Cost Reduction and Injectivity Improvements for CO2 Foams for Mobility Control

Grigg, Reid B.; Tsau, Jyun‐Syung; Martin, F.

doi:10.2523/75178-ms

Cited by 12 publications

(7 citation statements)

References 23 publications

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“…5 Earlier studies using lignosulfonate as a sacrificial agent or a cosurfactant demonstrated a significant reduction in the expensive surfactant adsorption. [6][7][8][9][10][11][12][13][14][15][16] Lignosulfonates (also called lignin sulfonates and sulfite lignins) are derived from the reaction of wood lignin with bisulfite or sulfate ions during the wood digestion reaction to make pulp. 17 Lignin, said to be the most common polymer on Earth, 17 is derived from abundant renewable resources.…”

Section: Introductionmentioning

confidence: 99%

“…Grigg and Tsau demonstrated that lignosulfonate could reduce the adsorption of the primary foaming agent-CD1045 TM by 24-60% in Berea core and 15-29% in Indiana limestone core samples. [12][13][14][15][16] In an earlier study the effect of concentration, salinity, temperature and injection rate on the equilibrium adsorption density and the effect of postflush rate, brine concentration and composition, temperature on the calcium lignosulfonate (CLS) desorption process in Berea sandstone cores were performed. 19 Equilibrium and kinetics are basic to the proper understanding of adsorption and desorption processes between surfactants and rocks.…”

Section: Introductionmentioning

confidence: 99%

“…Equilibrium adsorption of lignosulfonate onto some rocks has been studied. 10,[12][13][14][15][16]19 Little, however, has appeared in literatures concerning lignosulfonate adsorption kinetics. Knowledge of the adsorption and desorption rates aids in discerning the mechanisms controlling surfactant transport through reservoirs and predicting the fate of surfactant to provide cost-effective injection strategies.…”

Section: Introductionmentioning

confidence: 99%

See 2 more Smart Citations

Kinetics and Equilibria of Calcium Lignosulfonate Adsorption and Desorption onto Limestone

Bai¹,

Grigg²

2005

Proceedings of SPE International Symposium on Oilfield Chemistry

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractEquilibria and kinetics are two basic ingredients for the proper understanding of adsorption and desorption processes between surfactants and rocks. The adsorption and desorption of calcium lignosulfonate (CLS), commonly used as a sacrificial agent in surfactant-based EOR processes, has been studied.Kinetic results showed that adsorption and desorption are both time-dependent, not instant. Both adsorption and desorption were characterized by a biphasic pattern: a fast step followed by a slow step. Apparent adsorption and desorption rate coefficients were determined by a second-order kinetic model. Desorption is a much slower process than adsorption. Desorption is an un-equilibrium process under normal reservoir flow rate conditions. Equilibrium results show that CLS adsorption and desorption onto limestone can be described well by the Langmuir isotherm over the tested CLS concentration range, and that increasing concentration increases adsorption density. There is significant hysteresis between CLS adsorption and desorption isotherms. Increasing flow rate slightly decreased CLS equilibrium adsorption. Increasing both NaCl and CaCl 2 concentrations increased adsorption density; however, CaCl 2 had a much greater impact on the adsorption. Increasing pH decreased CLS adsorption onto limestone. The reasons for the effects of the different factors are elucidated in this paper.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Kinetics and Equilibria of Calcium Lignosulfonate Adsorption and Desorption onto Limestone

Bai¹,

Grigg²

2005

Proceedings of SPE International Symposium on Oilfield Chemistry

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“…[3][4][5][6][7] However, costs incurred by the loss of expensive foaming chemicals to adsorption on reservoir rocks often exclude this potentially beneficial option for many reservoirs. 8,9 Published IOR work on surfactant adsorption has focused on studying adsorption equilibrium with little mention of kinetics. [10][11][12] However, the kinetics of surfactant adsorption are important in determining the rate of adsorption onto the rock and the time required to reach equilibrium, and are thus useful in predicting the transport and fate of surfactant in the reservoir.…”

Section: Introductionmentioning

confidence: 99%

Adsorption Kinetics of Surfactant Used in CO2-Foam Flooding Onto Berea Sandstone

Bai

Grigg

Liu³

et al. 2005

SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThis paper reports adsorption/desorption kinetics and equilibrium onto Berea sandstone for a surfactant used as a CO 2 -water foaming agent. Also, foam stability of the surfactant is compared before and after adsorption/desortion has occurred. Results show that this surfactant's adsorption onto and desorption from Berea sandstone took several days to reach equilibrium. Both adsorption and desorption were characterized by a short period of rapid adsorption/desorption followed by a longer period of slower adsorption/desorption. Both adsorption and desorption processes were best fit by a pseudo-second-order kinetic model. Coefficients of adsorption and desorption rate were determined. A method to predict equilibrium adsorption density using adsorption process data over a relative short period is proposed, which saves considerable time in determining complete adsorption isotherms. Surfactant concentration and temperature affect equilibrium density. Foam stability is affected by selective surfactant adsorption onto the rock.

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“…Previous studies on the effects of pressure on IFT observed that trends also depended on the system studied. [60][61][62][63][67][68][69][70][71] Experiments were conducted on aqueous CD and a dense CO 2 system at different CD concentrations (Table 3). The pressure at which experiments were conducted ranged from 800 psig to 2000 psig at constant temperature of 25ºC (77ºF).…”

Section: Temperature Effect On Interfacial Tensionmentioning

confidence: 99%

Improving Gas Flooding Efficiency

Grigg¹,

Svec²,

Zhang³

et al. 2008

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This document is the Final Report for the project, "Improved Gas Flooding Efficiency," Department of Energy Contract No. DE-FC26-04NT15532. This study focuses on laboratory studies with related analytical and numerical models, as well as work with operators for field tests to enhance our understanding of and capabilities for more efficient enhanced oil recovery (EOR).Much of the work has been performed at reservoir conditions. This includes a bubble chamber and several core flood apparatus developed or modified to measure interfacial tension (IFT), critical micelle concentration (CMC), foam durability, surfactant sorption at reservoir conditions, and pressure and temperature effects on foam systems.Carbon dioxide and N 2 systems have been considered, under both miscible and immiscible conditions. The injection of CO 2 into brine-saturated sandstone and carbonate core results in brine saturation reduction in the range of 62 to 82% brine in the tests presented in this paper. In each test, over 90% of the reduction occurred with less than 0.5 PV of CO 2 injected, with very little additional brine production after 0.5 PV of CO 2 injected.Adsorption of all considered surfactant is a significant problem. Most of the effect is reversible, but the amount required for foaming is large in terms of volume and cost for all considered surfactants. Some foams increase resistance to the value beyond what is practical in the reservoir. Sandstone, limestone, and dolomite core samples were tested.Dissolution of reservoir rock and/or cement, especially carbonates, under acid conditions of CO 2 injection is a potential problem in CO 2 injection into geological formations. Another potential change in reservoir injectivity and productivity will be the precipitation of dissolved carbonates as the brine flows and pressure decreases.The results of this report provide methods for determining surfactant sorption and can be used to aid in the determination of surfactant requirements for reservoir use in a CO 2 -foam flood for mobility control. It also provides data to be used to determine rock permeability changes during CO 2 flooding due to saturation changes, dissolution, and precipitation.v

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Cost Reduction and Injectivity Improvements for CO2 Foams for Mobility Control

Cited by 12 publications

References 23 publications

Kinetics and Equilibria of Calcium Lignosulfonate Adsorption and Desorption onto Limestone

Kinetics and Equilibria of Calcium Lignosulfonate Adsorption and Desorption onto Limestone

Adsorption Kinetics of Surfactant Used in CO2-Foam Flooding Onto Berea Sandstone

Improving Gas Flooding Efficiency

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