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Wellbore dynamics is one of the key factors in reservoir testing, acting as a bridge between the reservoir and surface measurements. The objective of this research is to address the challenges encountered in well control and highlight the outcomes of employing wellbore dynamic simulation to enhance the safety of formation tester (FT) sampling and deep transient tests (DTT) conducted in wells, with a special emphasis on pre-job simulations multi-parameter sensitivity analysis. This effort is geared towards advancing our comprehension of the interaction between hydrocarbons and wellbore mud during and following FT pump-out operations. The most recent advancement in DTT technology allows for the pumping of a larger volume of hydrocarbons into the wellbore, when compared to the operation of a conventional formation tester. While conducting DTT, formation fluids pumped from the well are mixed with drilling mud from the surface through a circulation sub into the annulus. This mixture of fluids is then circulated out from the annulus to the surface during the flowing period. It is imperative to possess a thorough comprehension of these procedures to ensure well control safety. Consequently, the utilization of a dynamic multiphase flow simulator that considers the interactions between downhole pumped hydrocarbons and drilling fluids becomes crucial to enhance the accuracy of pressure simulations during the DTT operation. Given the paramount importance of safety in oil and gas operations, a cloud-based wellbore dynamics simulator enables precise quantification of drilling fluid adjustments, circulation rates, hydrocarbon composition, downhole pump rates, well depth, hole diameter, overbalance pressure, and pump duration for various FT design sequences. This allows for accurate forecasting of downhole well pressure and the distribution of free gas throughout the well, adjusting these parameters as needed. Subsequently, we will explore scenarios with kick potential and risk mitigation strategies. This paper showcases a total of 15 case studies (different hydrocarbon types and overbalance scenarios), where cloud-based wellbore fluid simulations were performed for different flow rate scenarios, and to predict the potential well control situations. A special emphasis was given to the near critical hydrocarbon fluids such as condensate, volatile oil, and wet gas.
Wellbore dynamics is one of the key factors in reservoir testing, acting as a bridge between the reservoir and surface measurements. The objective of this research is to address the challenges encountered in well control and highlight the outcomes of employing wellbore dynamic simulation to enhance the safety of formation tester (FT) sampling and deep transient tests (DTT) conducted in wells, with a special emphasis on pre-job simulations multi-parameter sensitivity analysis. This effort is geared towards advancing our comprehension of the interaction between hydrocarbons and wellbore mud during and following FT pump-out operations. The most recent advancement in DTT technology allows for the pumping of a larger volume of hydrocarbons into the wellbore, when compared to the operation of a conventional formation tester. While conducting DTT, formation fluids pumped from the well are mixed with drilling mud from the surface through a circulation sub into the annulus. This mixture of fluids is then circulated out from the annulus to the surface during the flowing period. It is imperative to possess a thorough comprehension of these procedures to ensure well control safety. Consequently, the utilization of a dynamic multiphase flow simulator that considers the interactions between downhole pumped hydrocarbons and drilling fluids becomes crucial to enhance the accuracy of pressure simulations during the DTT operation. Given the paramount importance of safety in oil and gas operations, a cloud-based wellbore dynamics simulator enables precise quantification of drilling fluid adjustments, circulation rates, hydrocarbon composition, downhole pump rates, well depth, hole diameter, overbalance pressure, and pump duration for various FT design sequences. This allows for accurate forecasting of downhole well pressure and the distribution of free gas throughout the well, adjusting these parameters as needed. Subsequently, we will explore scenarios with kick potential and risk mitigation strategies. This paper showcases a total of 15 case studies (different hydrocarbon types and overbalance scenarios), where cloud-based wellbore fluid simulations were performed for different flow rate scenarios, and to predict the potential well control situations. A special emphasis was given to the near critical hydrocarbon fluids such as condensate, volatile oil, and wet gas.
Wellbore dynamics play a crucial role in reservoir testing, serving as a crucial link between the reservoir and surface measurements. This research aims to tackle the challenges faced in well control and highlight the benefits of using wellbore dynamic simulation to improve the safety of formation tester (FT) sampling and deep transient tests (DTT) conducted in wells. Special attention is given to pre-job simulations and multi-parameter sensitivity analysis. The focus is on advancing our understanding of the interaction between hydrocarbons and wellbore mud during and after FT pump-out operations. Recent advancements in DTT technology allow for the pumping of larger volumes of hydrocarbons into the wellbore compared to conventional formation tester operations. During DTT, formation fluids pumped from the well mix with drilling mud from the surface in the annulus. This fluid mixture is then circulated out from the annulus to the surface during the flowing period. Understanding these procedures is crucial for ensuring well control safety. Therefore, the use of a dynamic multiphase flow simulator that considers the interactions between downhole pumped hydrocarbons and drilling fluids becomes essential to improve the accuracy of pressure simulations during DTT operations. To enhance safety in oil and gas operations, a cloud-based wellbore dynamics simulator allows for precise quantification of drilling fluid adjustments, circulation rates, hydrocarbon composition, downhole pump rates, well depth, hole diameter, overbalance pressure, and pump duration for various FT design sequences. This enables accurate forecasting of downhole well pressure and the distribution of free gas throughout the well, with adjustments made as necessary. Furthermore, scenarios with kick potential and risk mitigation strategies are explored. This paper presents 15 case studies involving different hydrocarbon types and overbalance scenarios, where cloud-based wellbore fluid simulations were conducted for various flow rate scenarios to predict potential well control situations. Special attention is given to near-critical hydrocarbon fluids such as condensate, volatile oil, and wet gas.
Exploration and development drilling in offshore China is extending to Paleogene formations that are characterized by low-resistivity-contrast and low-permeability rocks. These formations have become a focus for increasing reserves and production. During exploration activities, these low-resistivity, low-formation-contrast formations have been critical and challenging for formation evaluation because the geological structure and lithology are more complex than in previously discovered fields. Differentiating hydrocarbon from water using petrophysical interpretation has a large uncertainty in these formations. Confirming the fluid type using conventional formation testing technology has been extremely challenging because the produced fluid is mainly mud filtrate, which is no use for fluid confirmation. A new-generation intelligent wireline formation testing platform consisting of a focused radial probe inlet and a dual flowline with dual downhole pumps to enable flexible focused sampling was applied to three appraisal wells in offshore China. Given the larger flow area of the probe system, flow tests could be conducted in as low as 0.004-md/cP mobility zones (the tightest on record), and fluid identification could be performed in-situ while the fluid flowed through a group of sensors. Previous formation testing in these formations had been challenged because the water-based mud system caused suspension of solid particles (debris and mud solids). Filter and standoff accessories available with the intelligent wireline formation platform enabled designing a fit-for-purpose approach to overcome this challenge in a short time. This dedicated design resulted in increased efficiency in water sampling compared to previous testing done by the operator. Clean water resistivity, measured in situ, can now be applied to this new exploration block to recalculate the water saturation for reserve estimation. Whereas previous gas-water transition zone sampling was challenging because high water-based mud filtrate fractions masked the presence of formation water and formation hydrocarbon, the radial probe, combined with state-of-the-art resistivity measurements, allowed identification of gas and the measurement of formation water resistivity in a multiphase flow environment. The formation testing of these low-resistivity-contrast and low-permeability formations enabled acquisition of a 2% contaminated formation water sample in 140 minutes with formation mobility of 1 md/cP. The gas-water zone was confirmed from a dual flowline resistivity measurement and a hydrocarbon show in mobility of 1.4 md/cP.
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