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Artificial Lift Techbook 2018

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42 | July 2018 | hartenergy.com ARTIFICIAL LIFT: CASE STUDIES and workover costs for the project were approximately one-half of what they would have been using a rig. The rigless-deployed ESP system also reduced overall instal- lation time by 50% compared to a rig-deployed system. A second system was deployed for the operator of a mature field offshore Malaysia that was looking for an economic intervention solution to stabilize production and manage increasing water production. The well had been shut in for 18 months due to inad- equate reservoir pressure to achieve natural flow with an increasing water cut and reduced gas rates. In this first offshore installation, the system reduced work- over costs by more than 50% compared to a rig-based intervention. The system boosted oil production by 127 bbl/d after more than a year of being offline, generating thousands of dollars of additional daily revenue in the process. The third system was installed in a reservoir with high H 2 S content. Two ESPs previously installed in the same well had both failed pre- maturely due to electrical failure. A workover rig pulled the failed ESPs in August 2017 and ran the necessary completion for the rigless ESP deploy- ment. The new install operation was completed in December 2017 in half the time it took to install the first system. The well now produces at a rate of 8,000 bbl/d. In these field trials and others, the rigless-deployed ESP system consistently saved time and money on lift system installations while dramatically increasing reliability at reduced HSE risk. Other operators are looking to deploy the new ESP system to recover oil in wells that they might have otherwise abandoned due to high intervention costs. n The TransCoil system is installed through the existing completion via CT. Unlike wireline-deployed ESPs, the system can be installed through a deviation in the wellbore, allowing operators to land the ESP closer to the producing zone. (Photo courtesy of Baker Hughes, a GE company)

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