Abstract: Disclosed is a system for installing an ESP on a well. In one example the system comprises a production tree (12, 50) that is operatively coupled to a well (14), an ESP spool (16) that is operatively coupled to the production tree and production tubing (60) that extends into the well. The system also comprises an ESP (22) positioned within an inside diameter of the production tubing (60), wherein the ESP (22) comprises an electric motor (22M) and a pump (22P), the electric motor (22M) being positioned above the pump (22P), and wherein the pump (22P) comprises a fluid inlet (22X) and a fluid outlet (22Y). The system is installed above the existing down hole safety valve, and requires no modification to the existing well's completion equipment.

Abstract: A well tube configured for use with a subsea well assembly which includes a Christmas tree arranged on top of a subterranean well. The well tube includes a bore, a lockable insert arranged within the bore, and a locking assembly. The locking assembly includes a locking dog which moves into and out of a locking position, an actuator which moves the locking dog, and a control channel which couples the actuator to an exterior of the well tube and controls the actuator to move the locking dog to removably lock the lockable insert within the bore.

Abstract: Adapter (15) for an oil or gas field Christmas tree (4), said adapter (15) comprising a first interface (16) to connect the adapter (15) to a corresponding Christmas tree interface (17) on the top of the Christmas tree (4), distinctive in that the adapter (15) further comprises a second interface (18), at least one feed-through, and at least one of: a well barrier element, an internal profile for setting a plug, a hanger or a combined hanger and plug.

Abstract: Provided is a system, including a first module (35b) configured to process fluid from a well, wherein the first module (35b) has an extension conduit (5b), having a connection that is coupleable to a central mandrel of a manifold (5), a processing device arranged in a region surrounding the extension conduit (5b), a processing input (18a), and a processing output (19a). Further provided is a method of processing well fluids, including diverting fluids from a bore of a manifold (1) to a processing module (35b), wherein the processing module (35b) is coupled to a mandrel of the manifold (5), processing the fluids in the processing module (35b), and returning the fluids to a flowpath (19a) for recovery.

Abstract: The present invention relates to an apparatus for inspecting and monitoring flexible collection and production lines in real time, rendering possible constant tracking of the condition of the internal structures of a flexible riser, specifically of the tensile armor thereof. The device may be provided at any point along the riser ensuring the establishment of an area of physical and visual contact directly over the surface of the tensile armor of the riser for the installation of equipment for analysis, which area permits further accesses without destroying the sealing of the chamber there formed.

Abstract: A method, device, and system for determining whether liquid enters a subsea system includes a flow line having an inside bore capable of carrying producing fluids from a subsea wellhead to a floating production storage and offloading vessel (FPSO). An annulus is defined between an innermost sheath that surrounds the inside bore and an outermost sheath at an exterior of the flow line. The device further includes a housing element disposed within the annulus and in hydraulic communication with the annulus; a sensor element disposed at a predetermined location within the housing element; and data acquisition equipment capable of: determining environmental characteristics of the annulus based on measurements made by the sensor element, and determining at least one of the presence, location, and rate of collection of liquids in the subsea system based on the environmental characteristics of the annulus.

Abstract: A system for the detection, containment and removal of hydrocarbon leaks in a subsea environment.

Abstract: A system and method for channeling fluids from underwater to the surface. Including a channel system for channeling the fluids from an oil leak through the channel system starting from an underwater pipe leak to a containment reservoir at a sea surface. In one aspect, the channel system is made up of interchange parts, where some are flexible, attachable, and/or can influence the flow of the fluids inside the channel system.

Abstract: The isolation tool works at depth in the bore of a pipe whose upper end is to be severed and replaced. The tool isolates the lower pipe bore from the upper bore so that flammable downhole fluid is prevented from reaching a welding site along the pipe wall. The tool incorporates: means for establishing a pair of axially spaced apart annular seals engaging the pipe inner surface; means for venting downhole fluid to ground surface. The tool is primarily mechanical in nature. It finds use in connection with off-shore platform riser renewal operations.

Abstract: A method of pressure testing a lower marine riser package includes forming an inflatable packer having exposed slats and an inflatable packer element. The packer is positioned within the lower marine riser package above the cap seal with the exposed slats above the packer element. The packer is inflated and fluid pressure is then applied to test the integrity of the cap seal. The packer may be inverted, then positioned below the BOP/riser connection, the packer inflated, and pressure increased above the inflated packer element to test the fluid integrity of the BOP/riser connection.

Abstract: A leak detection system for a wellbore. The leak detection system includes: (1) at least one sensor configured to be positioned outside of a casing of the wellbore; (2) an interrogation system for sending signals to, and receiving signals from, the at least one sensor; and (3) an optical lead cable disposed between the interrogation system and the at least one sensor. A method of detecting a fluid leak in a wellbore is also disclosed.

Abstract: Methods and systems for detecting subsea cement returns, leaks in subsea cement, leaks in blowout preventer operating systems or other equipment or conduits, or the presence of sweep or spacer media subsea or at the surface, include mixing an indicator, such as sodium fluorescein, with a quantity of cement or other medium, the indicator being insulated from contact with the subsea environment. The medium and indicator can be provided into a subsea wellbore, and upon contact of a portion of the medium with the subsea environment, the indicator can become detectable. Exposing the subsea environment proximate to the wellbore to a detector, such as an ultraviolet light source, enables detection of the indicator, and thereby, detection of the medium, which can indicate a cement return or leak of operating fluids in a subsea blowout preventer system.

Abstract: A technique for improving the capability of measuring gas losses at the rig surface area uses a predetermined quantity of a preselected gas injected into the drilling fluid used in the drilling rig, which is then detected and compared to measure the gas loss. Various embodiments may use special-purpose gases. Other embodiments may use air or components of air, such as nitrogen or oxygen, as the gas to be detected and measured.

Abstract: A subsea line monitoring device includes a diagnostic unit adapted to be deployed, in use, in a subsea location and having a first connector, the diagnostic unit being operable, in use, to output a signal indicative of the integrity of a line or device connected to the first connector. The subsea line monitoring device may be deployed on a long term or permanent basis at the subsea location.

Abstract: A method of monitoring a plurality of properties relating to a hydrocarbon fluid flow through a pipeline at a tree for a subsea hydrocarbon extraction facility, the method comprising locating a plurality of sensors at or near a position which is optimum for monitoring the at least one of the plurality of properties in regard to the configuration of the pipeline, the sensors being configured to monitor at least one of the plurality of properties.

Abstract: A wellhead safety device can include a tubular with outer surface portions having different diameters. A first seal groove can be disposed on a first outer diameter. A locking groove can be formed in a first outer surface portion, and can have sloping sides that taper to a center for receiving locking pins of a tubing head. A sloping guide can extend from a first end towards a central bore of the wellhead safety device. A second seal groove can be disposed on a second outer surface portion for containing a second seal. A guide shoulder can be formed on a second end, and can taper from the second outer surface portion to the central bore. A J-latch can be formed in the first end. A landing shoulder can stop the wellhead safety device from slipping into wellbores.

Abstract: Apparatus and methods are described for subsea control system testing including one or more of electrical, optical and fluidic conduit testing, wherein the testing is conducted subsea using a subsea testing skid. In one embodiment of the invention a subsea pipeline service skid is provided that includes at least one skid mounted pump dimensioned to deliver from about 3000 to about 20000 p.s.i. of pressure for pressure testing the fluidic conduits to desired pressures. Modular construction of the skid permits customization for testing service of unique subsea control equipment.

Abstract: A fitting includes a body having at least two portions coupled together to form a body having a passage through the body. The passage allows at least a portion of a conduit to be located at least substantially lengthwise within the body. First and second ports are located on the body and are in fluid communication with the passage. A first seal is located on the passage wall between a first end of the body and the first port. A second seal is located on the passage wall between the first port and the second port. A translatable ring is located on the passage wall between the first and second seals. The ring moves along the passage wall when the first seal is activated so that the second seal is activated. The ring includes an opening proximate the first port to provide access to the conduit from the first port. The first and second seals provide a seal in the passage.

Abstract: A method, device, and system for determining whether liquid enters a subsea system includes a flow line having an inside bore capable of carrying producing fluids from a subsea wellhead to a floating production storage and offloading vessel (FPSO). An annulus is defined between an innermost sheath that surrounds the inside bore and an outermost sheath at an exterior of the flow line. The device further includes a housing element disposed within the annulus and in hydraulic communication with the annulus; a sensor element disposed at a predetermined location within the housing element; and data acquisition equipment capable of: determining environmental characteristics of the annulus based on measurements made by the sensor element, and determining at least one of the presence, location, and rate of collection of liquids in the subsea system based on the environmental characteristics of the annulus.

Abstract: A technique includes providing a chamber in a well tool to receive pressure to control an operation of the tool. The technique includes providing a seal to isolate the chamber from well pressure. The technique also includes providing a pressure relief mechanism to relieve pressure from the chamber in response to the pressure exceeding a threshold.

Abstract: A subsea wellhead assembly for a subsea well including a low pressure wellhead housing having a string of conductor piping extending therefrom. A high pressure wellhead housing, having a string of outer casing suspended therefrom, lands within the low pressure wellhead housing. The high pressure wellhead housing has a housing bore. An adapter is positioned within the housing bore. The adapter has an external load shoulder that lands on a housing load shoulder of the high pressure wellhead housing. The adapter also has an adapter bore with an inner adapter load shoulder formed thereon. A casing hanger is carried in the adapter bore, and has a string of inner casing suspended therefrom and is cemented in the well. The casing hanger lands on the inner adapter load shoulder.

Abstract: A subsea gas compressor module having a housing comprising a sealing element generally defining within the pressure housing a first compartment holding as compressor and a second compartment holding an electric motor, the compressor and motor being driveably connected by at least one shaft. The first compartment is connected to an inlet line and an outlet line for sealing hydro carbon gas and for discharging gas. The second compartment has magnetic bearings for supporting the at least one shaft, and a pressure and volume regulator is fluidly connected to the second compartment and a gas supply, and includes elements for sensing respective pressures in the inlet and outlet lines whereby, based on the magnitude of sensed pressure, the pressure and volume regulator controls the pressure at which gas is injected into the second compartment.

Abstract: The invention concerns a dual-type plug to be used in a wellhead. The plug has a separate retrievable inner plug (50). Retrieving only the inner plug allows the use of lighter workover equipment than if the whole plug (10) must be pulled.

Abstract: An offshore universal riser system. A riser system includes a valve module which selectively permits and prevents fluid flow through a flow passage extending longitudinally through a riser string. An anchoring device releasably secures the valve module in the flow passage. A method of constructing a riser system includes the steps of installing the valve module in the flow passage, and installing at least one annular seal module in the flow passage. The annular seal module is operative to prevent fluid flow through an annular space between the riser string and a tubular string positioned in the flow passage. Drilling methods include injecting relatively low density fluid compositions into the annular space, and selectively varying a restriction to flow through a subsea choke in a drilling fluid return line. The riser string, including housings for the various modules and external control systems, is dimensioned for installation through a rotary table.

Abstract: The present invention includes a method and system for detecting and locating a breach of a pipe in nested multi-pipe petroleum wells through the use and measurement of pressure valves and pressure sensors. The system “locates” breaches in the sense that it determines in which pipe or pipes, if any, in a nested multi-pipe production well the breach exists. The method comprises the steps of, first, connecting at least two of the well pipes of a nested multi-pipe production well to a collection reservoir to allow fluid communication from the well into the reservoir; second, sealing the well pipes to maintain the pressure therein; third, measuring a pressure parameter within each of said at least two well pipes until said pressure parameter indicates a stabilization of pressure therein; fourth, altering the pressure within one of the well pipes; fifth, measuring a pressure parameter within the other well pipes; and sixth, stabilizing the pressure in the well pipe within which the pressure was previously altered.

Abstract: A system for detecting leaks from a subsea system is disclosed which includes at least one subsea structure anchored to a sea floor, a fluorescence detector attached to the subsea structure, the fluorescence detector adapted to generate a light beam having a wavelength that will fluoresce material leaking from the subsea system when the material is irradiated with the light beam, and a camera adapted to observe the fluorescence of the material as it is being irradiated by the light source.

Abstract: A fixed-point packoff element for a full-bore pressure isolation tool supports a primary seal and a test seal to permit the primary seal to be tested by injecting test fluid through a side port of a tubing head spool before the pressure isolation tool is rigged up for a well stimulation procedure.

Abstract: A method of reducing a pressure within a first cavity of a subsea device is disclosed which includes transferring fluid within the first cavity to an accumulator, increasing a pressure of the fluid within the accumulator and, after increasing the pressure of the fluid within the accumulator, transferring at least some of the fluid in the accumulator into a second cavity, wherein the second cavity is at a higher pressure than said first cavity.

Abstract: A method and apparatus is disclosed for testing a blowout preventer (BOP) by: using a drillpipe to install a test plug into one end of the throughbore of a (BOP); using a valve in the BOP to isolate the opposite end of the throughbore of the BOP, using piping to connect the output of a cementing unit to the throughbore of the BOP; using the cementing unit to increase the pressure in the throughbore of the BOP to a predetermined level; displaying the pressure in the piping as a function of time; and displaying the pressure in the piping as a function of time for the same blowout preventer system at an earlier time when leakage was deemed to be within predetermined acceptable limits. The pressure decline caused by a leak can be detected reliably and efficiently with high-resolution pressure data.

Abstract: An externally testable redundant connection for a subsea well includes a tube, a connector assembly, and collar. The connector assembly includes a jam nut over the tube; a ferrule over the tube adjacent the jam nut; and a double jam nut disposed over the tube adjacent to the ferrule. The double jam nut includes a test port adapted to receive a test fluid through the test port for determining if the primary seal and the secondary seal are providing a leak proof sealing engagement. The collar engage the tube and transfers an axial force from the double jam nut and compresses the tube into a female profile forming a primary seal. A secondary seal is formed from a compression of the ferrule into the double jam nut using the jam nut.

Abstract: A subsea wellhead assembly has a tree that connects internally to the bore of wellhead housing. The tree has a lower end that has a lock member that is moved radially outward into engagement with a profile in the bore of the wellhead housing. The tree is a monobore, having a production passage but no tubing annulus passage extending through it. The tubing hanger has a tubing annulus passage and a production passage. A valve is mounted in the tubing hanger for controlling flow through the tubing annulus passage.

Abstract: A drill-through spool body sleeve assembly comprises a test sleeve removably installed within a drill-through spool body having a bore with the terminal ends of the outer diameter of the test sleeve sealingly engaging the bore wall. The sleeve assembly also comprises a wear bushing removably installed in the bore between the bore wall and the test sleeve. The test sleeve is of sufficient thickness to pressure test the spool body outlets, ports, and valves before drilling and production. The test sleeve seals the bore from the outside of the spool body during the pressure testing. After the pressure tests are completed, the test sleeve is removed from the spool body, leaving the wear bushing in place. The wear bushing protects the bore wall, outlets, ports, and valves while allowing equipment such as drilling and wellhead equipment to pass through the spool body.

Abstract: A test technique and mechanism includes lowering a junction assembly to a junction between at least two bores of a well. The junction assembly includes one or more sealed connections that are tested by the generation of a test flow of fluid. The distal ends of the junction assembly are blocked so that a pressure increase in the junction assembly can be monitored. The level of this pressure increase is used to determine if there is any leakage in the junction assembly. To reduce the costs associated with a faulty junction assembly, the testing is performed during an installation procedure of the junction assembly. Thus, if a faulty junction is detected, it can be quickly removed and replaced with another junction assembly.

Abstract: A method for addressing the problem known as formation breathing occurring during the drilling of a subsea well in an earth formation in performing a series of leak off tests to determine the earth formation fracture propagation pressure and the earth formation fracture reopen pressure and maintaining the hydrostatic pressure on the earth formation in a range between the fracture reopen pressure and the fracture propagation pressure.

Abstract: A horizontal Christmas tree is adapted for ESP/HSP or downhole sensor deployment by a coiled tubing hanger 38 received in the tubing hanger 12. Coiled tubing 40 suspends downhole equipment such as ESP 60, and carries power/signal lines. These lines are connected to an external line 58 via a transition connector 46 in a tubing access plug 44 provided in an internal tree cap 32. A debris cap 50 is provided with a further connector 52. Self orientating wet mate connectors 48, 54, 56 are provided between the connectors 46, 52 and external line 58. The coiled tubing hanger and/or tubing hanger may be provided with flow by flutes or holes (78, 80 FIGS. 4 and 5) sealable by a separate adapter plug (88, FIG. 5) above the coiled tubing hanger. Flow test procedures are also disclosed.

Abstract: A method for eliminating the presence of micro-annuluses associated with a subsea hydrocarbon producing wellbore for accurate gathering of data within the subsea hydrocarbon producing wellbore. The method involves using a sea floor pressure head assembly in conjunction with a subsea blow out preventer, where the sea floor pressure head assembly has an elongated tube with a stop ring formed thereon and an ambient pressure side. The blow out preventer is connected to the entrance of the subsea hydrocarbon producing wellbore, and includes an inflatable bladder and is connected to a hollow riser connected thereto.

Abstract: A tubing hanger positioned within the bore of a wellhead body has a vertical bore from which a tubing string may be suspended within a well bore. When the hanger is landed, a fluid passageway in the tubing hanger has one end in fluid communication with a passageway in the wellhead body and its other end connected to a pressure responsive downhole function. The poppet valve mounted in the passageway is urged closed, and when opened permits fluid pressure from a source to be supplied to the function.

Abstract: A susbsea well has communication passages to enable annulus pressure surrounding inner and intermediate strings of casings to be monitored at the surface. The passages both have outlets that allow communication to the tree assembly for monitoring. In one embodiment, the passage outlets are located in the bore of the high pressure well head housing and communicates to the tree assembly along an isolation sleeve. In another embodiment, the passage outlets are located on the exterior of the high pressure wellhead housing and communicate through a flying lead coming down from the tree. In another embodiment, the passage outlets are located on the exterior of the high pressure wellhead housing and communicate to an upward facing connection which is stabbed with a downward facing connection coming down from the tree.

Abstract: A method for addressing the problem known as formation breathing occurring during the drilling of a subsea well in an earth formation in performing a series of leak off tests to determine the earth formation fracture propagation pressure and the earth formation fracture reopen pressure and maintaining the hydrostatic pressure on the earth formation in a range between the fracture reopen pressure and the fracture propagation pressure.

Abstract: A well data monitoring system which enables annulus pressure and other well parameters to be monitored in the outer annuli of the well casing program without adding any pressure containing penetrations to the well system. This non-intrusive approach to monitoring pressure and other well parameters in the annuli preserves the pressure integrity of the well and maximizes the safety of the well. In the preferred embodiment an intelligent sensor interrogation system which can be located externally or internally of the pressure containing housing of the wellhead is capable of interrogating and receiving data signals from intelligent well data sensors which are exposed to well parameters within the various annuli of the well and wellhead program.

Abstract: A method for detecting a leak in a drill string valve used when drilling a subsea well. The method comprises measuring a first inlet pressure at a subsea mudlift pump while a subsea mudlift pump and a surface pump are operating and before a well is fully shut-in and measuring a second inlet pressure at the subsea mudlift pump after the mudlift pump and the surface pump are shut down and after the well is fully shut-in. The first and second subsea mudlift pump inlet pressure measurements are then compared, and a check is performed to determine if the subsea mudlift pump inlet pressure has increased by an amount greater than an estimated annular friction pressure.

Abstract: A buoyancy system for a deep water floating platform includes at least one buoyancy module coupled to the a riser. The module may be coupled to a ring structure of an end cap coupled to the riser, or two modules may be coupled to a ring structure to couple them together. The modules have an interior flange extending into the interior cavity and abutting the ring structure. Fasteners couple the interior flange of the module to the ring structure to form an interior attachment. A seal may be formed between the flange of the buoyancy module and the ring structure, and may include a seal member disposed in a groove. A test port extends to the groove to allow testing of the seal. The module may include a material and may have a thickness that together allow a wall of the buoyancy module to expand outwardly under an internal pressure and force the flange against the ring structure to enhance sealing between the flange and ring structure.

Abstract: A method for detecting a leak in a drill string valve used when drilling a subsea well. The method comprises measuring a first inlet pressure at a subsea mudlift pump while a subsea mudlift pump and a surface pump are operating and before a well is fully shut-in and measuring a second inlet pressure at the subsea mudlift pump after the mudlift pump and the surface pump are shut down and after the well is fully shut-in. The first and second subsea mudlift pump inlet pressure measurements are then compared, and a check is performed to determine if the subsea mudlift pump inlet pressure has increased by an amount greater than an estimated annular friction pressure.

Abstract: A method and apparatus for testing blowout preventer systems that enables testing of various size pipe rams, as well as safe and efficient shut-in of a well, without having to trip the entire apparatus out of a well. The testing apparatus generally includes an upper elongated testing cylinder, an upper test seal assembly, a lower elongated testing cylinder, a lower test seal assembly and a test plug. Additionally, the testing apparatus may include a circulating flow assembly, a side-port assembly, and a check-valve assembly, all of which are axially connected in a series to allow the testing tool to be easily lowered into a riser to a subsea blowout preventer assembly. The subject invention permits testing of blowout preventers that are designed to seal around various size pipe diameters during a single pipe trip. The invention also allows the operator to efficiently and safely shut-in a well if a kick is experienced during testing operations.

Abstract: The present invention refers to a connection device (14, 15), particularly for the connection of a rigid duct to a flexible duct in a submarine system for petroleum exploration, comprising a base (16); a hub fixed on the base; a hoisting/launching device, and a tube (20) with its first end connected to the hub and its second end being free, the novelty basically consisting in that the hoisting/lauching device (22) is placed above the center of gravity of the connection device (14, 15) and the second end (21) of the tube (20) is movable.

Abstract: Method and apparatus are disclosed for confirming the integrity of a seal system extending between a conduit disposed within a subterranean well and a surface or top Christmas tree assembly such that the confirmation steps do not adversely thereafter effect the sealing integrity of the system when exposed to high pressure and/or temperature environments.

Abstract: A subsea well has a tubing hanger which has an annulus bore and a production bore. A check valve is located in the annulus bore. A running tool runs the tubing hanger on a monobore riser such as a drill string while holding the check valve in the open position. After setting and testing, the running tool is lifted and a blowout preventer is closed around the landing string. The operator monitors the choke and kill line of the drilling riser, which will be in communication with the check valve. If the check valve is leaking, an annulus plug may be installed in the annulus bore. The installation of the annulus plug may be handled by using a retrieval tool configured to align the annulus bore with the landing string passage. A wireline tool may be lowered through the landing string and retrieval tool to retrieve the check valve and install the plug. Alternately, the check valve may remain in the tubing hanger and the plug is set in the annulus bore above it.

Abstract: A composition and uses of said composition are described for a latex based setting system for remedial and other operations within a wit bore. The composition comprises a pH-reducing agent and/or a coagulant. By controlling the amount of agent, the setting time of the system can be controlled in a range of 0.5 h to 15 h.

Abstract: A method and apparatus for testing blowout preventer systems that enables testing of various size pipe rams, as well as safe and efficient shut-in of a well, without having to trip the entire apparatus out of a well. The testing apparatus generally includes an upper elongated testing cylinder, an upper test seal assembly, a lower elongated testing cylinder, a lower test seal assembly and a test plug. Additionally, the testing apparatus may include a circulating flow assembly, a side-port assembly, and a check-valve assembly, all of which are axially connected in a series to allow the testing tool to be easily lowered into a riser to a subsea blowout preventer assembly. The subject invention permits testing of blowout preventers that are designed to seal around various size pipe diameters during a single pipe trip. The invention also allows the operator to efficiently and safely shut-in a well if a kick is experienced during testing operations.

Abstract: A wellhead cap assembly (10) includes a high security barrier (16) for installation onto a wellhead (12) containing any leakage safely and for permitting the installation of a subsea xmas tree onto the wellhead (12) whilst, simultaneously, providing means for containing full pressure control during rectification of the leak. The barrier (16) is provided by an internal tree cap which allows pressure between the top of the tubing hanger (34) and the underside of the tree cap (16) to be monitored by pressure monitoring means (20) via a port (29) in the assembly (10) and, in addition, in the event the presence of well bore fluids is detected indicating that leakage has occurred, the cap assembly allows intervention in order to rectify the leakage.