Baker Hughes Corporation

Ignacio F Martinez

Dan A Merrill

Donn Jason Brown

Steven Keith Tetzlaff

John Jay Mack

Thomas McClain Scott

Sean A Cain

Clark D Shaver

Juan M Garoby

Damián Heber Munõz

Raul M Krasuk

A heat exchanger to serve ESP equipment installed on the seabed located in either a caisson or skid. A hot oil line connects the base of the ESP motor with the externally located heat exchanger, allowing hot motor oil to be circulated through coils externally exposed to seawater. The heat from the oil is rejected to the seawater and the cooled oil is reintroduced to the motor via a cold oil line that communicates with the seal section. The heat exchanger arrangement reduces the temperature of an ESP motor, thus allowing the motor to operate longer and more reliably.

Heat exchanger for ESP motor

Systems and methods of cooling a motor of an electrical submersible pump (ESP) assembly employed in an electrical submersible subsea booster pumping system, are provided. A supporting frame structure such as an ESP mounting skid or top end assembly of a caisson having structural members exposed to environmental seawater, is modified or designed to include fluid conduits within the structural members to establish lubricant pathways for lubricant to flow. A heated/hot lubricant line connects between a supporting structure lubricant inlet port and an ESP motor lubricant outlet port. A cooled lubricant line connects between a supporting structure lubricant outlet port and an ESP motor lubricant inlet port. A pump or other fluid moving device circulates lubricant from the ESP motor to the lubricant pathways within the supporting frame structure, whereby the seawater cools the lubricant contained therein, which is then circulated back into the motor to assisting cooling the motor.

Systems and methods of using subsea frames as a heat exchanger in subsea boosting systems

Systems and methods for monitoring partial discharge within a remotely located and inaccessible electric motor. One embodiment comprises a downhole electric motor of an electric submersible pump system positioned in a well. The motor includes a partial discharge monitoring system coupled to the motor's power terminals. The partial discharge monitoring system includes a filter subsystem, a processing subsystem, and a communication subsystem. The filter subsystem allows higher frequency signals to pass from the terminals to the processing subsystem. The processing subsystem identifies signal constituents that are associated with partial discharge, and may perform various types of processing or analysis of the signal received from the processing subsystem. The partial discharge information generated by the processing subsystem is passed to the communication subsystem, which communicates the information to remotely located surface equipment. The subsystems of the partial discharge monitoring system are configured to operate in a high-pressure, high-temperature downhole environment.

Partial discharge monitoring systems and methods

An expansion chamber to serve ESP equipment installed on the seabed located in either a caisson or a conduit on a skid. The expansion chamber provides an external reservoir for expansion and contraction of motor oil in the ESP equipment. During operation of an ESP, the heat generated in the motor raises the temperature of the motor oil, causing it to expand. The expansion chamber is connected to the ESP equipment via oil lines that allow oil to expand into the expansion chamber when the temperature of the motor oil increases. The expansion chamber has a movable barrier therein that defines primary and secondary chamber. Oil communicates with the primary chamber. Formation fluid within the conduit surrounding the motor communicates with the secondary chamber.

External oil expansion chamber for seabed boosting ESP equipment

A string for drilling a well for installation and retrieval of ESP equipment without a rig. A well is drilled past the end of casing which has been cemented in place and extends to a wellhead at the surface. A receptacle is attached between production casing joints and run into the well. The receptacle is a tubular member with an inclined pocket formed on a side. At least one passage or port in the pocket intersects with a passage in receptacle with one or more lengths of tubing attached to the pocket. A wet connector within the production casing is landed in the receptacle and self aligns to the tubing. Electrical wires run within the tubing mate and lock with the wet connector. This allows an ESP to be run into the well via winch such that it stabs into the wet connector to receive power.

Wellbore drilled and equipped for in-well rigless intervention ESP

An in-well ESP string that can be installed or retrieved with a wireline instead of a rig. The ESP is combined with a motor and a hydraulic valve to pump formation fluid from a well to the surface. A wet connector is used to facilitate electrical and hydraulic connections. The ESP system is disposed within a tubing string located within the casing of a well. The hydraulic valve controls the flow of formation fluid to the ESP, opening to allow formation fluid to flow to the ESP, and closing to shut off production. When the valve is closed, the ESP may be cleaned with brine introduced via a flow port in the valve. This cleaning operation allows the ESP string to be to retrieved in an environmentally friendly manner. In addition, the wireline installation and retrieval is significantly less costly and less complicated than currently possible with a rig.

In-well rigless ESP

Upstream and downstream pump assemblies are mounted in a capsule having a bulkhead between the upstream and downstream pump assemblies, dividing the capsule into upstream and downstream chambers sealed from each other. In a dual operation mode, well fluid flows through the inlet of the capsule into the upstream chamber, where it is pumped to a first pressure level by the upstream pump assembly and discharged into the downstream chamber. The downstream pump assembly then pumps the well fluid to a second pressure level and discharges the well fluid out the outlet of the capsule. The assembly has also an upstream pump assembly only operational mode and a downstream pump assembly only operational mode.

Capsule for two downhole pump modules

A well production system has a string of production tubing with a junction having two legs. A first leg is sealed to the casing by a packer located above well perforations. A submersible pump assembly is secured to a second leg, the pump having an intake in the tubing annulus surrounding the first leg. A gas lift valve is secured to the tubing. A port in the first leg allows well fluid to flow out of the first leg to the intake while in the pumping mode. In the pumping mode, a barrier is placed in the first leg above the port and the port opened to cause well fluid to the pump intake. In the gas lift mode, the port is closed and a barrier is placed between the second leg and the first leg.

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Macae, Brazil

Ignacio F Martinez