Permeability, Skin, and Inflow-Profile Estimation From Production-Logging-Tool Temperature Traces

Abstract

Summary Temperature traces from multiple rates are used to estimate the production-inflow profile and layer permeability and skin by use of a transient coupled reservoir/wellbore model. Production-logging-tool (PLT) temperature traces from two rates show heating of approximately 6–11°F above the geothermal because of the Joule-Thomson expansion of the reservoir oil. Production is single-phase oil from a high-pressure oil reservoir. Nonlinear regression was used to automatically adjust the layer permeability and skin values until the observation temperature traces from both rates were matched. History matching the temperature data provides a quantitative estimate of the skin and permeability within each contributing layer; this cannot be obtained from conventional pressure-transient analysis, which, unless for highly specialized cases, provides only a single value of permeability and skin. The production-inflow profile is then constructed by use of the history-matched layer permeability and skin values. In addition to the wellbore-temperature profiles, temperature and pressure profiles within the reservoir will be shown that illustrate the relative effect of the reservoir permeability and skin on the wellbore-temperature responses. The approach in this paper is different from many of the previous studies in the literature, in which only a single temperature trace is history matched and often under the assumption of steady-state conditions. Furthermore, no studies were found in which multiple temperature traces were matched by use of a transient model in which the temperature data were field data as opposed to synthetic data. Information on the coupled reservoir/wellbore model and the optimizer will be provided.

A Novel Temperature Prediction Model Considering Stress Sensitivity for the Multiphase Fractured Horizontal Well in Tight Reservoirs

“…During the production of the horizontal well, water (fracturing fluid) flows into the wellbore, resulting in a decrease in wellbore temperature. (2) The fracture half-length, water production, and formation permeability have been identified as the main factors affecting the wellbore temperature of two-phase flow multistage fractured horizontal wells in a tight reservoir. (3) The model was applied to interpret the DTS temperature profile of a multistage fractured horizontal well in a tight oil reservoir.…”

“…Obtaining an accurate production profile of the fractured horizontal well is the key to evaluating the effectiveness of fracturing. The production profile of multistage fractured horizontal wells can be directly measured by the production logging instrument [2,3]. However, the PLT instrument is impeded from accurate wellbore flow data by the complexity of the multiphase fluid flow pattern in the horizontal wellbore and the difficulty of operating the PLT instrument.…”

Evaluation of the Release Mechanism of Sustained-Release Tracers and its Application in Horizontal Well Inflow Profile Monitoring

“…At present, a few studies have proposed that the numerical simulation method can be used to predict the inflow profile; however, the numerical simulation model requires a lot of reservoir parameters, which impacts the accuracy of the prediction results. , The conventional production logging tool is the most successful inflow profile testing method, but there are still some limitations of this approach . For instance, the technology involves a one-time test that cannot be monitored over a long period and the requirement of a well-like structure that allows the test instrument to be run within the annulus makes it unsuitable for different types of horizontal wells. , The distributed temperature sensing is a newly developed technology that can monitor the real-time inflow profile . However, due to the lack of accurate inversion approaches and the temperature measurement performance of fiber, it is difficult to accurately monitor the inflow profile .…”

“…7 For instance, the technology involves a one-time test that cannot be monitored over a long period and the requirement of a well-like structure that allows the test instrument to be run within the annulus makes it unsuitable for different types of horizontal wells. 8,9 The distributed temperature sensing is a newly developed technology that can monitor the real-time inflow profile. 10 However, due to the lack of accurate inversion approaches and the temperature measurement performance of fiber, it is difficult to accurately monitor the inflow profile.…”