Artificial Lift Techbook 2019

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Page 40 of 59 | April 2019 | 39 ARTIFICIAL LIFT: TECHNOLOGY 50,000 miles. You can run the car until the engine falls out or you can get an oil change. "With traditional ESPs it is not practical to per- form maintenance, so the system runs to failure. What we're doing now is pulling ESPs for main- tenance based on time or if there is any indication that there might be a problem. The advantage is in pulling it in a scheduled pull, using simple, low-cost slickline," Malone emphasized. The associated lost production is two or three days for the workover. At the same time, if an operator needs to modify the pump, do a cleanout or whatever else, it can do that as well. Currently the industry is in a run-to-failure mode. With the ability to go in on slickline and pull a working ESP without killing the well, the cost of maintaining the ESP is pretty small. "The idea of preventive maintenance of ESPs com- pletely makes sense because then it is a scheduled workover. You don't have production downtime. You're not repairing equipment, you're maintaining the equipment. We pull systems out of the ground. We rebuild and refurbish them at one-third the cost of a new system, and it goes back in the next well, which is a complete change in the mode of operating an ESP," he said. There are two new technologies that are impacting ESP installations. The first is the development of a very high-density PMM. That is important because the ESP motor must now fit inside the tubing instead of inside the casing. Also it has to be short enough so that it can be deployed with a wireline lubricator. "You want a very high-power motor in a very small package," Malone said. The second technology is a wet connector that sits in a dock that the ESP plugs into when it is tripped into the well. "Today if you look at a lot of the deepwater assets, operators would choose to have ESPs in those wells to optimize recovery and field economics. But the cost of an intervention in deep water can be in the hundreds of millions of dollars. The ability to install and retrieve an ESP without pulling the tubing makes that practical whereas a conventional ESP system wouldn't be," he noted. Tapping into IIoT There is value in monitoring and controlling differ- ent applications on the wellpad whether these are artificial lift, compression management, vapor recov- ery units, chemical management or basic production data monitoring, said WellAware's Morgan. "We are seeing companies have opportunities to improve operational efficiencies and well performance by augmenting existing products or services more effi- ciently with our IIoT automation solution. This often leads to other potential revenue streams that they can explore with the quality and resolution of data they are now tracking and trending," he explained. Morgan described WellAware as a full-stack IoT to the cloud company with hardware, software, commu- nication and analytics pieces are managed internally. The company has two pieces of hardware that are used in the development of custom solutions—the WellAware Integrated Real- time Controller (WIRC) Gateway Plus device and the WIRC EDGE device. Both bring intelligence to the "edge" and result in higher frequency and higher resolution data. "The Gateway Plus device is really a remote terminal unit [RTU] or a cloud ter- minal unit with low power utilization. This device has multiple input/outputs [I/Os] that cover pretty much anything you need for most oil and gas applica- For the AccessESP system, the Tubing Run Dock Connector (or permanent completion) is on the right, while the Thru-Tubing Retrievable Assembly is shown on the left, showing the mating electrical connector in its position when deployed and connected. (Photo courtesy of AccessESP)

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