With the introduction of new technologies, the energy industry is continually challenged to explore all potential applications. An additional responsibility lies in optimizing the combination of new and existing technologies in highly deviated and horizontal wells to provide useful solutions. This paper highlights two case history examples of this undertaking.
The pilot study case at hand will demonstrate how such a technology combination provided savings in both money and time spent diagnosing wellbore conditions and performing remedial work. Logging tools were deployed using a tubing-conveyed method without the usual direct mechanical attachment of the logging tool to the string itself. This method minimized the risk of damage to the smaller-sized toolstrings and reduced the time required to log these tools by eliminating tripping of the complete workstring back to surface after each logging run.
Included within are descriptions of job planning, acquisition methods, and decisions utilizing an optimized mixture of evaluation technologies to provide results that far exceed previous achievements. The combination of log measurements included a gravel pack density tool and a downhole video surveillance camera. As a result of this approach the following information was made available to design downhole remedial operations:
areas of loss or lack of gravel pack material
indication of high water influx zones
wellbore mechanical integrity
scale and debris detection
The recompletion design has been enhanced with utilization of information provided by the logging program, including a previously unsuspected corrosion problem. Better decisions can now be made with greater confidence based on higher quality evidences.
This combined logging method was first run as a pilot project in a field where wells are often completed with a horizontal gravel pack Many wells in the pilot area and surrounding fields suffer electric submersible pump (ESP) failures, which are commonly attributed to sand production. Some of these failures had previously been traced back to ESP positioning in the wellbore. Some improvement was gained by ensuring that the pumps were not located within the tangential sections of the wellbore, which contributes to reduction in pump life.