Micellar Flooding: Sulfonate–polymer Interaction

Trushenski, Scott P.

doi:10.1016/b978-0-12-641750-0.50022-0

Cited by 40 publications

(10 citation statements)

References 4 publications

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“…However, when the selected hydrolyzed polyacrylamide is added to formulations earlier described, phase separation and precipitation phenomenon was observed. This surfactant-polymer negative interaction has widely been described for sulfonate surfactants, leading to losses of both surfactant and polymer and poor efficiency in core flooding experiments (Pope 1982, Trushenski 1977. More recently (Wever 2011), it has been reviewed that there are also significant interactions among other anionic surfactants (carboxylate and sulfates) and HPAM, depending on the surfactant concentration, pH and presence of electrolyte, similarly to sulfonate surfactants.…”

Section: Surfactant-polymer Interactionsmentioning

confidence: 98%

“…This approach allowed us to reduce the amount of alkali and consequently the concentration of polymer. Furthermore, the selected anionic high-molecular weight surfactant showed some negative interactions with anionic polymers, leading to some gel-like formation and even precipitation when a critical amount of alkali was reached, as previously described by as surfactant-polymer incompatibility (Pope, 1982 andTrushenski, 1977). Hence, the final experimental tasks dealt with the selection of a co-solvent or co-surfactant alleviating this incompatibility phenomenon while keeping ultra-low IFT and viscosity of the formulation.…”

Section: Introductionmentioning

confidence: 95%

See 1 more Smart Citation

Design of an ASP Pilot for Caracara Sur Oilfield: Selection of Chemicals and Laboratory Assessment

Prieto

Rodríguez

Romero

et al. 2016

SPE Improved Oil Recovery Conference

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The design of an alkali-surfactant-polymer (ASP) formulation for chemical Enhanced Oil Recovery poses multiple challenges from the experimental point of view. The present research examines the laboratory procedures and experimental results aimed at selecting the most suitable chemicals for an ASP pilot trial at the Caracara Sur field (Los Llanos Basin, Colombia). The key challenge was the limited compatibility of the surfactant and polymer selected under reservoir conditions (temperature and total salinity), leading to phase separation of the ASP solution and losses of the activity of both chemicals. An extension of the experimental program was required to re-design the formulation and mitigate risks of damaging the formation in the following field trials. The formulation comprised an alkyl benzene sulfonate as main ingredient, a hydrolyzed polyacrylamide as viscosifying agent and some weak alkali to reach the optimum salinity of the mixture. A mono-alkyl diphenyl disulfonate ether was added as coupling agent to improve compatibility of the ASP mixture. The performance of the selected ASP formulation was assessed by means of interfacial tension measurements, long-term thermal stability tests and dynamic core-flooding tests. The formulation provided ultra-low interfacial tension (Ͻ 10 -2 mN/m) and viscosity enough to assure an appropriate mobility control. Hence, the formulation was considered to be suitable for further testing in the field pilot.

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Section: Surfactant-polymer Interactionsmentioning

confidence: 98%

Section: Introductionmentioning

confidence: 95%

Design of an ASP Pilot for Caracara Sur Oilfield: Selection of Chemicals and Laboratory Assessment

Prieto

Rodríguez

Romero

et al. 2016

SPE Improved Oil Recovery Conference

View full text Add to dashboard Cite

show abstract

“…This incompatibility is due to several factors: salinity, polymer concentration and surfactant concentration. [17] ▪ Szabo provided data about several additional polymers and sulfonates. Types of polymers were: Xanthan Gum, PAM.…”

Section: Literature Review : ▪mentioning

confidence: 99%

Effect of Components Concentration of ASP Chemical Flooding Solution on the Phase Behavior (Oil/ASP

AlBredi¹

2019

Journal of Petroleum and Mining Engineering

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In this research, the effects of the following factors on phase behavior of Oil/ASP solution were studied: Change of DDBSCa concentration in ASP solution on phase behavior of (Oil/ASP); Change of Na2CO3 concentration in ASP solution on phase behavior of (Oil/ASP) and Change of Xanthan Gum concentration in ASP solution on phase behavior of (oil /ASP) . Later The optimum concentrations of ASP components were restricted depending on phase behaviour The researcher has investigated this effect By studying change each of :oleic phase volume (Voleic) that result of emulsification between the oil and ASP solution -ASP solution volume that form emulsifier (Vd) . By relationship with (VASP%) which means : the percentage of ASP solution volume that added to the total volume (Oil+ASP solution) . The results referred to the following : the Miscibility of (ASP \Oil) is affected strongly by components concentration of ASP solution. Also, The optimum concentrations of ASP solution components that achieve successful ASP flooding depending on phase behavior are compatible with the concentrations that I found from my previous studies that achieved : minimum interfacial tension at minimum concentration (regarding surfactant and alkaline). Maximum viscosity compatible with oil viscosity of the studied oil field (regarding the polymer).

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“…Particularly, numerous reasons for the chemical loss through porous media in surfactant-based chemical flooding have been documented. Trushenski (1977) stated that when multiple phases form in the presence of polymer and a micellar fluid in dynamic core tests, one phase may be trapped in the core. Glover et al (1979) point out that a large retention of surfactant in a system, which is at optimal salinity at injected conditions, may occur.…”

Section: Introductionmentioning

confidence: 99%

Phase Trapping Effects in Viscous-modified Low Interfacial Tension Flow during Surfactant-polymer Flooding in Heavy Oil Reservoirs

Jamaloei

Kharrat

Asghari

et al. 2014

Energy Sources, Part A: Recovery, Utilization, and Environmenta

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This study examines the effects of non-wetting phase trapping in viscous-modified low-interfacial tension flow during viscous surfactant waterflooding (or surfactant-polymer flooding) under three different injection flowrates in three initially preferential water-wet porous media (each with a different pore throat size) partially filled with heavy oil and brine. In two approaches developed in this study, dynamic mean pore-scale capillary number N c1 is considered as the foremost criterion to characterize the effect of non-wetting phase trapping. In the first approach, which is a pore network approach, the effect of phase trapping on the value of N c1 is neglected. In the second approach, which is a numerical method, the effect of phase trapping is included. By comparing the values of N c1 from the pore network approach and numerical method, the effect of phase trapping is characterized. The change in N c1 was found to be an appropriate tool to characterize the effects of phase trapping in viscous surfactant waterflooding.

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Micellar Flooding: Sulfonate–polymer Interaction

Cited by 40 publications

References 4 publications

Design of an ASP Pilot for Caracara Sur Oilfield: Selection of Chemicals and Laboratory Assessment

Design of an ASP Pilot for Caracara Sur Oilfield: Selection of Chemicals and Laboratory Assessment

Effect of Components Concentration of ASP Chemical Flooding Solution on the Phase Behavior (Oil/ASP

Phase Trapping Effects in Viscous-modified Low Interfacial Tension Flow during Surfactant-polymer Flooding in Heavy Oil Reservoirs

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