Identifying the Optimum Wettability Conditions for the Near-Wellbore Region in Gas-Condensate Reservoirs

Zoghbi, Bilal; Fahes, Mashhad; Nasrabadi, Hadi

doi:10.2118/134966-ms

Cited by 8 publications

(6 citation statements)

References 23 publications

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“…A simulation study conducted by Zoghbi et al to find the optimum wetting conditions that improve gas well productivity using chemicals covered different states of wettability from gas repellence to liquid repellence. 52 They showed that an intermediate gas-wetting state rather than a strong gas-wetting state maximizes well productivity. Furthermore, they studied the effect of treatment radius, reservoir permeability, and pressure on the well productivity increment.…”

Section: Chemically Induced Wettability Alterationmentioning

confidence: 99%

“…Different relative permeability curves can represent wettability states as addressed in some studies. ,,,, It is stated that the crossover saturation shifts to the left by changing the wettability from liquid-wetting to gas-wetting. According to Figure , a change in the wettability to gas-wetting shifts the crossover point of the relative permeability curve to the left.…”

Section: Introductionmentioning

confidence: 99%

“…51 In a wettability alteration, the interfacial tension between rock surface and liquid reduces using a treatment agent (e.g., polymer, nanoparticle, and/or surfactant) and so the recovery factor increased. 52 A comprehensive understanding of the interactions between rocks, fluids, and chemicals is essential for enhancing production and promoting economic development in unconventional formations. 53 Surfactants have been widely acknowledged as effective agents for EOR since the 1970s.…”

Section: Introductionmentioning

confidence: 99%

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Wettability Alteration in Gas Condensate Reservoirs: A Critical Review of the Opportunities and Challenges

Kazemi,

Khlyupin,

Azin

et al. 2024

Energy Fuels

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The gas condensate reservoir is classified as a natural gas resource that produces condensate liquid in the reservoir when the pressure in the reservoir drops below the dew point. An innovative strategy to address condensate blockage near the wellbore involves modifying the wettability of the surface of the reservoir rock. This is achieved through chemical treatment, transitioning the surface from a state of strong liquid-wetting to either strong or intermediate gas-wetting. This modern approach effectively mitigates condensate blockage and its associated challenges. Adjusting and sustaining wettability conditions within gas reservoirs requires proper chemicals for a certain reservoir condition. The paper presents a thorough review of wettability and the processes involved in wettability alteration specifically in gas condensate reservoirs. Then, the commonly used wettability alteration chemicals along with their induced flow mechanisms are discussed and reviewed together with a molecular modeling point of view on modern problems of wetting and interfacial phenomena. This paper also focuses on using nanoparticles and fluorochemicals as wettability alteration agents, given that fluorinated nanoparticles are allegedly superior to the chemical wettability altering agents as they change the wettability of the rock surface by modifying both surface energy and surface roughness. This Review indicates the promising use of various nanoparticles along with fluoro materials to enhance ultimate hydrocarbon recovery in gas condensate reservoirs. In the next part, molecular dynamic simulation of imbibition of n-alkanes in kerogen organic slits are presented. The influence of competitive adsorption on multicomponent flows of crude oil and wetting transition on surfaces with molecular roughness are discussed. Actual problems and challenges of molecular modeling methods are also presented.

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Section: Chemically Induced Wettability Alterationmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Wettability Alteration in Gas Condensate Reservoirs: A Critical Review of the Opportunities and Challenges

Kazemi,

Khlyupin,

Azin

et al. 2024

Energy Fuels

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“…The method using the traditional capillary force curve to obtain a relative permeability ignores interfacial tension and wettability and considers only pore geometry, which is very unsatisfactory in EOR (enhanced oil recovery) as the interfacial force, and wettability may change during the injection of alkaline surfactants and CO 2 (Kong and Wardlaw 1991;Altunbay et al 2001;Goda and Behrenbruch 2004;Nurkamelia and Arihara 2004;Li et al 2010;Shaddel et al 2014;Bai et al 2014a, b). A lowpermeable reservoir was selected for this study as the ratios of both the surface and pore-throat are larger, the interaction between rock and fluid is more spectacular, and the influences of the interfacial force and wettability are larger than in medium-to high-permeability reservoirs (Zoghbi et al 2010;Fatemi and Sohrabi 2013). Therefore, the influence of these two factors needs to be considered when dealing with a low-permeable reservoir.…”

Section: Introductionmentioning

confidence: 99%

A new approach to obtaining relative permeability curves during chemical flooding process in a low-permeable reservoir

et al. 2015

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It is always difficult to obtain the relative permeability curve for a low-permeable reservoir using chemical flooding, as there are so many problems associated with the current measurement methods, especially when interfacial tension r, wettability cosh and pore-throat radius ratio m are considered as the main factors that influence the shape of the relative permeability curve, and thereby the oil recovery. This paper presents a new concept of modified capillary numbers (N CM ), associated with these three factors. First, laboratory experiments were carried out to get relationship between N CM and the residual oil saturation S OR under different conditions. Second, oilwater relative permeability curves for a target oil layer using the steady-state flow method were determined. Using these two steps, a relative permeability curve under different conditions of interfacial tension r, wettability cosh and pore-throat radius ratio m has been drawn. Based on the calculated relative permeability curves, the oil displacement efficiency and flow capacity were determined. Subsequently, the relationships between the relative permeability curve, oil displacement efficiency, flow capacity and the factors for a low-permeable reservoir were established using chemical flooding.Keywords Low permeable Á Chemical flooding Á Relative permeability Á Modified capillary number Á Pore-throat radius ratio Á Wettability Á Interfacial tension List of symbols hWetting angle (°) coshAverage contact angle cosine, the parameters of the wettability (-) N CM Modified capillary numbers (-) mPore-throat radius ratio (-) S OR Residual oil saturation (%) rInterfacial tension (mN/m) V wsp Water absorption oil discharge quantity in the Amott wettability index measurement experiment (ml) V wt Volume of oil by water displacement (ml) I W I W = V wsp /(V wsp ? V wt ) shows that the degree of water-wet (-) V osp Oil absorption water discharge quantity (ml) V ot Volume of water by oil displacement (ml) I O I O = V osp /(V osp ? V ot ) shows the degree of oil-wet (-) Amott wettability index I A

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“…When the gas is rendered as the wetting phase, it can suffer a reduction in effective permeability even with the enhancement in liquid mobility. Preceding simulation work (Zoghbi et al 2010) suggests the existence of an "optimum wetting state" where maximum gas condensate well productivity is reached. In this study, we show that this can be achieved experimentally, and the choice of the polymer concentration and treatment procedure should take that into account.…”

Section: Introductionmentioning

confidence: 99%

Wettability Alteration at Optimum Fluorinated Polymer Concentration for Improvement in Gas Mobility

Fernández

Fahes

Zoghbi

et al. 2011

SPE EUROPEC/EAGE Annual Conference and Exhibition

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In gas condensate reservoirs, deliverability starts to decrease when retrograde condensation occurs. As the bottom-hole pressure drops below the dew-point, gas condensate and water build-up impede flow of gas to the wellbore. In order to stop the reduction in productivity, many publications suggest wettability alteration to gas-wetting as a permanent solution to the problem. Previous simulation work suggests an "optimum wetting state" to exist where maximum gas condensate well productivity is reached. This work has direct application in gas-condensate reservoirs, especially in identifying the most effective stimulation treatment which can be designed to provide the optimum wetting conditions in the near-wellbore region.In this work, we aim to show the existence of such an optimum state of wettability that result in maximum gas mobility and in an increase of the relative permeability curves. We present an experimental study on Berea sandstone rocks treated with a fluorinated polymer and investigate the optimum fluorinated polymer concentration that would alter the wettability to intermediate gas-wet. Different experimental techniquesincluding flow tests and spontaneous imbibition are conducted to examine the effect of treatments on wettability. Interaction between rocks and the fluids is studied using a MicroCT scanner.The studies in this area are important to improve the productivity of gas condensate reservoirs where liquid accumulates, decreasing production of the well. Efficiency in the extraction of natural gas is important for the economic and environmental considerations of the oil and gas industry. Wettability alteration is one of the newest stimulation methods proposed by researchers, and shows great potential for future field applications and further research studies.

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Identifying the Optimum Wettability Conditions for the Near-Wellbore Region in Gas-Condensate Reservoirs

Cited by 8 publications

References 23 publications

Wettability Alteration in Gas Condensate Reservoirs: A Critical Review of the Opportunities and Challenges

Wettability Alteration in Gas Condensate Reservoirs: A Critical Review of the Opportunities and Challenges

A new approach to obtaining relative permeability curves during chemical flooding process in a low-permeable reservoir

Wettability Alteration at Optimum Fluorinated Polymer Concentration for Improvement in Gas Mobility

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