Browsing by Autor "J. Alberto Espinosa"

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Improving ESP Performance with Two Stages of Gas Separation in 7 Casing Case Study
(2020) Anderson Delgado; J. Alberto Espinosa; María Isabel Hernández; Luis Guanacas; Gustavo Gonzalez; William Aya
Abstract The Electrical Submersible Pump (ESP) has become one of the most popular ALS worldwide due to its capacity of lifting high fluid volumes with high efficiency, however, its application is questioned under some circumstances related to difficulties that this system presents when managing high gas rates. Even though the ESPs can handle high volumes, they are also highly affected by gas bubbles flowing through each component, affecting: the motor temperature, lifting efficiency, the integrity of the motor and cable, situations that can lead to premature failure and expensive workover operations. This is the reason why some companies decide to install a different ALS instead of an ESP. The present study shows a successful ESP optimization in combination with a new gas mitigation system that allowed to manage high GOR and GLR and avoid gas locking, low lifting efficiency, multiple shutdowns due to poor cooling in the motor, and surge production (changes on motor load). The new double stage gas mitigation system was designed to manage a GOR&gt;1,200 SCF/STB with a WC of &lt;1%, BHT of 200 °F, and 85% of free gas flowing into the pump intake. This gas separation system for ESP was complemented by installing a shrouded ESP to assure a proper cooling of the motor and to prevent the free gas to flow directly to the pump intake. This paper contains all the descriptions of each component of the 2 stage gas mitigation/separation system. The well showed a notorious production improvement and the operator was able to decrease the PIP below 630 psi (Max limitation on the Jet pump system due to low efficiency of this ALS) achieving a production increase from 300 to 700 BOPD (↑400 BOPD)
New Mechanism of Sand Management Above ESPs: Cases Study in Colombia
(2022) Anderson Delgado; J. Alberto Espinosa; María Isabel Hernández; Gustavo Gonzalez; Luis Guanacas; William Aya; Juan Perdomo
Abstract One of the most expensive artificial lift systems in the oil industry is the Electric Submersible Pump (ESP) system, hence the unavoidable need of extending the run life of wells that have installed this system. Following the need of extending the run life, a sand regulator has been designed to protect the pump during shutdowns, and it has been incorporated into traditional sand control configurations to offer extensive protection above and below the pump. This paper will explain the mechanism of the sand regulator as well as the benefit of installing this system alone above the pump or complemented with a sand control system below the pump. The candidate wells to this integrated solution were selected from MMV (Middle Magdalena Valley) and Putumayo Basins, in Colombia. The wells had sand problems history and it was necessary to review pump designs, pulling reports and sensor parameters. Well conditions such as production, tubing size, and particle size distribution were analyzed to build the best design for every single well. In the design the geometry of the well was assessed to accommodate the cable and CT (Capillary tube) line downhole. The ADN Field in Colombia is characterized by heavy oil production (API between 13-18°), with fluid production between 1,000-2,000 BFPD, with a viscosity of 270 - 3090 cP @ 122°F, water cuts oscillating depending on the waterflooding effect (Between 1% to 95%) and high fine sand production (200 – 24,000 ppm). The CH Field wells produce between 1,000 – 6,000 BFPD, with API between 17-20°, high water cuts (&gt; 77%) and a high sand production between 100 – 3,000 ppm. The wells selected had other type of sand control and management systems and were highly affected by frequent shutdowns. The Sand Regulator design was installed in 20 wells and was compared with the performance achieved using traditional sand control solutions. After the installation, production has remained stable in all the wells applied, allowing to reduce the PIP of the well of up to 400 psi. Less current consumption has been observed after each shutdown in all the wells, extending the run life of some wells up to double the average. Sensor parameters were analyzed after each pump restart to determine how difficult it was to restart operation after shutdowns. Compared to the tools installed above the ESP, this sand regulator allows flushing operation through it with flow ranges from 0.5 to 5 bpm. In addition, the unconventional design of this tool has opened the door to a new concept of ESP protection that works in wells with light or heavy oil and can be refurbished or inspected completely without cutting the tool.