Abstract: A retrievable connection module for establishing a fluid flow between a subsea station and a subsea flow line. The connection module includes a first fluid port, a first connection profile, a second fluid port, a second connection profile, and a utility arrangement which alters or monitors an aspect or a characteristic of the fluid flow between the first and the second fluid ports. The first connection profile is releasably couplable to a flow line to permit a fluid communication between the flow line and the first fluid port. The second connection profile is releasably couplable to the subsea station to permit a fluid communication between a subsea well and the second fluid port. The first connection profile disconnects the flow line and restricts the fluid communication at the first fluid port. The second connection profile disconnects from the subsea station and restricts the fluid flow at the second fluid port.

Abstract: This disclosure includes methods for testing hydraulically-actuated devices and related systems. Some hydraulically-actuated devices have a housing defining an interior volume and a piston disposed within the interior volume and dividing the interior volume into a first chamber and a second chamber, where the piston is movable relative to the housing between a maximum first position and a maximum second position in response to pressure differentials between the first and second chambers. Some methods include: (1) moving the piston to the first position by varying pressure within at least one of the first and second chambers such that pressure within the second chamber is higher than pressure within the first chamber; and (2) while the piston remains in the first position: (a) reducing pressure within the second chamber and/or increasing pressure within the first chamber; and (b) increasing pressure within the second chamber and/or decreasing pressure within the first chamber.

Abstract: The present disclosure provides a latch system that is activated internally after installation in a tubular member and requires no external penetration through a wall of the tubular member. The latch system and the tool on which it is installed includes an energizing ring and a lock ring resting on a portion of the tool, where the energizing ring can be pressed toward the lock ring to expand the lock ring radially outward and lock into an internal lock groove in a bore of the tubular member. A self-locking mechanism using corresponding profiles in the components can, with the lock ring expansion, longitudinally lock the energizing ring with the lock ring and lock the energizing ring with the tubular member. The dual locking of the three components locks or otherwise restrains the components together, so that the tool is fixed in a longitudinal position relative to the tubular member.

Abstract: Installation for producing fluid such as crude oil having a floating support having at least two tanks, an undersea bottom-to-surface connection pipe having a first pipe portion on the sea bottom from a well head to the bottom end of a second pipe portion at the floating support, a first auxiliary pipe for transporting gas extending from the floating support to the bottom end of the second pipe, and a plurality of valves for isolating or putting into communication the first auxiliary pipe, for isolating or putting into communication the first production pipe portion and the second production pipe portion, end to end, and suitable for isolating or putting into communication the proximal end of the first production pipe portion and the bottom end either of a fourth auxiliary pipe rising directly to the surface, or a bottom portion of the first auxiliary pipe.

Abstract: A fracturing fluid delivery system is provided. In one embodiment, the system includes a wellhead assembly, a fracturing fluid supply line, a vertical branch extending upward from the fracturing fluid supply line, and a fluid conduit coupling the vertical branch in fluid communication with the wellhead assembly. The fluid conduit may extend linearly from the vertical branch to the wellhead assembly. Additional systems, devices, and methods are also disclosed.

Abstract: The invention relates to the drilling of subsurface oil and gas wells and the installation of subsurface equipment (11). A lifting vessel 7 brings heavy equipment such as Xmas trees or manifolds and wet parks this equipment (11) on the seafloor (5) during good weather when the significant wave height is low. The equipment (11), once it is underwater, has much lower weight and may easily be moved into place onto a wellhead (10) at an appropriate time using lower capacity lifting gear. The timing of this operation is much less sensitive to weather conditions because the equipment does not need to pass through the splash zone (sea surface). This makes for efficient use of expensive drilling rig time, and allows for acceleration of production of first wells on the template as critical heavy lifts could not else be done until rig has left the location. (FIG. 1).

Abstract: A method is for placing an object on a seabed. The method includes connecting the object to at least two vessels by use of a work wire; attaching one or more buoyancy devices to the work wire, to achieve a distributed buoyancy of the work wire that forms a double curvature which disassociates at least some vessel movement from the object, to allow for controlled movement of the object; and co-operating the vessels to move the object into a position in a sea distant from the vessels, to lower the object to the seabed and to place the object on the seabed. Also described is a system for transporting an object to a position in a sea where the water comprises gas bubbles significantly lowering the load-carrying capacity of the water and for lowering the object to an area having a wellbore from which the gas bubbles enter the sea.

Abstract: An offshore production system includes a surface vessel, a tubular tendon extending between the surface vessel and a lower connection system disposed at a seabed, the riser coupled to the surface vessel with an upper connection system, and an electrical cable extending through a central passage of the tubular tendon, wherein the upper connection system comprises a connector that physically supports the electrical cable.

Abstract: The invention provides an apparatus and system for accessing a flow system (such as a subsea tree) in a subsea oil and gas production installation, and method of use. The apparatus comprises a body and a plurality of connectors configured to connect the apparatus to the flow system. A flow access interface is provided on the body for connecting the apparatus to a subsea process apparatus, and the body defines a plurality of flow paths. Each flow path fluidly connects one of the plurality of connectors to the flow access interface to provide an intervention path from a connected subsea process apparatus to the flow system in use. Aspects of the invention have particular application to flow metering, fluid sampling, and well scale squeeze operations.

Abstract: Method of stopping production and making safe an undersea bottom-to-surface connection production pipe having a first pipe portion on the sea bottom from a well head to the bottom end of a second pipe portion extending to a ship or floating support. After stopping production, depressurization of the entire undersea bottom-to-surface connection production pipe is performed. Thereafter, the following steps are preformed: isolating the first production pipe portion from the second pipe portion, and leaving the production fluid in the first production pipe portion, but not in said second pipe portion, depressurizing the first production pipe portion filled with production fluid by reducing the pressure in the first pipe portion and by discharging more completely the gas contained in the production fluid that it contains.

Abstract: A torque tool to apply torque to a subsea component with a remotely operated vehicle (ROV) includes a housing, a socket drive to rotate within the housing, and a latch mechanism. The latch mechanism includes a latch to move with respect to the housing between an engaged position to engage the subsea component and a disengaged position to disengage the subsea component. The latch mechanism further includes a biasing mechanism to bias the latch from the engaged position towards the disengaged position, and/or an electric motor to move the latch from the disengaged position towards the engaged position.

Abstract: The invention provides an apparatus and system for accessing a flow system (such as a subsea tree) in a subsea oil and gas production installation, and method of use. The apparatus comprises a body and a plurality of connectors configured to connect the apparatus to the flow system. A flow access interface is provided on the body for connecting the apparatus to a subsea process apparatus, and the body defines a plurality of flow paths. Each flow path fluidly connects one of the plurality of connectors to the flow access interface to provide an intervention path from a connected subsea process apparatus to the flow system in use. Aspects of the invention have particular application to flow metering, fluid sampling, and well scale squeeze operations.

Abstract: Methods and systems for automated well event detection and response are provided herein. Example methods are implemented in an automated tripping management application. The application can execute to perform a remote management function for operation of a drilling rig. This includes monitoring actual and calculated running speeds, bottom hole pressures, and drill string pressures based on fluids used at the drilling rig, and generating both alerts in the event of operation outside of predetermined thresholds, and recommended adjustments to operation of one or more drilling rigs. The thresholds and alerting can be based on a set of operating rules developed to automate monitoring of such processes in a way that additional events are detected and responded to.

Abstract: Pipe replacement devices, and systems are shown. Devices and systems may include jointed cutters and floating cutters to navigate difficult pipe replacement conditions. Devices and systems may also include replacement pipe with pre-installed supply hoses, such as lubricant supply and/or pneumatic supply hoses. Methods of pipe replacement are also described, including splitting old pipe and pulling in new pipe behind the equipment as splitting progresses.

Abstract: An early production system includes an Emergency Disconnect Package (“EDP”), a production riser coupled between the EDP and a sea surface processing facility, a gas export tubing coupled between the EDP and the sea surface processing facility, and a flow base. The flow base is detachably connectable to the EDP. The flow base also includes an Independent Production Control System (“IPCS”) for controlling at least one production valve.

Abstract: A connection assembly for automated lifting and positioning of a chiksan or other fluid conduit in proximity to a fluid inlet of a device such as, for example, a cement or hydraulic fracturing head. Once a chiksan or other flow line is positioned in a desired location, a secure connection is made between the outlet of the chiksan or other fluid conduit and the fluid inlet including, without limitation, when the device is positioned at an elevated location above a rig floor.

Abstract: A method of installing a flexible line between an offshore platform and a subsea structure and a method of removing a flexible line deployed between an offshore platform and a subsea structure. The method of installing includes at least partially deploying the line in the water using an installation vessel located outside of an exclusion zone in the vicinity of the platform, including lowering a topside end of the line either to the seabed or to an intermediate location between the seabed and the platform. The method further includes pulling the topside end to a position within the exclusion zone and winching the topside end up to the platform, and coupling the topside end to the platform.

Abstract: The present disclosure provides a cooling system and method for a reciprocating mandrel in a blowout preventer test system that provides coolant to the mandrel through a majority of its stroke. The system includes an inner coolant tube and an outer coolant tube, with both tubes inserted into a mandrel inner bore. The inner coolant tube is fixed in position on a base and not attached to the mandrel. The outer coolant tube is fixed in position and attached to the mandrel. The outer coolant tube slidably and optionally sealingly engages the inner coolant tube throughout the mandrel stroke. Coolant can flow through the base, upward through an inner volume of the inner coolant tube, and into an inner volume of the outer coolant tube and out of coolant openings in the outer coolant tube to flow on the inner bore surfaces of the mandrel to cool the mandrel.

Abstract: A hydraulic valve arrangement (1) is provided comprising comprising a supply port arrangement having a high pressure port (2) and a low pressure port (4), a working port arrangement having two working ports (6, 7), a first valve (13) arranged between said high pressure port (2) and said working port arrangement (6, 7), a second valve (14) arranged between said low pressure port (4) and said working port arrangement (6, 7), a controller (19) for controlling said first valve (13) and said second valve (14), said controller (19) having an input connection (20) for receiving a signal of an operator input device, and a regenerative flow path which can be established by means of at least one of said first valve (13) and said second valve (14). The function of such a hydraulic valve arrangement should be enhanced. To this end said controller (19) said controller interrupts said regenerative flow path when a feed pressure at said working port arrangement (6, 7) exceeds a predetermined pressure level.

Abstract: Extender jumper systems and methods including an extender jumper system having an extender jumper assembly with a flowline and first and second connectors positioned at first and second ends of the flowline, and a support assembly configured to couple the extender jumper assembly to a support structure within a subsea field and to support the second connector to facilitate attachment between the second connector and a corresponding connector of another extender jumper or a jumper.

Abstract: A connector assembly for connecting a hose to a tubular element. The connector assembly includes a housing, a hose connector, and a latch. The housing encloses a main passage which is parallel to a longitudinal axis of the housing and which has a side passage extending through the housing from an exterior of the housing into the main passage. The side passage extends through a connector tube mounted on an exterior of the housing. A hose connector is secured to an end of the hose and engages with the connector tube to connect the hose to the tubular element. The hose connector comprises a pipe portion which mates with the connector tube to connect an interior of the hose to the side passage. The latch urges the connector tube and the pipe portion into engagement and prevents a separation thereof.

Abstract: A connection assembly for automated lifting and positioning of a chiksan or other fluid conduit in proximity to a fluid inlet of a device such as, for example, a cement head. Once a chiksan or other flow line is positioned in a desired location, a secure connection is made between the outlet of the chiksan or other fluid conduit and the fluid inlet of a cement head including, without limitation, when the cement head is positioned at an elevated location above a rig floor.

Abstract: A riser tree controls adapter comprises an outer riser tree controls adapter, placed outside a first tubular, and an inner riser tree controls adapter placed outside a second tubular and configured to be received into the outer riser tree controls adapter. Once inserted into the outer riser tree controls adapter, one or more control signal pathways are provided between a junction plate control connection receiver and a corresponding set of inner connection interfaces.

Abstract: A system for diverting fluids from a wellhead in a subsea environment has a capping stack with a connector suitable for connection or interconnection to the wellhead, a flow base fixedly positioned in the subsea environment, and a conduit connected to the outlet of a diverter line of the capping stack and connected to the inlet of an interior passageway of the flow base. The conduit is suitable for passing fluids from the capping stack toward the flow base. The flow base is a modified horizontal Christmas tree. The interior passageway within the horizontal Christmas tree has a plug therein located a level below the level of the inlet to the flow base. The flow base can be attached to a wellhead or to an anchor pile in the subsea environment.

Abstract: A subsea mud pump can be used to return heavy drilling fluid to the surface. In order to provide a less stringent requirement for such a pump and to better manage the bottom hole pressure in the case of a gas kick or well control event, the gas should be separated from the drilling fluid before the drilling fluid enters the subsea mud pump and the pressure within the separating chamber. The mud pump suction should be controlled and kept equal or lower than the ambient seawater pressure. This can be achieved within the cavities of the subsea BOP by a system arrangement and methods explained. This function can be used with or without a drilling riser connecting the subsea BOP to a drilling unit above the body of water.

Abstract: A subsea relief valve system for use in a subsea environment has subsea piping having a first portion and a second portion, a choke cooperative with the subsea piping and movable between an open position and a closed position, a hydraulic actuator connected to the choke so as to move the choke between the open and closed positions, and a signal source cooperative with the hydraulic actuator so as to actuate the choke to the open position when an overpressure condition is detected. The open position of the choke is suitable for venting a fluid to the subsea environment. The closed position of the choke is suitable for retaining the fluid within the subsea piping.

Abstract: A system for connecting flow interface equipment to a subsea manifold is disclosed. The system relates particularly to an apparatus adapted to inject fluids into a well having a flow bore. The system includes a connection apparatus adapted to land a conduit means on a subsea manifold and to connect a conduit means of the connection apparatus to a choke body of the manifold.

Abstract: A wellhead for subsea use and a method of making same where the wellhead is constituted by a body having a bore (3) therethrough and at least one side bore (9, 11) for provision of fluid communication through the wall of the wellhead (1), and where the wellhead (1) includes a pipe hanger (30) provided with a bore (34) therethrough and a side bore (36) for provision of fluid communication between a tubing string (9?) connected to the pipe hanger (30) and one of the side bores (9) of the wellhead (1), where the wellhead (1) is provided with at least one internal safety valve (42, 44) arranged to be able to shut off fluid communication through the wellhead.

Abstract: A system compensates for heave-induced pressure fluctuations on a floating rig when a drill string or tubular is lifted off bottom and suspended on the rig, such as when tubular connections are made during NIPD, tripping, cementing operations or when a kick is circulated out during conventional drilling. In one embodiment, a pressure relief valve or adjustable choke allows the movement of fluid from the riser when the tubular moves down, and a pump with a pressure regulator moves fluid to the riser when the tubular moves up. The system also compensates for heave induced pressure fluctuations on a floating rig when a riser telescoping joint located below an RCD is moving between its retracted and extended positions while drilling.

Abstract: Subsea wellhead assembly with an inner bore for conduction of produced hydrocarbons, equipped with a cooling means for cooling a section of the wellhead assembly exposed to heating by said hydrocarbons.

Abstract: A system, in certain embodiments, includes a subsea tree and a tubing spool including a longitudinal bore configured to receive a tubing hanger. The tubing spool also includes a lateral flow passage extending from the longitudinal bore and configured to transfer product to the subsea tree. The subsea tree includes multiple valves each coupled to a structure positioned radially outward from the tubing spool such that the subsea tree does not block a subsea intervention connection or blowout preventer (BOP) access to the longitudinal bore.

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 assembly comprises a housing (1) having a first end having an inlet channel and a second end having an outlet channel, said channels being connected by a central passage (3), said housing further comprising a side-entry bore (2) providing communication between said central passage and the external of said housing, the assembly also comprising a hanger positioned below said side-entry bore, supporting a coiled tubing and provided with a first passage communicating with said coiled tubing and a second separate fluid passage communicating with the annulus surrounding said coiled tubing.

Abstract: An electrical and hydraulic configuration on a subsea tree that facilitates the use of an ROV control system to operate the tree during well installations, interventions, and workovers. An SCM at the tree is in communication with a fixed junction plate that receives a production umbilical during normal operation. The ROV can be deployed to disconnect and park the production umbilical during well installations, interventions, and workovers to prevent accidental operation of the SCM or tree. The junction plate is configured to connect with the ROV and thereby establish communication with the hydraulic lines of the SCM. The ROV may carry an umbilical from a vessel to provide electrical and hydraulic service to the SCM during well operations. In addition, the ROV has facilities to repressurize spent control fluid to thereby allow reuse of the control fluid by the SCM.

Abstract: Systems for accessing a well bore including a BOP stack with a universal intervention interface are disclosed. In some embodiments, the system includes a BOP stack and a valve assembly. The BOP stack has a throughbore and is installable on a well such that the throughbore is in fluid communication with the well bore. The valve assembly is coupled to the BOP stack and includes a fluid flowpath in fluid communication with the BOP stack throughbore, two valves connected in series and disposed along the fluid flowpath, the valves operable to control flow through the fluid flowpath, and a ROV panel including ports accessible by a ROV for operation of the two valves.

Abstract: A system for capping a blowout preventer has a capping stack with a connector suitable for connection to the blowout preventer, a flowing stack, and an intervention blowout preventer connected to a connector of the flowing stack. The capping stack has a fluid passage extending from the connector. The capping stack has at least one diverter line in communication with the fluid passage. The flowing stack has an interior passageway extending to the connector at an upper end thereof. The flowing stack has at least one pipe in communication with the interior passageway. The pipe is connected with the diverter line of the capping stack such that a flow fluid passing through the diverter line passes through the pipe into the interior passageway of the flowing stack.

Abstract: An apparatus to allow backup or alternate fluid flow routes around malfunctioning BOP control components using a remotely installed removable hydraulic hose connection. The backup fluid flow route sends pressure-regulated hydraulic fluid to a BOP operation via an isolation valve rigidly attached to the BOP, then to a hose connected to an intervention panel on the BOP and finally through a valve that isolates the primary flow route and establishes a secondary flow route to allow continued operation. To increase reliability, the backup components route from a spare BOP function and are rigidly fixed to the BOP.

Abstract: A drilling system employing a main tubular having a plurality of fluid inlet and outlet conduits positioned thereon and a concentric inner tubular having a plurality seals for sealing the annular space between the concentric inner and main tubulars. The fluid inlet and outlet conduits work in cooperation with the annular seals to selectively open and close for effective management of pressure within the tubulars.

Abstract: Methods and apparatus for diverting fluids either into or from a well are described. Some embodiments include a diverter conduit that is located in a bore of a tree. The invention relates especially but not exclusively to a diverter assembly connected to a wing branch of a tree. Some embodiments allow diversion of fluids out of a tree to a subsea processing apparatus followed by the return of at least some of these fluids to the tree for recovery. Alternative embodiments provide only one flowpath and do not include the return of any fluids to the tree. Some embodiments can be retro-fitted to existing trees, which can allow the performance of a new function without having to replacing the tree. Multiple diverter assembly embodiments are also described.

Abstract: Wellhead-based systems, apparatus, and methods for controlling a well are provided. During a failure of an emergency system such as a blowout provider, a wellhead based emergency control apparatus according to an embodiment of the invention can be employed to control the well. A casing strings compression assembly can radially compress each of the casing strings and/or drilling pipe extending through the wellhead housing to restrict or stop well fluid passage. A casing strings penetrator of an emergency well fluid diversion assembly can also or alternatively be employed to form an aperture in the casing strings. A diverter, integral with or connected to the penetrator, is extended through an aperture in a side of the wellhead housing and one or more of the apertures cut by the penetrator to divert well fluid from within the wellhead housing through a passageway in the diverter and to an external conduit.

Abstract: Methods and apparatus for diverting fluids either into or from a well are described. Some embodiments include a diverter conduit that is located in a bore of a tree. The invention relates especially but not exclusively to a diverter assembly connected to a wing branch of a tree. Some embodiments allow diversion of fluids out of a tree to a subsea processing apparatus followed by the return of at least some of these fluids to the tree for recovery. Alternative embodiments provide only one flowpath and do not include the return of any fluids to the tree. Some embodiments can be retro-fitted to existing trees, which can allow the performance of a new function without having to replacing the tree. Multiple diverter assembly embodiments are also described.

Abstract: A high pressure sleeve for a dual bore high pressure riser is provided. The high pressure sleeve is arranged for forming a connection between either the annulus bore and the high pressure sleeve, or for forming a connection between the high pressure sleeve and the production bore. The choice of connection is made by rotation of the sleeve.

Abstract: Technical system (2; 2?), method and uses for dosing of at least one liquid treatment means (12) into injection water (16) to an injection well (22), wherein the technical system (2; 2?) comprises:—an underwater line (14; 14?) for transport of the injection water (16) from a shipment site (20; 48) for the injection water (16); and—at least one liquid-tight storage unit (10) containing the at least one liquid treatment means (12). The distinctive characteristic is that the at least one storage unit (10) is structured as a volumetrically flexible unit;—wherein said storage unit (10) is placed under water (6); and—wherein said storage unit (10) is connected, in a flow-communicating manner, to the underwater line (14; 14?) for dosing of liquid treatment means (12) into the injection water (16) to the injection well (22).

Abstract: Methods and systems for drilling subsea wells bores with dual-gradient mud systems include drilling the subsea well bore while employing a subsea pumping system, a subsea choke manifold and one or more mud return risers to implement the dual gradient mud system. When a well bore influx is detected, the well bore is shut in, and components determine if pressure control may be used to circulate the influx out of the well bore, the size of the influx, and how much the mud system weight will need to be reduced to match the dual gradient hydrostatic head before the influx reaches the subsea pump take point. The subsea pumping system, subsea choke manifold, and mud risers are isolated while the influx is circulated up one or more fluid passages in the drilling riser package using the surface pump, through the wellhead, and out the surface choke manifold.

Abstract: A method of repairing a subsea pipeline has the steps of positioning a pile onto a subsea floor in a location adjacent to the subsea pipeline, cutting a section of pipeline from the subsea pipeline so that the subsea pipeline has a first cut end and a second cut end, moving a length of pipeline to the pile so as to hingedly connect the length of pipeline with the receptacle on the pile, pivoting the length of pipeline about the hinged connection so as to move the length of pipeline from a generally vertical orientation to a generally horizontal orientation, connecting the first end of the length of pipeline to the first cut end, and connecting the second end of the length of pipeline to the second cut end.

Abstract: A device for inhibiting severe slug flow in a multiphase fluid stream flowing through a pipeline and into a riser, wherein, the device is positioned immediately upstream of the riser and comprises at least one unit comprising (i) an upwardly inclined section of pipe having a lower end and an upper end and (ii) either a substantially horizontal section of pipe having a first end and a second end or a downwardly inclined section of pipe having an upper end and a lower end, wherein the lower end of the upwardly inclined section of pipe is connected either directly or indirectly with the pipeline, the upper end of the upwardly inclined section of pipe is connected either directly or indirectly with the first end of the horizontal section of pipe or with the upper end of the downwardly inclined section of pipe, and the second end of the horizontal section of pipe or the lower end of the downwardly inclined section of pipe is connected either directly or indirectly with the riser, and wherein the angle of inclinati

Abstract: An apparatus to allow backup or alternate fluid flow routes around malfunctioning BOP control components using a remotely installed removable hydraulic hose connection. The backup fluid flow route sends pressure-regulated hydraulic fluid to a BOP operation via an isolation valve rigidly attached to the BOP, then to a hose connected to an intervention panel on the BOP and finally through a valve that isolates the primary flow route and establishes a secondary flow route to allow continued operation. To increase reliability, the backup components route from a spare BOP function and are rigidly fixed to the BOP.

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: Pressure within a subsea well is managed as temperature within the well fluctuate. The management of the pressure mitigates stress to the structure of the well caused by the pressure. To manage the pressure, fluid is received from and/or provided to the well to reduce and/or increase pressure within the well.

Abstract: A system compensates for heave induced pressure fluctuations on a floating rig when a drill string or tubular is lifted off bottom and suspended on the rig, such as when tubular connections are made during MPD, tripping, or when a kick is circulated out during conventional drilling. In one embodiment, a liquid and a gas interface moves along a flow line between a riser and a gas accumulator as the tubular moves up and down. In another embodiment, a pressure relief valve or adjustable choke allows the movement of fluid from the riser when the tubular moves down, and a pump with a pressure regulator moves fluid to the riser when the tubular moves up. In other embodiments, a piston connected with the rig or the riser telescoping joint moves in a fluid container thereby communicating fluid either into or out of the riser annulus.