Wettability Alteration to Intermediate Gas-Wetting in Gas-Condensate Reservoirs at High Temperatures

Fahes, Mashhad; Firoozabadi, Abbas

doi:10.2118/96184-pa

Cited by 91 publications

(43 citation statements)

References 21 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The σ hw could also be affected. In our experience the use of fluorochemical polymers and its adsorption in rock substrate often increases the contact angle through water from 0° to about 150° by just reducing the surface energies of the substrate, and without affecting the surface tension in the gas‐liquid fluid systems 32. Figure 5 shows how capillary adhesion force is reduced as contact angle is increased between 0° and 60° with h = 3 nm.…”

Section: Resultsmentioning

confidence: 99%

Effects of antiagglomerants on the interactions between hydrate particles

et al. 2007

Self Cite

View full text Add to dashboard Cite

in Wiley InterScience (www.interscience.wiley.com).Hydrate inbibition in natural gas production by antiagglomeration is promising because of effectiveness at high subcoolings encountered in many offshore operations. There are various mechanisms that are believed to contribute to the repulsion and attraction of hydrate particles. These include: (1) steric, (2) dispersion, (3) capillary, and (4) shear forces. Some of the expressions derived, and some formulas are used from the literature to provide a theoretical analysis of the forces between two hydrate particles to examine antiagglomeration using surfactants. Results show that hydrate particle size has the most important effect on antiagglomeration. Results also show that the contact angle increase and the oil-water interfacial tension decrease will either reduce capillary forces significantly or eliminate it. Effective antiagglomerants reduce the size, decrease interfacial tension, and increase contact angle through the water phase.

show abstract

Section: Resultsmentioning

confidence: 99%

Effects of antiagglomerants on the interactions between hydrate particles

et al. 2007

Self Cite

View full text Add to dashboard Cite

show abstract

“…The influence of fluorosurfactants on wettability alteration at high temperatures has also been examined. Wettability results show that wettability alteration has a substantial effect on improving gas productivity at high reservoir temperatures [12,13]. Stanly and Firoozabadi [14] revealed that wettability of Berea and low permeability reservoir rocks can be permanently altered from liquid-wetting to intermediate gas-wetting.…”

Section: Introductionmentioning

confidence: 99%

The Effect of Fluoropolymer on Wettability Alteration of Sandstone at Elevated Temperatures

Jin

Wang

Ren

et al. 2016

J Surfact & Detergents

View full text Add to dashboard Cite

Gas condensate reservoirs are generally recovered using a pressure depletion drive. Gas can condensate into the liquid phase near the wellbore region when the reservoir pressure falls below the dew point pressure, which can kill gas deliverability. Wettability alteration is an effective means of overcoming this problem; core wettability can be altered from liquid‐wet to gas‐wet to alleviate the effect of condensate accumulation near the wellbore region. To establish the effect of fluoropolymer on wettability alteration in a gas‐condensate reservoir, a gas‐wetting alteration agent was synthesized by emulsion polymerization using different molar ratios of fluorine‐containing monomers and acrylic monomers. FTIR and SEM were performed to analyze the structure of the gas‐wetting agent. Contact angle measurements were used to assess surface alteration by the Owens two‐liquid method. The effects of alteration agent concentration, salt concentration, pH and temperature on gas‐wetting alteration were also evaluated. Results showed that the best molar ratio of fluoropolymer monomer to acrylic monomers was 1:2. The egg‐like structure of the fluoropolymer latex on the core surface mainly contributes to gas‐wetting alteration. The contact angles of brine and oil can be altered from 23° and 0° to 137° and 67° by 1 wt% FP‐2 treatment, respectively. The surface free energy of the core was reduced from 67.52 to 1.66 mN/m. Moreover, the treated cores remain gas‐wetting up to 100 g L−1 of salt solution, 120 °C and within the pH range of 5–7. This novel gas‐wetting alteration agent can be used to solve the problem of liquid blocking effects in gas condensate reservoirs and improve gas recovery significantly.

show abstract

“…The presence of liquid hydrocarbon and water in the vicinity of wellbores was considered as the main restricting parameter making only 10% of original gas in place recoverable from this reservoir (Engineer 1985). A large number of theoretical and experimental studies have been devoted to understanding, modeling, and predicting the condensate accumulation and its associated impaired well productivity (O'Dell and Miller 1967;Fussell 1973;Danesh et al 1991;Henderson et al 1993Henderson et al , 1998Fevang and Whitson 1996;Mott 2002;Jamiolahmady et al 2003).…”

Section: Introductionmentioning

confidence: 99%

Optimization of Fluorinated Wettability Modifiers for Gas/Condensate Carbonate Reservoirs

Fahimpour¹,

Jamiolahmady²

2015

SPE Journal

View full text Add to dashboard Cite

Significant reduction in well productivity of gas/condensate reservoirs occurs because of reduced gas mobility caused by the presence of condensate/water liquid phases around the wellbore.There are certain fluorinated wettability modifiers that are capable of delivering a good level of oil and water repellency to the rock surface, making it intermediate gas-wet and alleviating such liquid blockages. The main objective of this experimental work has been to evaluate the performance of such chemicals for wettability alteration of carbonate rocks, which have received much less attention in comparison with sandstone rocks. Screening tests, including contact-angle measurements, unsteady-state-flow tests, and compatibility tests with brine, were performed by use of mainly anionic and nonionic fluorosurfactants.Results demonstrated that on positively charged carbonate surfaces, the anionic chemicals were sufficiently effective to repel the liquid phase, whereas the nonionic chemicals showed an excellent stability in brine media. A new approach of combining anionic and nonionic chemical agents was proposed to benefit from these two positive features of an integrated chemical solution. A number of low-and high-permeability carbonate-core samples were successfully treated by use of chemicals selected through screening tests. Optimization of the solution composition and its filtration before injecting it into the core proved very effective in reducing/eliminating the risk of possible permeability damage because of deposition of large chemical aggregates on the rock surface. The chemical solution optimized in this study can be considered as a potential wettability modifier for mitigating the negative impact of condensate/water banking in gas/condensate carbonate reservoirs.

show abstract

Wettability Alteration to Intermediate Gas-Wetting in Gas-Condensate Reservoirs at High Temperatures

Cited by 91 publications

References 21 publications

Effects of antiagglomerants on the interactions between hydrate particles

Effects of antiagglomerants on the interactions between hydrate particles

The Effect of Fluoropolymer on Wettability Alteration of Sandstone at Elevated Temperatures

Optimization of Fluorinated Wettability Modifiers for Gas/Condensate Carbonate Reservoirs

Contact Info

Product

Resources

About