Abstract: Various downhole tools, such as drilling motors, drilling tools, reamer tools, casing reamer shoes, and related methods of installation, assembly and use. Casing reamer shoes and drilling reamers or motors may have internal impellers, progressive cavity pumps, hollow rotors and other parts, universal joints, and other features. A progressive cavity section may have a rotor and a stator. Rotor contacting surfaces of the stator, and stator contacting surfaces of the rotor, may be rigid during use. The stator contacting surfaces and the rotor contacting surfaces may be made of metal. After the casing is run, the casing is cemented and the reamer shoe drilled out.

Abstract: A directional drilling system includes a housing and a motor positioned within the housing and operably coupled to a drill bit to rotate the drill bit. The system further includes a primary pad assembly comprising a primary pad and a primary actuator coupled to the primary pad to selectively extend from an exterior of the housing, and a backup pad assembly to back up the primary pad assembly, the backup pad assembly comprising a backup pad and a backup actuator coupled to the backup pad to selectively extend from the exterior of the housing.

Abstract: A tubular element for a drill stem includes a substantially cylindrical body and two tool joints. Each tool joint is disposed at one end of the body and provided with a threaded portion that can be joined to a complementary element. At least one of the tool joints has a lifting surface that can cooperate with a lifting tool of the element to connect it into a drill stem. The lifting surface has a non-circular cross-section forming an activation zone for a drilling fluid.

Abstract: A centralizer can be produced from a process comprising forming a plurality of composite bow spring from a fiber and a resin, curing the composite bow springs in a desired shape to form a plurality of cured bow springs, disposing a first portion of a resin-wetted fiber about a cylindrical mandrel to form a plurality of collars, disposing the plurality of cured bow springs onto the mandrel with the bow spring ends in contact with the first portion of resin-wetted fiber, disposing a second portion of the resin-wetted fiber about the cylindrical mandrel, curing the collars to form a cured centralizer, and pressing the mandrel out of the cured centralizer.

Abstract: This hydraulic drilling apparatus including a casing comprising a front part, a shank including a fluid injection conduit and intended to be coupled to at least one drill rod equipped with a tool, the shank, a striking piston slidably mounted inside the casing along a striking axis (A) and configured to strike the shank, an extraction piston disposed around the shank and comprising an extraction portion configured to cooperate with the shank, and a cartridge removably mounted on the front part and disposed around the shank, the cartridge including an injection part configured to fluidly connect the fluid injection conduit to a fluid delivery conduit. The cartridge delimits a receiving housing in which the extraction piston is slidably mounted.

Abstract: A well support structure includes a well support base for urging below a bottom of a body of water. A first support is coupled to the well support base at a first longitudinal support level. A first load transfer device is operatively coupled between the first support and a wellbore tubular component. At least a second support is coupled to the well support base at a second longitudinal level below the first longitudinal support level. The wellbore tubular component extends between a longitudinal position above the first support to at least the longitudinal position of the at least a second support. Means for transferring load is provided between the wellbore tubular component and the at least a second support.

Abstract: A vessel adapted to perform subsea wellbore related operations involving a riser string that is assembled from releasably interconnected riser sections and extends between a subsea wellbore and the vessel. The riser string vertical handling system of the vessel comprises a controlled motion device that is adapted to displace the riser string lifting tool in at least one horizontal direction relative to the riser spider device at least whilst travelling between said elevated and lowered position thereof loaded by the riser string suspended from the riser string lifting tool, thereby allowing to establish an inclined travel path with selectively variable inclination of the riser string lifting tool relative to an imaginary vertical line through the riser string passage of the riser spider device, e.g. said inclined travel path having an inclination selected to correspond to an actual water current induced inclination of an upper portion of the riser string during the riser string assembly process.

Abstract: A fingerboard latch assembly includes a latch body, a finger member pivotably connected to the latch body at a first pin, and an actuator assembly coupled to the finger member, wherein the actuator assembly is configured to actuate the finger member from a closed position to an open position in response to the application of fluid pressure to the actuator assembly.

Abstract: In a method to degrade filtercake in a hydrocarbon reservoir using downhole in-situ heat generation, a filtercake breaker, configured to degrade filtercake at a temperature, is mixed with a drilling fluid. The drilling fluid mixed with the filtercake breaker is flowed through a hydrocarbon reservoir in which a wellbore is being drilled. A filtercake forms in a portion of the hydrocarbon reservoir responsive to flowing the drilling fluid. A temperature of the portion of the hydrocarbon reservoir is less than the temperature at which the filtercake breaker is configured to degrade filtercake. Multiple filtercake chemicals are flowed to the portion of the hydrocarbon reservoir. The multiple filtercake chemicals, when mixed, are configured to react in an exothermic reaction to release heat to increase the temperature of the portion of the hydrocarbon reservoir to at least the temperature at which the filtercake breaker is configured to degrade filtercake.

Abstract: In a method to degrade filtercake in a hydrocarbon reservoir using downhole in-situ heat generation, a filtercake breaker, configured to degrade filtercake at a temperature, is mixed with a drilling fluid. The drilling fluid mixed with the filtercake breaker is flowed through a hydrocarbon reservoir in which a wellbore is being drilled. A filtercake forms in a portion of the hydrocarbon reservoir responsive to flowing the drilling fluid. A temperature of the portion of the hydrocarbon reservoir is less than the temperature at which the filtercake breaker is configured to degrade filtercake. Multiple filtercake chemicals are flowed to the portion of the hydrocarbon reservoir. The multiple filtercake chemicals, when mixed, are configured to react in an exothermic reaction to release heat to increase the temperature of the portion of the hydrocarbon reservoir to at least the temperature at which the filtercake breaker is configured to degrade filtercake.

Abstract: An apparatus (10) for capturing drilling fluid returns in an exploration drilling process, as well as a related method of capturing the drilling fluid returns. The apparatus (10) is adapted to be fitted onto a drill collar/casing (11) adjacent its open top (13). The apparatus (10) comprises a body (21) defining a reservoir (23) for receiving the drilling fluid returns flowing out through the open top end (13) of the drill collar/casing (11) and spilling into the reservoir (23). The reservoir (23) comprises a collecting portion (25) in which the fluid returns spilling from the drill collar/casing (11) can be collected. The reservoir (23) also comprises a sump portion (27) which can receive the drilling fluid returns and from which the drilling fluid returns can be pumped by way of a sump pump (28). The reservoir (23) is configured to direct the drilling fluid returns collected by the collecting portion (25) to the sump portion (27) as a continuous flow.

Abstract: A riser pipe system for releasably securing a rotating flow control device internally within a riser string for use in offshore drilling can include a riser pipe section, a removable latch assembly for releasably securing the RFCD, and optionally, a removable seal assembly for sealing against the RFCD. The latch and seal assemblies are disposed within the riser pipe section and axially restrained by at least one removable retaining member. The latch assembly and seal assembly may be hydraulically or pneumatically actuated together or separately.

Abstract: A reverse circulation debris cleanup tool has a pressure control valve that closes up a passage through the body based on a sensed well condition to help pressure control the well when rams close around the tool to isolate the surrounding annulus. The sensor can hold the valve open for a predetermined time to allow debris removal operations and then close. The debris chamber below an eductor in a VACS tool can be thousands of feet long and the valve can provide protection during running in or removal of the tool from well pressure events so as to avoid using shear rams and losing the bottom hole assembly in the borehole and a fishing operation to get it out.

Abstract: A downhole vibration assembly includes a valve positioned above a rotor that is disposed at least partially within a stator. The rotor is operatively suspended within an inner bore of a housing and configured to rotate within the stator as a fluid flows through the vibration assembly. The valve includes a rotating valve segment and a stationary valve segment each including at least one fluid passage. The rotating valve segment rotates with a rotation of the rotor. In an open position, the fluid passages of the valve segments are aligned and a fluid flows through the valve. In a restricted position, the fluid passages of the valve segments are partially or completely unaligned, thereby temporarily restricting the fluid flow through the valve to create a pressure pulse. The unobstructed pressure pulse is transmitted through the drill string or coiled tubing above the valve.

Abstract: A downhole tool is disclosed herein that has an inlet for receiving fluid into a housing of the downhole tool. The downhole tool further includes a vibratory apparatus at least partially disposed within the housing of the downhole tool, the vibratory apparatus having an operational flow path disposed therein to operate the vibratory apparatus when fluid flowing through the operational flow path is above a predetermined pressure. Furthermore, the downhole tool has a bypass passageway disposed in the housing for providing an additional flow path for fluid through the downhole tool to prevent fluid from reaching the predetermined pressure in the operational flow path of the vibratory apparatus, the bypass passageway selectively blockable such that fluid in the operational flow path is increased above the predetermined pressure to activate the vibratory apparatus when the bypass passageway is blocked. A method of using the downhole tool is also disclosed.

Abstract: A method of controllably disintegrating a downhole article comprises disposing a first article in a downhole environment, the first article being the downhole article to be disintegrated; disposing a second article in the downhole environment after the first article is disposed, the second article carrying a device, a chemical, or a combination comprising at least one of the foregoing; and disintegrating the first article with the device, chemical, or the combination comprising at least one of the foregoing from the second article.

Abstract: A drilling jar in an oil and gas drilling operation or fishing operation includes a control unit having one or more transceivers configured to communicate wirelessly with a surface control unit. The control unit is configured to receive an activation signal from the surface control unit, and cause to activate the drilling jar in response to the activation signal. The wireless transceivers may communicate using any wireless communication technology, including but not limited to Wi-Fi, Wi-Fi Direct, and BLE. A method for operating a drilling jar includes receiving, by a control unit comprising one or more transceivers configured to communicate wirelessly with a surface control unit, an activation signal from the surface control unit, and causing to activate the drilling jar in response to the activation signal.

Abstract: A shear blade 10 for a downhole apparatus 50 comprises a body portion 12 and a first cutting edge 21 provided at a cutting end of the shear blade 10, the first cutting edge 21 comprising a sharp edge 22 located at or near a central region of the first cutting edge 21 and at least one blunt edge 23 located at or near at least one outer portion of the first cutting edge 21. In an embodiment, the shear blade 10 has a recess or slot 40 which is provided at or near a central region of a shear face 30 and which extends partially between a first side 27 and a second side 28 and which is generally aligned with the sharp edge 22 of the first cutting edge 21 in a plane substantially parallel to an axis of the throughbore and perpendicular to the first cutting edge 21.

Abstract: A wellbore liner-hanger tie-back system includes a bore receptacle coupled with a liner hanger at a downhole end of the bore receptacle, where the liner hanger is configured to be positioned in a wellbore, a tieback casing configured to be disposed in the wellbore, where a portion of an outer surface of the tieback casing is disposed proximate to an inner surface of the bore receptacle, and a seal system including at least one swellable seal. The seal system is disposed between the tieback casing and the bore receptacle to seal a space between the portion of the outer surface of the tieback casing and the inner surface of the bore receptacle.

Abstract: An improved plug for sealing a tubular as described. The improved plug comprises a plug body, the plug body comprising a propellant and an initiator adapted to initiate the propellant upon a signal. Upon initiation the propellant deflagrates causing the plug body to at least partially disintegrate.

Abstract: The present invention relates to an annular barrier for isolating a production zone, the annular barrier having a first end and a second end, comprising: a tubular metal part for mounting as part of a well tubular metal structure, the tubular metal part having an outer face, an expandable metal sleeve surrounding the tubular metal part and having an outer face facing a wall of a borehole, each end of the expandable metal sleeve being connected with the tubular metal part, an annular space arranged between the expandable metal sleeve and the tubular metal part, the expandable metal sleeve being configured to expand by pressurised fluid entering the annular space, a first tubular metal connection assembly surrounding the tubular metal part connecting one end of the expandable metal sleeve with the tubular metal part and a second tubular metal connection assembly surrounding the tubular metal part connecting the other end of the expandable metal sleeve with the tubular metal part, each tubular metal connection a

Abstract: A backup ring assembly has a plurality of radially offset ring members including an outermost ring member formed from plurality of axially extending segments. Each of the plurality of axially extending segments includes an outer surface. A first interlock member support is coupled to the outer surface of one of the plurality of axially extending segments of the outer most ring member. A second interlock member support is coupled to the outer surface of an another one of the plurality of axially extending segments of the outermost ring member. An interlock member includes a first end supported at the first interlock member support and a second end supported at the second interlock member support. The interlock member restrains radially outward expansion of the ring and circumferential expansion of a gap extending between the one of the axially extending segments and the another one of the axially extending segments.

Abstract: Wellbore isolation devices may be produced with wear bands and slips having modified surfaces to change the frictional properties between these components and the surrounding wellbore surface. A wellbore isolation device may include: a mandrel; slips disposed circumferentially about the mandrel and in a first position along the mandrel. The slips comprise particles coupled thereto forming a modified surface. The particles comprise at least some sharp protrusions. At least one packer element is disposed along the mandrel and in a second position along the mandrel.

Abstract: Methods and systems for reducing fluid communication between wells. Providing a first treatment fluid comprising synthetic clay and an aqueous carrier fluid; pumping the first treatment fluid into a first fracture network in fluid communication with a first well; placing the synthetic clay in the first fracture network; pumping a second treatment fluid into the first fracture network after placing the synthetic clay in the first fracture network; wherein the second treatment fluid is not produced in a second well in fluid communication with a second fracture network, and wherein the second fracture network is in fluid communication with the first fracture network.

Abstract: A technique facilitates controlling fluid flow in a well system or other flow related system. The control of fluid flow may be accomplished by utilizing a flow control valve which is selectively actuated via the controlled application of an actuating fluid. An isolation valve is positioned along the flow of actuating fluid at a location upstream of the flow control valve. The isolation valve establishes a preset pressure which is applied to establish flow of actuating fluid to the flow control valve and also isolates detrimental pressure transients. For example, the isolation valve may be used to reduce or block the propagation of detrimental pressure transients along the actuating fluid to other controlled devices.

Abstract: An actuator mechanism for a valve system includes a housing having an outer surface, an inner surface defining an opening and a chamber extending partially about the housing between the outer surface and the inner surface. A hinge is mounted to the housing. The hinge is exposed at the chamber. A valve member is fixedly connected to the hinge. The valve member is selectively positionable across the opening. An actuator is arranged in the chamber and selectively biased against the hinge to transition the valve member between an open configuration and a closed configuration.

Abstract: A diffuser assembly is provided, comprising a diffuser adapted to reside within a conduit, having an upper member mountable within the conduit and having a fluid inlet port, and a lower section having a diffuser screen. A resilient member is connected between the upper member and the lower section, wherein the resilient member enables the diffuser screen to vibrate relative to the upper member. A plurality of diffusing members is positioned below the resilient member, wherein the diffusing members are oriented relative to a central axis of the diffuser screen. A centralizing member is positioned above the diffuser screen having a diameter greater than the diffuser screen. The diffuser screen is a cylinder having a plurality of diffuser apertures formed therein, the cylinder including a bottom cap having a fluid exit port; and wherein the plurality of diffusing members extends substantially parallel to the central axis.

Abstract: Supercritical carbon dioxide is directed into a wellbore to a specified depth. The supercritical carbon dioxide is directed at an inner surface of the wellbore at the specified depth. Scale is removed from the wall of the wellbore with the supercritical carbon dioxide.

Abstract: Supercritical carbon dioxide is directed into a wellbore to a specified depth. The supercritical carbon dioxide is directed at an inner surface of the wellbore at the specified depth. Scale is removed from the wall of the wellbore with the supercritical carbon dioxide.

Abstract: Systems and methods for determining operating settings of a fluid production system with a gathering network and a plurality of reservoirs, at least some of which include a method that includes lumping common pseudo-components into reservoir pseudo-components associated with each of the reservoirs. Each common pseudo-component is associated with the gathering network and maps to one reservoir pseudo-component of each of the reservoirs. The method further includes performing at least part of a fully-coupled simulation of the gathering network and the reservoirs using the common pseudo-components to obtain one or more operating settings that meet one or more constraints of the production system, and presenting to a user the operating settings.

Abstract: A downhole system having a liner hanger assembly includes a liner hanger and a running tool. The running tool includes a tubular and an expandable member disposed circumferentially around the tubular. The expandable member is configured to increase in volume from a first condition to a second condition at a surface location. The second condition of the expandable member connects the running tool to the liner hanger.

Abstract: An abrasive perforator tool with a bypass flow channel. Two valve sleeves are slidingly mounted inside a tool housing for sequential deployment. The valve sleeves may be arranged end-to-end and may be sealed to the inside diameter of the housing. Each of the valve sleeves may be telescopically mounted in a retainer sleeve and releasably secured in the undeployed position. When the valve sleeves are ball-actuated, the ball seat in the first valve sleeve may be at the lower end of the sleeve. Initially, with both sleeves in the undeployed position, fluid flows straight through the main bore and out the outlet end. When the first valve sleeve is deployed, fluid is redirected to the nozzles for perforating, and subsequent deployment of the second valve sleeve blocks the nozzles and opens the bypass channel to reestablish flow out through the bottom of the tool.

Abstract: Methods and apparatus are provided for conducting multiple successive same-location firings of a number of shaped charges carried by a perforating gun that is lowered into the wellbore and precisely positioned by engagement with a landing base assembly that includes a through-tubing retrievable bridge plug to which is secured a receiving member that matingly engages a perforating gun assembly that includes a mating guide member secured to the downhole end of the perforating gun and a rotating head member attached to the opposite upper end of the gun, the rotating head member configured for attachment to the downhole end of a length of coiled tubing for lowering the gun assembly and permitting its axial rotation and downward vertical movement into a final secure, but releasably engaged position with the fixed landing base assembly.

Abstract: A method and apparatus for containing one or more shaped charges in a single plane, arrayed about the center axis of a gun body, and detonated from a single initiator in a shaped charge cluster assembly.

Abstract: A method for locking an internally threaded end piece such as a head piece, a tail piece, an end or sealing nut to a mandrel for a down hole tool to obviate the need for pins, set screws, and the like, to provide a more robust assembly. In two embodiments the threaded end piece is locked to the mandrel in a swaging operation.

Abstract: A downhole artificial lift system comprises a production string for communicating fluid from a downhole location towards surface, a pump arrangement in communication with the production string for pumping fluid along the production string towards surface, and a gas lift arrangement deployed within the production string for delivering a lift gas into the production string.

Abstract: A method and system for servicing a well. Servicing a well often includes running a service string into a production string, which may include a rod string. A service portion is provided in the production string during completion. The service portion is located at or uphole of a large rod string feature. The service portion has a greater inside diameter than production tubing and other standard production string components. The service portion provides sufficient clearance for the service string alongside the large feature. The large feature may be, for example, a PCP stator, a centralizer, or a rod collar. The large feature may be pulled uphole into the service portion prior to running in the service string, allowing servicing downhole of the large feature without pulling the entire rod string. The service portion may also mitigate rod wear in deviated or other portions of the well.

Abstract: An electrical submersible pump assembly for producing hydrocarbons from a subterranean well includes a motor-seal click connector releasably connecting a motor to a seal section and engaged by relative axial movement between the motor and the seal section, and a pump-seal click connector releasably connecting the pump to the seal section and engaged by relative axial movement between the pump and the seal section. Electrical conductors are located within a sidewall of the motor housing, a sidewall of the seal section housing, and a sidewall of the pump housing. A male motor-seal electrical connector is axially extending and electrically connects the electrical conductors of the motor housing with the electrical conductors of the seal section housing. A male pump-seal electrical connector is axially extending and electrically connects the electrical conductors of the pump housing with the electrical conductors of the seal section housing.

Abstract: An integrated system is disclosed to handle production of multiphase fluid consisting of oil, gas and water. The production stream is first separated into two streams: a liquid dominated stream (GVF<5% for example) and a gas dominated stream (GVF>95% for example). The separation can be done through shrouds, cylindrical cyclonic, gravity, in-line or the like separation techniques. The two streams are then routed separately to pumps which pump dissimilar fluids, such as a liquid pump and a gas compressor, and subsequently recombined. Both pumps are driven by a single motor shaft which includes an internal passageway associated with one of the pumps for reception of the fluid from the other pump, thereby providing better cooling and greater overall efficiency of all systems associated therewith. A method for providing artificial lift or pressure boosting of multiphase fluid is also disclosed.

Abstract: An electric submersible pump (ESP) intake system, apparatus and method is described. An ESP intake system includes a filtered intake section coupled adjacently to a sliding sleeve intake section, wherein the sliding sleeve intake section has a closed initial state and is selectively actuatable to an open position when the filtered intake section becomes at least partially clogged. An ESP intake method includes operating an ESP pump downhole in a well including abrasive-laden fluid, the ESP pump including a filtered intake section and an actuatable intake section, employing the filtered intake section as a first fluid entrance into the ESP pump, monitoring information from ESP sensors during employment of the first fluid entrance to identify clogging of the filtered intake section, and opening the actuatable intake section upon the clogging so identified such that the actuatable intake section serves as a second fluid entrance into the ESP pump.

Abstract: A well pump electrical motor has a motor housing filled with a dielectric motor lubricant. A motor head has at least one motor lead passage in fluid communication with the motor lubricant. An outer seal, which is exposed to well fluid, seals around a motor lead in the motor lead passage. An inner seal seals around the motor lead in the motor lead passage inward from the outer seal and has an inner side in contact with the motor lubricant in the motor. A barrier fluid passage extends into an annular space between the inner and outer seals and contains a barrier fluid. A pressure compensating device has an inner side in contact with the barrier fluid in the barrier fluid passage for reducing a pressure differential between the barrier fluid and a hydrostatic fluid pressure of well fluid on the exterior of the motor.

Abstract: Techniques for controlling hydrocarbon production includes (i) identifying a plurality of reservoir measurements of a subterranean hydrocarbon reservoir located between at least one injection wellbore and at least one production wellbore; (ii) processing the identified plurality of reservoir measurements to generate a petrophysical model of the subterranean hydrocarbon reservoir; (iii) determining, based on the petrophysical model, a flow of an injectant from the injection wellbore toward the production wellbore; and (iv) adjusting an inflow control device (ICD) positioned about the production wellbore based on the determined flow of the injectant.

Abstract: Techniques for controlling hydrocarbon production includes (i) identifying a plurality of reservoir measurements of a subterranean hydrocarbon reservoir located between at least one injection wellbore and at least one production wellbore; (ii) processing the identified plurality of reservoir measurements to generate a petrophysical model of the subterranean hydrocarbon reservoir; (iii) determining, based on the petrophysical model, a flow of an injectant from the injection wellbore toward the production wellbore; and (iv) adjusting an inflow control device (ICD) positioned about the production wellbore based on the determined flow of the injectant.

Abstract: A method for performing a fracture operation. A log of a formation parameter is obtained for a formation surrounding a wellbore in which the fracture operation is to be implemented. A relation is determined between the formation parameter and a parameter of the fracture operation. A value of the parameter of the fracture operation is selected based on the relation and a value of the formation parameter.

Abstract: A method for drilling a well includes prescribing a drill recipe with a drill analysis engine based on a field-specific model. The drill recipe identifies prescribed segments, mud flow parameters, and drill parameters. Each prescribed segment of the prescribed segments includes a start depth. The method further includes initiating drilling of the well based on the drill recipe; receiving a drill log in narrative text format; detecting a drill event inconsistent with the drill recipe by analyzing the drill log with a log analysis engine; prescribing an adjusted drill recipe with the drill analysis engine based on the field-specific model in response to the drill event, the adjusted drill recipe including adjusted prescribed segments; and drilling the well based on the adjusted drill recipe.

Abstract: A method includes automatically creating one or more test schedules for a well test of one or more wells in an oil or gas production environment. The method also includes automatically creating one or more test frames for use in generation of the well test. The method further includes, following execution of the test frame, automatically validating one or more test records generated during the one or more test frames. In addition, the method includes automatically creating the well test for determining one or more well characteristics.

Abstract: A borescope may include a housing including a transparent viewing window, a bumper surrounding at least a portion of a periphery of the transparent viewing window, wherein the bumper is configured to be pressurized by a fluid, and at least one imaging assembly configured to visualize a field of view exterior of the housing through the transparent viewing window.

Abstract: A method for material evaluation may include detecting photons from gamma ray interactions with material in an annular region between a geological formation and a casing. An energy spectrum is generated from the detected photons. A difference between materials may then be detected based on a comparison of the generated energy spectrum with a reference spectrum for a known material (e.g., good cement, known fluid).

Abstract: A method for monitoring performance of an electric submersible pump. The method includes receiving data indicating a plurality of observable parameters from one or more sensors, generating a reduced set of components representative of at least some of the observable parameters and the reduced set having a dimensionality less than the plurality of observable parameters, identifying one or more components of the reduced set that captures a total variance of the plurality of observable parameters above a predetermined threshold, constructing at least one manifold of normal operation of the electric submersible pump in a reduced component space, receiving additional data from the sensors, transforming the additional data into the identified components establishing an electric submersible pump performance, and detecting whether a deviation of the electric submersible pump performance from a normal mode of operation of the electric submersible pump exceeds a predetermined threshold.

Abstract: In an assembly of an instrument panel and an anti-fouling system, the instrument panel is designed for arrangement on a subsea structure that includes at least one instrument which is to be inspected and/or manipulated underwater, by a remotely operated underwater vehicle. The anti-fouling system includes at least one anti-fouling appliance for performing an anti-fouling action on at least a portion of the exterior surface of the instrument panel. The anti-fouling appliance may have at least one of various possible arrangements with respect to the instrument panel, including an exterior arrangement and an interior arrangement, and an arrangement on the exterior surface of the instrument panel. The anti-fouling appliance includes an ultraviolet light source. A light guide may be provided to guide light from the light source to desired destinations.