Enhanced Oil Recovery by Hot CO2 Flooding

Picha, Mahesh S.

doi:10.2523/105425-ms

Cited by 3 publications

(1 citation statement)

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“…Sleipner field, Norwegian North Sea; Bentham & Kirby 2005). CO 2 may also be injected into depleted oil reservoirs to enhance oil recovery (EOR; Picha 2007) and into gas fields to enhance methane recovery (EGR; Gozalpour et al 2005;Oldenburg & Benson 2001). CO 2(aq ⁄ g) is an important agent for organic-inorganic rock-water interactions (Helgeson et al 1993;Seewald 2003).…”

Section: Introductionmentioning

confidence: 99%

Hydrogeochemical modelling of CO₂ equilibria and mass transfer induced by organic–inorganic interactions in siliciclastic petroleum reservoirs

Berk¹,

Schulz²,

Fu³

2009

Geofluids

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Different feldspar types control complex hydrogeochemical processes in hydrocarbon-bearing siliciclastic reservoirs, which have undergone different degrees of degradation. To test such processes generically, carbon dioxide equilibria and mass transfers induced by organic-inorganic interactions have been modelled for different hydrogeochemical scenarios. The approach is based on and compared with data from the Norwegian continental shelf (Smith & Ehrenberg 1989) and assumes local thermodynamic equilibrium among solids and fluids. Equilibrating mineral assemblages (different feldspar types, quartz, kaolinite, calcite) are based on the primary reservoir composition. Equilibration and coupled mass transfer were triggered by the addition and reaction of different amounts of CO 2 , CH 4 and H 2 (plus acetic acid) at temperatures between 50 and 95°C (323 and 368 K). These components occur in oil fields as products of anaerobic bacterial degradation, hydrolytic disproportionation of hydrocarbons and ⁄ or thermal maturation of kerogen. We apply two different computer codes and two different thermodynamic data bases to calculate the results. Reaction of 0.32-0.6 mol CO 2 , 0.16-0.3 mol CH 4 and 0.8-1.5 mol H 2 with K-feldspar, quartz, kaolinite and calcite in 1 l of pore water results in modelled values of 0.3-2.3 mol% CO 2 in a multicomponent gas phase that resembles measured data (0.2-1.5 mol%). Similar CO 2 contents result from acetic acid addition (CO 2 , CH 4 , H 2 + 0.016 mol CH 3 COOH). Equilibration with albite or anorthite reduces the release of CO 2 into the multicomponent gas phase dramatically, by 1 or 4 orders of magnitude compared with the equilibration with K-feldspar. Minor differences in the modelled CO 2 content (0.1-0.2 mol%) result from calculations with different computer codes if the same thermodynamic data base is applied. Relevant differences (up to 1.9 mol% CO 2 ) result from calculations using different thermodynamic data bases.

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Section: Introductionmentioning

confidence: 99%

Hydrogeochemical modelling of CO₂ equilibria and mass transfer induced by organic–inorganic interactions in siliciclastic petroleum reservoirs

Berk¹,

Schulz²,

Fu³

2009

Geofluids

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Comprehensive review of enhanced oil recovery strategies for heavy oil and bitumen reservoirs in various countries: Global perspectives, challenges, and solutions

Seidy-Esfahlan,

Tabatabaei-Nezhad,

Khodapanah

2024

Heliyon

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Viscosity reduction of extra heavy crude oil by magnetite nanoparticle-based ferrofluids

Aristizábal-Fontal

Cortés

Franco

2017

Adsorption Science & Technology

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The main objective of this work is to synthesize and evaluate magnetite (Fe 3 O 4) nanoparticlebased ferrofluids for reducing the viscosity of an extra heavy crude oil. The carrier fluid of the nanoparticles was synthesized using an engine lubricant recycled from the automotive industry and hexadecyltrimethylammonium bromide as a surfactant. Fe 3 O 4 nanoparticles were synthesized by coprecipitation method. The effect of the concentration of nanoparticles in the viscosity reduction degree was determined for dosages between 0 and 50,000 mg/L. Different dosages of carrier fluid were evaluated between 0 and 10% v/v. The effects of the amount of brine emulsified, temperature, time, and shear rate were assessed. Overall, the results showed that viscosity and shear stress of extra heavy crude oil could be reduced up to 81 and 78% in the presence of ferrofluid, respectively. The rheological behavior of extra heavy crude oil in the presence and absence of ferrofluid was assessed by Cross, Ostwald-de Waele, and Herschel-Bulkley models.

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Enhanced Oil Recovery by Hot CO2 Flooding

Abstract: TX 75083-3836, U.S.A., fax 01-972-952-9435.

Cited by 3 publications

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Hydrogeochemical modelling of CO₂ equilibria and mass transfer induced by organic–inorganic interactions in siliciclastic petroleum reservoirs

Hydrogeochemical modelling of CO₂ equilibria and mass transfer induced by organic–inorganic interactions in siliciclastic petroleum reservoirs

Comprehensive review of enhanced oil recovery strategies for heavy oil and bitumen reservoirs in various countries: Global perspectives, challenges, and solutions

Viscosity reduction of extra heavy crude oil by magnetite nanoparticle-based ferrofluids

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Enhanced Oil Recovery by Hot CO2 Flooding

Abstract: TX 75083-3836, U.S.A., fax 01-972-952-9435.

Cited by 3 publications

References 0 publications

Hydrogeochemical modelling of CO2 equilibria and mass transfer induced by organic–inorganic interactions in siliciclastic petroleum reservoirs

Hydrogeochemical modelling of CO2 equilibria and mass transfer induced by organic–inorganic interactions in siliciclastic petroleum reservoirs

Comprehensive review of enhanced oil recovery strategies for heavy oil and bitumen reservoirs in various countries: Global perspectives, challenges, and solutions

Viscosity reduction of extra heavy crude oil by magnetite nanoparticle-based ferrofluids

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Hydrogeochemical modelling of CO₂ equilibria and mass transfer induced by organic–inorganic interactions in siliciclastic petroleum reservoirs

Hydrogeochemical modelling of CO₂ equilibria and mass transfer induced by organic–inorganic interactions in siliciclastic petroleum reservoirs