Temperature Prediction Model for Flowing Distribution in Wellbores and Pipelines

Abstract

AbstractDown-hole temperature data are important information needed to understand flowing conditions. Since wellbore temperature profile is affected by inflow profiles, it is then possible to predict inflow of fluid into the wellbore.While gas production usually causes a temperature decrease due to Joule Thomson effect water entry result in warming of the wellbore. Warmer water entry is as a result of inflow from a warmer aquifer zone due to water coning. Water entry by water coning can therefore easily be detected from temperature profile since it increases the wellbore temperature.In this study, we successfully developed a temperature prediction model which calculates temperature profiles for fluid flowing in the wellbore and considers Joule Thomson coefficient as a function of mass flow rate of the fluid phases (oil, water, and gas). We modified the Alves et al temperature equation into three phase temperature equation and it was used to predict water and gas inflow into the wellbore. Correlations that can be applied to oil field ranges of temperature and pressure were used to determine fluid properties. The model was used to investigate the effect of gas and water entry that created change in temperature profile along the wellbore. The temperature equation can be applied to pipelines or production and injection wells under single phase, two phase, and three phase flow for horizontal, vertical, and inclined wellsCases were considered to analyze the effect of water and gas entry into the wellbore. Fluid inflow was predicted from the temperature profile, the result shows that water entry increases wellbore temperature and gas entry decreases wellbore temperature.