Deployment of a Remotely Activated Liner Hanger System to Improve Drilling and Well Construction Efficiencies

Operators for deepwater and extended-reach wells, where daily rig costs can exceed $500k per day, are continuously exploring methods to reduce nonproductive time (NPT) and increase operational efficiency. For example, a common point of focus is liner string deployments in deepwater and highly deviated applications that predominantly employ hydraulic liner hangers. This paper presents a new liner hanger system that uses simple mud flow signals to remotely communicate with a downhole controller on the work string. The controller receives the specific activation signal from the surface and then relays that signal to the liner hanger or running tool via an acoustic signal. The results of the first test trial of the remote liner hanger system controller will be discussed. The traditional method for setting a hydraulic liner hanger includes the use of single or multiple activation balls being dropped from the surface so that pressure can be applied to the work string to function the hydraulic liner hanger and running tool. However, in deepwater and extended-reach applications, many operational issues experienced with running hydraulic liner hangers are related to not landing the ball on seat, which can lead to days of NPT. Developing a liner hanger system that does not rely on dropping activation balls from the surface nor rely on pipe manipulation can reduce the time required to run the liner hanger and minimize issues that lead to higher NPT. This new system does not require dropping activation balls from the surface, reducing the amount of running tools in the work string and the amount of time required to set the liner hanger. The system also allows the use of a solid liner hanger body, eliminating the potential leak paths inherent to hydraulic liner hangers. The results will demonstrate the first deployment of the remote system controller in a well, confirming that it detects various remote commands from the surface. The results will also demonstrate how the system enables operators to choose the activation method depending on the well and rig conditions, for example, varying the flow rate activation signals. This system and method can improve well construction efficiencies and is a step in the direction of a smarter and safer oilfield through more automated operations.