Design of an ASP flood in a High-Temperature, High-Salinity, Low-Permeability Carbonate

Levitt, David; Dufour, Sophie; Pope, Gary A.; Morel, Danielle; Gauer, Pascal Rene

doi:10.2523/14915-ms

Cited by 41 publications

(18 citation statements)

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“…65 Ryles 64 found that the rate of hydrolysis is rapid at 90 • C, moderate at 70 • C, and negligible at 50 • C. While about 90% DOH is reached within a few days of aging at 100 • C, 67 at 83 • C about 70% DOH is reached within 100 days at neutral pH. 68 Moradi et al 69 also concluded that in the presence of divalent cations the maximum temperature limit is 75 • C. All of the above-mentioned studies were conducted in the presence of divalent cations, and the use of HPAM was recommended up to 100 • C when the concentration of divalent cations is less than 200 ppm. 39 Subsequently it was found that in the absence of divalent cations, HPAM maintained half of the original viscosity at 100 • C for 8 years and at 120 • C for 2 years.…”

Section: Thermal Stability Of Hpammentioning

confidence: 95%

Review on Polymer Flooding: Rheology, Adsorption, Stability, and Field Applications of Various Polymer Systems

Kamal¹,

Sultan²,

et al. 2015

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Polymer flooding is one of the most promising techniques for the recovery of remaining oil from light oil reservoirs. Water soluble polymers are used to enhance the viscosity of displacing fluid and to improve the sweep efficiency. In this paper, water soluble polymers used for chemical enhanced oil recovery are reviewed. Conventional and novel modified polymers are discussed along with their limitations. The review covers thermal stability, rheology, and adsorption behavior of various polymer systems in sandstone and carbonate reservoirs. Field and laboratory core flooding data of several polymers are covered. The review describes the polymer systems that are successfully applied in low-temperature and low-salinity reservoirs. Comprehensive review of current research activities aiming at extending polymer flooding to high-temperature and high-salinity reservoirs is performed. The review has identified current and future challenges of polymer flooding.

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Section: Thermal Stability Of Hpammentioning

confidence: 95%

Review on Polymer Flooding: Rheology, Adsorption, Stability, and Field Applications of Various Polymer Systems

Kamal¹,

Sultan²,

et al. 2015

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“…A high oil and water solubilization ratio at optimal salinity is correlated with an ultralow IFT, which is the key mechanism in surfactant-based chemical EOR. The details of this method are well established (Flaaten et al 2009;Liu et al 2010;Levitt et al 2011). Determining the IFT value at optimal salinity is very important in surfactant selection and performance.…”

Section: Methodsmentioning

confidence: 99%

“…CO 2 gas injection is more desirable compared to other injection gases due to its lower injectivity problems, lower formation volume factor, abundance of reserves, and higher incremental oil recovery (Kulkarni 2003;Al-Abri and Amin 2010). The microscopic sweep efficiency of CO 2 injection is good; however, the mobility ratio which controls the volumetric sweep efficiency between CO 2 and oil is poor (Hinderaker et al 1996;Faisal et al 2009).…”

Section: Introductionmentioning

confidence: 99%

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An experimental and numerical study of chemically enhanced water alternating gas injection

Majidaie¹,

Önür

Tan³

2015

Pet. Sci.

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In this work, an experimental study combined with numerical simulation was conducted to investigate the potential of chemically enhanced water alternating gas (CWAG) injection as a new enhanced oil recovery method. The unique feature of this new method is that it uses alkaline, surfactant, and polymer additives as a chemical slug which is injected during the water alternating gas (WAG) process to reduce the interfacial tension (IFT) and simultaneously improve the mobility ratio. In essence, the proposed CWAG process involves a combination of chemical flooding and immiscible carbon dioxide (CO 2 ) injection and helps in IFT reduction, water blocking reduction, mobility control, oil swelling, and oil viscosity reduction due to CO 2 dissolution. Its performance was compared with the conventional immiscible water alternating gas (I-WAG) flooding. Oil recovery utilizing CWAG was better by 26 % of the remaining oil in place after waterflooding compared to the recovery using WAG conducted under similar conditions. The coreflood data (cumulative oil and water production) were history matched via a commercial simulator by adjusting the relative permeability curves and assigning the values of the rock and fluid properties such as porosity, permeability, and the experimentally determined IFT data. History matching of the coreflood model helped us optimize the experiments and was useful in determining the importance of the parameters influencing sweep efficiency in the CWAG process. The effectiveness of the CWAG process in providing enhancement of displacement efficiency is evident in the oil recovery and pressure response observed in the coreflood. The results of sensitivity analysis on CWAG slug patterns show that the alkaline-surfactant-polymer injection is more beneficial after CO 2 slug injection due to oil swelling and viscosity reduction. The CO 2 slug size analysis shows that there is an optimum CO 2 slug size, around 25 % pore volume which leads to a maximum oil recovery in the CWAG process. This study shows that the ultralow IFT system, i.e., IFT equaling 10 -2 or 10 -3 mN/ m, is a very important parameter in CWAG process since the water blocking effect can be minimized.

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“…Betaine surfactants have recently attracted increasing attention for their advantages such as good tolerance to high temperature and high salinity, high hardness, and high interfacial activity at low concentration [19][20][21]. With oilfield development, more and more oilfields [22][23][24] with high temperature and high salinity are needed to develop. Based on that, betaine is a promising surfactant, especially to high salinity and high temperature reservoir.…”

Section: Introductionmentioning

confidence: 99%

Effect of organic acid on lauroamide propyl betaine surface dilatational modulus and foam performance in a porous medium

Wang

Ge²,

Zhang

et al. 2017

Journal of Dispersion Science and Technology

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The purpose of this work was to study the effect of surface tension and surface dilatational modulus on foam performance in high salinity water in a porous medium. In order to clarify the role of the surface dilatational property in foam flow in a porous medium, three systems were established: a system with low surface dilatational modulus and high surface tension, a system with low surface dilatational modulus and low surface tension, and a system with high surface dilatational modulus and low surface tension. Measurement of dilatational modulus and surface tension showed that lauroamide propyl betaine (LAB) could not reduce surface tension and that surface dilatational modulus was low. The addition of lauric acid (LCOOH) to LAB could not achieve high surface dilatational modulus, however, could reach lower surface tension. The addition of myristic acid (MCOOH) to LAB could achieve high surface dilatational modulus and lower surface tension. Unlike the other two systems, the results of a dilatational modulus comprised of a mixture of MCOOH and LAB was not a constant, as demonstrated by varied surface area deformation outcomes. With the increase of deformation, surface dilatational modulus decreased. Results of foam flow tests showed that among the two lower surface dilatational Downloaded by [Nanyang Technological University] at 05:22 15 June 2016 2 modulus systems, LAB foam had higher flow resistance regardless of flow rate. Among the two systems of similar lower surface tension, the mixture of LAB and MCOOH showed higher flow resistance than the mixture of LAB and LCOOH. However, with the increase of flow rate, pressure differences between the two systems became smaller, which corresponded to the decrease of surface dilatational modulus with an increase of deformation.

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Design of an ASP flood in a High-Temperature, High-Salinity, Low-Permeability Carbonate

Cited by 41 publications

References 0 publications

Review on Polymer Flooding: Rheology, Adsorption, Stability, and Field Applications of Various Polymer Systems

Review on Polymer Flooding: Rheology, Adsorption, Stability, and Field Applications of Various Polymer Systems

An experimental and numerical study of chemically enhanced water alternating gas injection

Effect of organic acid on lauroamide propyl betaine surface dilatational modulus and foam performance in a porous medium

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