Successful Installation of Curve ESP Systems in the Permian Maximizing Economics and Recovery in Highly Deviated Wellbores

Successful Installation of Curve ESP Systems in the Permian Maximizing Economics and Recovery in Highly Deviated Wellbores
1.    OBJECTIVES/SCOPE: Please list the objectives and scope of the proposed paper. (25-75 words)
Horizontal drilling is an essential technology for exploiting unconventional resources. However, wellbores often include zones with high Dog Leg Severity (DLS), which can limit the installation of Electrical Submersible Pumping (ESP) systems at the deepest possible setting depth. Placing the ESP as deep as possible is critical to maximizing recovery and cash flow. This work highlights the successful application of curve ESP systems in Permian Basin wells with DLS values of 17°/100 ft, and discusses both the challenges encountered and the potential benefits of this technology.

2.     METHODS PROCEDURES, PROCESS: Briefly explain your overall approach, including your methods, procedures and process. (75-100 words)
The industry standard tolerance for deviation is approximately 6° per 100 ft for a conventional ESP system to reliably pass through the curved section of a wellbore. In this study, deviation surveys from several wells were carefully evaluated, and stress analysis was performed to assess mechanical stresses and the potential risk of equipment failure when navigating high-DLS zones. A group of wells with elevated DLS values was selected as pilot candidates for deployment of the new curve ESP system. Well models were developed, and sensitivity analyses were conducted to evaluate the impact of pump setting depth on production performance. The ESP systems were subsequently designed and installed, with production data collected and operating parameters closely monitored.
3.     RESULTS, OBSERVATIONS, CONCLUSIONS: Please describe the results, observations and conclusions of the proposed paper. (100-200 words)
Based on stress analysis simulations, a standard ESP system wouldn’t be able to pass through zones with high DLS. In the first install a conventional ESP was installed and the system setting depth was shallow. The unit was subsequently pulled and replaced with a curve ESP system, allowing for a deeper setting depth while passing through zones with DLS of 12°/100 ft. The pump setting depth was increased from 6,660 ft to 7,800 ft—an additional 1,100 ft. As a result, production increased by 75%, adding 550 BOPD and generating approximately USD 1 million in the first 30 days of operation. The unit has since demonstrated stable operating trends with minimal X- and Y-axis vibration, indicating limited mechanical wear.
In a separate case study, two curve ESP systems were deployed in a well with DLS of 17°/100 ft consecutively. The first unit achieved a run life of 802 days, while the second operated for 551 days, further demonstrating the reliability and field-proven performance of this technology.

4.     Please explain how this paper will present novel (new) or additive information to the existing body of literature that can be of benefit to a practicing engineer. (25-75 words)
The standardized industry practice for deploying ESP systems in wells with high DLS is to avoid traversing the curved section by setting the pump at a shallower depth. Alternatively, operators may attempt to pass through by reducing pump length, which typically requires decreasing the number of stages, thus limiting lift capacity and selecting smaller motors, which reduces available power. Both approaches compromise system performance and production potential. The curve ESP system provides a viable solution to these mechanical and hydraulic limitations, enabling reliable installation at greater depths and unlocking the full production capacity.
In short, the post is important because it demonstrates Baker Hughes’ thought leadership, technical expertise, and investment in the next generation of engineers, while also reinforcing their role in delivering measurable value to the energy industry.