New Viscoelastic Fluid for Chemical EOR

Morvan, Mikel; Degré, Guillaume; Leng, Jianqiao; Masselon, Chloë; Bouillot, Jerome; Zaitoun, Alain; Moreau, Patrick

doi:10.3997/2214-4609.201404820

Cited by 24 publications

(8 citation statements)

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“…VES surfactants, according to another research, shape worm-like micelles that form gel-like structures . These have a low adsorption rate in sandstone cores and bring down residual oil saturation from 0.49 to 0.20 . Another investigation on VES, which goes by orange II sodium salt as a trade name, effectively lowers the IFT between oil and water to 10 –4 mNm –1 .…”

Section: Other Class Of Surfactantsmentioning

confidence: 99%

“…193 These have a low adsorption rate in sandstone cores and bring down residual oil saturation from 0.49 to 0.20. 194 Another investigation on VES, which goes by orange II sodium salt as a trade name, effectively lowers the IFT between oil and water to 10 −4 mNm −1 . It also proved to convert oil-wet rock surfaces to water-wet conditions through VES adsorption which makes it suitable for a fracture flow-back operation.…”

Section: Types Of Surfactants Used In Eormentioning

confidence: 99%

See 1 more Smart Citation

Comprehensive Review on the Role of Surfactants in the Chemical Enhanced Oil Recovery Process

Chowdhury

Shrivastava

Kakati

et al. 2022

Ind. Eng. Chem. Res.

101

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With a constant upsurge in energy demand, production from depleted and harsh reservoirs through enhanced oil recovery techniques (EOR) has significantly increased. Among many EOR techniques, chemical EOR (cEOR) is one of the most widely used methods of oil extraction. Surfactants used in cEOR are instrumental in reducing interfacial tension (IFT) and altering the wettability of rock, which leads to additional oil recovery. This review draws attention to detail on surfactants from fundamentals to field scale. Properties of surfactants like phase behaviors, critical micelle concentration (CMC), hydrophilic–lipophilic balance and deviation, zeta potential, and their importance are discussed in depth. The presence of a saline environment, polymer, cosurfactant, and other factors affecting the performance of surfactant during the cEOR process are also elaborated. Key findings on surfactant adsorption on reservoir rock with other influencing aspects have also been reported in this study. Types of surfactants, from basic to the likes of polymeric, viscoelastic, Gemini, natural, and their effects on oil recoveries have been analyzed and compared. Special emphasis on emerging aids for surfactant flooding such as applications of nanotechnology, use amphoteric Janus particles, and synergies of surfactant–low salinity water flooding, along with their mechanisms and recent advances have been thoroughly duscussed. Lastly, the review delineates discerning criteria for the selection of surfactants, reviews recent field applications, and outlines the challenges that the industry faces while implementing surfactant cEOR. It has been found that exhaustive studies have been conducted on sandstones with success. However, extreme temperature and saline conditions in the case of carbonate reservoirs limit the applicability of surfactants, and the pursuit to accomplish its efficacy continues.

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Section: Other Class Of Surfactantsmentioning

confidence: 99%

Section: Types Of Surfactants Used In Eormentioning

confidence: 99%

Comprehensive Review on the Role of Surfactants in the Chemical Enhanced Oil Recovery Process

Chowdhury

Shrivastava

Kakati

et al. 2022

Ind. Eng. Chem. Res.

101

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“…Morvan et al evaluated a VES-based fluid for chemical enhanced oil recovery (CEOR). The viscosity of the formulated fluid is insignificantly affected by the presence of brine concentration when tested in low salinity and synthetic seawater [ 25 ].…”

Section: Ves Applicationsmentioning

confidence: 99%

The Synergetic Impact of Anionic, Cationic, and Neutral Polymers on VES Rheology at High-Temperature Environment

Othman

AlSulaimani²,

Aljawad

et al. 2022

Polymers

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Hydraulic fracturing operations target enhancing the productivity of tight formations through viscous fluid injection to break down the formation and transport proppant. Crosslinked polymers are usually used for desired viscoelasticity of the fracturing fluid; however, viscoelastic surfactants (VES) became a possible replacement due to their less damaging impact. To design a fracturing fluid with exceptional rheological and thermal stability, we investigated mixing zwitterionic VES with carboxymethyl cellulose (CMC), hydroxyethylcellulose (HEC), or a poly diallyl dimethylammonium chloride (DADMAC) polymers. As a base fluid, calcium chloride (CaCl2) solution was prepared with either distilled water or seawater before adding a polymer and the VES. A Chandler high-pressure, high-temperature (HPHT) viscometer was used to conduct the viscosity measurements at a shear rate of 100 1/s. It has been found that adding 1% CMC polymer to 9% (v/v) VES increases the viscosity more compared to 10% (v/v) VES at reservoir temperatures of 143.3 °C. On the other hand, adding only 1.0% of HEC to 9% (v/v) VES doubled the viscosity and proved more effective than adding CMC. HEC, nevertheless, reduced the system stability at high temperatures (i.e., 148.9 °C). Adding DADMAC polymer (DP) to VES increased the system viscosity and maintained high stability at high temperatures despite being exposed to saltwater. CaCl2 concentration was also shown to affect rheology at different temperatures. The improved viscosity through the newly designed polymer can reduce chemical costs (i.e., reducing VES load), making it more efficient in hydraulic fracturing operations.

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“…Recently, viscoelastic surfactant (VES) flooding has attracted the attention of researchers because of its dual capability to enhance mobility and the IFT. − VES can lower the IFT and increase the viscosity, achieving the properties of surfactants and polymers. − Briefly, they are non-Newtonian fluids that combine elastic and viscous properties . Therefore, VES flooding enhances displacement efficiency and increases oil recovery. − In addition, it proved good endurance to harsh conditions, like high temperatures and salinity. − Thereby, VES flooding can effectively enhance the oil recovery from both sandstone and carbonate reservoirs. ,− , …”

Section: Introductionmentioning

confidence: 99%

“…25−27 Thereby, VES flooding can effectively enhance the oil recovery from both sandstone and carbonate reservoirs. 15,[18][19][20]28 T h i s c o n t e n t i s Most studies for VES are for fracturing applications, 29,30 while very minor studies were for EOR. 31 The scarcity of fresh water in the gulf area made using seawater in chemical flooding operations an advantage because the cost of water softening is saved.…”

Section: ■ Introductionmentioning

confidence: 99%

Investigating Effects of Chelating Agents on Viscoelastic Surfactant Flooding at the Pore Scale Using Micromodels

et al. 2023

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Viscoelastic surfactants (VES) have proven their suitability for enhanced oil recovery (EOR) because they increase the viscosity and decrease the interfacial tension (IFT). In this work, we are proposing chelating agents to suppress the effect of salinity and maintain the required value to build the viscosity to optimize the amount of VES needed for a successful EOR job. Two different VES concentrations were investigated, 0.5 and 1.25 wt %. The chelating agents were diethylenetriaminepentaacetic acid (DTPA) and glutamic acid diacetic acid (GLDA), with different chelating agent concentrations ranging from 2 to 8% for each VES concentration. Rheology results showed that, for DTPA, the highest viscosity at the working shear rate of 1 s −1 is 717 cP achieved by 6% DTPA with 1.25% VES. While for GLDA, the highest viscosity at the working shear rate is 738 cP achieved by 8% GLDA with 1.25% VES. On the other hand, the IFT results for GLDA showed the lowest value of 0.0022 mN/m at 4% GLDA with 1.25% VES, and for DTPA, the lowest value was 0.0068 mN/m at 8% DTPA with 1.25% VES. The microfluidic recovery test was done for the selected best performance in IFT and rheology for each chelating agent with the pure VES. The ultimate recovery from 4% GLDA with 1.25% VES is 56% out of the original oil in place, while 43% using 8% DTPA with 1.25% VES. The pure VES at 1.25% gave 48% ultimate recovery. The chelating agent proved to be successful in suppressing the effect of salinity in reducing the IFT. Therefore, normal seawater without sweetening can be used with VES and GLDA and achieve promising recovery.

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New Viscoelastic Fluid for Chemical EOR

Cited by 24 publications

References 0 publications

Comprehensive Review on the Role of Surfactants in the Chemical Enhanced Oil Recovery Process

Comprehensive Review on the Role of Surfactants in the Chemical Enhanced Oil Recovery Process

The Synergetic Impact of Anionic, Cationic, and Neutral Polymers on VES Rheology at High-Temperature Environment

Investigating Effects of Chelating Agents on Viscoelastic Surfactant Flooding at the Pore Scale Using Micromodels

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