Investigation of Well Productivity in Gas-Condensate Reservoirs

El-Banbi, Ahmed; McCain, William D.; Semmelbeck, M.E.

doi:10.2118/59773-ms

Cited by 43 publications

(15 citation statements)

References 13 publications

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“…This phenomenon, known as condensate banking or condensate blockage, results in reduced gas relative permeability and lowered well deliverability. Water blockage also lowers gas relative permeability (El-Banbi et al 2000) and increases the impact of liquid blockage on the well deliverability. Several treatment options exist for reducing condensate blockage and the impact of condensate saturation.…”

Section: Introductionmentioning

confidence: 99%

Wettability Alteration of Reservoir Rocks from Liquid Wetting to Gas Wetting Using Nanofluid

et al. 2015

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Well productivity in gas condensate reservoirs is reduced by condensate banking when the bottom hole flowing pressure drops below the dew point pressure. Among the several methods which have been proposed for condensate removal, wettability alteration of reservoir rock to intermediate gas wetting in the near wellbore region appears to be one of the most promising techniques. In this work, we report use of a nanofluid to change the wettability of the carbonate and sandstone rocks to intermediate gas wetting. Application of nanofluid in the wettability alteration of carbonate and sandstone rocks to gas wetting has not been reported previously and is still an ongoing subject. Static and dynamic contact angle measurements, along with imbibition tests, have been performed to investigate the wettability of carbonate and sandstone rocks in presence of nanofluid. It was found that the nanofluid used in this work can considerably change the wettability of both surfaces to preferentially gas wetting in just one day of ageing time. We also report the effect of initial oil saturation and ageing time on the nanofluid capability for wettability change. Initial oil saturation reduces the impact of the nanofluid on wettability change, and hence, a pre-treatment before using nanofluid is necessary. In addition to these small slab-scale experiments, applicability of nanofluid in wettability alteration of sandstone rocks to gas wetting is also investigated in core scale. The results of core displacement tests confirm the ability of nanofluid to change the rock wettability from liquid wetting to gas wetting in core samples. They also show the effectiveness of chemical treatment in subsurface conditions.

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Section: Introductionmentioning

confidence: 99%

Wettability Alteration of Reservoir Rocks from Liquid Wetting to Gas Wetting Using Nanofluid

et al. 2015

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“…As the pressure drops below the dew-point pressure, condensate accumulates at the wellbore in high saturations and reduces gas relative permeability (Barnum et al 1995;El-Banbi et al 2000). The injection of a volatile solvent such as an alcohol has been implemented to remove the accumulated liquid (Ahmed et al 1998;Du et al 2000;Walker et al 2000;Al-Anazi et al 2005b) at the wellbore to increase gas well deliverability.…”

Section: Introductionmentioning

confidence: 99%

Permanent Alteration of Porous Media Wettability from Liquid-Wetting to Intermediate Gas-Wetting

Firoozabadi

2010

Transp Porous Med

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Wettability of Berea and low permeability reservoir rocks are permanently altered from liquid-wetting to intermediate gas-wetting. We use water and decane as model liquid, and air and nitrogen as model gas in the experiments. New chemicals with various functional groups are used in the wettability alteration. We perform compositional analyses of the treated chemical solutions extracted from rock treatment by gas chromatography-mass spectrometry (GCMS) and by inductively coupled plasma-mass spectrometry (ICPMS). The analyses demonstrate reaction between the chemicals and the rock substrate. There is no measurable change in permeability from the chemical reaction for the low molecular weight chemicals. The results reveal the permanent alteration of wettability. Tests are conducted to measure contact angle, spontaneous imbibition, and flow to assess the effect of wettability alteration on flow performance as a function of chemical concentration and functionality. For Berea, the contact angle for the water-air-rock is altered from 0 • to ∼150 • depending on the chemical concentration. For the reservoir rock, the contact angle is altered from ∼70 • to ∼130 • . As a result of the treatment, the water flow rate may increase two and a half times for a given pressure drop in the Berea. The permanent alteration of wettability with the new chemicals is intended for prevention of water blocking in gas production from tight reservoirs. Instead of hydraulic fracturing when water is introduced in formations with most of the water retained by the water-wet rocks, one may use the new chemical surfactants in fracturing to avoid water retention for high gas well productivity.

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“…El-Banbi et al 28 showed that the well productivity of vertical wells in a moderately rich gas condensate reservoir initially decreased rapidly and then increased as the reservoir was depleted. This phenomenon was explained by compositional simulation.…”

Section: Condensate Blockingmentioning

confidence: 99%

Gas Condensate Damage in Hydraulically Fractured Wells

Ravari

Wattenbarger

Ibrahim³

2005

SPE Asia Pacific Oil and Gas Conference and Exhibition

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This project is a research into the effect of gas condensate damage in hydraulically fractured wells. It is the result of a problem encountered in producing a low permeability formation from a well in South Texas owned by the El Paso Production Company. The well was producing from a gas condensate reservoir. Questions were raised about whether flowing bottomhole pressure below dewpoint would be appropriate. Condensate damage in the hydraulic fracture was expected to be of significant effect.In the most recent work done by Adedeji Ayoola Adeyeye, this subject was studied when the effects of reservoir depletion were minimized by introduction of an injector well with fluid composition the same as the original reservoir fluid. He also used an infinite conductivity hydraulic fracture along with a linear model as an adequate analogy. He concluded that the skin due to liquid build-up is not enough to prevent lower flowing bottomhole pressures from producing more gas.This current study investigated the condensate damage at the face of the hydraulic fracture in transient and boundary dominated periods when the effects of reservoir depletion are taken into account. As a first step, simulation of liquid flow into the fracture was performed using a 2D 1-phase simulator in order to help us to better understand the results of gas condensate simulation. Then during the research, gas condensate models with various gas compositions were simulated using a commercial simulator (CMG). The results of this research are a step forward in helping to improve the management of gas condensate reservoirs by understanding the mechanics of liquid build-up. It also provides methodology for quantifying the condensate damage that impairs linear flow of gas into the hydraulic fracture.

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Investigation of Well Productivity in Gas-Condensate Reservoirs

Cited by 43 publications

References 13 publications

Wettability Alteration of Reservoir Rocks from Liquid Wetting to Gas Wetting Using Nanofluid

Wettability Alteration of Reservoir Rocks from Liquid Wetting to Gas Wetting Using Nanofluid

Permanent Alteration of Porous Media Wettability from Liquid-Wetting to Intermediate Gas-Wetting

Gas Condensate Damage in Hydraulically Fractured Wells

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