Page 149 - Hybrid Enhanced Oil Recovery Using Smart Waterflooding

Index

A Coarse grid model, 44 DLVO theory. See Derjaguin-Landau-
Acid/base number (AN/BN), 8e9 CO 2 enhanced oil recovery (EOR) Verwey-Overbeek (DLVO) theory
Alkaline-surfactant-polymer flood, captive bubble method, 118e119 Dynamic contact angle measurement,
104e107 carbonated water injection (CWI), 119e121
Anion-exchange sites, 34 125e127
Aqueous reactions, 41 condensing/vaporizing mechanisms, E
112 Electrical double layer (EDL), 5e7
B conventional waterflood, 119 Electrical double layer expansion, 30
B-dot model, 41 coreflooding, 117 Equilibrium constant, 40
Berea sandstone core, 133 CO 2 water-alternating gas (CO 2 Exothermic reactions, 129
Bond product sum (BPS), 52e54 WAG) process, 113, 116f Expensive zwitterionic surfactants,
BPS. See Bond product sum (BPS) dynamic contact angle measurement, 87e88
Brunauer- Emmett-Teller (BET), 78 119e121
Buckley-Leverett two-phase flow, experiments, 113e121 F
44e45 first-contact miscibility, 111e112 Field-scaled modeling, 59e61
fluctuating pressure drop, 119 Fine grid model, 44
C liquefied petroleum gas (LPG), 113 Fines migration, 27, 28f
Capillary desaturation curve (CDC), low salinityeaugmented CWI Freshwater injection, 1e2
49 (LS-CWI), 125
Capital expenditures (CAPEX), microemulsion test, 125e126 G
69e70 minimum miscible pressure, 111 Gas chromatography (GC), 76
Captive bubble method, 118e119 miscible/immiscible processes, Geochemistry
Carbonated water injection (CWI), 111e112 aqueous reactions, 41
125e127 MMP, 114e115 basic reactions, 41e43
Carbonate reservoirs multiple-contact miscibility, 112 aqueous solutions, 41
mechanisms, 31e36 multiple mixing cell (MMC), 117 cation exchange capacity (CEC), 42
anion-exchange sites, 34 numerical simulations, 121e125 ion exchange, 42e43
cation-exchange sites, 34 oil recovery and pressure drop, mineral reactions, 41e42
conditions, 36 122f surface complexations, 43
crude oil/brine/rock (COBR) rising bubble apparatus (RBA), 117 B-dot model, 41
adhesion energy, 33e36, 34f seawater brine, 118e119 empirical modeling without, 43e44
Derjaguin-Landau-Verwey- simultaneous water and CO2 gas Buckley-Leverett solution, 44
Overbeek (DLVO) theory, injection (SWAG), 124e125, 124f salinity-dependent relative
34e35 solubility, 112 permeability, 44
mineral dissolution, 32, 33f effect of salinity, 113 salinity-dependent residual oil
negatively charged organic solvent phase behavior, 112 saturation, 43e44
components, 31e32 tertiary recovery factor, 113e114 wettability modification modeling,
organic carboxylic materials, 32 CO 2 water-alternating gas (CO 2 43e44
potential-determining ions, WAG) process, 113, 116f equilibrium thermodynamics, 39e41
31e32 Critical micelle concentration (CMC), acitivity, 40e41
surface charge, 32e33 88e89 Debye-Hückel theory, 40e41
wettability modification, 31e32, Crude oil/brine/rock (COBR) system, equilibrium constant, 40
32f 2e3, 33e36, 34f field-scaled modeling, 59e61
Carbonate rocks, 1e8, 22 SWCTT test, 61
Carboxylic group, 55e56 D Gibbs free energy, 39e40
Cation exchange capacity (CEC), 42 Debye-Hückel theory, 40e41 mechanistic modeling, 44e59, 45f
Cation-exchange sites, 34 Degree of oil sorption, 33 bond product sum (BPS), 52e54
Cationic surfactant, 97e98 Derjaguin-Landau-Verwey-Overbeek Buckley-Leverett two-phase flow,
Chromatographic test analyzes, (DLVO) theory, 34e35, 52e54 44e45
11e13 Disproportionate permeability capillary desaturation curve
Cloud point, 88e89 reduction (DPR), 69 (CDC), 49

Note: Page numbers followed by “f” indicate figures, “t” indicate tables.

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