, 40-4,

40-5 Reservoir-volume estimation, 38-9, 38-11 Reservoir with watersand, 46-26 Reservoirs amenable to thermal recovery,

46-3. 46-4 Reset. 13-50, 13-52, 13-53 Residual free-gas saturation, 40-8 Residual gas saturation, 36-3, 40-16, 44-25,

49-26 Residual hydrocarbon saturation. 446 Residual liquids, defimtion, 27-8 Residual oil after waterflooding,

effect of initial saturations, 44-6 fresh-core techniques, 44-5 influence of wettability. 44-6, 44-7 interpretation of conventional core-

analysis data, 445 relative-permeability curves, 446 restored-state technique, 44-5. 446

Residual oil, definition. 22-21 Residual oil saturation (ROS), 28-5, 28-8,

28-11, 373, 40-16, 40-17, 40-19, 42-2, 42-4, 442, 44-4 to 44-6, 449, 4411, 4432, 4446, 46-21, 46-37, 47-1, 47-9, 47-10, 47-17, 49-26, 49-27, 49-36

Residual-resistance factor, 35-5 Residual-viscosity function. 20-9 Residual wellbore storage, 35-19 Residue gas. 10-16, 39-16 Resilient-type seal, 3-9 Resin-coated gravel packing. 56-3 Resin derivatives, 19-10 Resistance factor, 47-5 Resistance function, 38-4 Resistance-network model, 44-20 Resistance networks, 4434 Resistance of a process, 13-50

Resistance thermal detector (RTD), 16-7 Resistivity.

annulus region, 49-6, 49-7 apparent, 49-7 devices, requirements for and types. 49-7 formation factor. 49-4 formation, relation to saturation. 49-5 formation waters. 49-4, 49-26 in permeable formations invaded by mud

filtrate. 49-5 to 49-7 index. 49-5. 49-26 invaded zone 49-6. 49-7 logging devices, 49-l 1 to 49-14 mud, 49-4 mud-filtrate, 49-4 mudcake, 49-4 ranges of. 49-5 scales, 49-2 1 true, determination of. 49-27 uncontaminated zone, 49-27 units, 49-2 versus NaCl concentration, 49-3 water,

dependence on salinity and temperature. 49-3

relation to formation resistivity, 49-5 Resistivity index, 26-28, 26-29, 26-3 I, 44-6 Resistivity log, 51-33 Resistivity of a material, definition, 26-28 Resistivity of formation water, 24-14. 24-16 Resistivity of partially water-saturated rocks,

26-3 I, 26-32 Resolution of BHP gauge, 30-2, 30-4, 30-6,

30-7 Response time, subsea valves, 18-49 to

18-51 Responses of normals and laterals in hard

formations, 49-13 Restored pressure measurement, 5 l-31 Restored-state capillary-pressure method,

26-24, 26-25, 284, 28-10 Restored-state technique, 44-5, 44-6 Restoring forces, 18-9. 18-10, 18-16 Retarded acids, 54-8. 54-1 I Retention time for coalescence, 19-9, 19-15.

19-18, 19-22, 19-23 Retort method, 26-2 I Retorting, 27-8 Retrievability, of packers, 4-4, 4-5 Retrievable gas-lift valve, 5-2, 5-34 Retrievable packers,

all latched, 4-3 control-head compression, 4-2 control-head tension. 4-2 hydraulic set, 4-3 isolation, 4-2 mechanically set, 4-3 removal of, 4-5, 4-6 solid-head compression, 4-2 solid-head tension, 4-2 weight-set tension type. 4-4

Retrievable-valve mandrel. 5-2, 5-22 Retrograde-condensate gas. 43-1 Retrograde condensation, 14-l. 23-4, 39-3,

39-8, 39-9, 39-16, 48-7 Retrograde dewpoint pressure, 21-12 Retrograde liquid, 39-7 to 39-10, 39-14,

39-16 Retrograde vaporization, 234 Return-flow equations. jet pump, 6-46 Return-flow fluid gradient, 6-42 Return on investment, 36-1 Return water saltwater, 44-42, 44-43 Revenue-interest fraction (RI). 41-2 Revenue interests, 41-3. 414. 41-9 Reverse ballooning of tubing strings. 4-10 Reverse-circulating gravel pack. 568

6(l PETROLEUM ENGINEERING HANDBOOK

Reverse combustion, 46-2, 46-3, 46-14. 46-3 1

Reverse emulsions. 19-l. 19-2, 19-28 Reverse fault. 29-3 Reverse flow,

check valve, 5-12, 5-23. 537 free-pump cycle, 6-6 installation, 6-6, 6-8 jet-pump casmp type, 6-5 systems. 6-5 to 6-7 tubtng arrangement. 6-7

Reversionary interest, definition. 4 I 1 Reynolds number. 6-36, 6-56. 6-57, 15-l to

15-3, 15-5, 15-24, 17-7, 19-2, 34-2, 34-3. 34-27. 34-38, 34-39

Reynolds-number factor, 13-8, 13-14 to 13-25

Rheological properties, 55-5. 55-6. 55-8 Rheology, 1829, IS-36 Rhombohedral packing of spheres, 26. I.

26-2 . - Rhumba shaker, 52-8 Rice University, 25-20 Rig-selection considerations offshore,

criteria, IS-4 drilling equipment, IS-10 to IS-16 mooring system (stationkeeping), 18-8 to

18-10 motion characteristics, 18-7 performance evaluation, 18-7, 18-E types of rigs, 18-5 to 18-7

Rig types for offshore operations, IS-6 to 18-S

Right to transfer, by landowner, 57-6 by lessee, 57-7

Ring-joint gasket, 3-28 to 3-32 Ring-type plunger, 8-6 Rim-type tester. 5-16, 5-17 _ . Riser analysis,

ball-joint angle. 18-17 mtroduction, 18-16, 18-17 pipe collapse. 18-17 pipe stress, 18-17 sheave friction, I E-17 tensioner-line angle, 18-17 top angle, 18-17 top tension. 18-17

Riser angle, 18-13 Riser pipe, 3-38. 3-39 Riser-pipe collapse, IE- 17 Riser-pipe stress, 18-17 Riser tensioner, 18-11, 18-13 to 18-15 Riser-tensioner systems, 18-17 Riser-top angle, 18-17 Riser-top tensions, 18-4, 18-16 to 18-18 Risk factor. 41-3 RMS efficiency of motor, IO-25 Robinson field, Illinois, 46-15 Robots, 3-36 Rock bulk compressibility. 26-7 Rock compaction, 26-7 Rock composition, 51-5 Rock compressibility, 26-7, 26-9, 37-2,

37-3. 37-6, 37-10 Rock Creek field, Texas, 41-4 Rock-Eva1 11” (RE), 52-10, 52-l 1 Rock flow model, 4420 Rock/fluid interactions, 47-20, 47-21 Rock-frame compressibility, 51-4 Rock-frame incompressibility, 5 l-49 Rock-grain compressrbility, 5 14 Rock matrix, 51-39, 51-49 Rock-matrix compressibility. 26-7 Rock-matrix density, 50-26 Rock mechanics, 55-1 Rock properties, 39-1, 43-7

Rock quality dcstgnatton (RQD), 51-43. 51-44

Rock tortuostty. 26-28 Rock wettability alteration, 44-39, 4440 Rocking a well, 5-54 Rockwell C scale. 9-t Rockwell hardness, 2-2. 2-37 Rocky Mountain area, 24-8. 27-14, 27-15,

28-11, 28-18, 41-1, 47-3 Rocky Mountain method, 49-27, 49-3 I.

49-32 Rod-and-plunger system, 6-10, 6-16 Rod and pump data, 9-6, 9-7 Rod grades, Y-5 Rod-pumped-well control, 16-I 1 Rod pumps. 8-l to 8-4, 8-8 Rod stress, 9-2 Rod string design, 9-5 Rollover fault closures, 29-3 Romania. 46-3, 46-4, 46-15, 46-18, 46-28,

46-29 Rose equation. 28-3 Rosin, 44-45 Rotameter. 13-45, 13-48 Rotary converter. IO-36 Rotary cores. 26-20, 26-21 Rotary floatmg drilling vessel, 18-2 Rotary gas meter. 16-6 Rotary gas separator. 7-5, 7-6 Rotary inducer-centrifuge, ‘7-5 Rotary pumps, 15-15 Rotary-vane positive-displacement meter,

32-l 1 Roughness factors for new pipe, 15-2, 15-3 Round-thread casing and coupling, 2-l. 2-5,

2-7, 2-9, 2-11, 2-13. 2-15. 2-17. 2-19, 2-28, 2-30. 2-57. 2-58. 2-61, 2-64

Round-thread tubing form, 2-64 Rounding rules. 58-5 to 58-7 Royalties. definitton, 41-I Royalty.

acres, 57-7 clause. 57-5. 57-10 deeds, 51-6, 57-7 gas. 57-10 interest, 57-5 to 57-8 oil, 57-5 overriding, 57-5, 57-7 to 57-10

Royalty interests. definition, 41-l to 41-3 Rubber lining coating, II-6 Rubble pile, IS-39 “Rubm,” computer subordinate routine,

17-6 Rugosity . 5 l-33 Rule of capture, 57-1, 57-2 Rules for writing metric auantities. 58-l 1 Rules of thumb,- ’

for critical-flow-pressure ratio. 13-37 for liquid recove-ty, LTS system, 14-5 for regulators. 13-55 for sizing transformers, IO-3 1 for sucker-rod length and cycle strokes.

9-3 of performance htstory required, 37-3 of water-handling equipment, 44-46 of when gas-condensate system exists,

39-2 Run tickets, 17-7 Running, and pulling sucker rods, 9-10

BOP, 1818 to 18-20 20.in. casing. 1 S- 18 30.in. casing, IS-18

Rupture disk, 12-39. 12-40 Ruska universal uermeameter. 26-17 Russell grain-volume method, 26-3, 26-4 RJR, method for water saturation, 49-28 Rylon@. 4-5 Ryton, 7-3

s

S. El Mene field, Veneaula. 24-13 Splat (cumulative logarithmic diagram).

56-6 S-wave critical angle, 5 I-12 S-wave velocity. 51-l 1. 51-37 S-wave velocity ratio vs. porosity, 51-9 S-waves, 51-2, 51-3. 51-5. 51.11, 51.36.

51-44, 51-47 Saccharoidal. 29-8, 29-9 Sacrificial anodes. 1 l-6 SAE 20 lubricating oil, 25-4 Safe nominal interest rate. 41-21. 41-22.

41-24 Safety and pollution preventton equipment

(SPPE) certificate holder, 3-39 Safety controls of engines. IO-17 Safety factor of Goodman diagram, 9-9 Safety factor of motor temperature, IO-26 Safety factors for casing strings,

collapse strength, 2-l to 2-3, 2-32, 2-34. 2-35

internal yteld pressure, 2-l. 2-2, 2-32. 2-34. 2-35

joint strength, 2-l. 2-2, 2-32, 2-34. 2-35 pipe-body yield strength, 2-l. 2-2. 2-34,

2-35 Safety factors, gas lift, 5-3, 5-24, 5-27 Safety factors in continuous-flow gas-lift

installation design. 5-22 Safety factors, manufacturers’, 3-l Safety features for 011 and gas separators.

12-39 Safety head. 12-39, 12-40 Safety relief valves, 12-40 Safety shut-in system. 3- 19 Safety shut-in valves. 16-3, 16-4. 16-I 1 Safety shutdown system. 13-58, 18-43.

1844 Safety systems offshore. 18-47, 18-48 Safety valves, 6-48, 6-49, 18-28. 18-34 Sage and Olds correlation. 2 l-l 1 Salem unit. Illtno~s. 4441 Sales contracts. 40-l Sales gas, 14-6 to 14-8, 14-12. 14-14 Sales-gas line, 14-5, 14-11. 14-15, 14-18.

14120, 14-21 Sales-gas pressure, 14-3 Sales-gas volumes, 39-10 Sales method of oil and gas, 36-2 Salient gradient floods. 47-15 Salinitv:

definition. 47-2 effect on IFT, 47-20 from reuresentative oilfield brines. 47-3 general,* 47- 14 of brine. 19-26, 47-3 to 47-5. 47-10,

47-11, 47-13, 47-21 of ice, 18-39 of injection water, 44-2. 47-22 of oilfield waters, 24-13. 24-20

Salt-bath heater. 14-14. 14-15 Salt content, 19-26, 24-14 Salt deposition in flow string, 33-20, 33-21 Salt domes, 24-7 Salt intrusions, 29-5 Salt plugs, 29-5 to 29-7 Saltwater disposal projects, 24-3 Saltwater sources, 44-41 to 4443 Salty muds, 49-20. 49-25. 49-27 Salvage value. 41-3. 41-11. 41-13 Sample collection and evaluatton. gas-

condensate reservoirs, dewpoint and P/V relations, 39-7 recombination of separator samples, 39-6 simulated pressure depletion. 39-7 to

39-10

SUBJECT INDEX 61

Sample containers. 24-4 Sample. Control and Alarm Network

(SCAN), 46-20 Sample description tabulation. 24-5 Sample lag time. 52-8 Sample logs. 41-8 Sample procedure, oilfield waters,

containers. 24-4. 24-5 field-filtered sample, 24-4 for determining unstable properties or

species. 24-4 for sample containing dissolved gas. 24-3 for sampling at wellhead, 24-3, 24-4 for stable-isotope analysis, 24-4 for tabulation of sample description, 24-5 sampling at flowline. 24-3

Sampling crude oil, 17-l to 17-8 Sampling crude-oil emulsions, 19-6 Sampling natural-gas fluids, 17-7 Sampling of petroleum and petroleum

products. 17-5 Sampling of produced waters,

drillstem test, 24-3 procedure for, 24-3 to 24-5

Sampling of water, 44-43 Samson post, 10-3, 10-4 San Ardo field, California, 46-4, 46-15,

46-18 San Joaquin Valley, California, 46-23 San Miguel-4 tar sand, Texas, 46-26 Sand bridging, gas Ii?, 5-38 Sand-by-sand correlation. 36-7 Sand consolidation treatments. 56-3 to 56-5 Sand control.

an acoustic log use, 51-45, 51-46 clay control, 56-5, 56-6 consequences of sand production, 56-3 formation analysis. 56-3 formation properties. 56-2 formation sampling, 56-3 geology of sand formation, 56-2 gravel packing, 56-8. 56-9 gravel selection, 56-6, 56-7 methods of, 56-3 properties of sand formation. 56-2 screen selection. 56-6. 56-7 well preparation, 56-3 to 56-5 why sand is produced, 56-2, 56-3

Sand counts, 49-22, 49-25 Sand filters, 15-20. 15-21, 16-14 Sand formation propertles and geology, 56-2 Sand-grain volume (GV). 26-3 to 26-5, 26-7 Sand-grain volume, laboratory measurement,

26-3 to 26-5 Sand-jetting and drain systems. 19-20 Sand line, 49-10 Sand model,

for radial flow, 26-13 for rectilinear flow, 26-11 for vertical flow, 26-12

Sand pans, 19-29, 19-30 Sand pressure filters, 4447 Sand production, consequences of, 56-3 Sand removal, 19-29 Sandblasting, 46-2 I Sandface plugging, 39-25 Sandface pressure, 34-28 Sandia Laboratories, 30-7 Sanding. 46-2 I Sandpacks, 26-l 1, 26-12 Sandstone acidizing, 54-4 Sansinena field, California, 6-24 Santa Barbara Channel, California. 18-1,

18-2 Santa Fe Springs field, California. 29-2 SARABAND log analysis, 49-37 Saskatchewan, Canada, 24-8. 24-12. 51-32

Satelhte navigation (SAT NAV) systems, 18-18

Satter’s equation. 46-6 Saturated depletion-type oil reservoirs. 40-8

to 40-12 Saturated liquid. definitmn, 22-21 Saturated-oil viscosity. 22-15 Saturated steam, 46-5. 46-6, 46-40 Saturated systems. oil formation volume

factor for. 22. IO. 22. I1 Saturated systems, oil-viscosity correlations.

Beal’s for dead oil, 22-14 Beggs and Robmson. 22-15. 22-16 Chew and Connally, 22-14, 22-15

Saturated water content of natural gas, 25-I I to 25-15

Saturation change with frontal advance, 38-15

Saturation CUNCS, 23. I, 23-2 Saturation exponent, 26-31 Saturation gradient. 28-3 Saturation measurements, 28-4 to 28-7 Saturation method of determining porosity,

26-6 Saturation pressure, 14-10, 21-11, 21-13 to

21-15, 22-1, 22-5, 22-21 Saturation vapor pressure. 17-7 Saudi Arabia, 12-39 Saunders-type valve bdies, 16-3 Saybolt seconds furol (SSF). 22-13, 22-14 Saybolt seconds universal (SSU), 22-13 Scale or scaling, 5-25. 5-53, 6-48, 6-55,

9-2, 11-13. 19-1, 19-2, 19-26. 19-29, 19-32. 56-l

Scale deposits, 44-43, 56-2 Scale trap. 13-59 Scaled physical models. 45-10 Scaled porous models. 44-17, 44-34 Scales. resistivity, 49-21 Scaling laws. 46-13 Scanning electron micrographs (SEM), 51-8

to 51-l 1 Scanning electron microscope. 46-21 Scannmg-electron-mlcroscope analysis, 56-3 Scattered neutron, 50-9. 50-10 Schilthuis equation, 37-5 Schlumberger. 49-2, 49-36, 49-37, 51-18,

51-21, 51-24, 51-25, 51-41 Schlumberger Borehole Compensated Sonic

log, 51-24 Schlumberger Ltd., 53-19 Schlumberger neutron porosity (SNP), 50-29 Scholem Alechem field, Oklahoma, 6-24 Schoonebeek field, Netherlands, 46-3, 46-14 Scintillation detector, 50- 12, 50-13 Scoring, 6-50 Screen-factor devices, 47-5 Screen selection, 56-7, 56-8 Screen specifications and sizes, 56-9 Screening guides and parameters, 47- 1,

47-22 Screening guides. thermal recovery, 46-13,

46-14 Screening thermal prospects, 46-12 to 46-14 Screenout, 56-8 Screens and filters, jet pumps, 6-48 Scrubbers, 6-33, 12-1, 12-2. 12-10, 12.13,

13-58, 39-26 Scurry field, Texas, 29-4 Sea ice. 18-38, 18-39 Seafloor manifold, 18-33, 18-35 Seal Beach field, California, 6-24 Sealing bores, 6-3. 6-4 Sealing element of packers, 4-5 Search angle, dipmeter, 53-10, 53-11 Seating nipple, 5-3 Seatmg shoe, 6-3

Seawater, 24-17. 24-18, 24-20. 24-2 I Seawater-injection projects. 4437 Second-stage separator gas, 39-9. 39.10.

39-14 Secondary/backup power. 18-45 Secondary drainage, 28-12 Secondary electrical systems, 10-29. 10-30.

lo-32 Secondary functions of oil and gas

separators. maintain liquid seal, 12-S maintain optimum pressure, 12-4

Secondary imbibition. 28-12 Secondary porosity, 26-l. 29-3. 36-6,

51-31. 51-33 Secondary recovery, 16-2. 18-44. 24.2,

24-3, 29-7, 40-4, 41-9. 43-l. 44-45, 45-9

Secondary-recovery methods, 44 I to 44-3 Secondary-seal assembly, 3-6 to 3-8 Secondary separation in separator, 12. I9 Secondary skin-effect correction, 49.16,

49-17 Secondary stratigraphic traps, 29-5 Secondary voltage, lo-29 Section gauge log, 49-25 Securities and Exchange Commission

(SEC), 40-1, 40-2, 41-3 Sediment in crude oil by centrifuge method.

17-5 Sediment in crude oils by extraction

method, 17-5 Sediment in fuel oils by extraction method,

17-5 Sedimentary features. dipmeter patterns in,

53-13 Sedimentary rock porosity, 26-7 Sedimentation flume capacity, 15.18. 15-19 Seeligson field, Texas. 39-3 Segmental orifices. 13-45, 13-48 Segments of circles, table, i-31, l-32 Segments of spheres, table, l-33 Segregation, complete, 37-14, 37-15 Segregation. in gas-injection performance

predictions, 43-16 Seismic analyses, 18-27 Seismic compressional surveys, 5 l-28 Seismic exploration, 5 I-IO Seismic interpretation, 51-28, 51-29 Seismic mapping, 18-18 Seismic studies, 18-5 Seismic velocities, 58-25 Seismograph Service Corp., 5 I-l Seismologists, 57-8 Seisviewer@, 5 l-27 Selecting appropriate PIE ratlo. 6-28 Selecting motor size, IO-2 1 Selecting mud-logging service, 52-28 to

52-30 Selecting pumps and drivers, 15-14 to 15-18 Selection,

of backpressure valves, 3-8 of casing hangers, 3-6 of gas-lift installation and equipment, 5-3 of gas-lift port size, 5-28 of independently screwed wellhead

equipment, 3-39 of intermediate casing heads, 3-7 of lowermost casing heads. 3-2 to 3-5 of materials for wellhead service, 3-36.

3-37 of multiple-completion tubing hangers,

3-16, 3-17 of storage-tank location, 1 I-1 1 of subshrface safety valves, 3-27, 3-29,

3-3 1


of surface closing pressure, gas-lift valves, 5-44

of surface safety valves, 3-27 of tubing hangers, 3-9 of waterflood plants, 44-45

Selection and application of gas scrubbers, 12-35

Selection and applicatton of separators, horizontal, 12-35 spherical, 12-35 vertical, 12-35

Selection data and methods, electric submersible pumps (ESP), 7-9 to 7-12

Selective adsorption systems, 14-10 to 14-13, 14-15, 14-17

Self-contained pressure gauges, 30-l to 30-3 Self-contained thermometers, 31-1, 31-2 Self-generating mud acid (SGMA), 54-4 Self-operated controller, 13-50 Semblance, 51-25 Semiconductor sensor element, 52-7 Semidiesels, 10-15, lo-16 Semilog straight-line solution, 354, 35-8,

35-16 Semipermanent packers, 4-1, 4-3, 4-6 Semiquartzitic sandstone, 26-6 Semisteadv state. 37-2 1, 37-22 Semisubmersible rig, 3-38, 18-2 to 18-7,

18-13, 18-21, 18-25, 18-34 to 18-36 Sensible heat, 14-5, 14-10, 14-21 Sensitivity analysis, 39-17 Sensitivity of t&erial-balance results, 37-13

to 37-17 Sensitivity of regulators, 13-54, 13-5.5 Sensitivity of variable, 13-50 Sensitivity studies, 37-16 to 37-18, 48-14 Sensitivity to shock, BHP gauges, 30-5,

30-7 Sensitivity to vibration, BHP gauges, 30-5

to 30-7 Sensor coils, 53-22, 53-23 Sensor sub. 53-2 Sensors, 3-18, 3-19, 3-31, 3-33, 3-34 Separated fluids, estimated quality of,

crude oils, 12-13 gas. 12-15 gas from scrubber, 12-15 measuring, 12-15, 12-16 water, 12-15

Separating foaming crude oil, 12-6, 12-7 Separation of water from oil, 12-3, 124 Separator, design, 12-21 to 12-32, 23-1 Separator high-level float control, 16-9 Separator pressure, 12-16, 12-17. 12-22,

12-23, 12-25 to 12-34, 12-36 to 12-39, 39-9

Separator temperature, 12-17, 12-22, 12-23, 12-25, 12-26, 12-28 to 12-30, 12-36, 12-37, 12-40, 12-41

Separators: see oil and gas separators Sequence-restart timer, 10-27 Sequential-piloted hydraulic control, subsea,

18-5 I, 18-52 Sequestering agents, 4445, 54-7, 54-9 Service company nomenclature (table), 49-2 Service facilities, 39-24 Service factor, of motor, 10-25, 10-26 Service factor, of steel sucker rods, 94, 9-5 Settled solids removal, 19-29 Settling, in breaking foaming oil, 12-7

in water treating, 44-46 to remove gas from oil in separators,

12-13 Settling space, in emulsion treating, 19-8 Settling tanks, 6-59, 19-18 to 19-21 Settling time, 11-13, 12-3, 19-9, 19-15

Seven-point, hexagonal-gridblock scheme, 48-11

Seven-spot pattern, 43-2, 4413, 4414, 4416, 4417, 44-21, 44-23, 44-34, 46-17, 46-18, 46-26

Severance of minerals, 57-2 Severance tax, 39-27, 41-9, 41-12, 41-15 Shaker screen, 52-8, 52-19 Shale baseline, 49-10 Shale bulk density, 52-19 Shale compaction. 24-20 Shale-data log, 52-20 Shale distillation, yield, 58-29 Shale effect on neutron porosity, 50-31 to

50-33 Shale effects on compressional and shear

velocities, 51-34 Shale factor, 52-21, 52-22 Shale index, 49-38, 49-39 Shale intercalations, 36-6 Shale-outs, 442, 4439 Shale point, 50-24, 50-34 Shale/sand ratio, 36-4 Shale stringers, extent of, 36-6 Shale transit time, 51-39 Shallow dual laterolog (LLS), 49-19 Shallow-hazard surveys, 18-5 Shallow laterolog (LLS), 49-20 Shallow MICROSFL (MSFL), 49-20,

49-22, 49-28 Shaly (dirty) formations, 494 Shaly sand, 26-31, 50-34, 51-34, 51-35 Shannon Pool field. Wyoming, 46-14

Shoestring sands, 29-4, 29-9 Shop-welded tanks, 11-1, 11-5, 11-9 Shoreline sandstone, 36-4 Short or net ton, l-70 Short-cycle units, 14-10, 14-13. 14-17 Short-duration cycling, electric submersible

pump (ESP), 7-15 Short lateral, 49-l 1 Short normal, 49-11, 49-14, 49-26, 49-27,

49-29 to 49-3 1 Short-normal resistivity. 53-2, 53-4 Short-normal resistivitv log. 51-26. 51-46 Short-spaced acoustic logs: 5 1-24 Short-thread casmg, 2-5, 2-7, 2-9, 2-l 1,

2-13, 2-15, 2-17, 2-19. 2-29, 2-57, 2-64 Shoulder-bed corrections, 49-l I, 49-21 Shrinkage,

by liquid recovery, 39-23 definition, 22-21 factors, 22-20, 44-3 of liquid, 32-10, 32-15, 33-14 of oils, 19-7, 37-1, 37-6. 37-22, 37-23.

43-l test, 39-6

Shrouded configuration application, electric submersible pump (ESP), 7-1 to 7-3

Shuttle ball, 13-48 Shuttle tankers, 18-36 SL

derived units. 58-2. 58-4. 58-10. 58-11.

angle unit, 58-5 base quantities and units, 58-3, 58-9.

58-10, 58-21, 58-23 bending moment, 58-5, 58-34

Shaoe factor. 6-57. 26-18. 35-4. 35-5. 35-7. 35-12, 35-16, 37-19, 37-20

Shape functions. 32-5 Sharing arrangements, 41-15 Sharp-edged orifice plates, 13-36, 13-37,

58-2 1, 58-23 energy unit, 58-5, 58-11, 58-23, 58-24.

58-32 international system of units, 58-2 to

58-20 i3-45 Sharp-edged valve seat, 5-14, 5-15, 5-20,

5-35, 5-40 Shear bulk modulus, 58-34 Shear-history method, for friction losses in

fluids, 55-5, 55-6 Shear modulus. 51-1, 51-4, 51-37, 51-43,

51-44. 51-49 Shear rams, 18-15 Shear rate, in fluids, 55-5 Shear rate, in oilfield emulsions, 19-6 Shear-rate/viscosity relations, 474 Shear-thinning fluid, 47-4. 47-9 Shear-wave amplitude, 5 1-46 Shear-wave attenuations, 51-2, 51-6 Shear-wave logging, 51-24 Shear-wave transit (travel) times, 5 1-5,

51-15, 51-24, 51-25 to 51-27, 51-30, 51-31, 51-35. 51-43

Shear-wave velocities, 51-2, 514 to 51-9, 51-12 to 51-14, 51-24, 51-25, 51-28, 51-30, 51-34, 51-35, 51-37, 51-38, 51-43

Shear waves, 51-2, 51-3, 51-12 to 51-14, 51-24, 51-25, 51-27, 51-30, 51-35, 5144

Shearing stress, 22-l. 22-13 Sheave friction, 18-17 Shedding, 13-48 Shelf carbonates, 36-6 Shell breccia, 29-8, 29-9 Shell nroun. 46-13 Shell oil Co., 16-12, 46-4, 46.15, 46-16,

46-18, 46-24, 46-25 Shipper’s ton, l-70 Ships and ship-shaped vessels, 18-5, 18-7,

18-13, 18-21, 18-34, 18-36 Shock load, IO-28 Shock mobility ratio, 47-1

metric system of units, 17-7, 58-l to 58-20

non-S1 metric units. 58-10 prefixes, 58-4. 58-12, 58-13 to 58-20 pressure unit, 58-5, 58-l 1, 58-23 to

58-25, 58-28, 58-29 stress unit, 58-5, 58-11, 58-23, 58-34 supplemental units, 58-2, 58-3 temperature units, 58-5, 58-23, 58-24,

58-28 time units, 58-5, 58-22, 58-23, 58-27 torque units, 58-5. 58-34, 58-38 unit prefixes, 58-3 unit symbols, 58-3, 58-4, 58-15 to 58-20,

58-22 units, 58-9 to 58-11, 58-26 to 58-38 volume units, 58-5, 58-23

Side-pocket mandrel, 3-35. 5-2, 5-53 Side-scan sonar, 18-5 Side-static method of gas metering, 13-37 Side-well producing cuts, 4424, 4425 Sidewall cores, 26-20, 26-21 Sidewall epithermal neutron device, 50-20 Sidewall neutron logs, 51-33 Sidewall neutron porosity, 51-19 Sidewall-pad tool, 49-22 Sidewall vs. conventional core analysis,

comparative data, 27-8 Sidum steam-injection pilot, Arkansas,

46-26 Sieve analysis, 56-3, 56-6, 56-7 Siggins field, Illinois, 47-9 Signal Oil Co., 46-22, 46-23 Significant digits, 58-6, 58-9 Silica, 19-5, 24-4 Silica flour, 46-19 Silica gel beads, 14-21 Silicate-control agents, 54-7

63 SUBJECT INDEX

Silicon-controlled rectifiers @CR’s), 18-45 Silicone, as surface tension reducer, 12-13 Silicone-controlled rectifier relays, 7-6 Silver. 50-12 Silverdale field, Alberta, Canada, 46-18,

46-2 1 Simple harmonic motion, 51-2, 51-3 Simple interest, 41-25 Simpson’s rule, 34-24, 34-26. 40-4, 40-5 Simulated pressure depletion, 39-7 to 39-10 Simulation and simulator studies, 37-2 I,

37-22. 40-l Simulation models, consideration in

applications, fluid- and rock-description data, 48-8,

48-9 history matching, 48-9 model grid selection, 48-7. 48-8 of complex reservoir, 443 1, 4432 type selection. 48-7

Simulation steps, 36-10 Simulation technology, 48-13 to 48-17 Simultaneous formulatmns, 48-14 Sinclair, 47-22 Singapore, 12-39 Smgle-actmg downhole unit. 6-10, 6-20 Singleacting pump, 6-8 to 6-10, 6-18 to

6-20 Single- and two-phase inflow-performance-

relationship (IPR) equation, 34-33, 34-34 Single-carbon-number (SCN) groups, 39-1 I Single-component phase diagrams, 23-1,

23-2 Single-contact miscibility, 48-5 to 48-7 Single-control line valve, 3-27, 3-29 Single-cylinder engines, IO-15 Single-elenlent fuses, IO-28 Single-element simulation, 48-7 Single-element unbalanced gas-lift valve.

5-12 to 5-15 Single-horsepower rating, lo-25 Single-pattern simulation studies, 48-8 Smgle-payment present-worth factor, 41-25 Single-phase flow, 28-2, 34-2, 34-3, 34-31,

34-33, 34-36. 34-38, 3445 Single-phase fluid, constant compressibility,

35-3 Single-phase motors, IO-2 1 Single-phase transformer, 7-6, 7-7, 10-30,

19-25 Single-phase turbulent flow, 34-37 Single-piece jacket, 18-23 Single-point mooring @PM). 18-2. 18-34 Single-ported valves. 13-55, 13-57 Single satellite wells, 18-31, 18-32 Single-real pumps, 6-39 Single-seated valve. 13-55 Single-shot surveys, 53-3 Single-stage desalting, 19-26 Smgle-tubing-string completions, 3-13 Single-welded butt joints, 12-40 Single-well coning studies. 48-14 Single-well depletion reservoir, 35-1 Single-well power umt, 6-60, 6-61 Single-well systems. 6-60 to 6-63 Single-wing well manifold, 16-l I, 16-12 Singleton field, Nebraska, 4440, 47-22 Sinking fund. 41-16, 41-21. 41-22 Sinking fund, table, l-65 Sinusoidal alternating-current field. 19-13 Siphon breaker, 6-62 Siphon strings, 33-21 Site conditions and considerations offshore,

expected environment, 18-4 introduction, 18-3 logisbcs. 18-4. 18-5 seismic and other location studies. 18-5 water depth, 18-4

Site survey offshore, 18-5 Six-pole induction motor, lo-23 Six-spot pattern, 46-17 Sizes,

of casing hanger, 3-6 of casing head, 3-7 of meter and meter run, 13-36 of separator, estimating, 12-21 to 12-2.5 of tubing hanger, 3-9 of tubing heads, 3-8

Sizing and capacities of separators, capacities of spherical separators, 12-30,

12-31 capacity curves for vertical and horizontal

separators, 12-27 to 12-29 computer sizing of separators, 12-25 to

12-27 equation for gas capacity, 12-23 equation for sizing, 12-23 to 12-25 gas velocity, maximum, 12-22 horizontal separator sizing, 12-30 vertical separator sizing, 12-29

Sizing, curves, 13-53 equations for plate coalescers, 15-24 instructions, ultrahigh-slip motor, lo-22 of waterflood plants, 44-45 oil and gas separators, 12-25 to 12-27,

12-32 pumping units, IO-7

Skewness, definition, 26-2 Skim piles, 15-23, 15-26, 15-27, 15-30 Skim tanks and vessels, 15-23, 19-28 Skimming, 19-23 Skin-effect correction, IL, 49-17 Skin effects, 30-10, 30.14, 32-5, 354,

35-7, 35-l 1. 35-14, 35.15,.35-19, 40.27, 49-16

Skin factor. 33-11, 37-20 Skirt piles, 18-3, 18.22, 18-23 Sleeve bearings, 13-48 Slide-rail motor mounts. lo-19 Sliding-sleeve valve, 3-35 Slim-hole coupling, 9-5 Slim-hole-coupling derating factor, 9-5, 9-8 Slim-tube displacement tests, 39- 16 Slim-tube displacements, 48-9 Slip joints, 18-13, 18-20 Slip of motor, 10-23, lo-24 Slip-on socket connection, 3-3 Slip-type tubing hanger, 3-39 Slip velocity, 34-27, 34-38 Slip-weld casing hanger, 3-6 Slipform methods, of gravity platform

construction, 18-23 Slippage effect on energy losses, gas-lift

wells, 34-37 Slippage-loss equation, 8-5 Slippage, past pump plunger, 8-4 to 8-6 Slocum field, Texas, 46-15, 46-18, 46-26,

46-27 Slope of backpressure curve, 33-5 Slope of buildup curve, 30-10, 30-12 Sloping-sided structure, 18-42 Sloss field MP pilot, Nebraska, 47-18 Sloss field. Nebraska, 46-14, 46-15, 46-18,

46-2 I, 46-30, 46-33 Slow-speed engines, IO-14 to lo-19 Slowing-down length. 50-l 1, 50-19 to

50-2 I. 50-29 to 50-32 Slowness time coherence, 51-25 Sludge, 19-11, 19-12, 19-32 Sludge tank, 4447 Sludgmg of oil, IO-13 Slug flow, 34-36 to 34-40 Slug-mtst transitton flow, 34-36, 34-37,

34-40 Slug-stze retention ratio, 47-17

Slugging, 12-23, 12-35, 12-38, 39-26 Slugs of well fluids, 12-l. 12-20, 12-32 Smackover field, Arkansas, 46-15, 46-24 to

46-26 “Smart” end devices. 16-2 Smectite-rich clay, 52-21 Smoke point, 21-7, 21-9 Snap action, control mode, 13-49, 13-51 to

13-53, 13-56 Snell’s law, 51-3, 51-12 Sniffer, 52-6 Soaking, in steam stimulation, 46-9 Soap-type gels, 55-5 Soave modification of Redlich-Kwong

equation, 20-8, 23-13 Sot. of Automotive Engineers (SAE), lo-12 Sot. of Petroleum Engineers (SPE),

joint committee member on reserve definitions, 40-2

SPE letter and computer symbols std., 59-2 to 59-70

SPE metric unit standards, 58-21 to 58-39 SPE papers on relative permeability, 28-12 SPE-preferred metric unit. 58-21, 58-24 to

58-38 SPE Reprint Series, 44-36 Sot. of Professional Well Log Analysts

(SPWLA), 52-30 Soda ash, 14-22 Sodium aluminate sand-consolidation

technique, 46-2 1 Sodium chloride (NaCI), as water

contaminant, 24-16 Sodium chloride conversion chart, 49-3 Sodium dodecyl sulfate, 47-7 Sodium hydroxtde, 4440, 4442, 47-18,

54-3 Sodium iodtde (Nal), detector, 50-12 to

50-16, 50-23, 50-35 Soft-packed plungers, 8-6 Soft-start capability. 7-9 Solid-desiccant dehydratton umt, 14-20,

14-22 Solid-head compresston packer, 4-2, 4-8 Solid-head tension packer, 4-2, 4-8 Solid hydrates, 25-1, 25-3, 25-19 Solid-propellant gas generators, 18-16 Solid-state detector, gamma rays, 50-12,

50-14, 50-23, 50-35 Solid-state electrical detector. 52-7 Solid-state electronic components, 16-9 Solid-state electronics, 16-1 Solid-state switchboards, 7-6 Solids in brine, 14-4 Solids wetting, 19-9, 19-10 Soluble-sulfide analyzer, 52-7 Solubility, definition, 45-1

of bentonite in mud-removal acid, 54-4 of CO, in water, 25-15 of methane in water, 25-16 of natural gas in water, 25-17 of propane in water, 25-17 of silica in mud-removal acid, 54-4 of water in refrigerants, 14-10 of water in various hydrocarbons, 25-16

Solubilization parameter or ratio, 47-13, 47.14, 47-20

Solutes concentration in aqueous phase, 25-16

Solution cavtties, 26-6 Solution gas, definition, 12-3

in oil reservoirs, 40-6, 40-13 increases as temperature decreases, 22-10 release of, 22-2 1

Solution-gas drive, definition, 22-20, 40-8 Solution-gas-drive process. 42-5


Solution-gas-drive reservoirs, basic data required, 37-3 to 37-5 calculation of reservoir pressure, 35-8 comparison of Tarner’s and Tracy’s

methods. 37-10 definitions, 37-l insights from simulator studies, 37-22 introduction, 37-l material-balance calculations using Muskat

and Taylor’s method, 37-10 to 37-13 material-balance calculations using Tracy’s

method. 37-7 to 37-10 material-balance equation, 37-5, 37-6 material-balance equation as a straight

line. 37-6. 37-7 models. types used, 37-2 nomenclature. 37-26, 37-27 nonideal behavior of, 35-3 performances. 37-l) 37-2 production rate and time calculations,

37-17 to 37-21 references, 37-27 sensitivity of material-balance results,

37-13 to 37-17 single empirical IPR equation for, 34-3 I tank-type material balance. basic

assumptions of, 37-2, 37-3 volatile-oil-reservoir performance

predictions, 37-22 to 37-26 Solution-gas production rate, 37-l I Solution GOR, definition, 22-l. 22-21,

37-14 to 37-18, 37-21, 37-22, 40-6, 40-8, 40-9, 40-13, 46-34, 46-36

Solution GOR for saturated oils, Lasater correlation, 22-9 Standing correlation, 22-9 Vasquez and Beggs correlation. 22-9

Solution-mined caverns, 11-13 Solution porosity, 29-8 Solutron techniques for math models. 48-16,

48-17 Solvent breakthrough, 45-7 Solvent extraction, 12-16 Solvent extraction and distillation, 27-8 Solvent-extraction effect. 46-4, 46-5 Solvent override. 48- I2 Solvent slug, 45-2 Sondes, 49-l Sonic fluid-level tests, 40-27 Sonic level control. 16-5 Sonic log and logging, 44-3, 49-15, 49-16,

49-25 to 49-27. 52-20, 52-27, 58-25 Sonic meters, 13-49. 13-50 Sonolog, 32-6 Sonoloy. 30-7 Sour corrosion, 3-36. 4-4 Sour crude. I I-IO Sour-crude tanks, I l-6 Sour gas. 5-2, 10-16, 14-7. 14-21, 18-47 Sour-water strrpper correlations, 25-17,

25-18 Sour-water systems, 25-16 Source of hydrocarbon prospects, 57-8 Source rock, definition. 24-19 South America. 18-7 South Belridge tirellood. California. 46-14,

to 46.16. 46-18 South Oklahoma field, 46-15, 46-16 South Pass 27 field. Louisiana, 36-4 South Sunshine field. Wyoming. 24-18 Southeast Texas field, 47-22 S.P. PacksTM. 19-12, 19-19 Space, Sl units for, 58-26, 58-27 Spacer fluids, 56-4 Spacing, defhution, 49-12 Spacing-factor gradient, 5-45

Spacing factor, mtermutent pressure gradient, 5-42, 5-43

Spacing-load design, 5-48 Spacing pressure differential, 5-29 Spain, 58-20 Sparker, 18-5 Spatial gradient, 48-10 Spatial truncation error, 48-7, 48-9 to 48-12 Special alloy rods, 9-8 Special-service structures, 18-25 Specific conductivity. 39-20 Specific entropy. 58-28 Specific fuel consumption, 58-33 Specific gravities of fluid columns, 6-22,

6-23 Specific gravity (relative density), 204,

20-10 Specific-gravity factor, 13-3, 33-14 Specific gravity, increase with pressure,

saltwater, 24-15 of gas mixtures, 20-4 of natural-gas mixtures, 17-7 of salt soluuons, 24-14 vs. temperature for crude oils, 19-8

Specrfic heat capacity, 58-28 Specific heat ratio. 13-8. 13-13, 14-10,

39-24 Specific heats, of mid-continent liquid oils,

21-6 Specdic-isopermeability map, 39-22 Specnic permeability, 28-l. 28-2, 28-13,

43-3. 43-5 Specific productwity index (PI), 30-l I,

32-4, 58-38 Specific volume, gascondensate system,

21-16, 21-17 of oil. 224. 22-5 of total fluids, 46-7 units and conversions, 58-29 vs. molality. 24-15

Specification of reservoir rock and fluid description data. 48-8

Specifications of coatings, Il.4 Specifications of diesel fuel, IO-16 Spectral fatigue analysis, 18-27, 18-28 Spectral gamma ray device, 50-15, 50-16,

50-24 Spectral gamma ray log, 50-25 Spectrographic technique, qualitative

emission, 24-5 Spectroscopic gamma ray detection, 50-12 Spectroscopic-quality gamma ray detectors,

SO-IS Speculative interest rate. 41-17, 41-21,

41-24 Speculative nominal interest rate, 41-22 Speculative nominal rate of return, 41-18,

41-22, 41-24 Speculative rate of return, 41-21 Speed factor, ultrahigh-slip motor, IO-22 Speed reducer, IO-5 Speed/torque curves. IO-24 Speed variation of engines. 10-14, 10-17,

IO-22 Speed variation of motor, IO-24 Spending time of acids, 54-4. 54-5, 54-8,

54-11 Spent acid, 54-3 to 54-7. 54-9, 54-l I Sperry Sun BHP gauge, 304 Spheres and spheroids. measurement and

calibration. 17-3 Spherical-cell model. 25-8 Spherical separator. 12-I. 12-16 to 12-18,

12-21. 12-30 to 12-32 Spherical-shell equations. 12-38 Spherical three-phase oil/gas/water

separator. 12-5

Spherically focused log (SFL), 49-15, 49.18. 49.20, 49-27

Spiking, 5 l-24 Spindletop dome. Texas, 18. I, 24-7 Splash-proof motor, lo-26 Splash zone, 3-36 Split detector, 53-18, 53-19 Spontaneous ignition 46-2, 46-19. 46-20 Spontaneous potential (SP). 49. I

baseline shift, 49-10 current path, 49-8 curve, 46-26, 49-l I, 49.15, 49.19. 49-25.

49-38, 49-39, 51-16. 51-17, 51-22 to 51-24, 51-32, 51-46

deflections, factors influencing shape and amplitude, 49-9

effect of interstitial shales, 49-8 effect of invasion. 49-8, 49-10 geometric effect. 49-9 in hard formations, 49-10 in soft formations, 49-10 influence of mud resistivrty and hole

diameter, 49-9 origin, 49-7 phenomena in highly resistive formations,

49-10 pseudostatic, 49-9, 49-10, 49-28 to 49-30 R, determination from, 49-8 static. 49-9 to 49. I I, 49-28 to 49-30

Spool adapter flange, 3-9 Spraberry tield, Texas, 40-2 Spray zone, 3-36 Spread-mooring patterns or system, 18-9 Spreader or spreader plate, 6-58, 19-13.

19-18 to 19-20, 19-23 to 19-25, 19-29 Spreader bar, 7-12 Spring compression regulator, 13-54 Spring-loaded gas-lift valves. 5-17, 5-19 to

5-2 11 5-42 Spring-loaded regulator, 13-54, 13-55,

13-57 Spring-loaded valves. 6-49. 6-50. 13-55 to

13-57 Spring-return fail-safe actuators. 18-15 Spudding the well, 18-18 spurt loss, 55-4 Square roots of certain fractions, table, l-13 Square roots of numbers, table, l-2. l-1 I to

I-13 Squares of numbers, table, I-I to l-6 Squeeze cement job, 56-4 Squeeze cementing, 5 I-40 Squeeze gravel packing, 56-8 Squirrel-cage rotor. 7-3 Stability analyses, 48-l Stability of BHP gauges, 30-5 to 30-7 Stabilization of separated fluids, 12-2 I,

12-33, 12-35 Stabilization period of wells. 32. I5 Stabilization process and unit, 12-33. 12-35.

12-42, 14-14, 14-15, 39-27 Stabilized PI, 34-30 to 34-35 Stabilizer, 14-5, 14-7, 14-8, 14-l I, 14.14,

14-15, 14-17, 54-9. 55-6 Stable emulsions, 19-2, 19-4 to 19-6 Stable isotopes, sample for analysis, 26-4 Stage-compression ratio. 39-24 Stage-pressure ratio. 12-33 Stage separation. 12-32 to 12-35. 14-14,

14-15 Stage separator, 12-1, 12-17, 12-19 Staggered line drive. 4413 to 44-16, 44-22.

44-34. 4436 Stainless steel. 30-4. 56-7 Stainless-steel filaments. 12-12 Stainless-steel pipe, 15-l I

SUBJECT INDEX

Standard conditions. definition, 22-21.

58.24, 5X-25

Standard deviation, 50-5

Standard distribution of residuals. table,

I-61

Standard lateral, 49. I 1

Standard of weights and measures.

definitmn of. l-68

Standards for mud logging, 52-30

Standing and Katz charts, 20-9

Standing correlations. 22-5. 22-8 to 22-l I,

22.13. 22-14

Standing valve. 5-50 to 5-53. 6-3. 6-31.

6-32. 6-48. 6-49. 6-51. 19-28 Standing valve puller. 8-2. 8-4

Standing’s equations, 37-21

Star diagram. 24. I9

Starter contactor for motors. 10-2X

Starters for engines. IO-19

Startup of a prqject, 15-3 I

Startup spike. electric submersible pump

(ESP), 7- 14

Startup-spikes chart. ESP. 7- I5

Static-body test pressure, 3-I

Static BHP. calculation of. 34-3 to 34-9

Static drainage-area pressure. 30-9

Static elastic constants, 51-4

Static electricity. I I- 13

Static error, 13-50

Static-fluid level. 5-25. 5-28, 5-37. 5-45.

5-46. 5-48 Static fluids. 34-3

Static-force balance equations. S-17 to 5-19.

5-23 Static geothermal surface temperature, 5-23

Stattc InJectton-gas pressure. 5-37

Static inJection-gas pressure at depth. 5-3 to

5-6 Static-load fluid gradient. 5-23. 5-25. 5-33,

5-48 Static-load fluid gradient traverse. 5-45.

5-46, 5-49 Static-load fluid traverse, 5-25. 5-28. 5-29.

5-33. 5-45 Static prehaure. downstream taps. 13-30 to

13-x

Static pressure from partial buildup, 30-9,

30-10 Static pressure. mean of up-and down

stream taps. 13-33. 13-34

Static pressure. upstream taps, 13-26 to

13-29 Static self potential (SP),

definition. 49-9

determination of. 49-10, 49-28

determination of R,,., 49-10. 49-l I

Static stress. 18-17

Static-type gas separator. 7-4, 7-5

Static voltage level. IO-29

Station-keeping systems. 18-2. 18-S to

18.11. 18-16, 18-21. 18-24, 18-43

Stationary-barrel rod pump, 8-3. 8-4. 8-8,

&IO

Stationary-fluid methods. 28-8

Stationary metering installation, 32-13

Statistical mechanical theory. 25-2

StatistIcal mechanics for adsorption

approach, 25-5

Steady-state analog techmques. 39-2 I

Steady-state conductivity. 4433

Steady-state electrical model, 39-20

Steady-state flow. 32-4, 32-5. 43-3, 43-4

Steady-state in,jectivity, 44-33, 44-34

Steady-state methods of relative-permeability

measurement. 28-3 to 2X-7. 28-14

Steady-state radial flow. 34-31

Steady-state relative-permeability apparatus.

28-4 Steady-xtate relative-permeability methods,

experimental procedure. 28-3, 28-4

saturation measurements. 28-4 to 28-7

Steam-breakthrough times. 48-12

Steam-cheat models. 46-9

Steam displacement. 46-l. 46-23, 46-24

Steam distillation. 46-4. 46-5, 46-15

Steam-distillatmn drive. 46-24

Steam flooding or floods, 19-28. 48-2. 48-5

to 48-8. 48-10. 48-l I. 48-13. 48-17

Steam generation and injection, 46-19

Steam-generation water. 24-5

Steam generators. 46. L9. 46-20

Steam injection. 42-6, 56-2

Steam-injection model. 46-l I. 46-12

Steam-InJection rate. steamfloods. 46-18

Steam/oil ratio (SOR), 46-S. 46-14, 46-15.

46-23. 46-24, 46-27

Steam placement. 46-22

Steam propertles (table), 46-40

Steam quality, 46-5, 46-7. 46-13. 46-18,

46-22 Steam recovery. mechanisms contributing

to, 46-5

Steam splitting. 46-22

Steam stimulation, 46-l. 46-3, 46-4. 46-22

Steam-stimulation operations,

coinjection of gas and steam, 46-22

Huntington Beach. 46-22

ParIs Valley. 46-22. 46-23

Steam/tar ratio. 46-27, 46-28

Steam/water equilibrium. 46-12

Steamdrive, 46. I

Steamtlood, 46-l to 46-4. 46-12 to 46-28

Steamflood front in nine-spot pattern, 48. I2

Steamflood pmjects. 46-23 to 46-28

Steamflooding operations. 25-l

Steaming. 6-48

Steel gravity oil-storage structure. 18-2

Steel gravity structure. 18-2

Steel island. I8- I

Steel jackets, 18-2. 18-26

Steel-laminated elastomers. 18-13

Steel sucker rods.

allowable loading, 9-4

application. 9-2

care and handling. 9-10

coupling connections, 9-2

failures. 9-8. 9-9

manufacture 01; 9-I

predictive calculations, 9-2 to 9-4

rod grades, 9-5, 9-8

rod storage, 9-10

running and pulling, 9-10

service factor, 9-S

unloading and loading, 9-10

Steel template, 18-2

Steelman field, Saskatchewan, Canada,

51-32

Stern travel, 5-15, 5-19. 5-28

Step length, dipmeter. 53-10. 53-l I

Step profile transit time, 51-20

Stepdown transformer. IO-2 I

Stereographic plots, 53-12

Stevens porowneter. 26-4 to 26-6

Stiff diagmm, 24-19

Stiffness analysis. IS-26 to 18-25

Stiles calculation, 44-7. 44-S

Stile5 method. 40-19. 40-20. 44-7

Stimulation coFts. 41-12

Stimulation ratio. 55-4

Stimulation results. fracturing. 55-4. 55-5

Stock-tank gas. 39-9. 39-14

Stock-tank measurement. 32-6. 32-7

Stock-tank oil. definition. 22-21

Stock-tank oil in place per acre-ft. 40-6,

40-8 Stokes’ law, 6-56. 6-57. 12-22. 15-18.

15-21. 15.26. 19.14, 19-15

Stoneley waves. 51-12 to 51-14, 51-2.5.

51-27. 51-47

Stopcock controller, 16-4

Slobcocked wells. 32-15 Storage capacity offshore, 18-7

Storage faciliti&. 6-60

Storage of sucker rods. 9-10, 9-13, 9-14

Storage pressure of products, I I-12

Storage size, evaporation losses. I I 12

Storage-tank types,

bolted-steel, I l-l, I l-3

cone-bottom, I l-2

field-welded. I l-2

fixed-roof. I l-2

flat-sided (non-API), I l-2

floatmg. I l-2

pipe. I l-2. I l-4

welded-steel. I l-l

Storm chokes. 13-57

Straight-hne extrapolation, 40-3 I, 40-32

Straight-line relationship, 39-25

Straightening vanes, 12-22. 12-25. 13-36

Strain-gauge transducers, 30-5. 30-7

Strain-sensitive resistor, 30-7

Strand Ime, 29-4. 29-5. 29-9

Stratification. 36-5, 42-3. 45-7 to 45-10,

45.12. 45-13

Stratification ratio, 39-19

Stratified reservoirs. 44-7. 44-29

Stratigraphy. 44-2

Stratigraphy from dipmeter patterns, 53. IO.

53-12, 53-14

Stratigraphic traps, 29-3 to 29-S. 29-8. 44-2

Streamlines. 44-15. 44-16

Streamtube models, 45-10

Street Ranch field, Texas, 46-26 to 46-2X

Stress analyses. 18.25. 18-27

Stress-concentration effect, 9-8

Stress-concentration factor. 9-5

Stress conversions. 58-7

Stress, in acoustic-wave propagation in

rocks, 51-6. 51-7

Stress, in suspended casing strings, 2-36

Stress-range diagram. 9-I I. 9- I3

Stress ranges recommended for riser pipe,

18-17

Stress relaxation, 2% I3

Stress, Sl unit for, 58-5. 58-l I. 58-23,

58-34 Stress/strain diagram. 5 l-2

Stretch factor, IO-6

Stretch, in casing, 2-35 to 2-37

in tubing. 2-46

Strike of a formation, 53-7

Strike-slip faults. 29-3, 29-9

Stripper hanger, 3-39

Stripper rubber, 3-9

Stripper wells. 8-6

Strongly impliclt procedure (SIP), 48-16

Strontium, 24-9. 24-18. 4444. 44-45

Structural bearings. 10-4. 10-5, IO-12

Structural casing, 18-18. IX-19

Structural closure, 29-l. 29-5, 29-6

Structural con1ours, 39-22

Structural-design process. offshore, environmental criteria

fatigue analysis. 18-2; l*-25

field-development plan. 18-25. 18-26

in-situ analysw. IX-26

transportation and launch. 18-26. 18-27

Structural drawings. 15-31

Structural engineer. 18-Z

Structural-frame analysis. I X-22


Structural maps, 41-8 Structural nose, 29-3, 29-4 Structural pinchouts. 44-39 Structural traps. 29-l to 29-3 Structure *a,, 44-38 Structure map, West Heidelberg field,

46-28. 46-30 Structure. principal factor in gravitational

segregation, 442 Structure selection offshore.

concrete gravity, IS-25 guyed towers, 18-25 template/jackets. IS-25 tension-leg platform, 18-25

Structures, offshore. background and philosophy, 18-22 classification of, 18-22 to 18-24 dcaign process of, 18-25 to IS-27 guyed towers, 18-24 selection of, 18-25 special services. 18.25 r&ion-leg platform. 18-24. I X-25

Strudel scour, 18-43 Studded adapter flange, 3-9 Studded flanged outlets. 3-3 Studded flanges, 3-8 Stymie condition, 5-54 Sub-bottom profiler. 18-5 Subleases, 41-15. 57-7 Subhmation curves. 23-l. 23-2 Submarine cables, 18-44. 18-45 Submarines. 3.38 Submerged Lands Act of 1953. 57-l I Submerged zone, 3-36 Submersible electric motor, 7-l. 7-3. 7-4 Submersible electrically driven pumps,

I l-14 Submersible pumps, 7-l to 7-17. 44-42 Submersible rig. 18-2. 18-S. 18-6 Subordinate phase. 446 Subscript symbols in alphabetical order,

59-63 to 59-70 Subsea applications,

fixed platform drilling. 3-38 floating drilling vessels, 3-39 SPPEiOCS equipment, 3-39

Subsea completion system. IS-3 Subsea drilling system. IS-IO Subsea hydraulic power unit, 18-52 Subsea (seafloor) pipelines, 18-29, 18-30,

18-35, 18-36 Subsea satellite wells, 18-33 Subsea tree, 18-31, 18-32 Subsea valve actuator. 18-50, 18-5 1 Subsea well completions,

control lines, 18-33. 18-34 flowlines, 18-33. 18-34 introduction, I E-30. 18-3 1 manifolds. 18-32 multiple templates. 18-32 single satellite wells. 18-31 well servicing. 18-34 well workovers, 18-34 wset vs. dry, 18-31

Subaea wellhead installation. 6-6. 6-7 Subsea wells. 18-3. 18-14, 18-31. 18-34 to

18-38. I X-48 Subsurface completions. 3-26 Subsurface-controlled subsurface safety

valves (SSCSV’s). 3-29 Subsurface tlowing pressure. calculation,

33-18 SUbSUr~dCC mapping, 40. I Subsurface~pressure surveys. 42-4 Subsurface pressures. calculation, 33-13 Subsurface pump. 9. I, 9-I 3 Subwrfxe-pump bores. X-l Subsurface-pump woke length, Y-12

Subsurface safetv valves (SSSV’s). 3-26. 3-27, 3-31, j-33, 3-34. 6-48

Subsurface saltwater, 44-42 Subsurface shut-m pressure, calculation,

33-19 Subsurface sucker-rod pumps, 8-l to S-10 Subsurface waters, 24-3. 24-19 Successive overrelation (SOR), 48-16 Sucker-rod fxlure, lo-29 Sucker-rod life, IO-17 Sucker Rod Pumping Research Inc., 8.10 Sucker-rod pumps, 6-8, 8-1, 8-10 Sucker-rod string. 8-8, 8-10, 10-1, 10-5,

IO-6 Sucker rods.

allowable stress and range of stress, 9-8 chemical and mechanical properties, 9-4 chemistries of. 9-5 couplings and subcouplings, 9-3, 9-4 fiberglass, 9-10 to 9-14 general dimension. 9-2. 9-3 introduction, 9-I joint circumferential displacement values,

9-10 mcchamcal properties, 9-5 pin failures, 9-9 rcfcrences. 9-14 rod and pump data, 9-6, 9-7 steel. 9-l to 9-10 storage, 9. IO tolerances, 9-3

Suction gradlent, 6-29 Suction pipmg. 15-17 Sukkar and Cornell’s method, 34.9 to 34-24 Sukkar-Cornell integral f[lr BHP calculation,

34-10 to 34-22 Sulfate-reducmg bacteria (SRB), 44-41,

44-43, 4444 Sulfide stress crackmg, 3-35, 3-36 Sulfonates, 19-10, 47-16 Sulfur, 3-3. 10-16. 19-28, 24-16, 46-22 Sulfur dioxide. 14-17. 14-22 Sulfur “il. I l-6 Sulfur/oxide ran”, 52-7 Sulfuric acid, 1 l-6 Summation-of-tluids method, “orositv. 27-1 Sun Oil Co.. 46-15, 46-18. 46-29 to*46-32 Supercompressibility factor, 13-8, 22-20,

~33.13 Supercritical CO*, 45-5 Supercritical-tluid drive, 45-5, 45-6 Superficial velocitv of gas. 34-46 Superheated stea, 46-j Superposition, 35.8, 35.9, 40-12 Suber&“ry control and data acquisition

(SCADA), 16-l. 16-2, 16-6 to 16-10, 16-12

Suplacu de Barcau field, Romania, 46-4, 46-1.5. 46-18. 46-28, 46-29

Surface-active agents, addme to oil. 56-2 in coitrolling stability of emulsions, 19-l in drilling fluids, 445

Surface-active agents in waterflooding. interfacial-tenTinn reduction, 44-40 mohilitv Improvement. 44-39. 4440 rock-&ttab~lity alteration. 44-40

Surface-active chemicals, 24-2 Surface area of crude. evaporation from,

1 I-12 Surface area of fracture. 55-2, 55-X Surface area, specific, 28-8 Surface casing. 3-3 Surface closmg pressure, gas-lift valves,

5-44 to 5-47 Surface control valve. 18-50 Surface-controlled subsurface safety valves

(SCSSV‘s). 3-29. 18-47. 18-48 Surface-driven pumps. 4442

Surface environment, 36-2 Surface equipment, hydraulic pumping,

control manifolds, 6.54 fluid controls, 6-51 lubricators, 6-54 power-fluid systems, 6-54 to 6-57 power-oil tank and accessories, 6-57 to

6-59 pumps, 6-49 to 6-54 single-well systems, 6-60 to 6-63

Surface extractmn efticiency, 52-18 Surface facilities, design and operating

program for, 39-23 for closed power-fluid system, 6-59 for open power-fluid system, 6-58 for saltwater disposal and waterflooding,

15-l to 15-33 formulating policy for. 40-l

Surface-flowline hackpressure, 5-54 Surface-gas gravity td well-fluid gravity

ratio, 21-17 Surface geothermal temperature, 5-48 Surface injection-gas pressure, 5-44 Surface kick-off injection-gas pressure,

5-46, 5-48 Surface-line heat losses, 46-4 Surface opening pressures, gas-lift valve,

5-39 Surface preparation for coatings. I l-5 Surface production equipment, 12-2 Surface production facilities, 36-2 Surface bumping unit, 9-1, 9-3, 9-13 Surface pumps. 6-49 to 6-51 Surface-recording BHP gauges, 30.4. 30.5 Surface safety valves (SSV’s), 3-19 to 3.21,

3-27, 3-31, 3-33. 3-34. 3-39. 18-47. 18-48

Surface seismic shear surveys, 5 I-28 Surface separation equipment, 40-24 Surface steam generators, 46-4, 46-19 Surface tension, 19-14, 22-16, 22-17,

22-19, 22-21, 24-16. 47-8, 54-6 to 54-8, 58-35. 58-38

Surface transfer pumps, 19-28 Surface unloading flowing wellhead

temperature, 5-46. 5-48 Surfactant absorption on metal oxide

surface. 47-15 Surfactant as foaming agent, 55-6 Surfactant breakthrough times, 47-17 Surfactantlbrineioil phase behavior. 47-1 I to

47-13 Surfactant chemistry, 47-7 Surfactantidivalent comolexes. 47-15 Surfactant flooding, 48-j Surfactantipolymer processes, 23.7 Surfactant ietdntion; 47-10, 47-15 to 47-17 Surfactant slug, 48-5 Surfactant systems. 23-8 Surfactants, adsorption of. 47-8

chemistry of. 47-7 classiticatlon of, 47-7 definition of, 54.6 in interfacial-tension reduction, 44-40 in mud removal. 56-l in water blocks and emulsion removal.

56-2 micellaripolymer. 47-7 molecular structures. 47-7 reducing acid reaction rate. 54-8 solutions, 47-11 surface tension of. 47-8 to avoid emulsification. 54-9, 54-10

Surge tank, 24-3, 44-47 Surging, applicability of horizontal

separator, 12-35 in gas-lift installations. 5-I. S-22, 5.24,

5-38 in rod pumps, X-4

SUBJECT INDEX 67

Surging flow. 13-52, 13-53 Suspended solids, 15-18, 19-15, 24-5.

44-36. 44-45 Swab cups or noses, 6-47 Swabbing. 52-17, 52-18 Sweden. 12-39 Sweep after breakthrough. 44-29 Sweep efficiency. 39-18, 46- 14 Sweep efficiency at breakthrough, 4419,

44-20 Sweepout-pattern efficiency, 4423 to 44-25,

44-28 Sweet corrosion, 3-35, 4-4, 4-5, 9-8 Sweet gas, 11-10, 14-21, 14-22 Sweet natural-gas systems method, for

estimatmg initial hydrate formation, 25-5 Sweetening by ethanolamines, 14-2 1, 14-22 Swelling clays, 26-18 Swelling tests. 48-9 Switchboard. electric submersible pump

(ESP), 7-5 to 7-7, 7-12 Switchboard-motor controller. 7-8 Switches for control of oilfield motors,

LO-27 Switching valves, 13-56 Switzerland. 12-39 Symbol subscript definitions in alphabetical

order. 59-52 to 59-62 Symbol subscripts in alphabetical order,

59-63 to 59-70 Symbols in alphabetical order, SPE

standard, 59-2 to 59-17 Symmetrical folds, 29-2 Syngenetic interstitial water. definition.

24-18 Syntactic foam, 1X-15 Synthetic polymers in acidizing, 54-8 System. definition. 22-2 1 Systeme International d’Unit&. 58-2

T

Tadpole plot, 53-10. 53-12 Tadpole symbol or structure, 47-7 Tailgate booster, 7-2 Tailing. 9-10 “Taint,” computer subordinate routme,

17-6 Tandem labyrinth path model, 7-l 1 Tandem pumps, 6-7, 6-8 Tangential method of calculating dtrecttonal

surveys, 53-5. 53-6 Tangible cost. 41-I 1. 41-13 Tangible property, 57-l I Tank battery,

connections, II-9 consolidation. 16-1, 16-2 for hydrogen-sulfide crude storage. I I-10 installation and hookup, 11-Y maintenance and operation, 11-10, 11-l 1

Tank bottoms, 19-32 Tank calibration. 17-3 Tank cars. measurement and calibration,

17-3 Tank corroston protection,

cathodic protection, 11-6 coatings specifications, I l-4 to 11-6

Tank dimensions, 114, 11-5 Tank gauging, 17-3, 174 Tank grades, 11-I 1 Tank pressures. evaporation loss from,

11-12 Tank-type depletion performance, 37-10 Tank-type material balance, 37-2, 37-4,

37-19, 37-21 Tank-type models. 37-2, 37-4, 37-5, 37-l I,

37-14. 37-17 Tanker loading operations, 18-36 Tanker mooring devices. IS-2

Tanker mooring systems. 18-43 Tankers. 18-43 Tankers vs. semtsubmersibles. 18-35, 18-36 Tanks, aboveground. nonrefrigerated,

emergency ventmg capacity, 11-7, I l-8 means of venting, 1 l-8. I l-9 normal ventmg capacity, 1 l-7 venting requirements, determination of,

I l-6 Tanks, measurement and calibration, 17-3 Tapered valve seat. 5- 15 Tar production history, 46-28 Tar sands, 46-3, 46-31 Tar Springs sand reservoir, Illinois, 40-32,

40-33 Tamer method. 37-10. 40-9, 40-10 Tax consequences related to conveyances,

41-15. 41-16 Taxation, 57. I1 Taylor method, 37-10 to 37-13 Taylor series expansions, 48. IO Tectonic stresses, 55-l Teflon@ seal rings, 2-1, 2-38. 4-5 Telemetry. 3-18, 3-27, 18-45. 51-27 Telemetry system, 53-1, 53-2 Tell-tale screen, 56-8 Temperature,

actual, 31-2 to 314 average annual, U.S., 31-3 gradient, effect of cement behind casing,

31-6 ideal curves of flutd migrating through

casing hole, 31-5 in wells, 31-l to 31-7 logs. 31-l mean surface, 31-3 radial differential log, 3 1-7 static bottomhole. 31-6 surveys. 31-l to 31-7, 42-4

Temperature-base factor, 13-3, 13-12 Temperature controls, 12-40 Temperature conversion chart, 58-39 Temperature conversion tolerance

requirements, 58-7 Temperature correction factor (coefficient).

5-6. 5-7, 30-2, 30-3 Temperature data log, 52-23 Temperature dependence of compressional-

and shear-wave velocities. 51-8 Temperature dtstribution.

in annular completion, 46-6 in Marx-Langenheim model, 46-7

Temperature effect of tubmg string, 4-Y. 4-10

Temperature. effect on acid reaction rate. 54-4

effect on BHP gauges, 30-2, 30-3. 30-5 effect on corrosion inhibition, 54-6 effect on confined bellows-charged dome

pressure, 5-6 to 5-8 effect on elastic-wave velocities, 51-7

Temperature gradient. 33-18, 58-28 Temperature log, 46-26, 49-25 Temperature measurement, 16-7 Temperature. method of measuring of

petroleum and petroleum products, 17-5 Temperature of crude, evaporation loss,

11-12 Temperature, of liquid hydrocarbons. 17-5 Temperature profiles. 4-6. 4-7 Temperature ranges, of gas-condensate

reservoirs, 39-2 Temperature rating of insulations, IO-26 Temperature txe of motor. IO-25 Temperature sensors, IO-29 Temperature. SI unit for, 58-5, 58-23,

58-24. 58-28 Temperature transition zone, 52-22 Temperature vs. pressure drop. 14-2

Template/jacket, 18-22. 18-23. IS-25 Ten Section field, California. 34-35 Tendon system, 18-25 Tenneco Oil Co., 46-14, 46-18 Tensile load, 18-22 Tensile strength, 3-3. 9-4. 9-5. 9-8, Y-12,

1 l-9, 18-49. 30-4. 55-l Tensile strength, API casing and liner

casing, 2-2 API tubing, 2-37 line pipe. 2-46 of construction materials. 12-41

Tensiometer, 24-16 Tension-leg platform (TLP). 18-2. 18-3,

18-24, 18-25. 18-44 Tension packer. 4-2. 4-3 Tension tests of round-thread casing jomts.

2-60 Tension-type tubing hanger. 3-16 Tensional forces, 29-2, 29-3 Tensioner-line angle, 18-17 Tensioning unit, 18-13 Tensleep sand reservoir. Wyoming, 40-19 Terminology in conversion and rounding

practices, 58-8, 58-9 Ternary-phase diagrams, 23-4 to 23-6, 23-8,

23-13, 47-l 1 Tertiary oil recovery. 24-2, 24-3 Tertiary polymer floods. 47-6. 47-10 Tertiary recovery, wet combustion, 46-30.

46-33 Test pressures.

extra-strong threaded line pipe, 2-50 extreme-line casing, 2-62 internal-joint tubing, 2-62 plain-end line pipe, 2-50 to 2-53, 2-62 threaded line pipe, 2-47, 2-62. 2-63 wellhead equipment. 3-1, 3-2

Test procedures, gas-condensate reservoir. 39-5

Test-rack closing pressure, 5-6. 5-17, 5-18. 5-20

Test-rack opening pressure, 5-6 to 5-8. 5-16 to 5-18, 5-21, 5-22, 5-29. 5-31 to 5-37, 5-46, 5-47. 5-49 to 5-51

Test separator. 12-17, 32-6 Tester setting temperature, S-46. 5-49 Testing crude oil, 17-I to 17-8 Testing natural gas fluids. 17-7 Tetrabromoethane. 52-20 Tetraethylene glycols (TRG), Id- 18 Texaco, 464. 46-15, 46-18 Texas, 16-12. 16.13. 18-2. 19.15. 21-2,

214, 21-S. 24-3, 24-7, 24-S. 24-10, 24.20, 24-21. 26-7. 29-3. 29-4, 29-7, 29-8, 32-l. 32-2. 33-l. 33-21, 36-l. 36-2, 36-6. 39-3, 39-20 to 39-22. 39-25. 40-19, 40-23, 40-33. 40-34. 41-4, 44-14, 44-36, 4437, 44-40, 44-42. 44-46, 46-3, 46-4, 46-15. 46-18, 46-26 to 46-32. 47-3. 47-7. 47-22. 49-l 1, 49-3 I, 58-20

Texas allowable rule. 32-l Texas gulf coast, 27-6 to 27-8 Texas Railroad Commission. 32-l. 32-2,

32-15, 33-15 Texture of foams. 47-8 Texture of rock, 51-8 to 51-l 1 Thallium, 50. I3 Thaw settlements, 18-41 Theoretical considerations of multiphase

flow, 34-36, 34-37 Theoretical considerations of thermal

recovery, surface-hne heat losses. 46-4 wellbore heat losses, 46-5

Theorettcal models, 51-S Theoretical productivtty index. 32-4

6X PETROLEUM LNGINEERING HANDBOOK

Theories of emulsions. color. 1’1-5 definition of an emulsion, 19-l. 19-2 effect on viscosity of fluids. 19-6 emulsifying agents, 19-3 to 19-5 how emulsions form, 19-2. 19-3 prevention of, 19-5 stability of, 19-5, 19-6

Theory of elastic-wave propagation in rocks. 51.49, 51-50

Theory of elasticity. bulk modulus, 51-l. 51-2 elastic parameters, relationships among.

51-2 Poisson’s ratio. 51-2 shear modulus. 51-I Young’s modulus, 5 Ill

Thermal-absorption cross section, 50-10, 50-22

Thermal ammeter, IO-33 Thermal analysis, 18-41 Thermal breathing, 11-6 Thermal conductance, conversion of units,

table. 1-79 Thermal conductivity, conversion of units,

table. 1~79 detector (TCD). 52-4 to 52-6. 52-l 1 of a gas. 3 l-2 of a material over a depth increment,

52-22 of adjacent formation, 31-7 of cement, 46-b of common sediments, 3 l-4 of geological strata. 3 l-2 of insulating materials. 46-4 of- Kern River oil sands. 46-39 of mineral oils in motors, 7-3 of refrigerants. 14-l 1 overburden, 46-7 units and conversion factors, 58-34 variation with brine saturation, 46-37

Thermal contractum of liquid, 22-2 I Thermal cracking, 46-12, 46-15. 46-16 Thermal detectors, 50-20, 50-21 Thermal-diffusion coefficient. 50-l 1 Thermal diffusivity, 46-5, 46-7. 46-10 Thermal efficiency, 46-8, 46-Y, 46. I4 Thermal energy neutron. 50.11, 50.17.

50-36 Thermal-expansion coefficients, 17-5, 17-6 Thermal-exoansion factor. 13-8 Thermal expansion of hydrocarbon liquids,

22-3, 22-5 Thermal flooding, 40-4 Thermal inbreathing, I l-6. 11-7 Thermal lag, 31-I. 31-2 Thermal model, 484 to 48-7, 48-14 Thermal neutron absorption, 50-4, 50-2 1 Thermal neutron detectors, 50-15 Thermal neutron porosity device, 50-12.

50.20. 50.30, 50-32 Thermal overload relay, IO-29 Thermal packers, 46-19 Thermal porosity device, 50-2 I, 50-28,

50-32 Thermal properties,

chemical kinetics, 46-37 oil viscosities, 46-3 I, 46-34. 46-35 pore-volume compressibility, 46-37 relative-permeability curve, 46-34, 46-37 steam properties, 4640 thermal conductivity, 46-37 vaporization equilibrium. 46-37

Thermal recovery, analytical models for steam injection, 46-7

to 46-l I case histories, 46-22 to 46-3 I current status, 46-3, 46-4 field facilities, 46-19, 46-20

field prolects, 46-13 to 46. I7 general references, 46-45. 46-46 geographical dtstribution of projects. 46-3 historical development. 46-3 in-situ combustion, three forms of, 46-l

to 46-3 mtroductton to. 46-I laboratory experimentation, 46-12, 46-13 monitoring and coring programs, 46-20,

46-2 I nomenclature, 46-40, 46-41 numerical simulation, 46-I I, 46- 12 oil recovery, 46-14. 46-15 operational problems and remedies, 46-2 I,

46-22 proJect design, 46-17 to 46-19 references, 46-43 to 46-45 reservoirs amenable to. 46-3, 46-4 steam injection processes, two forms of,

46-l theoretical considerations, 46-4 to 46-7 thermal properties, 46-3 I to 46-40 well completion, 46-19

Thermal resistance. 58-34 Thermal strength stabilizing agent, 46-19 Thermal stress. 46-19 Thermal trip capabibty of circuit breakers,

IO-28 Thermal venting capacity of tanks, 11-7 Thermalization. SO-22 Thermaiytic Hydrocarbon Analyzer (THA).

52-10, 52-l 1 Thermistor. 16-7, 3 l-2 Thermocouple-amplifier transducers. 46-21 Thermocouples. 16-7, 31-2, 51-5 Thermodynamic equilibrium, 23-12 Thermodynamic temperature, 58-10, 58-23 Thermogenic hydrates, 25-18 Thermometers.

differential, 31-2. 31-5 electrical surface-recording, 31-2. 3 l-5 in gas, 31-2 self-contamed, 3 l-l, 31-Z time response. 3 l-2

Thermometry. l-68, l-69, 31-2 to 31-7 Thermoplastic line pipe. 15-10 Thermoset restns, 9-12 Thermosetting resin line pipe, 15-10 Thermosiphon. 19-2 I Thickening agents, 55-5 Thief hatch, 11-9, II-l], 11-13 Thief sampler, 17-1, 17-2 Thin-bed corrections, induction log, 49-17 Thin-film epoxy system, 15-10 Thu-film strain-gauge transducer, 30-7 Thmnest reservoir, fireflood. 46-29 Thtosulfates, 14-22 “Third for a quarter” transaction, 41-15 l3-spot pattern. 46-17, 47-18, 46-26 Thodos gas-viscosity method, 20-9, 20-15 Thorium. 50-2 to 50-4. 50-15, 50-16, 50.24

to 50-27, 50-34. 50-35 Thread galling, 9-9 Thread limitations, wellhead equipment,

3-1, 3-2 Thread pressure rating for casing, line pipe,

and tubing, 3-3, 3-4 Threaded adapter flange, 3-9, 3-l 1 Threaded flanges, 3-8. 3-17 Threaded line pipe. 246 to 2-49 Threading and’machining dimensions, 2-63,

2-64, 2-67. 2-68 Threading data, API, 2-64 to 2-72 3-D Log’“. 51-18 3D seismic techniques, 36-I) 36.8, 36.9 3D simulator, 36-10 3D velocity log, 51-44 3D vertical mtgration, 36-9 Three-phase autotransformer, 7-6

Three-phase critical point. 25-15 Three-phase tlow. 28-9 Three-phase induction motors. 10.20, 10.31,

IO-35 Three-phase numerical simulators, 46-7 Three-phase relative mobility, 28-9 Three-phase relative permeability, 28-12 Three-phase saturation condittons. 28-B.

28-9 Three-phase saturation trajectory, 28-7 Three-phase separator, 12-4. 12-5. 12.14.

12-15, 12-19. 12-21, 15.21. 16-7. 16-8 Three-phase standard transformer, 7-6 Three-phase transformer. IO-30 Three-phase voltage, IO-23 Three-phase well tester. horizontal skid-

mounted, 12-4, 12-21 with batch-type meters, 32-9 with oil-volume meter and PD meter,

32-8 with PD meters, 32-7

Three-point rule, 41llO Three-stage separation, 12-33, 12-34 Three-tube pump, 8-8, 8-9 Three-way bypass valve. 14-S. 14-6 Three-way engine valves. 6-9 Threshold energy, 50-7, 50-9 Threshold pressure, 28-6 Throat annulus. jet pump, 6-38. 6-40, 641.

6-46 Throat-diffuser loss coefficient, 6-37 Throat of jet pump, b-32, 6-34 to 6-37.

6-39 to 6-42. 6-46. 6-47 Throttling discharge of liquid. 12-42 Through-flowline (TFL) completions, 5-2 Through-flowline (TFL) installations. b-2.

6-6, 6-7. 6-34 Through-flowline (TFL) well servicmg,

18-34 Thrust fault, 29-3 Tia Juana Este field. Venezuela. 46-4.

46-15, 46-18 Tickell diagram, 24-19 Tie lines, 23-5, 23-9, 23-10. 45-5 Tier and rate structure, windfall profit tax,

41-15 Time-average equation. 5 I-30, 5 I-33 to

51-35. 51-50 Time-clock tab, IO-28 Time-cycle control. 5-41 to 5.44, 5-54 Time-cycle controller, 5-38, 5-40, 5-4X,

5-53, 5-55, 14.11. 14-20, 16.3, 164. 16-11

Time-cycle-operated controller, adjustment of. 5-55

Time designation, Sl metric system, 5822 Time lag of a process, 13-52. 13-53 Time-lapse techmque, 50-36 Time of injection operations, 42-2 Time-rate performance, 45. I2 Time, SI units for. 5X-5. 58.22. 58-23.

58-27 Time truncation error, 48-10 Time value of money, 41-3 Title examination, 57-9 Titled polar scan displays. 51-28 Tixier relation, 26-29 Tolerance, definition. 58-9 Tolerances,

of buttress-thread casing coupling, 2-29 of external-upset tubing coupling, 243 of integral-joint tubing upset, 2.45 of line-pipe lengths. 2-47 of nonupset tubing coupling, 2-42 of ring-joint gaskets, 3-28, 3-30, 3-32 of round-thread casing coupling, 2-28 of sucker and pony rods. 9-3, 9-l 1

Toluene, 17-2, 17-5, 24-18, 26-22 Ton as a umt, l-70

SUBJECT INDEX 69

Tool characteristxs. acoustic logging. 5 1-l 5 Tool-face angle, 53-1 Tool for long-spacing acoustic logging.

51-21 to 51-23 Tool span. conventional acoustic logging.

51-16 Tools available for directional surveys,

53-3, 53-4 Tooth efficiency, 52-25 Top-seating holddown. 8-3 Topworka (motor), 13-49 TorIspherical head equations. 12-38 Tornado chart>. 49-28 Torpeda sandstone. 28-10, 46-5 Torque. engine, IO-17 Torque factors, 10-6, IO-7 Torque mode of motors, IO-20 to 10-22,

10-25, 10-31, :O-32 Torque of motor, LO-25 Torque reductions, IO-24 Torque, SI umt for, 58-5, 58-34, 58-38 Torsion. 29-2, 29-9 Torsion modulus, 51-l Torsional waves. 5 1-2 Tortuosity, 26-28, 26-29, 26-31. 2X-6 Total dissolved solids (TDS), 15-29, 24-5.

24-l to 24-13. 24-20, 44-44, 47-2. 47-3 Total dvnamic head (TDH), 7-10 Total (&o-phase) FVF. 6-47. 6-48, 22-l,

22.13. 22.14. 22-20 Total-gas analysis. 52-3

Total

Total-gas analyzer. 52-9

po’rosity. 26-2.

Total-gas detector, 52-5

26-3. Total liauid saturation. 40. IO

26-7 Total solids. M-45

Transmission method, 51-11, 51-12. 51-27 Transmission 011, IO-12 Transmission system, 12-10. 12-l I Transmitter of sonic meter, 13-49 Transport coefficient, 28-l. 28-3 Transport energy, 34-46 Transport equations, 28-13. 28-14 Transport properties. umts and conversions,

Trespass, 57-2

58-34, 5x-35 Transportation and launch offshore, 18-26 Transportation fatigue. 18-27 Transportation systems offshore.

marine terminals, 18-43

Triangular diagram,

pipeline, 18-42. IS-43 tankers, IX-43

23-4.

Transverse captllary imbibition, 28-12

23-5,

Transverse dispersion, 28-12, 45-6

23-8.

Trap, 12-1 Trap classification. 29-l to 29-6 Trapezoidal integration, 34-24 Trapezoidal rule, 33-17, 40-15 Travel time, 51-15 Travel-time measurement. borehole-

compensated (BHC) log, 51-16 Travelmg-barrel rod pump, X-4, 8-10 Traveling valve. 19-28 Travcrae wa*es, 5 l-2 Treating crude-oil emulsiona. 19-6 to 19-15 Treating emulsions produced from EOR

project\. 19-28 Treatment planning. hydraulic fracturing,

55-9 Treatment plant. 39-24 Tree savers, 55-9

collapse resistance, 2-39, 2-41. 2-43 design factors, 2-38 design safety factors, 2-38, 2-39, 2-45.

2-46 dimensions, 2-42, 2-43. 2-45. 2-58, 2-65.

2-66 elongation, 2-37 equation for calculating performance

properties, 2-46, 2-54 to 2-56 external upset, 2-38 to 2-45 gross linear footage from net footage,

2-45 hydrostatic test pressure, 2-62 integral joint, 2-38 to 2-45 internal yield, 2-39. 2-41, 2-43, 2-46 joint strength. 2-61 joint yield strength, 2-39, 2-41, 2-43,

2-46

Tubing/casing annulus, 6-2, 6-4. 6-5. 18-33, 34-27

multiplication factors. 2-45 nonupset coupling, 2-38 to 2-44 performance properties, 2-38 to 2-43 range lengths, 2-37. 2-38 round-thread and form, 2-58, 2-64 round-thread height dnnensions, 2-66 safety factors, 2-38. 2-39, 2-54 to 2-56 selection of weight and grade, 2-39 special joints, 2-38 stretch when freely suspended. 2-46 string of single weight and grade, 2-38 tensile requirements. 2-37. 2-38 thread dimensions, 2-65. 2-66 tolerance, 2-42. 2-43, 2-45 weight, 2-42, 243. 2-45 vIeId strength. 2-37

Total water. definition of. 27-8 23-13. 45-2 to 45-7 Totally enclosed fan cooled (TEFC) motor, Triaxial PV-comprewbility technique, 26-8,

IO-26 26-9 Totally enclosed nonventilated (TENV)

motor, IO-26 Triethylene glycol (TEG). 14-7. 14-18 to

14-20, 25-19 Tow and launch analysis procedure. 18-27 Toxic concentration of refrigerants. 14-10 Toxic decomposition products of

refrieeranta. 14-I 1

Triethylenr-glycoliwater mixtures, 39-5 Triggering, 51-16, 51-17 Trigonometric functions, table, l-50 to 1-54 Trimdad. 36-9, 46-3 Trinle ooint. 23-l. 23-2 Triplex’ pumps. 6-1. 6-30. 6-33, 6-45, 6-46,

Tubing cleanliness. 56-3 Tubing constants. 4-10 Tubing hanger bowl, 3-8, 3-13 Tubing hangers, 3-8. 3-l I. 3-14, 3-16,

3-26. 3-37. 3-39 Tubing-head adapter flange, 3-9, 3-11 Tubing-head bowl. 3-8, 3-9. 3-39 Tubing heads, 3-8, 3-11, 3-14, 3-37, 3-39 Tubing installation, 33-2 I Tubing/packer system,

advantages, 4-6 combination, 4-l I illustration, 4-9 in completion or workover, 4-10 operational well modes. 4-6 to 4-8 where packers are used, 4-6

Tubing performance curve, 34-50 Tubing plug, 3-35 Tubing-profile calipers, 53-17 to 53-19 Tubing pump. 8-I. 8-4 Tubing response characteristics,

ballooning and reverse ballooning. 4-10 buckling effects, 4-10. 4-l I introduction. 4-8. 4-9 piston effect, 4-9 temperature effect, 4-9

Tubing-retrievable subsurface safety valve!,

Toxicity: 52-20 Trace-element absorption factor. 50-34 Tracer studies. IS-2j Tracers. 26-21, 46-21, 52-26 Tracy’s method, 37-7 to 37-10, 37-21 T&Alaska Pitxline Ssstem. 18-3 Transducer assehbly of’sonic meter, 13-49 Transducer criteria, 30-5 Transducers, 30-6. 30-7. 46-21 Transfer pressure line. 5-48 Transformer voltage drop, lo-33 Transformers. 7-6. 7-l 1, IO-29 to IO-3 I,

10-35. 19-3 I Tranwnt backpressure, 44-35 Tramlent period, 30-l I to 30. I3 Tramlent-pressure test, 36-7 Tranwnt &tine. 35. I 1 Tranrlent well&t analysis.

buildup tr\ting, 35-15, 35-16 detern&ation‘of I)~, 35. I6 drawdown test, 35-14, 35-15

Transit time. 51-15 Transit-time integration curves. 51-22 Transit-time log, 51-47, 51-48 Transit-time measurement. 51-14 Transit-time/pressure correlation, 5 l-40 Transition collapse-pre\rure equation, 2-54,

2-55 Transitmn llow (slug-mist), 34-36. 34-37.

34-40 Transition zones, 27-8 Transmonal sediments, 36-3 Transmissibility. 39-19. 48-3, 48-14 to

48-16

6-49 to 6-51. 6-60, 6-61, 15.14, 16-11, 55-9

Tripolite, 51.5, 51-6 Tritium, 46-2 I Tritium ion, 50-6 Trix-Liz field, Texas. 46-18 Troubleshooting electrtcal submersible pump

(ESP). 7-1, 7-14 to 7-17 Troubleshootmg gutde. 6-28. 6-31 to 6-33,

6-47. 6-51 Troy granite, 51-8 to 51-10 Trube correlation, 20-I I. 20-16 Trube method, 22-l I. 22-12 Trucking charges, al-12 True boiling pomt, 21-7 to 2 l-9 True equdibrium state, 25-3 True mass, dctinition of. I-70 True porosity. SO-20, 50-28 to 50-30 True stratigraphic thickness (TST), 53-10,

53-12, 53-15, 53-16 True vapor pressure, I l-12, 14-13 True vertical depth (TVD). 5-4, 5-6. 18-41,

49-37. 53-3. 53.15, 53-16 True vertical thickness (TVT). 53-10,

53-12. 53-15. 53-16 Truncation, 29-4. 29-S. 29-9 Trustee. definition. 57-3 Tube amplitude mtlo. 51-47. 51-43 Tube-type HZ detector. 52-b. 52-7 Tube wave. Sl-12. 51-47. 51-48 Tubmg.

collapse pressure. 2-46

(SSSV’s), 3-27. 3-33 Tubing size vs. constant B. 6-20 Tubing sizes, F, values for, 34-25 Tubing support. electrical submersible pump

(ESP), 7-6 Tubing thread<. wellhead equipment, 3-2 Tubing-to-packer connections, 4-1 Tubular goods sizes. 3-S Tungsten carbide. 6-34 Tunisia, 24-18 Turbidity, 44-44 Turbine expansion systems. 14-8 Turbine meters, 13-45. 13-49, 16-6, 16-7.

16.12. 17-4, 17-7. 32-6. 32-12 Turbine-powered propulcion systems. 18-43 Turbine prime mover, 18-45

PETROLEUM ENGINEERING HANDBOOK 70

Turbo-expander process, 14-X Turbocharged engine. IS-16 Turbopumps, 6-67 Turbulence, 14-2. 14-3 Turbulence and short-circuiting factor,

15-19 Turbulence, energy loss due to, 13-2, 13-3

permanent pressure loss from, 13-2 Turbulent flow regime, 28-13 Turnkey format, 15-32 Two-cycle engines, IO-14 to 10-16, IO-19 Two-dimensional (2D) relief maps, 5 l-28 2- and 3D seismic surveys, comparison,

36-9 2D simulator. 36-10 Two-phase compressibility factor. 39-7.

39-8, 39-10, 39-14 Two-phase flow, 34-33, 34-34, 34-37 Two-phase (total) formation volume factor

(FVF), 647, 648. 22-1, 22-13, 22-14, 22-20

Two-phase separators, 12-9, 12-10, 12-17 to 12-19. 12-21. 12-25

Two-phase vertical-flow model, 7-12 Two-phase waterflooding. 47-l Two-phase well tester.

with positive displacement (PD) meter, 32-8

with volume meters. 32-9 Two-receiver system, acoustic logging.

51-15. 51-16 Two-stage desalting, 19-26, 19-27 Two-stage separation, 12-33, 12-34, 22-7 Type curve, 35-6 Type II(-) phase, 23-8 Types of injection. 424 Typewritmg recommendations, Sl metric

syatcm, 5X-13

U

Ultimate chemical analysis, 21-I. 21-2 Ultimate depletion, 42-2 Ultimate gas recovery, 40-24, 40-34 Ultimate &I recovery, 44-37, 47-20 Ultimate recovery, 30-I I, 36-3, 37-3,

37-21, 37-25, 39-10, 39-13, 39-17, 39-20. 39-23. 39-24. 40-l. 40-2. 40-4. 40-S. 40-11. 40-13, 40-15, 40-16, 40-24, 40-26. 40-32. 40.33. 40-37. 40-39. 41-10. 41-I I. 42-2. 42-6. 44-2 to 444, 447, 4431

Ultimate recovery efficiency. 43-3 Ultimate water requirements. 4441 Ultrahigh-slip motors, IO-19 to 10-24.

10-31. IO-32 Ultrasonic level device. 16-5 Ultrasonic tests. 19-30 Ultrasonic thickness indicators. 12-40 Ultraviolet absorption unit, 12-16 Ultraviolet detectors, 3-34 Ultraviolet light, 52-10, 52-l 1 Ultraviolet photographs, 46-21 Ultraviolet radiation, I l-9 Ultraviolet (UV) sensors, 18-47 Umbilicals in subaea control systems, 18-49 Umbrella effect, 43-7 Unbalanced backpressure regulator, 5-13 Unbalanced gas-lift valves. 5-39 Unbalanced pressure regulator, 5-12 Unbalanced. single-element gas-lift valves,

5-12, 5-14. 5-17. 5-19 to 5-22, 5-41 to 5 -44

Unconformity, 29-5, 29-8. 29-9, 49-25. 53-12

Uncrosslmked gels, 55-5 Underbalance method, 56-5 Underbalanced condition, 52-17 to 52-19 Undercurrent loadmg. 7-15

Underllow slurry, 15-19 Underground storage, 11-13, 1 I-14 Undersaturated carbonate reservoir, 44-36 Undersaturated oil, 37-10 Undersaturated oil reservoirs, 40-7, 40-12 Undersaturated reservoir, 37-5, 37-6, 37-9 Undersaturated system, definition, 22-21 Undersaturated systems, oil FVF for,

Trube method, 22-l I, 22-12 Vasquez and Beggs method, 22-12, 22-13

Undersaturated systems, oil-viscosity correlations, 22-16

Undervoltage relay, IO-28 Underwriters’ Laboratories Inc., IO-27 Undiscounted future net cash flow. 41-5 Unfavorable mobduy ratio, 28-7 Uniboom. 18-5 Union of Soviet Socialist Republics (USSR),

12.39. 21-2 Umon Oil Co.. 46-15. 47-22 Unit displacement, 43-10, 43-l I Unit displacement efficiency, 42-3, 43-3,

43-5: 43-6, 43-8, 43-9 - Unit-of-production basis, 41-16, 41-17,

41-23 Unit of weights and measures, definition of,

l-68 Unit operations, 57-7, 57-8 Unit pressure of fluid columns, 6-22, 6-23 Unit-recovery equation,

depletion recovery factors, 40-10 to 40-12 depletion-type reservoir, 40-8 dry-gas reservoir, 40-25 Muskat‘s method. 40-9 Tamer’s method. 40-9, 40-10 water-drive reservoir, 40-16

Unit-recovery factor, 40.16, 40.18, 40-19, 40-24

Unit recovery for gas reservoir without water drive. 40-24

18-23. 18-25, 18-46, 24-l. 24-2, 24-6, 24-21. 36-2, 39-16, 40-16, 41-12, 44-1, 44-4. 51-l. 52-22, 52-26, 52-30

U.S. areas. core-analysis data from, 27-9 U.S. Beaufort Sea. 18-3 U.S. Bureau of Mines (USBM), l-80, 33-1,

Unit response function. 35-8, 35-9 United Geophysical. 51-I United States (U.S.), l-68 to l-71, 9-8,

12-38, 12-39, 17-4, 18-3, 18-18, 18.20,

Unitization of tank batteries, 32-7 Unitized BOP stack, 18-12 Unitized pressure-energized secondary seal,

3-6 Unitorque geometry, IO-4 Units and names to be avoided, 58-5 Units and systems of weights and measures,

British and U.S. systems, l-69, I-70 relative density and density, l-80 standards of, l-70, I-71 subdivision of umts. I-70 tables of, l-71 to l-80 the metric system, 1-68. l-69 unit and standard definitions, l-68

Universal rails, motor mounts, IO-19 U. of Houston, 50-15 Unloading and loading sucker rods, 9-10 Unloading daily production rate, 5-23 Unloading flowing-pressure traverse, 5-28,

5-32 Unloading flowing-temperature-at-depth

traverse. 5-32 Unloading gas-lift valve, 5-55 Unloadinp gas-lift valve depths, 5-51 Unloading gas-lift valve temperature, 5-46.

5-48 Unloading intermittent-spacing-factor

traverse. 5-45. 5-46 Unloading procedure, gas lift, 5-53 to 5-55 Unloading temperature traverse. 5-46 Unrecoverable oil, 44-11 Unsegregated reservoir, 37-5 Unstable properties, sample for determining,

24-4 Unsteady-state methods of relative-

pernledbihty measurement, 28-3, 28-10, 28-12, 28-14

Upflow filters, 15-20 Upkicking, 6.31 Upset configuration, 9-2 Upstream taps, 13-26 to 13-29, 13-33,

13-34, 13-37

Urethane jacket, 18-49 Utah, 24-8, 24-20, 24-21. 46-16. 46.30.

46-31. 46-33, 46-34

V

Uranium, 24-16, 50-2 to 50-4, 50-15. 50-16, 50-23 to 50-27, 50.34. 50-35

33-3 USBM BHP gauge, 30-I U.S. Bureau of Standards, 21-8 U.S. bushel. l-69, I-70 U.S. Coast Guard jurisdiction, 18-44 U.S. customary umts. 5X-9 U.S. Dept. of Interior, 57-I 1 U.S. DOE, 21-9, 45-l U.S. gallon, 1.69. l-70 Urnted States Geological Survey (USGS),

3-39. 41-9 U.S. Government. 53-5 U.S. gulf coast area. 24-7, 24-8, 24-17 U.S. Metric Board, l-69 U.S. Mineral Management Service, 18-5 U.S. Natural Gas Policy Act of 1978, 57-10 U.S. Navy. 18-4 U.S. oil production by EOR, 46-3 U.S. OCS Orders. 18-46. 18-47 U.S. Prototype Kilogram No. 20. l-69,

I-70 U.S. sieve number, 56-6, 56-7 U.S. survey foot, l-69 U.S. system of weights and measures. l-69,

I-70 U.S. Tax Reduction Act of 1975, 57-i I U.S. Weather Bureau, 31-2 Unitization agreements, 41-9, 57-8 Unitization. definition of, 57-7

V-belt drive, 10-5. lo-12 Vacuum-breaker holes, II - I3 Vacuum deaeration. 15-29 Vacuum distillation, 27-8 Vacuum-line system, 1 I-13 Vacuum models, 46-l 3 VaCUUm relief of storage tanks, 1 l-7 Vacuum units and conversions, 58-29 Validity of simulation results.

model assumptions, 48-9, 48-10 spatial truncation errors, 48-10, 48-12 uncertain reservoir-description data.

48-12. 48-13 Valuation,

analytical methods for computation of appraisal value. 41-3 to 41-R

cash-flow projection preparation, 41-3 check list of data required for evaluation,

41-8, 41-9 fair-market-value determination, 41.2.

41-3 Valuation concepts,

accounting method, 41.16. 41.17. 41-22, 41.23

average annual ROR method. 41-23, 41-24

DCF method, 41-17 to 41-20 Hoskold’s method. 41-16. 41-20 to 41-22

iUBJECT INDEX 71

Morkill’F method, 41-16. 41-22 Valuation methods. equations, 41-17. 41-18 Valuatmn of oil and gas reserves.

concepts of. 41-16 to 41-24 development and operating costs. 41-1 I.

41-12 federal taxes. 41-12 to 41-16 forecast of future production rate. 41-Y to

41-11 general references, 41-37 interest tables and deferment factors,

41-25 to 41-36 nomenclature. 41-36 references, 41-37 types of oil and gas property ownership,

41-I. 41-2 valuation, 41-2 to 41-9

Valve depths, continuous-flow gas-lift installation, 5-32 to 5-35

Valve depths. gas lift, 5-28 Valve mechanics, gas lift,

bellows-assembly load rate. 5-16, 5-17 bellows protection, 5-16 constant closing pressure. S-13 crosswer seat. 5-16 inJection-gas volumetric throughput

profiles, 5-20, 5-21 introduction. S-12 opening and closing pressures, 5-19 pilot and differential opening njection-

pressure-operated valves, S-13. 5-14 port configurations, 5-15 production-pressure factor and valve

spread. 5-19. 5-20 purpoacs of valves, 5-12 specifications and stem travel. 5-14, 5-15 static-force balance equations, 5-17 to

5-19 unbalanced single-element valves. 5-12.

5-13 Valve port area, 5-36 Valve port size, gas lift, 5-44 Valve-spacing transfer production pressures.

5-48 Valve specifications and stem travel, 5-14.

5-15 Valve spread. 5-19 Valve surface closing pressure, 5-47 Valve switches, 16-3 Valve-travel increment. 13-54 Valve types. 16-3. 16-4 Valves at wellhead. 3-11 to 3-13 Valves, gas-lift.

crossover seats, 5-15 for intermittent lift, S-42. 5-43 injection-pressure operated, 5-12 to 5-14 mechanics, 5-12 to 5-21 mtrogen-charged. 5-16. 5-17 pilot-operated. 5-13 port configuration. 5-15 production-pressure-operated, 5-13 purpose of, 5- 12 unbalanced. single-element, 5-12, 5-13 wireline-retrievable, 5-2

van der Waals’ equation. 20-7 to 20-9, 23-12

van der Waals forces, 47-8 Van Everdingen, Timmerman, and

McMahon method. 38-9 to 38-l I Vanadium, 50-23, 50-35 Vane-type compressor, I l- 13 Vane-type mist extractor, 12-S. 12-9. 12-11 Vapor control in storage tanks, I I-12 to

II-14 Vapor equivalent of stock-tank liquid, 39-10 Vapor/liquid equtlibrutm (VLE) constant,

14-16 Vapor/liquid equilibrtum ratio, 39-l I.

39-12. 39-15

Vaporillquid:hydrute formation condmons. 25-13

Vapor losses. II-II. 11-12 Vapor pressure, 6-36, II-I I, I l-12. 19-8.

20-3. 20-11 to 20-13, 20-16, 20-17 Vapor-pressure curves,

for binary mixtures. 23-4 for light hydrocarbons, 23-4

Vapor pressure, empty hydrate, 25-l I of water. 25-15 temperature curves. 14-13 temperature plot, 20-12

Vapor recovery, equipment. 19-32 line valve. 11-I I system. 11-12. II-13 unit. 15-27

Vapor/solid equilibrium constants, 25-7, 25-8

Vapor-solids equilibrium ratio method, 25-5 Vaporization/condensation phenomenon,

46-11 to 46-13 Vaporization (vapor-pressure) curve. 23-l.

23-2 Vaporization equilibrium. of an oil fraction,

46-37 of hydrocarbons. 46-12

Vaporization losses, storage tanks, II-12 Vaporizing ga$ drive, 45-l. 45-2, 45-4,

45-5, 45-13 Vaporizing gas drive simulator, 45-14 Vara as length unit. 58-7, 58-21 Variable-bore rams, 1% I I Variable deck load, 18-7 Variable deck-load capacity, 18-7 Variable Density LogTM (VDL), 51-18,

51-35, 51-41, 51-42, 51-45. 51-46 Variable-density presentation, 5 I-24, 51-25 Variable flowing pressure-gradient method,

5-22 Variable-gradlent design, 5-22 Variable-gradient valve spacing, 5-32 to

5-37 Variable-inductance transducer. 30-6 Variable-reluctance transducer, 30-5 Variable-speed drive, 7-7 to 7-9. 7-12. 7-16 Variables that affect sucker-rod string and

pumping-umt loadIn& IO-5 Variance, 38-9 Vasquez and Beggs correlations, 22-7 to

22-13 Velocity, equivalents (table), l-76

in gas lines, 15-7 in liquid lines, 15-2. 15-5 of propagation. 51-2 porosity correlations, 5 l-34 porosity laboratory data. 5 l-6 ratio. compressional to shear wave, 51-35

to 51-38 Velocity meters.

derivation of an orifice equation, 13-2. 13-3

energy balance. 13-l. 13-2 forms of meter, 13-2

Vena contracta. 13-3 Venango fields. Pennsylvania. 44-4 Venezuela. 6-24. IO-IS, 12-39. 18-l. 19-2.

21-4, 24-6. 24-9, 24-13, 27-9, 27.20, 46-3. 46-4. 46.15. 46.16, 46.18, 58-20

Vent discharge for tanks, I I-Y Venting atmospheric and low-pressure

storage tanks. 1 l-6 to I I-9 Venting capacity of tank<, I I-7 Venting requirements for storage tanks,

II-6 Ventura Avenue field. California, 40-12 Ventura field. Californta, 6-24 Venture capital. 57-8 Venturi plug valves, 3-12 Venturi tube, 13-2

Venturi-tube flowmeter. 32-13 Verscntates’“. 44-45 Vertical communication. 4X-10. 48.12 Vertical conformance, 44-5 Vertical coverage. 44-39 Vertical cylindrical vessel. 15-24 Vertical electric grids. 19-26 Vertical emulsion treater?. 19.7, 19.21 to

19-23 Vertical flow downward, 34.28 Vertical-flow system, 26-12. 26-13 Vertical fractures, 44-25. 44-28, 51-28.

51-46 tn 51-48. 55-2, 55-9 Vertical free-water knockout. 19-17 Vertical hydraulic fracture. 35-4 Vertical multiphase flowing-gradient

correlation, 6-27, 6-28. 6-30. 6-43, 6-45 Vertical multistage pumps, 1 I-14 Vertical permeability, 37-5, 48-8 Vertical recycling separator. 12-14 Vertical reservoir continuity, 36-4 Vertical saturation distribution. 37-4 Vertical scrubber, 12-38 Vertical sections, directlonal-data

presentation, 53-7 Vertical segregation, 37-l Vertical separator, 12-l. 12-7 to 12-9.

12-14, 12-16 to 12-25. 12-27 to 12.30, 12-35, 12-40, 18-28

Vertical-separator sizing, 12-29, 12.30 Vertical settling tank. 19-2 1 Vertical-sided structures. 18-42 Vertical splits of pipe, 53-18, 53-20 Vertical stratification, 39-18 Vertical stresses, 55-l Vertical sweep, 46-14, 46-21. 46.30. 46-3 I Vertical sweep efficiency, 39-17. 39-18.

47-11 47-2 Vertical three-phase oil/gas/water separator.

12-4 Vertical three-phase separator. 19-17 Vertical vessels, 13-53 Vertically fractured reservoirs. 35-4 Vertically fractured reservoirs, shape

factors. 35-5 Vessel-motion terminology. 18-7 Vessel response to motion. 18-X Vibrating crystal (quartz) transducer. 30-6.

30-7 Vibratmg wire transducer, 30-5 to 30.7 Vibration,

dampening, 16-5 fatigue, IS-34 lackmg in jet pumps, 6-34 of casing in high-current drilling, 18-21 problems in instrumentation for gas

measurement, 13-I stresses, 3-1 surface pumps with oil power tluid, 6-55 switch for pumping unit. IO-29 vortex shedding, 18-2 I, 18-22

Vinyl ester, 9-12 Viscosities of gas-condensate (CC) systems,

39-4 Viscosity breaker, 56-8 Viscosity-controlled fluids, 55-4 Viscosity corrections. 6-20 Viscosity correlations. gas. 20-9 Viscosity factor, 20-15. 20-16 Viscosity gradients, 6-69 Viscosity in SI metric system. 58-24, 58-35 Viscosity index. 21-7 Viscosity number, 10-12. IO-13 Viscosity, of brine. 24-16

of dead and live oils, 46-3 I, 46-35. 46-36 of fluids. effect of emulsion on. 19-6 of formation water. 24-16, 24-17 of gas, 20-9, 20-15 of gas-free crude. 6-68. 46-35


of hydrocarbon gas. 15-6

of oil vs. specific gravity. 6-67

of oils. 6-24

of pure compounds, 20-8

of refrigerants. 14-l 1 of sodium chlortde (N&I) solutions.

24-17

of water, 6-24. 6-67

profile. 55-5

ratio vs. pseudoreduced temperature, 20-9

tWtOS. 43-5, 43-6, 45-7. 45-I I

recommendations for gear and chain

reducers, lo-12

relations. polymers. 47-4

temperature relationships. 19-7. 19-S.

46-31, 46-34, 46-35

Vtscous emulsions. 55-8

VISCOUS fingering or fingers, 28-13, 45-7,

45-8, 47-2, 48-13

Viscous forces. 35 Il. 44-3 I, 47-9

Viscous hydrocarbons, metering, 17-4

Visual cell. 39-7

Viton? 4-5

Vocabulary of petroleum measurement

standard. 17-3

Vogel method. for thermal efficiency, 46-9

Vogel‘s Inflow-performance relationship

(IPR). 34-3 1 to 34-35. 37-2 I

Void volume. detinttton of, 27-l

Volanr”. 49-37. 49-38

Volatile-oil reservoir,

comparison of predicted vs. actual

reservoir performance. 37-25. 37-26

material balance. 37-25. 37-26

multicomponent-flash method. 37-23 to

37-26

Muskat-method applicability. 40-9

performance predictions, 37-2, 37-25,

37-26

volumetric methods. 40-13

Volatile solvents, 39-26

Voltage drop for overhead and buried cable,

IO-33

Voltage drop in electrrcal systems, IO-32

Voltage frequency. 10-21. IO-23

Voltage gradient, 19-25

Volume correction factors, 17-5, 17-6

Volume correction to 15T. 17-6

Volume correction to 60°F. 17-5. 17-6

Volume equivalents. table, l-73

Volume-limit switches, 16-13

Volume loss vs. temperature for crude oil,

19-9

Volume meters, 32-8, 32-9. 32-l I

Volume of spheres by hundredths, table,

l-34, I-35

Volume, SI unit for. 58-5, 58-23

Volume tank for engine installations, IO-19

Volumeters, 26-3

Volumetric analysis. 40-I

Volumetric-average boiling point, 2 l-l I,

21-12

Volumetric-average density, 34-27

Volumetric balance, 40-10, 4438

Volumetric behavior.

of a binary mixture, 23-3

of a pure component, 23-2

Volumetric calculations, 37-3

Volumetric efficiency, 6-10, 6-24, 6-25,

6-38, 6-67. 84, 10-9, 43-3, 45-8, 45-9

Volumetric flow rates, 28-3, 34-27

Volumetric gas throughput, 5-3, 5-8 to

5-10, 5-15. 5-16

Volumetric heat capacity, 46-7, 46-10

Volumetric heat-transfer coefficient. 58-35

Volumetric liquid-settling capacity. 12-29

Volumetric material balance. 40-13

Volumetric matertal-balance equation, 48-2

Volumetric metering vessels. 12-6

Volumetrtc meters. 13 I

Volumetric methods.

free gas in gas reservoir of gas cap, 40-5

nonassociated-gas reservoirs, 40-2 1 to

40-X

oil-in-place, 40-S. 4-6

oil m rcscrvotr. 40-S. 40-6 oil reservoirs with gas-cap drive, 40.13,

40-14

oil reservotrs with water drive, 40-15 to

40-20

saturated depletron-type oil reservoirs,

40-S to 40. I2

solution gas in oil reservoir, 40-6, 40-13

undersaturated oil reservoirs, 40-12

volatile-otl reservoirs. 40-13

Volumetric pump efficiency, 40-27

Volumetric rdtto. 55-6

Volumetric recovery esttmates for

nonassociated-gas reservotrs,

compresstbility factor, 40-2 1. 40-22

gas FVF, 40-22, 40-23

gas in place, 40-23, 40-24

permeability distribution effect, 40-24 to

40-26

recovery with water drive, 40-26

untt recovery without water drive, 40-24

Volumetric reserves, 36-7

Volumetric reservon. 36-3, 37-6, 37-10

Volumetric solubility of methane in water.

25-16. 25-17

Volumetric sweep, 46-14, 46-19, 46-30,

46-3 I

Volumetric-sweep efficiency. 39-17. 39-18.

47-1, 47-2, 47-17

Volumetric technique for reserve estimation.

40-I

Volumetric unit recovery, 40-13

Voluntary unit operations. 57-8

Vortex breaker. I l-2, 19-18

Vortex chamber, 12-20, 12-21

Vortex core, 6-62. 6-63

Vortex tinder. 6-62, 6-63. 12-20

Vortex-finder tube. 12-20, 12-2 I

Vortex flow pattern, 13-49

Vortex meter. 16-6. 16-7

Vortex retainer. 12-13

Vortex shedding, 1X-2 1, IS-22

Vortex-shedding meter, 13-48

Vortices. jet pumps, 6-36

Vugs, 26. I. 26-h

Vugular pore openings, 26-2

W

W. Guara field. Venezuela, 24-13

Wabasca tar sand, 46-34

WAG (water-alternating-gas), 45-8, 48-6

Walking beam, IO-2 to IO-4

Wall-resistivity devices, 49-7

Walnut shells, 55-8

Warranty clause, 57-6

Wash-down gravel pack, 56-9

Wash pipe, 56-S

Wash tank, 19-20

Washburn-Bunting porosimeter, 26-4 to

26-6

Washouts, 51-33

Wasson field, Texas, 16-12, 23-10

Waste disposal, 41-9, 41-12

Watch-dog timer, 16-S

Water/air ratio (WAR). 46-2, 46-16, 46-17,

46-19. 46-28. 46-30

Water-alternating-gas (WAG), 45-S. 48-6

Water analyses, 24-18. 24-19

Water-based fluids, 18-49

Water-based fracturing fluids,

foams, 55-6. 55-7

gels, 55-5. 55-6

Water-based muds. 26-2 I, 40.19, 44.5.

53-9

Water block, 56-2

Water breakthrough, 39-16. 44-4. 44-7,

44-9. 44-11, 4412. 44-14, 44-15, 44-34 Water channeling, 31-S

Water compresstbility. 24-12, 24-l 3. 37-3.

37-6. 37-10, 40-7. 40-34

Water coning. 32-3. 48-6. 48-9

Water content,

dewpoint chart, 25-l I, 25 I2

equations, 25-13

equilibrnnn. 25-12

for natural gas in equilibrium with brines.

25-14

tn light-hydrocarbon systems. 25- I6

in vapor phase, effects of molecular

wetght, 25-16

metastable, 25-12. 25-13

of CO,, 25-14, 25-1.5

of CO,-rich tluid phases. 25-15

of effluent oil, 12-13

of gas in equilibrium with hydrates.

25-10, 25-l I

of gases tn vapor/hydrate region, 25-12

of hydrocarbon-rich liquid. 25-10, 25-l 1

of natural gases. 14-4, 25-l I to 25-15

of nitrogen in equilibrium with hydrates.

25-14

of propane liqwd and vapor phase, 25-18

of separated crude 011, 12. I3

of untreated oil, 19-l

of vapor in equilibrium with hydrates,

25-12, 25-13

of vapor m vapor/hydrate region, 25-13 to

25-15

of volume occupted by various gases.

25-14

saturated. of natural gas in equilibrium

with aqueous phase. 25-l I to 25-15

suppression, 25 I3

Water cut, S-12. 6-24. 6-25. 6-27, 6-29.

6-30. 6-36. 6-42. 6-44. 6.47, 6.56,

40-19. 44-7, 44-9. 44-25. 4428, 44-32,

44-39

Water-cut oil, I l-2

Water-cut recovery calculation, 45-10 Water-cut recovery curve. 44-8

Water depth, offshore operattons. 18-4

Water dewpoint of natural gas. 14-4

Water dewpoint temperature, 14-17

Water-discharge control valves, 12-39.

19-29

Water displacement, 28-10

Water disposal, IS-30

Water drive, 36-2. 36-3, 39-15. 39-16,

39-24. 40-6. 40-7. 40-12. 40-14. 40-18.

40-24. 40-34, 44 IO. 44-25

Water-drive behavior. 38-8

Water-drive constant, 40-6

Water-drive equations, 38-12, 38-13, 38-16

Water-drive oil reservoirs.

general references, 38-20

introduction, 38-l

mathematical analysis, 38-l to 38-16

nomenclature, 38-17. 38-18

recovery efficiency of. 40. I6

references, 38-20

shape factor. 35-5

Water-drive sand fields, 40-17

Water-drive unit recovery, 40-16 to 40-18

Water-dump valve, 19.20, 19-30

Water-external microemulsion, 47-l 1

Water films. I l-8

Water formation volume factor, definition.

22-20

Water fractional flow. 44-12, 44-13

Water/gas contact (WGC), 38-l

Water/gas relative permeability, 28-10

SUBJECT INDEX 73

Water gradient. 6-29, 6-44 Water-hammer problems. 15-2 Water/hydrocarbon systems, behavior of,

25-1 to 25-28 Water in crude oil by centrifuge method,

17-5 Water in crude oil by dtstillation method.

17-5 Water in effluent oil. 12-15, 12-16 Water-in-oil detectors, 19-3 I Water-in-oil emulsions, 6-27, 19-l. 19-2.

194. 19-7, 19-10, 19-11. 19-13, 19-28, 4440

Water in propane-rich fluid phases. 25-4 Water influx, 37-1, 37-3, 37-5 to 37-7,

38.2, 38-3. 40-6, 40-7, 40.15, 40.24, 40-26

Water influx rates. 38-2. 38-4 to 38-6, 38-8. 38-10. 38-14. 40-18

Water-injection case htstortes. 44-36. 44-37 Water injection, gas-condensate reservoirs,

39-15, 39-16, 39-18, 39-23. 39-24 Water-injection gradient, 3 l-5 Water-injection oil-recovery performance,

areal sweep and pattern efficiency. 44-12 to 4425

displacement calculation procedures, 44-7 to 4412

reservoir fractures, effect of, 44-25, 4426 waterflood performance-method selection,

44.31_ 44-32 waterflood performance-prediction

methods, 44-26 to 44-3 1 Water-injection pressure maintenance,

case histories, 4436. 4437 factors in, 44-2 to 44-5 mtroduction, 44 I nomenclature, 44-41. 44-48 oil-recovery performance predictions, 44-7

to 4432 pilot floods, 4437 to 44-39 references. 4449 to 4452 residual oil determination, 44-5 to 44-7 selection and sizing of waterflood plants,

44-45 to 44-47 surface-active agents in, 44-39 to 4443 water treatmg, 4443 to 4445 well behavior, 4432 to 4436

Water-injection rate, 44-32, 4441 Waterinjection requuements, 18-44 Water-injection operations, 42-5, 42-6, 43-l Water-injection systems, 6-l Water-injection well behavior. 44-32 to

44-36 Water jets or jetting, 19-29, 19-30 Water knockout, 12-1, 12-2 Water legs, 19-20 Water manometer. 13-37 Water of crystallization, 26-21 Water/oil contact (WOC), 38-1, 38-5, 38-9.

404, 40-5. 40-15, 40-34 Water/oil mobility ratio. 447. 44-8, 47-6 Water/oil ratio (WOR). 19-27. 24-20. 28-5,

34-41, 40-18 to 40-20. 44-7, 44-9. 441 I, 44-3 I, 44-32. 4439, 46-33

Water/oil viscosity ratio, 40-18, 44-10 Water permeability, 47-8 Water power fluid, 6-27, 6-29, 6-44, 6-55,

6-56, 6-60, 6-62, 6-63 Water-pressure function, 37-8. 37-10 Water-producing intervals, location of, 31-4,

31-6 Water relative permeability, 28-6, 28 IO.

28.13, 40-18, 40-26, 44-12, 44-40. 46-37, 4638

Water resistivity, 26-3 1 Water retention time, 12-15 Water salinity, 24-3. 24-17, 24-18. 26-18.

26-19, 44-40, 50-3. 50-36

Wateri\and discharge, IY-30 Water-saturation data, 399 Water saturation, determining. 26-22 Water-saturation distributions, 44-l 1 Water saturatton from caplliary-pressure

data, 26-25 Water-saturation profile. 44. I I Water sheds. 35-16 Water slugs. 14-21 Water source. 44-41 to 4443 Water specific gravity, 6-67 Water-supply wells. 16-14 Water surge tanks. 44-47 Water table, 44-41 Water-temperature bypass control, 13-59 Water treating.

dissolved gas, 44-43 microbiological growth, 44-44 minerals, 44-44 sampling. 44-43

Water treatment for steam generation, 46-20 Water-treatment plant. 16-14 Water types,

condensate water. 24-18 connate water. 24. I8 dtagenetic water. 24-18 formation water, 24-18 Interstitial water, 24-18 Juvende water, 24-18 meteoric water, 25-18 seawater. 24-18

Water underrun. 48-12 Water-vapor content, 14-3 Water-vapor removal, 14-17 to 14-21 Water viscosity, 44-6, 44-32, 44-33 Water/volatile-gas systems, 25-24 to 25-27 Water wash or washing, 19-7, 19-13,

19-15. 19-18 to 19-22, 19-27 Water-weight factors. 2-I. 2-33, 2-38 Water-wet, 19-9. 44-6 Water-wetting agent, 56-5 Watered-out, 39-15 Waterflood applications. 3-37 Waterflood displacement performance,

44-13 Waterflood oil-recovery predictions, 446 Waterflood performance-prediction methods,

4426 to 44.31 Waterflood plant facilities. 44-47 Waterflood plants, selection and sizing,

4445 to 4441 Waterflood prediction methods, table, 44-29

selection of, 44-31 Waterflood processes,

case histories, 4436. 44-37 factors in, 442 to 44-5 introduction. 44-l nomenclature, 44-47. 4448 oil-recovery performance predictions, 447

to 4432 pilot floods, 4437 to 44-39 references, 44-49 to 44-52 restdual oil determinatton, 44-5 to 447 selection and sizing of waterflood plants,

44-45 to 44-47 surfaceactive agents in, 4439 to 44-43 water treating, 4443 to 4445 well behavior, 4432 to 44-36

Waterflood recovery process, 28-8 Waterflood requnements.

daily water-injection rates, 44-4 I fresh waters, 44-41. 44-42 makeup water. 44-4 1 salt waters, 44-42. 44-43 ultimate water. 44-4 1 water sources, 4441

Waterflood susceptibility data, 45-8 Waterflood sweep eflicienctes, 4439

Waterflooding. an imbtbmon process. 28-14 complete. 40-16 factor in, 44-2 to 44-5 history and development, 44-I inJection wells. 34-28 of dissolved-gas reservoirs, 25-19 reservoir simulatton of, 48-4. 48-7,

48-10, 48-13 tests, 44-8 volume of produced water, 24-2

Waterfloods. in chemical tloodmg. 47-9. 47. IO. 47-2 I

Waterfrac services. 55-5 Waters produced from.

Appalachian area, 24-6. 24-7 California fields, 24-8 Canadian fields, 24. I2 gulf coast fields, 24-8 Illinois fields, 24-9 mid-comment fields. 24-9. 24-10 Rocky Mountain fields, 24-l I Venezuela fields, 24-13

Wave baffle, 19-17. 19-18 Wave equation. 9-3 Wave forces. IX-24 Wave propagation, 51-2. 51-3. 51-12, 51-46 Wave scatter diagrams. 18-26, 18-27 Waves in Arctic. IS-39 Waxes, 39. I Waxing, 6-56 Waxy-based hydrocarbon liquids or heavy

ends. 14-6. 14-7 Waxy distillates. 14-5 Weather-related downtime, 18-8 Weight, definition of, l-70 Weight-loaded regulator, 13-54, 13-55 Weight-loss corrosion, 3-36 Wetght of a body, 58-3 Weight on btt (WOB), 18-13, 18.14, 53-1,

53-2. 53-4 Weighted-average deferment factor, 41-21 1

41-23, 41-24 Wetghted loaded valves, 13-55 Wetghts and measures. definition of, 1-68

of buttress-thread casing coupling, 2-29 of concentrations of HCI, 54-2 of external-upset tubing coupling. 2-43 of extra-strong threaded line pipe, 2-50 of integral-joint tubing upset. 2-45 of nonupset tubing coupling, 2-42 of plain-end line pipe, 2-50 to 2-53 of round-thread casing coupling, 2-28 of threaded line pipe. 2-47

Weir or weir box, 19.19, 19.20, 19.23 Weir-tank-type LACT system, I6- I3 Welch field, Texas, 44-30 Weld-neck lme-pipe flange. 3-17, 3-19.

3-23, 3-24 Welded-steel tanks, 1 I-I, 1 l-2, 1 l-9, I l-l I Welded-type seal. 3-9 Welding slag, 5-53 Welex, 49-2. 49-36, 49-37. 51-18 Welge calculations, 44-I I , 44.12 Well completions, consideration in pilot

waterflooding, 44-39 offshore, 18-28 steam and firefloods. 46-19. 46-20

Well conditioning. gas-condensate reservoir, 39-5

Well costs and spacing, 39-l Well delwerability. 5-12. 39-l Well-effluent composition. 2 I 16 Well fluids and their characteristics,

condensate. 12-3 crude oil, 12-3 impurities and extraneous materials 12-3 natural gas. 12-3 physical and chemical. 12-21 water, 12-3


Well injectivity. 39-5, 39-6, 39-23 to 39-26, Wellhead choke, 34-45 Wireline-retrievable subsurface safety valves 46-17 Wellhead control valve, 6-51, 6-59 (SSSV’s), 3-27, 3-33, 6-48, 6-49

Well kick, 18-11 Wellhead corroston aspects, 3-35 Wireline tensile strengths. 30-4 Well killing, 39-25 Wellhead corrosion protection methods, Wireline unit, 18-28 Well-log analysis, 37-3 3-36 Wireline well servicing, 18-34 Well logging, letter and computer symbols, Wellhead equipment and Bow-control Wiring methods offshore, IS-46

59-2 to 59-51 devices, Woodsen Shallow field, Texas, 44-4 Well logs, API flanged or clamped types, 3-1 to 3-18 Woodson field, Texas, 46-3

caliner. 53-l corrosion. 3-35. 3-36 Work eauivalents. table. 1-77 casing collar-locator, 53-26 general references, 3-40 Work, init in SI metric’system, 58-23, casing inspection, 53-1 independent screwed wellhead, 3-39 58-24, 58-32 dinrn~ter. ‘53- 1 introduction. 3-l Working barrel. lo- 1 diiectional surveys, 53-1 other control devices, 3-34, 3-35 Working fluid level, 5-5 I in interpretation of paleoenvironments, references, 3-40 Working interest, 41-1 to 41-4, 41-9, 41-13.

36-3 safety shut-in systems, 3-18 to 3-34 41-15, 41-35, 57-5, 57-7, 57-9, 57-10 measurement while drilling (MWD), 53-1 special application, 3-36 to 3-39 Working-interest fraction (WI), 4 1-2

to 53-3 Wellhead sampling, 24-3, 24-4 Working pressure, wellhead equipment, 3-I references, 53-26 Wellhead support, electrical submersible to 3-5, 3-7, 3-8, 3-12 to 3-25, 3-27.

Well-pattern geometry, 39-1 pump (ESP), 7-6 3-38 Well-performance equations, Well’s inflow performance, 7-8 to 7-10, Workover fluld, 5-2

diffusivitv. 35-I. 35-2 7-12 Workover-fluid invasion. 54. I 1 gas well,‘%9 to 35-14 multiphase flow, 35-2 nomenclature, 35-20 oil well, 35-2 to 35-9 references, 35-21 transient well-test analysis, 35-14 to 35-20

Well preparation for sand control. cement bond, 56-4 cleanliness. 56-3. 56-4 uerforation cleanine. 56-5 perforations. 56-4,“56-5

Well-pressure performance, closed reservoir. 35-2

Well productivity, 39-5, 39-6, 39-13, 39-23 to 39-26. 46.17. 46-21. 56-3. 564

Well re-entry workbver, 18-33 Well servicing, 18-28, 18-29, 18-34 Well spacing,-39-13, 41-11 Well stimulation, 7-16, 56-1 Well-test control logic, 16-12 Well tester, 32-7 to 32-10 Well testing, 39-24, 39-25 Well-testing procedures, 32-15 Well tests and sampling gas-condensate

(CC) reservoirs, field sampling and test procedures, 39-5,

39-6 well conditioning, 39-5

Well-workover equipment, 18-28 Well workovers, 18-28, 18-29, 18-34, 4439 Wellbore cleanup by acidizing, 54-8 Wellbore deviation. 56-3 Wellbore fluid expansion, 35-6 Wellbore heat losses,

calculations including pressure changes, 46-6, 46-7

hot water, 46-6 model treating, 46-7 overall heat-transfer coefficient. 46-6 recent developments, 46-l saturated steam, 46-5, 46-6 superheated steam, 46-5

Wellbore hydraulics, flow through chokes, 3445 to 34-49 injection wells, 34-28 to 34-30 liquid loading in wells, 34-46, 34-50 metric conversion for key equations,

34-51 to 34-55 multinhase flow. 34-35 to 34-45 nome;lclature. 34-50, 34-51 oil wells, inflow performance, 34-30 to

34-35 producing gas wells, 34-3 to 34-28 references, 34-55, 34-56 theoretical basis, 34-1 to 34-3

Wellbore problems, 34-3 Wellbore-storage effect, 30-14, 35-4, 35-6,

35-7. 35-12. 35-15 Wellbore variables, influence on focused

electrode logs, 49-21, 49-22 Wellhead assembly, 3-2, 3-3

Wells required, gas-condensate (CC) reservoirs, 39-26

Wellsite data-acquisition system, 5 1-25 Wellsite log analysis, in real time, 49-36

in replay time, 49-37, 49-38 West Edmond field, 40-2 West Heidelberg field, Mississippi, 46-28,

46-30 West Newport field, California, 46-16,

46-18 West Panhandle field, Texas, 34-46 West Texas area, 27-16, 27-17 West Virginia, 21-2, 24-6, 24-7 Wet combustion, 46-2, 46-3. 46-14, 46-17

to 46-19. 46-22, 46-30, 4633 reverse, 46-3 1

Wet gas, 5-2, 10-16, 39-1, 39-10, 39-11. 39-13, 39-18 to 39-20, 39-23, 39-24

Wet vs. dry subsea completions, 18-31 Wettability, 28-10 to 28-13, 44-5, 446,

4.427, 4439 Wettability reversal, 47-19 Wetting aeents. 42-2 Wetting it&iscible fluids, 28-3, 28-5, 28-6 Wetting phase, 47-9 Wetting -phase relative pernreability, 28-12 Wetting-phase saturation, 26-27, 28-6 Weyburn field, Saskatchewan, Canada,

51-32 Weymouth equation, 15-7 to 15-9 Wheatstone bridge circuit, 52-3 Whittier field, California, 44-40, 47-21,

47-22 Whole-core analysis, 27-1, 27-8 Whole-core measurement of permeability,

26-17, 26-18 Whole cores, 26-2, 26-7 Wichert and Aziz’s chart, 20-15 Wilmington field, California, 6-24, 44-39 Windfall Profits Tax (WPT), 41-1, 41-4,

41-12, 41-15 Winding-insulation materials, lo-26 Winkleman Dome field, Wyoming, 46-15,

46-18 Winsor microemulsion systems, 47-12 Wire-mesh filters, 39-26 Wire rope guidelines, 18-14 Wire-wrapped screens, 56-7. 56-8 Wireline cores, 26-2 Wireline equipment, 49-1 Wireline formation tester. 49-l Wireline logging, 50-I Wireline logging operations (schematic),

49-2 Wireline lubricator, 18-34 Wireline operations, 6-2, 6-48 Wireline-retrievable gas-lift equipment, 5-2,

5-16, 5-26, 5-50, 5-53 Wireline-retrievable standing valve, 6-3,

6-48

Workover operations, 8-8, 30-8, 39-24 to 39-26, 56-4

Workover rigs, 56-3 Wormhole effect in acidiztng, 54-8, 54-10 Woven wire mesh. 19-14 Wrap-around tubing hanger, 3-8 Wye-delta transformer, IO-30 Wye-wye transformer, IO-30 Wyllie time-average equation, 5 1-29 Wvllie’s eauation. 26-20 Wyoming. ‘21-4, 23-7, 24-8, 24-11, 24-18,

24-20, 39-16, 40.19, 40-23, 44-42. 46-3, 46-14, 46-15, 46-18

X-plot wellsite analysis, 49-37 X-ray absorbers, 28-4 X-ray crystallography, 25-5 X-ray diffraction, 25-6, 5 1-5 X-ray-diffraction analysts, 54-9, 56-3 X-ray shadowgraph, 44-17, 4419 to 44-2 I,

4425, 4434 X-Y recording mode, 51-18 Xanthan gum, 47-3

Y

Y method, adjustment procedure for material-balance equation, 40-6

Yardsticks, 32-l. 32-3, 42-6 Yates field, Texas, 40-2 Year-end compound-interest factors, 41-20

to 41-22 Yield wint. 58-34 Yield-point collapse pressure, 2-54 Yield point of construction materials, 1241 Yield strength, collapse-pressure equation,

2-54 of API body and bonnet members, 3-3 of API casing and liner casing, 2-2 of API tubing, 2-37, 2-61 of elastic material, 58-2 of line nine. 2-46. 2-56. 2-63 of pipebbdy, 2-2, 2-4, 2-6, 2-8, 2-10,

2-12, 2-14, 2-16, 2-18, 2-32 of pipe material, 18-17 of sucker rods, 9-5

Yorba Linda field. California. 46-3. 46-18 Young’s modulus of elasticity’, 2-35, 5 I- I,

51-43, 51.44, 58-34

Z

Zeolite ion exchange, 46-20 Zeros, importance of, 58-6 Zinc acetate, 44-42

Subject

Documents

acoustic logging

acoustic beacons

acoustic energy

acoustic intensity

acoustic telemetry

acoustic impedance

acoustic waves

acoustic waveform