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Logging-while-drilling (LWD) technologies have long been used for real-time formation evaluation and geosteering. Several optimization techniques for drilling and completions have been developed, based on data acquired from emerging and existing LWD technologies. In this paper, methods and techniques are presented where LWD measurements were utilized for the purpose of safely planning, drilling, and completing vertical and horizontal boreholes. Optimizing drilling and completions can be achieved by continuously monitoring for signs of deteriorating borehole conditions in data coming from different LWD sensors like density, resistivity, or ultrasonic imagers. In addition to resistivity tools known to provide shallow and deep readings, density tools provide azimuthal borehole images from two detectors of different source-detector spacings, allowing their data to have different depths of investigation (DOI). Comparison between the responses of sensors having different DOI over multiple logging passes can be used to assess wellbore deterioration over time. Emerging tools like ultrasonic LWD imagers provide high-resolution, azimuthal hole-size measurements allowing advanced evaluation of wellbore conditions. Analysis of LWD data showed the potential to identify, mitigate or eliminate existing and potential wellbore stability risks. Integrating multiple sensors of different DOI in the logging suite, and comparing their individual responses, gives more insight into the borehole conditions than analysis of single-sensor data alone. Customized workflows were established where available data from LWD was integrated with surface-data-logging (SDL) data to provide full analysis of wellbore conditions in real time. Time-lapse analysis using data acquired while tripping out of the hole revealed deterioration that was not observed in the first logging passes while drilling. Interventions were made to mitigate wellbore instability and lessons have been captured to prevent hole deterioration in subsequent wells drilled in the area. Workflows have been developed to utilize existing and emerging LWD technologies for wellbore stability monitoring. Procedures have been established to mitigate borehole deterioration, thereby optimizing operations for drilling and completions.
Logging-while-drilling (LWD) technologies have long been used for real-time formation evaluation and geosteering. Several optimization techniques for drilling and completions have been developed, based on data acquired from emerging and existing LWD technologies. In this paper, methods and techniques are presented where LWD measurements were utilized for the purpose of safely planning, drilling, and completing vertical and horizontal boreholes. Optimizing drilling and completions can be achieved by continuously monitoring for signs of deteriorating borehole conditions in data coming from different LWD sensors like density, resistivity, or ultrasonic imagers. In addition to resistivity tools known to provide shallow and deep readings, density tools provide azimuthal borehole images from two detectors of different source-detector spacings, allowing their data to have different depths of investigation (DOI). Comparison between the responses of sensors having different DOI over multiple logging passes can be used to assess wellbore deterioration over time. Emerging tools like ultrasonic LWD imagers provide high-resolution, azimuthal hole-size measurements allowing advanced evaluation of wellbore conditions. Analysis of LWD data showed the potential to identify, mitigate or eliminate existing and potential wellbore stability risks. Integrating multiple sensors of different DOI in the logging suite, and comparing their individual responses, gives more insight into the borehole conditions than analysis of single-sensor data alone. Customized workflows were established where available data from LWD was integrated with surface-data-logging (SDL) data to provide full analysis of wellbore conditions in real time. Time-lapse analysis using data acquired while tripping out of the hole revealed deterioration that was not observed in the first logging passes while drilling. Interventions were made to mitigate wellbore instability and lessons have been captured to prevent hole deterioration in subsequent wells drilled in the area. Workflows have been developed to utilize existing and emerging LWD technologies for wellbore stability monitoring. Procedures have been established to mitigate borehole deterioration, thereby optimizing operations for drilling and completions.
Lateral changes in petrophysical parameters and diagenetic effects introduce uncertainty in porosity-permeability transforms in complex carbonate reservoirs. This results in discrepancies between actual downhole production and permeability profiles in horizontal wells. Designing sophisticated completions requires high confidence in predicted permeability to achieve lateral flow equalization and maximum oil recovery. This paper presents a model, to improve lower completion design and permeability prediction, by integrating multiple technologies such as nuclear magnetic resonance (NMR), formation tester while drilling (FTWD), and imaging. Analyzing deep and ultra-deep resistivity inversions can also be used to evaluate permeability variations away from the wellbore which can affect the production profile. NMR can be used to estimate lateral permeability since the Timur-Coates model, usually used for carbonate reservoirs, honors both pore size and porosity variations. Mobility calculations obtained while drilling using formation tests are used to calibrate the Timur-Coates permeability equation. Fracture analysis based on high-resolution images can also be utilized to derive permeability. Integrating multiple sensors and after logging several wells, a reservoir-specific permeability model is developed based on unique field-specific parameters. The calibrated permeability model is then imported into completion design simulation software to design inflow control devices (ICDs). Hence, a higher confidence of lateral inflow equalization, water breakthrough delay and oil recovery maximization are achieved. The main objective of ICD is to maximize recovery by equalizing the inflow of different permeability compartments along the horizontal wellbore. Hence, permeability is a main controlling factor behind ICD design. Porosity-permeability transforms can overestimate or underestimate the permeability, especially in heterogenous carbonates. Integrating multiple LWD measurements provides improved understanding of lateral permeability changes enabling timely ICD design decisions to be taken. One of the main benefits of the customized calibrated permeability is a better prediction of simulated productivity index (PI), primarily affected by permeability profile input into completion design software and most influential in ICD design. While NMR, FTWD and imaging are sensitive to permeability variations near the wellbore, indications of formation characteristics in the far field can be indicated by analyzing deep and ultra-deep resistivity inversions. Integrating both measurements in the completions design can allow for better flow equalization and delay in the predicted water breakthrough. This paper presents an integrated workflow for enhanced permeability evaluation for a heterogeneous complex carbonate reservoir.
Ultra-Deep electromagnetic (EM) azimuthal measurements provide critical data for well placement operations, allowing real-time assessment of resistivity boundaries over 100ft from the well. Historically, 1D and 2D inversions displayed vertical boundary changes, however they do not resolve azimuthal changes. Other 3D approaches lacked real-time aspect or endured costly deployment. This paper describes integration of real-time 3D EM Inversions for both inclination and azimuth trajectory corrections, to optimize well path and increase efficiency while drilling HA/HZ wells. Triaxial ultra-deep electromagnetic borehole logging tools provide 9 component multi-frequency data from multiple receiver assemblies, logging the 3D EM field around the wellbore. Although the raw component data shows observable signal changes representing the 3D EM field, evaluating this raw data in real-time is challenging. Therefore, a 3D EM inversion was implemented to provide real-time 3D representation of the geological structure and fluid distribution around the well. The 3D EM Inversion algorithm has been optimized to return model updates within a few minutes. The near real-time process allows well placement decisions to be made very quickly to help maintain the well path within the target reservoir. Real-time monitoring of the 3D EM inversion revealed a lateral disparity in the resistivity distribution for the target reservoir. In a particular interval, the presence of higher resistivity to the right-hand side of the well bore was revealed. The increase in resistivity was identified as improved reservoir properties. The trajectory of the well was adjusted to the right, interactively adjusting the plan. As with all deviations from the plan the impact of the azimuthal turn was assessed both in terms of safety and the potential impact on running the completion, no risks were identified, and a successful turn was conducted. Using the same methodology, a turn to the left of the well bore was conducted towards the toe of the well. Optimizing a wells TVD with inclination is common, but azimuthal changes based on LWD readings are much less so. The 3D Inversion and azimuthal resistivity measurements helped to minimize the loss of the effective length of the wellbore during the drilling in a complex geological structure. The effectiveness of the azimuthal turn can be assessed by comparing the resistivity of the actual and planned trajectories, estimated to have a 24-foot separation. The actual trajectory was placed in a zone with optimum quality reservoir without loss of the effective length (100% NTG). Real-time 3D Inversion has enabled for the first time the ability to steer azimuthally based on Ultra-deep EM data, changing the hole azimuth in real-time to target improved reservoir properties. The method of correcting the well path with azimuth as well as inclination in real-time based on 3D Inversion data ensures maximum efficiency for the well placement process in complex geology which can show vertical and azimuthal variations in resistivity. The depths of detection possible with Ultra-Deep EM tools allows these decisions to be made early reducing tortuosity of the well path while revealing the position of resistivity boundaries in all directions.
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