Chemical Stimulation of Gas/Condensate Reservoirs

Kumar, Vinod; Bang, Vishal; Pope, Gary A.; Sharma, Mukul M.; Ayyalasomayajula, Padmakar S.; Kamath, Jairam

doi:10.2523/102669-ms

Cited by 11 publications

(11 citation statements)

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“…This method can provide a long‐term solution to treat damage caused by liquid accumulation. Wettability alterations using fluoro‐components have been studied extensively in the past two decades 2–7…”

Section: Introductionmentioning

confidence: 99%

Wettability alteration of gas condensate reservoir rocks to gas wetness by sol–gel process using fluoroalkylsilane

Sharifzadeh

Hassanajili

Rahimpour

2012

J of Applied Polymer Sci

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Natural gas is becoming a very important energy source in recent years. A sharp reduction has been observed in gas deliverability in many low permeability gas reservoirs due to bottom‐hole pressure drops below the dew point pressure. It is an established fact that altering the wettability of reservoir rocks from liquid wetness to gas wetness could improve the gas deliverability. In this study, a new polymeric surfactant coating for altering the wettability of Sarkhun reservoir rocks was prepared by using a sol–gel process. Perfluorodecylsilane (PFDS) and triethoxysilane (TEOS) were used to obtain an inorganic‐organic network via hydrolysis and polycondensation reactions. The effect of this method was examined by various characterization tests such as FTIR, SEM, and EDX, static contact angle and imbibition tests for wettability alteration. The experimental results revealed that, the prepared polymeric network including the terminal fluorine groups were effective and provided sufficient repelling characteristics towards oil and water. Static contact angles were raised from 30 to 130° for water, and from <5 to 60° for condensate after sol–gel treatment. © 2012 Wiley Periodicals, Inc. J. Appl. Polym. Sci., 2013

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Section: Introductionmentioning

confidence: 99%

Wettability alteration of gas condensate reservoir rocks to gas wetness by sol–gel process using fluoroalkylsilane

Sharifzadeh

Hassanajili

Rahimpour

2012

J of Applied Polymer Sci

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“…Ayyalasomayajula, SPE, and J. Kamath, SPE, Chevron Firoozabadi 33 measured a strong reversal of wetting for gas and water at 284 °F, but the treatment was less successful for gas and oil. Kumar et al 4,20 evaluated several fluorosurfactants at reservoir conditions and found significant improvement in gas and condensate relative permeabilities after chemical treatment in both Berea and reservoir sandstones. The steady state gas and condensate relative permeabilities at 145 °F, 250 °F and 275 °F using different synthetic gas-condensate fluids increased by a factor on the order of 2.…”

Section: Spe 102669mentioning

confidence: 99%

“…Figure 1 shows a schematic diagram of the core flood apparatus. 4,20 The apparatus is rated for temperatures up to 400 °F and pressures up to 10,000 psig. The maximum flow rate that can be attained is in the range of 7,000 cc/hr.…”

Section: Spe 102669mentioning

confidence: 99%

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Chemical Stimulation of Gas/Condensate Reservoirs

et al. 2006

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractSignificant productivity loss occurs in gas-condensate wells when the bottom hole flowing pressure drops below the dewpoint pressure. The decline in productivity is due to nearwell accumulation of condensate in the reservoir rock, which is significant even for wells producing very lean gas with liquid dropout values less than 1%. Many different methods such as hydraulic fracturing, dry gas injection and solvent injection have been proposed and implemented to stimulate such wells. However, all of these methods offer short-lived stimulation and are sometimes not profitable. New experimental core flooding data using chemical treatments show that the steady-state gas and condensate relative permeability in both outcrop and reservoir sandstones can be increased by a factor of 2 to 3 over a wide range of temperature (145 to 275 °F). Spectroscopic data show that the sandstone surface remains modified by the chemical even after flooding the core with large volumes of gas. A relative permeability model that includes effects such as the decrease in the residual condensate saturation after treatment and the effect of capillary number is presented. Fine-grid compositional simulations of a single-well treatment were done using the calibrated relative permeability model to investigate the performance of chemical treatments under field conditions as a function of variables such as treatment radius. These simulations show that chemical treatments have the potential to greatly increase production at low cost relative to the increased revenue since only the near-well region blocked by the condensate needs to be treated.

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“…Well deliverability reduction due to condensate blockage has been reported for some fields to reach 40 to 80% under pseudo steady-state flow of gas and condensate (Mott et al, 1999). Experimentally, more than 95% reductions in flow rates from high and low permeability rocks have been reported (Du et al, 2000;Al-Anazi et al, 2002;Kumar et al, 2006). To create and optimise reservoir development plan, including recovery strategies and productivity prediction, it is necessary to both understand and model the complex flow and phase change behaviour that occurs in gas-condensate reservoirs.…”

Section: Introductionmentioning

confidence: 99%

Gas Condensate Flow Behaviour Within Tight Reservoirs

Al-Harrasi¹,

Grattoni

Fisher

et al. 2013

All Days

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Tight gas-condensate reservoirs contain large reserves, but can be extremely costly to develop. Understanding the fundamental controls on the fluid flow behaviour of tight gas and gas-condensate reservoirs has the potential to result in more cost-effective reservoir development and help increase the world's producible reserves. The principal objective of the paper is to improve understanding of multiphase flow within tight gas-condensate reservoirs. In order to achieve this objective a series of pore-to-core scale experiments under controlled conditions were performed, followed by numerical simulation. Three methodologies were used in this study: First, pore-scale experiments in glass micromodels with liquid-liquid systems were performed to improve understanding of the phase separation and flow mechanisms at pore level. Second, coreflood experiments were performed while in-situ saturation was monitored using an X-ray CT-scanner. A newly developed liquidliquid system was used in these experiments. Flow through tight gas sandstones allowed the determination of relative permeabilities as well as determining their dependence on absolute permeability and capillary number. Third, production simulation modelling has been conducted to investigate the implications of the results.The micromodel experiments have proved extremely useful for characterizing the flow behaviour of condensate systems. The results showed that the flow mechanisms and phases' distributions were affected largely by interfacial tension, pore structure and wettability. The experimental results showed the dependence of gas-condensate relative permeabilities of tight rocks on absolute permeability and capillary number. The incorporation of the results into production simulation modelling has shown an increase of gas production up to 70% for tight gas-condensate reservoirs when capillary number effects were included.The modelling has shown that the high velocity phenomena near the production well must be taken into account for tight gascondensate reservoirs. Therefore, the current practice of modelling these reservoirs using immiscible relative permeabilities should be immediately reviewed to avoid costly and ineffective reservoir development plans.

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Chemical Stimulation of Gas/Condensate Reservoirs

Cited by 11 publications

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Wettability alteration of gas condensate reservoir rocks to gas wetness by sol–gel process using fluoroalkylsilane

Wettability alteration of gas condensate reservoir rocks to gas wetness by sol–gel process using fluoroalkylsilane

Chemical Stimulation of Gas/Condensate Reservoirs

Gas Condensate Flow Behaviour Within Tight Reservoirs

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