An Improved predictive tool for liquid in a Gas well
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As the search for natural gas becomes increasingly high due to its high demand worldwide, the oil and gas
industry is faced with the challenge of liquid loading in gas or condensate wells. It is imperative to properly
design and predict the operational parameters necessary for handling flow assurance challenges due to
simultaneous flow of gas with liquid. The model of Guo et al is the most recent systematic approach for
predicting liquid loading in gas well. However, it did not account for the accumulation and kinetic terms in the
momentum energy equation used to estimate bottom-hole pressure in a gas/oiVwater/solid four phase flowing
well. The two neglected terms in Guo et al formulation have significant e ffects on the gas well operational
parameters such as the minimum gas flow rate for preventing liquid loading.
This paper presents an improved model that describes a systematic approach for estimating liquid loading in a gas
well without neglecting any term in the fundamental momentum equation. The results obtained showed that at the
early production time where initial trans ience at the onset of flow is experienced, the critical gas flow rate
obtained from the new model is lower than that predicted from Guo et al model due to inclusion of accumulation
term while at the later production time, the critical gas flow rate obtained becomes higher than that predicted from
Guo et al model and increases as the transient period elapses. Resu Its further show that at some point during
production, the minimum energy required to lift liquids out of the well bore is more than that required at the earlier
stage of production. The new model is reasonable, reliable and better when compare with Turner et al and Guo et
al models. It is useful for operators to refme their procedures and better manage the risk of liquid loading during
natural gas production.
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TP Chemical technology