Chevron U.s.a. Inc.

Petroleo Brasileiro S.a.

Antonio C F Critsinelis

Sid A Mebarkia

Christopher Allen Kassner

Farzan Parsinejad

Michelle A Wise

William C Hughes

Jason D Garcia

Edgar Uribe

Ahmed F Omar

Steven W Cochran

Michael J Quinney

Dane Ryne Drew

Yesudas J Manimala

Miguel Ruiz

Yesudas James Manimala

Renato M C Da Silva

Steven E Wooldridge

Vin&iacute;cius R Braga

Matthew Davis Hense

Helena Miao

Keiron Anson

Lynn Wang

Gary Anthony Giordano

Parsinejad Farzan

Systems and methods for thermal management of subsea conduits such as jumpers provide the ability to alternate between cooling and heat retention of production fluids within the conduit as needed depending on the phase of operation. Adjustable insulation elements are provided on the conduits so that convective heat transfer between surrounding seawater and the conduit can be allowed or reduced. A control system can activate an alarm indicating the need to adjust the insulation depending on the temperature and/or flow rate of fluids in the conduit. Conventional conduits can be retrofitted by adding adjustable insulation elements to enable thermal management.

Systems and methods for thermal management of subsea conduits using a jumper having adjustable insulating elements

Disclosed are systems and methods for thermal management of subsea conduits such as jumpers that provide the ability to alternate between cooling and heat retention of production fluids within the conduit as needed depending on the phase of operation. Adjustable insulation elements are provided on the conduits so that convective heat transfer between surrounding seawater and the conduit can be allowed or reduced. A control system can activate an alarm indicating the need to adjust the insulation depending on the temperature and/or flow rate of fluids in the conduit. Conventional conduits can be retrofitted by adding adjustable insulation elements to enable thermal management.

Disclosed are systems for securing a bend stiffener to a riser in an offshore energy production facility. In one system, the lower end of the bend stiffener has a magnet that repels a magnet in a clamp on the riser a distance below the bend stiffener. The magnets repel one another with a force during operation to decelerate falling and prevent contact between the clamp and the bend stiffener. Methods are provided for retrofitting a riser system by adding the magnets. In another system, the riser has an upper portion and a tapered portion immediately below the upper portion. The outer diameter of the tapered portion increases such that the tapered portion can be friction fit into the lower end of the bend stiffener in the event that the bend stiffener is forced down or free falls onto the riser.

Systems for securing bend stiffeners to riser systems in offshore energy production facilities

Disclosed are riser assemblies for connecting a topside structure and a subsea production facility. The assembly includes an upper riser having an upper end terminating at the topside structure, a flow diverting structure having an upper interface configured to connect to the upper riser and a lower interface configured to connect to at least two lower risers such that the upper riser is in communication with the at least two lower risers. Methods of deployment of the riser assemblies are also disclosed. The method includes connecting an upper riser to the topside structure, and connecting a first lower riser to a lower bore of the flow diverting structure such that the upper riser, the flow diverting structure and the first lower riser are connected, and the upper riser is in fluid communication with the first lower riser. Additional lower risers can be installed at a later time if desired.

Multiple bore flexible pipe riser systems and methods for deployment thereof

Disclosed is a pig assembly for maintaining a multi-diameter functional line with a large range of diameter variation for conveying fluid. The pig assembly includes a central shaft having a first shaft end and a second shaft end and at least one cylindrical pig body coaxially mounted on the central shaft. Attached to the at least one pig body are a plurality of arms capable of moving between an extended position radiating from the at least one pig body and a retracted position within the at least one pig body. Each of the pluralities of arms includes a spring to enable each arm of the plurality of arms to move into the extended position and to store potential energy when the arm is in the retracted position, and a roller to enable rolling contact between the pig assembly and an interior of a functional line during movement of the pig assembly within the functional line. The pig assembly further includes at least one set of a plurality of scraper elements located along the central shaft capable of rotating about the central shaft to move between an opened position and a collapsed position. A method for maintaining a multi-diameter functional line using the pig assembly is also disclosed.

Systems for maintaining a functional line for conveying fluid and pig assemblies for use therein

A system, apparatus, and method are provided for monitoring a subsea flow device such as a subsea flowline. The apparatus generally includes a thermoelectric device that is adapted to generate electric power from a thermal potential between the subsea flow device and the surrounding seawater. A sensor that is powered by the thermoelectric device is adapted to monitor one or more characteristics of the flow device, such as temperature or strain, and provide a communication that is indicative of the characteristic. The communication may be a radiation output or an acoustic output.

System, apparatus, and method for monitoring a subsea flow device

Disclosed is a pipe-in-pipe apparatus comprising an inner pipe disposed within an outer pipe wherein the inner pipe is an engineered pipe or umbilical. The outer pipe will shield the inner pipe. As a result, the design of the inner pipe only needs to address the functions required for the engineered pipe-in-pipe apparatus. The end fittings of the system are designed for enabling maximum operation and intervention flexibility. The engineered pipe-in-pipe apparatus will allow longer sections of the inner pipe to be used which will reduce the amount of field fabrication and streamline the installation process. The apparatus may be used for both new piping systems as well as the updating or retrofitting of an existing onshore or offshore piping system.

Pipe-in-pipe apparatus including an engineered pipe

An apparatus is disclosed which provides fluid communication between the inner bore and the annular space in a pipe-in-pipe system. Other embodiments disclose an apparatus which provides fluid communication between adjacent segments of the annular space, between the inner bore or the annular space and an external source in a pipe-in-pipe type system. Methods and systems are disclosed utilizing the various apparatus embodiments to transport well fluids in an offshore or onshore hydrocarbon production operation.

Pipe-in-pipe apparatus, and methods and systems

Disclosed are methods, systems and apparatus for circulating fluid within the annulus of a flexible pipe used in a riser in an offshore hydrocarbon production facility. Fluid, such corrosion inhibitors, can be introduced into the annulus by pumping fluid from a storage tank located on a platform or vessel into tubes within the annulus. Use of the system to flow the fluid through the annulus can prevent or reduce corrosion of the steel members within the annulus and increase the fatigue life of the riser.

Methods, systems and apparatus for circulating fluid within the annulus of a flexible pipe riser

Disclosed is a process and system for circulating fluid within the annulus of a flexible pipe used in a riser in an offshore hydrocarbon production facility. Fluid, such as corrosion inhibitors, can be circulated in a closed loop which includes the annulus of the riser terminating at a platform or floating vessel, a fluid storage tank located on the platform or vessel and an umbilical tube terminating at the platform or vessel and at a subsea location. Use of the system to flow the fluid through the annulus can prevent or reduce corrosion of the steel members within the annulus and increase the fatigue life of the riser.

Methods and systems for circulating fluid within the annulus of a flexible pipe riser

Disclosed are systems and methods for controlling lateral deformation and reducing axial displacement, also referred to as walking, of a subsea conduit such as a pipeline for conveying produced hydrocarbon fluids. The systems and methods include the installation of rolling assemblies on the conduit at predetermined locations. The rolling assemblies include elements for forming rolling modules rotatable with respect to the conduit. Also disclosed is a system for monitoring displacement of the conduit over time.

Lateral buckling mitigation apparatus, methods and systems for use with subsea conduits

A method for installing a subsea flowline and riser assembly on a sea floor includes providing a flowline having an axis and an end connected to a hinge-over joint, and a riser having an axis and an end connected to the joint such that the axes of the riser and flowline extend substantially parallel. An end of the flowline opposite the joint is lowered to the sea floor. The end of the flowline connected to the joint is lowered to the sea floor. The joint is connected to a foundation that is installed in the sea floor. The riser is rotated about the hinge-over joint such that the riser axis is substantially perpendicular to the flowline axis. A subsea jumper is connected between an opening formed in the flowline and an opening formed in the riser so that the riser is in fluid communication with the flowline.

Hinge-over riser assembly

A method for launching a steel catenary riser (SCR) from the seabed to the surface comprising three stages. During the first stage, joints are continually welded to the metal pipe resting on the seabed to form the length of the steel catenary riser (SCR) in contact with the seabed. In the second stage a length of pipe previously wound onto a receiving device is welded to the free end of the last joint welded and then it is unwound and launched to form the intermediate length of the steel catenary riser (SCR). In the third stage joints are again welded to the intermediate length of the steel catenary riser (SCR) to form the top length of the said steel catenary riser (SCR).

Growing community of inventors

Kingwood, TX, United States of America

Antonio C F Critsinelis