Baker Hughes Corporation

Christopher Kempson Shaw

Peter A Thompson

Michael H Johnson

Paulo S Tubel

Brown Lyle Wilson

Sunder Ramachandran

Wallace Woon-Fong Leung

Kenneth T Bebak

William Edward Aeschbacher, Jr

Michael J Fox

Jeffrey W Knight

Mitch C Means

David A Voss

Dewey Michael Loudermilk

Cindy L Crow

A seafloor pump assembly is installed within a caisson that has an upper end for receiving a flow of fluid containing gas and liquid. The pump assembly is enclosed within a shroud that has an upper end that seals around the pump assembly and a lower end that is below the motor and is open. An eduction tube has an upper end above the shroud within the upper portion of the caisson and a lower end in fluid communication with an interior portion of the shroud. The eduction tube causes gas that separates from the liquid and collects in the upper portion of the caisson to be drawn into the pump and mixed with the liquid as the liquid is being pumped.

Gas eduction tube for seabed caisson pump assembly

A system monitors and controls the injection of additives into formation fluids recovered through a subsea well. The system includes a chemical injection unit and a controller positioned at a remote subsea location. The injection unit uses a pump to supply one or more selected additives from a subsea and/or remote supply unit. The controller operates the pump to control the additive flow rate based on signals provided by sensors measuring a parameter of interest. A one mode system includes a surface facility for supporting the subsea chemical injection and monitoring activities. In one embodiment, the surface facility is an offshore rig that provides power and has a chemical supply that provides additives to one or more injection units. In another embodiment, the surface facility includes a relatively stationary buoy and a mobile service vessel. When needed, the service vessel transfers additives to the chemical injection units via the buoy.

Subsea chemical injection unit for additive injection and monitoring system for oilfield operations

A system for injecting water into a well boosts pressure in a flowline leading to the injection well. A bypass flowline is connected into and forms part of the main flowline. A bypass valve is located in the bypass flowline for opening and closing the bypass flowline. A housing has an inlet connected to the bypass flowline upstream of the bypass valve in an outlet connected to the bypass flowline downstream in the bypass valve. Inlet and outlet valves selectively open and close the inlet and outlet of the housing. A centrifugal pump assembly is mounted in the housing, the pump having an intake in communication with the inlet of the housing. The pump has a discharge tube that communicates with the inlet of the housing. An isolation member separates discharge pressure of the discharge tube from the intake pressure at the intake. A removable end cap on an end of the housing enables the pump assembly to be inserted and withdrawn from the housing.

Pump bypass system

A system for producing hydrocarbon fluids from a subsea formation includes at least one producing well penetrating the formation for producing hydrocarbon fluids. At least one dummy well is hydraulically connected to the at least one producing well for routing the hydrocarbon fluids from the producing well to the dummy well. At least one pump is disposed in the at least one dummy well. The pump takes suction flow from the dummy well and boosts the flow energy of the discharge flow of hydrocarbon fluids.

System and method for flow/pressure boosting in a subsea environment

&ldquo;Well equipment transporting well fluid from a gassy well. A conduit is hung and sealed inside a string of casing, forcing the gas and well fluid to flow into the conduit. A gas separator and a series of flow controls and valves are mounted into and run with the conduit. A pump assembly is hung and sealed into the conduit for pumping well fluid to the surface. The pump assembly is lowered and retrieved from the conduit on tubing. The pump may be located below the motor, or above the motor.&rdquo;

ESP pump for gassy wells

Methods for staged production from a wellbore include pumps sequentially operated during the life of the well. In described embodiments, production assemblies are used for progressive staged production process in which the production tubing is bifurcated to provide a pair of legs. One of the legs includes a first pump that may be selectively actuated to flow fluid through one of the legs. Means are also provided, including a sliding sleeve and a flapper valve diverter, for blocking production fluid flow through one leg or the other. A second fluid pump is lowered inside of the production tubing to pump fluid after the first pump has failed.

Progressive production methods and system

A riser is installed which extends from a wellhead near the sea floor to near sea level. An electrical submersible pump assembly is suspended within the riser to pump well fluids up the riser. The electrical submersible pump includes impellers for displacing well fluids, and a base member having an intake port for receiving well fluid. The pump assembly can also include a separator for separating any gases from the well fluids, a packer for sealing the pump to the riser, coiled tubing from the pump to at least the upper end of the riser, or NPSH stages to aid in pumping a mixed flow of well fluids and gas.

Electrical submersible pumps in the riser section of subsea well flowline

A system for separating fluids of differing densities includes a pair of pumps interconnected to and driven by a motor positioned therebetween. The pumps each have intake ends, distal second ends, and a pump intake proximal the intake end. The pumps, the motor, and a production tubing form a production string. A shroud is sealably connected to the production string at one end of the shroud at a position intermediate the motor and the pump intake of one of the pumps. The shroud surrounds the pump and extends at least partially over the pump. The shroud forms a fluid communication passageway between the pump and the shroud and an orifice at the end of the shroud opposite the sealed end to form an effective pump intake. A second shroud similar to the first shroud surrounds the other, second pump and is sealably attached to the production string intermediate the motor and the second pump. The effective pump intakes formed by the shrouds are at least sixty feet from one another.

Oil separation and pumping system and apparatus

Methods and apparatus are provided for separation of liquids of different densities in production fluid streams from underground wells. Methods and apparatus are also provided for separation of gas, oil and water in production fluids, transportation of the separated fluids to the surface, as well as reinjection of separated water from the production fluids into other formations. Other aspects include new separation arrangements which include gas or liquid driven motors, designs for multi-stage hydrocyclone separators and use of beam or rod pumps.

Method and apparatus for downhole hydro-carbon separation

The present invention related to a system which prevent coning while minimizing the problems associated with any reverse coning which may result. The system includes a production string disposed within a wellbore having both oil production perforations and water production perforations, wherein the production tubing is packed off against the wellbore annulus between the oil production perforations and the water production perforations. In addition to a pump for producing oil from the oil production perforations, a water pump is incorporated into the production tubing proximate the water production perforations in order to pump water to a reinjection point or other location. The system also permits recovery of amounts of oil and even solids existing within the water layer, preferably by the use of a separator. The separated oil is then directed upward through the production string for recovery. The invention permits increased pump rates by the pumps located both above and below the packer.

Apparatus and methods for downhole fluid separation and control of water

The present invention provides methods and apparatus for separating fluids using one or more hydrocyclone separators and a mixer disposed upstream from the hydrocyclone separators. The mixers are preferably static or rotary type mixers which mix the fluids prior to their delivery into the hydrocyclone separator. Using mixers provides a more homogeneous mixture of oil and water to the hydrocyclone separators in order to increase the efficiency of the separation. By controlling the degree of mixing it is also possible to substantially avoid the formation of emulsions.

Cyclonic separator assembly and method

Oil separation and pumping systems

The present invention provides an apparatus and method of producing a stream of hydrocarbons and water from a wellbore and separating the stream into a hydrocarbon-rich stream and a water-rich stream that can be reinjected into the wellbore from which it was produced. The method involves producing a production stream from production tubing in the wellbore to a separator located at least partially above the wellbore, separating the production stream into a water-rich stream and an oil-rich stream, reinjecting the water-rich stream into the wellbore from which it was produced; and maintaining separation of the water-rich stream from the production stream.

Fluid separation and reinjection systems

A computerized (e.g. intelligent) downhole oil/water separation system. A hydrocyclone separator is used downhole to separate oil from water. Downhole sensors monitor parameters associated with the oil/water separation and provide signals representing the parameters to a controller. The controller controls operation of the system by generating control signals and providing the control signals to one or more control devices. The oil/water separation is optimized and well profitability is enhanced.

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Claremore, OK, United States of America

Christopher Kempson Shaw