Nitrogen Injection vs. Gas Cycling in Rich Retrograde Condensate-Gas Reservoirs

Siregar, Simon; Hagoort, Jacques; Ronde, Hidde

doi:10.2118/22360-ms

Cited by 26 publications

(12 citation statements)

References 3 publications

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“…• re-perforating the wellbore, and solvent injection (Al-Anazi et al 2005;Liangui et al 2000;Alzate et al 2006) • dry gas injection (condensate re-vaporization) (Smith and Yarborough 1968;Shi et al 2001) • water injection, nitrogen injection to drive condensate back (Siregar et al 1992) • increasing reservoir contact using horizontal well (Muladi and Pinczewski 1999) • hydraulic fracturing, and near wellbore wettability alteration are additional examples to mention Apart from the wettability alteration method, other methods are not permanent solutions and the condensate bank will re-form (Li and Firoozabadi 2000a). The latter authors (2000b) studied the gas condensate system using a phenomenological network model and investigated the effects of interfacial tension, gravity, flow rate, contact angle hysteresis and network size on the critical 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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“…For carbonate reservoirs, acids can be used to dissolve part of the rock and create fractures or wormholes Schechter and Gidley 1969). For sandstone reservoirs, the main target of acidizing and acid treatments is to remove the formation damage caused by drilling, workover, or completion processes, and thus to restore the original permeability of the formation (Smith and Hendrickson 1965;Gidley 1985). Al-Anazi et al (2006) examined the applications of alcoholic acids to stimulate both carbonate and sandstone gas reservoirs.…”

Section: Acidizingmentioning

confidence: 99%

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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“…The accumulated condensate can be produced during the puff process [18,19]. The efficiency of different gas injection modes has been investigated [20][21][22][23][24][25][26][27][28][29]. The huff-n-puff process consists of three stages: huff (injection), soaking, and puff (production).…”

Section: Introductionmentioning

confidence: 99%

Performance Evaluation of CO2 Huff-n-Puff Gas Injection in Shale Gas Condensate Reservoirs

Meng

et al. 2018

Energies

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When the reservoir pressure is decreased lower than the dew point pressure in shale gas condensate reservoirs, condensate would be formed in the formation. Condensate accumulation severely reduces the commercial production of shale gas condensate reservoirs. Seeking ways to mitigate condensate in the formation and enhance both condensate and gas recovery in shale reservoirs has important significance. Very few related studies have been done. In this paper, both experimental and numerical studies were conducted to evaluate the performance of CO2 huff-n-puff to enhance the condensate recovery in shale reservoirs. Experimentally, CO2 huff-n-puff tests on shale core were conducted. A theoretical field scale simulation model was constructed. The effects of injection pressure, injection time, and soaking time on the efficiency of CO2 huff-n-puff were examined. Experimental results indicate that condensate recovery was enhanced to 30.36% after 5 cycles of CO2 huff-n-puff. In addition, simulation results indicate that the injection period and injection pressure should be optimized to ensure that the pressure of the main condensate region remains higher than the dew point pressure. The soaking process should be determined based on the injection pressure. This work may shed light on a better understanding of the CO2 huff-n-puff- enhanced oil recovery (EOR) strategy in shale gas condensate reservoirs.

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Nitrogen Injection vs. Gas Cycling in Rich Retrograde Condensate-Gas Reservoirs

Cited by 26 publications

References 3 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

Mitigation of the Effects of Condensate Banking: A Critical Review

Performance Evaluation of CO2 Huff-n-Puff Gas Injection in Shale Gas Condensate Reservoirs

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