A Combined Experimental and Theoretical Investigation on Application of Wettability Modifiers in Gas-Condensate Reservoirs

Fahimpour, Jalal; Jamiolahmady, Mahmoud; Sohrabi, Mehran

doi:10.2118/159807-ms

Cited by 8 publications

(1 citation statement)

References 29 publications

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“…Ahmadi et al (2011) found that, in the presence of brine, it is better to preflush the core with a solvent (such as IPA) followed by the chemical treatment, and the use of polyamine primer can improve the treatment's lifetime and increase the improvement factor of the wettability-alteration-chemical treatment. Fernandez et al (2011) found that there is an optimal concentration for the fluorochemical, and there was no more improvement in liquid mobility at concentrations above the optimum.…”

Section: Use Of Fluorosurfactants and -Polymers For Wettability Altermentioning

confidence: 92%

Mitigation of the Effects of Condensate Banking: A Critical Review

Sayed

Al-Muntasheri

2016

SPE Production &Amp; Operations

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With production from gas/condensate reservoirs, the flowing bottomhole pressure of the production well decreases. When the flowing bottomhole pressure decreases below the dewpoint, condensate accumulates near the wellbore region and forms a condensate bank. This results in a loss of productivity of both gas and condensate, which becomes more serious in intermediate-and low-permeability gas/condensate reservoirs, where the condensate bank reduces both the gas permeability and the well productivity.Several techniques have been used to mitigate this problem. These methods include:• Use of solvents and wettability-alteration chemicals to reduce the impact of condensate blockage • Gas cycling and injection of nitrogen and supercritical carbon dioxide as pressure-maintenance methods • Drilling horizontal wells, hydraulic fracturing, and acidizing to improve the well productivity Gas cycling aims to keep the reservoir pressure greater than the dewpoint pressure to reduce the condensation phenomena. The limited volumes of gas that can be recycled in the reservoir can hinder the application of this method. For an ideal gas-cycling process, the volume of the gas injected into the reservoir will be larger than the total gas that can be produced from such a reservoir. Other approaches are the drilling of horizontal wells and hydraulic fracturing, during which the pressure drop around the wellbore region is lowered to allow for a longer production time, with only single-phase gas flow to the wellbore. These approaches are costly because they require drilling rigs. Another technique is the use of solvents, which shows good treatment outcomes, but the durability is a questionable issue in these treatments. Moreover, wettability alteration needs to be approached very carefully so as not to cause permanent damage to the reservoir. The use of fluorinated polymers and surfactants dissolved in alcohol-based solvents for wettability-alteration treatments was reported in many studies.Each method has its own advantages and disadvantages, and can be applied under certain conditions. This paper presents all of these methods, along with their advantages and disadvantages and description of some of their field applications and case studies.

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Section: Use Of Fluorosurfactants and -Polymers For Wettability Altermentioning

confidence: 92%

Mitigation of the Effects of Condensate Banking: A Critical Review

Sayed

Al-Muntasheri

2016

SPE Production &Amp; Operations

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Wettability alteration using functionalized nanoparticles with tailored adhesion to the rock surface for condensate banking mitigation

Sayed

Saini

et al. 2021

Can J Chem Eng

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Accumulation of liquids near the wellbore in gas reservoirs can result in what is known as liquid banking, causing loss of gas and liquid production. One of the techniques that can be used to mitigate liquid banking is changing the rock wettability from liquid wetting to neutral wetting, allowing the gas to carry the liquid out of the pore space. Double‐functionalized wettability altering silica (SiO2) nanoparticles (NPs) were developed. The synthesized NPs were functionalized with both fluoro‐silane (F‐SiO2 NPs) and a charged functional group to enable coupling of the NPs to the substrate. Surfaces treated with F‐SiO2 NPs functionalized with coupling functional group showed superior wear and corrosion resistance in high salinity water compared to single‐functionalized F‐SiO2 NPs. By functionalizing 125 nm SiO2 NPs first with polyethylenimine (PEI‐) or N‐(2‐Aminoethyl)‐3‐aminopropyltrimethoxysilane (DAMO‐) l group followed by fluorination, a water contact angle of 120°and decane contact angle of 70° was achieved. Core flow testing performed under realistic reservoir conditions of pressure and temperature showed that F‐SiO2 NPs coated with PEI achieved a 58% improvement in gas and liquid relative permeability, indicating improvement in the surface repellency to liquids and reduction of the trapped liquid phases inside the pore space of the rocks. The developed double‐functionalized NPs achieved similar performance to the commercially used fluorinated surfactants but using less treatment volume. In addition, these double‐functionalized NPs enable one‐step treatment in the field, which results in simpler operations, shorter treatment time, and better treatment economics.

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Wettability Alteration to Reduce Water Blockage in Low-Permeability Sandstone Reservoirs

et al. 2023

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This study is a continuation of our previous work, which focused on a near-wellbore water blockage alleviation by applying a thermally cured silane-functionalized benzoxazine to modify rock wettability. In this new analysis, we have demonstrated that the resin can be applied in low-permeability sandstones (approximately 15 mD as opposed to 100 to 200 mD in the previous study) to change the rock surface wettability from water-wet to intermediate gas-wet. We have also demonstrated that curing temperatures as low as 125 °C (as opposed to 180 °C in our previous study) can significantly change wettability, indicating surface functionalization through the silane moiety and ring-opening polymerization of the benzoxazine moiety. In drainage core flooding experiments at 2.5 wt.% resin loading, compared to untreated samples, brine recovery increments of 6.3 to 6.9% were obtained for curing temperatures of 125 to 180 °C, respectively. A maximum 20% increment in the end-point relative gas permeability was achieved at a curing temperature of 180 °C. A coupled experimental and numerical study, conducted at core and wellbore scales, demonstrates the potential effectiveness of our chemical treatment in improving gas productivity at the field scale. Reservoir simulations indicate a 2.9 to 10.6% improvement in gas deliverability for a treatment radius of 4 to 16 m, respectively.

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A Combined Experimental and Theoretical Investigation on Application of Wettability Modifiers in Gas-Condensate Reservoirs

Cited by 8 publications

References 29 publications

Mitigation of the Effects of Condensate Banking: A Critical Review

Mitigation of the Effects of Condensate Banking: A Critical Review

Wettability alteration using functionalized nanoparticles with tailored adhesion to the rock surface for condensate banking mitigation

Wettability Alteration to Reduce Water Blockage in Low-Permeability Sandstone Reservoirs

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