Transient pressure test analysis of horizontal wells in gas condensate reservoirs: Evaluation of conventional multi-phase pseudo-pressure solutions

Shahbazi, Sh.; Maarefvand, Parviz; Gerami, Sh.

doi:10.1016/j.petrol.2016.05.046

Cited by 8 publications

(5 citation statements)

References 30 publications

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“…This may delay water coning in water drive reservoirs. The studies have been proved that critical production rate of horizontal wells is 3-20 times greater than that of vertical wells (Giger, 2013;Shahbazi et al, 2016;Razavi et al, 2017).…”

Section: Introductionmentioning

confidence: 99%

Simulation study of controlling water coning in oil reservoirs through drilling of horizontal wells

Dabiri¹,

Karaei²,

Azdarpour³

2017

Biosci. Biotech. Res. Comm

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Oil production is affected by the reservoir pressure, where the higher the reservoir pressure, the higher the production rate. In most cases, water is also produced with oil, which can cause several negative issues. In oil wells, after a short period of oil production, early water production will cause serious decrease in oil production. Actually water coning is an event in which water and oil surfaces will move simultaneously to the well perforation. This event, if occurs in a well, will affect the well production and will increase the costs. Consequently, the production life of the well will be shortened. This paper presents the results of simulation study of an under saturated oil reservoir with no primary gas cap present in the reservoir with oil API gravity of 35. The feasibility of water coning remedy through drilling new horizontal and vertical wells was investigated using ECLIPSE software. The simulation results showed that water production rate is increased with increasing the oil production rate from the reservoir. In addition, water coning was signifi cantly reduced with drilling new horizontal and vertical wells. However, horizontal wells found to be more effective than the vertical wells. The oil production rate increased with horizontal wells while water production rate decreased signifi cantly.

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Section: Introductionmentioning

confidence: 99%

Simulation study of controlling water coning in oil reservoirs through drilling of horizontal wells

Dabiri¹,

Karaei²,

Azdarpour³

2017

Biosci. Biotech. Res. Comm

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“…Abdolnabi and Gringarten applied composite models to horizontal wells. , Bozorgzadeh and Kgogo each gave an opinion that the type curves of lean and medium-rich condensate gas fluids have three-zone radial composite behavior. , However, rich gas fluids exhibit only two-region radial composite behavior . Shahbazi and Zhang proposed an analytical model to explain well test data in gas condensate reservoirs which provided a detailed explanation of the pressure transient analysis curve characteristics for horizontal wells. , Li presented a semianalytical model considering different gas components of the gas condensate reservoir . Dastan proposed a semianalytical model for natural fractured reservoirs under the condition of oil–water two-phase flow .…”

Section: Introductionmentioning

confidence: 99%

“… 20 Shahbazi and Zhang proposed an analytical model to explain well test data in gas condensate reservoirs which provided a detailed explanation of the pressure transient analysis curve characteristics for horizontal wells. 21 , 22 Li presented a semianalytical model considering different gas components of the gas condensate reservoir. 23 Dastan proposed a semianalytical model for natural fractured reservoirs under the condition of oil–water two-phase flow.…”

Section: Introductionmentioning

confidence: 99%

Semianalytical Modeling for Multiphase Flow in a Fractured Low-Permeability Gas Condensate Reservoir

Yin,

Cheng,

Liu

et al. 2023

ACS Omega

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During the production of fractured low-permeability gas condensate reservoir (FLPGCR), a phase transition takes place in both the formation and wellbore, resulting in multiphase flow when the pressure drops below the dew point pressure. Additionally, the presence of fractures causes the formation of stress-sensitive characteristics. Nevertheless, traditional analytical models, such as the two-region model or three-region model, overlook the coupling impact of the above factors, which could lead to incorrect pressure transient response and erroneous estimation of well and formation parameters. Therefore, this work presents a semianalytical model for an FLPGCR considering the effects of multiphase flow, stress-sensitive, and wellbore phase redistribution. The gas condensate reservoir is divided into N banks, and the radial fluid saturation variation is modeled by multiple annular reservoirs with a constant saturation in each annular reservoir. The behavior of a fractured reservoir is modeled by using the dualporosity model. The Pedrosa transform was utilized to address the nonlinear differential equation arising from stress-sensitive behavior. To verify the semianalytical solution, it was compared with numerical simulation results from CMG. The results showed that there are 10 flow regimes for the proposed model. The shape of the type curve has the potential to identify the degree of blockage within the FLPGCR. The wellbore phase redistribution only affects the first transitional-flow regime, which slows the rate of pressure drop. The stress sensitivity will lead to the upward characteristic of the curve in a later stage. More attention should be paid to the upward pressure derivative curve at late times, which is conventionally regarded as the effect of a closed boundary when it may not be the case. In addition, the shape factor and composite radius may obscure the radial flow regime. Finally, the proposed model was applied to interpret the pressure measurements recorded from the Bohai field in China, which exhibits a better fitting quality than the traditional models.

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“…The flow behavior and well test interpretation of gas condensate systems by the above-mentioned methods have been widely discussed in the literature (Gringarten et al 2000(Gringarten et al , 2006Bozorgzadeh and Gringarten 2006;Xu and Lee 1999;Mazloom and Rashidi 2006;Yousefi et al 2014;Shahbazi et al 2016). However, limited publications deal with volatile oil reservoirs below the P b (Sharifi and Ahmadi 2009;Sanni and Gringarten 2008).…”

Section: Introductionmentioning

confidence: 99%

Volatile oil well test analysis: application of two-phase pseudo-pressure approach

Baniasadi

Rashidi

2019

J Petrol Explor Prod Technol

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This study investigates flow behavior in the volatile oil reservoirs with two-phase flow around the wellbore and the application of two-phase pseudo-pressure function for well test analysis in such volatile oil reservoirs. To this end, flow behavior and saturation profile of the volatile oil reservoirs with flowing bottom-hole pressure below the bubble point pressure are investigated using a synthetic reservoir model. Subsequently, well test behavior of this reservoir in drawdown and buildup tests are examined. Finally, the application of two-phase pseudo-pressure concept is examined for analyzing well test data of the volatile oil reservoir. It is shown that two-phase flow near the wellbore causes a composite behavior in well test data with decreasing mobility during drawdowns and increasing mobility during buildups. Moreover, employing normalized two-phase pseudo-pressure function introduced in this study is found to be a suitable method for well test analysis in volatile oil reservoirs. Using the aforementioned method, effective permeability and wellbore skin are estimated by eliminating the effect of gas saturation on the well test results.

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Transient pressure test analysis of horizontal wells in gas condensate reservoirs: Evaluation of conventional multi-phase pseudo-pressure solutions

Cited by 8 publications

References 30 publications

Simulation study of controlling water coning in oil reservoirs through drilling of horizontal wells

Simulation study of controlling water coning in oil reservoirs through drilling of horizontal wells

Semianalytical Modeling for Multiphase Flow in a Fractured Low-Permeability Gas Condensate Reservoir

Volatile oil well test analysis: application of two-phase pseudo-pressure approach

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