Production data analysis of gas condensate reservoirs using two-phase viscosity and two-phase compressibility

Behmanesh, Hamid; Hamdi, Hamidreza; Clarkson, Christopher R.

doi:10.1016/j.jngse.2017.07.035

Cited by 19 publications

(8 citation statements)

References 16 publications

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“…shows that the effective permeability is dropped sharply when pressure declined, due to the condensate drop out and increasing liquid saturation. The results of effective permeabilities reconfirm the finding of Behmanesh et al, (2017);Fevang, (1995); Fevang and Whitson, (1996) and Mott, (2003), such that condensate drop out in gas condensate reservoirs leads to reduction in gas effective permeabilities. Relative permeability ratio of gas to oil (krg/kro) also determined using Eq.…”

Section: Resultssupporting

confidence: 82%

“…Transient pressure test data from high temperature heavy gas condensate well was obtained from Economides et al, (1989) and utilized to generate the IPR curves. New IPRs covers effect of condensate blockage near wellbore region as an important factor in reducing well productivity (Behmanesh et al, 2017;Chen et al, 1995;Fevang and Whitson, 1996;Gondouin et al, 1967;Rahimzadeh et al, 2016).…”

Section: Accepted Manuscriptmentioning

confidence: 99%

“…To emphasis the important of viscosity the research shows 1% error in calculating reservoir fluid viscosity resulted in 1% error in cumulative production (Al-Meshari et al, 2007;Fevang and Whitson, 1996;Hernandez;Sutton, 2005;Whitson et al, 1999). Behmanesh et al, (2017) found that using single dry gas viscosity and compressibility factor effect the performance prediction of gas condensate reservoirs. Well known method of Lee-Gonzalez-Eakin, (1966), which originally developed from natural dry gas, is used in most of PVT software due to its simplicity.…”

Section: Construction Of Pressure -Volume -Temperature (Pvt) Relationmentioning

confidence: 99%

“…In fact compressibility factor dictates gas and condensate recoveries in gas condensate reservoirs (Whitson et al, 2000(Whitson et al, , 1999. Studies by Behmanesh et al, (2017) Arukhe and Mason, (2012) elucidate that use of single phase compressibility factor underestimate the production in gas condensate reservoirs. Hence for better prediction of performance, two-phase compressibility factor correlation, developed by Rayes et al, (1992), shown in Eq.…”

Section: Accepted Manuscriptmentioning

confidence: 99%

“…The flow in this region is steady state flow, meaning what comes into Region 1 through its outer boundary, will flow at and will be produced at the surface with no net accumulation of fluid. Region 1 is the main source of deliverability loss due to condensate build up, which decreases relative permeability to gas in gas condensate reservoirs (Behmanesh et al, 2017;Bonyadi et al, 2012;Bonyadi and Rostami, 2017;Fevang and Whitson, 1996;Hekmatzadeh and Gerami, 2018;Mott, 2003;O'Dell and Miller, 1967).…”

Section: Two Phase Pseudopressure Approachmentioning

confidence: 99%

See 4 more Smart Citations

Development of inflow performance model in high temperature gas-condensate reservoirs

Faraji¹,

Ugwu²,

Nabhani³

et al. 2019

Journal of Petroleum Science and Engineering

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Inflow Performance Relationships (IPRs) are important element for reservoir engineers in the design of new wells and also for monitoring and optimizing existing wells. IPRs are used to determine optimum production of gas rate and condensate rate in a well for any specified value of average reservoir pressure and predict the performance. Jokhio and Tiab proposed a simple method of establishing IPR for gas condensate wells. The method uses transient pressure test data to estimate effective permeability as a function of pressure. Effective permeability data used to convert production bottomhole flow pressure into pseudopressure to establish well performance. Despite the effectiveness of the method, single phase correlations were used in PVT calculations of each phase, which over simplified the fluid flow in gas condensate wells. Single phase dry gas equations do not reflect the multiphase flow behaviour of gas condensate wells below the dew point. Due to this limitation Jokhio and Tiab method modified by this study and new analytical IPRs for gas condensate well proposed. The major improvement of the above method is incorporating new viscosity correlation developed by this study and using two-phase compressibility factor as key parameters for predicting gas condensate inflow performance. Therefore, the main contribution of this study is development of viscosity correlation which is a critical issue in predicting gas condensate inflow performance both above and below the dew point. Optimization techniques and nonlinear regression used to develop a new viscosity correlation for high temperature heavy gas condensate reservoirs under depletion. The application of the new model is illustrated with field example for current IPR curves. Compositional simulation study of the well performed in PIPSIM simulator. The proposal approach provides reasonable estimates of simulator input reservoir properties (e.g. IPRs). Accuracy of the new method compared with compositional simulation study. The proposed method presents average absolute relative deviation (AARD) of 5.8% for gas IPR and 7.5% for condensate IPR compare to compositional simulation results. New method provides a tool for quick estimation of gas condensate wells without need of relative permeability curves and expensive and time consuming compositional simulation.

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Section: Resultssupporting

confidence: 82%