Modeling of multiphase flow through chokes

Shao, Huaishuang; Jiang, Lei; Liu, Lei; Zhao, Qinxin

doi:10.1016/j.flowmeasinst.2018.02.015

Cited by 8 publications

(1 citation statement)

References 24 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Therefore, theoretical and analytical models were the predominant methods used then to predict flow rate through chokes. Due to the slippage effect that occurs between the gas and liquid phases as a result of density difference (Shao et al, 2018), slip models were developed as part of theoretical models.…”

Section: Theoretical Modelsmentioning

confidence: 99%

Modelling oil and gas flow rate through chokes: A critical review of extant models

Agwu

Okoro

Sanni

2022

Journal of Petroleum Science and Engineering

View full text Add to dashboard Cite

Section: Theoretical Modelsmentioning

confidence: 99%

Modelling oil and gas flow rate through chokes: A critical review of extant models

Agwu

Okoro

Sanni

2022

Journal of Petroleum Science and Engineering

View full text Add to dashboard Cite

Upper limit estimate to wellhead flowing pressure and applicable gas production for a downhole throttling technique in high-pressure–high-temperature gas wells

Wang,

Qin,

Zhang

et al. 2024

J Petrol Explor Prod Technol

View full text Add to dashboard Cite

In recent years, China has explored and exploited several high-pressure deep gas fields. Normally, high-pressure gas wells are gathered and processed through multichoke manifolds on well sites, creating hazards such as high wellhead flowing pressure (Pt) and high risk for on-site operation personnel. Moreover, downhole chokes have been used in place of surface chokes. In doing this, the Joule–Thomson (JT) effect is geothermally regulated, alleviating the formation of hydrates in surface facilities. However, its applicability to high-pressure gas wells is less explored. In an effort to guide its use, the objective of this study is to set selection criteria in terms of the allowable wellhead Pt and gas flow rate. First, isenthalpic lines are separately estimated for dry gas and high liquid hydrocarbon (LHC) content gas condensate at various inlet temperatures with the use of commercial software. Next, by analysis of the resulting isenthalpic curves, several results are obtained on the JT inversion curves and throttling process through a choke. Third, building on these insights, a method for projecting the maximum Pt is presented, leading to a value of 52.5 MPa. Finally, multiparameter models are separately run for two deep gas wells (8100 m and 5000 m), reinforcing the result of the pressure upper limit while maintaining a maximum daily gas production of 14 E4 m3. Both upper limits with a maximum Pt of 52.5 MPa and daily gas production of 14 E4 m3 are corroborated with field data records. These findings are vital to the selection of a viable high-pressure gas well for applying the downhole throttling technique.

show abstract