Onesubsea IP UK Limited

Akshay Kalia

Alireza Shirani

Marcus Lara

Adriano F Pinho

Gustavo M Gonzalez

Phillip M Theriot

Sergio Yamahata

Ted Mercer

Jan Illakowicz

Randy Kimberling

Tyler Skowronek

Brian Bibighaus

Tom Polasek

Tommy D Polasek

Fernando Saenz

Jack Coble

John A Roberts

Alessandro Sales

Jefferson Rodrigo Marcelino Dos Santos

Adriano Pinho

Gustavo Gonzalez

A flowline jumper for providing fluid communication between first and second spaced apart subsea structures includes a length of conduit having a predetermined size and shape and first and second connectors deployed on opposing ends of the conduit. The first and second connectors are configured to couple with corresponding connectors on the subsea structures. At least one electronic sensor is deployed on the conduit. The sensor is configured to measure at least one of a vibration and a load in the conduit.

Load and vibration monitoring on a flowline jumper

An apparatus includes a flowline connector having an inboard pipe and an outboard assembly. The outboard assembly includes a frame and an outboard pipe moveable within the frame to allow the outboard pipe to be moved toward the inboard pipe. The outboard assembly also includes a profile pipe in which the outboard pipe is received, and the profile pipe and the outboard pipe are connected to move together. The profile pipe includes at least one guide to change pitch or yaw of the outboard pipe to direct the outboard pipe toward alignment with the inboard pipe as the outboard pipe is moved within the frame toward the inboard pipe. Additional systems, devices, and methods are also disclosed.

Horizontal connector system and method

A vertical multi-bore jumper. The jumper is outfitted with interfaces that include rotatable hubs accommodating perimeter bore terminations that may be rotated about a central production bore. In this manner, the multiple bores may be flexibly aligned with corresponding couplers at equipment located on the seabed. As a result, undue torque is not placed on the jumper in attempting to align multiple bores at the interfaces which may be frequently misaligned at the outset of such installations.

Multi-bore jumper interface

A subsea pipeline system may include a subsea pipeline station configured to establish fluid communication between a first pipeline and a second pipeline. The first pipeline may have a first diameter, and the second pipeline may have a second diameter different from the first diameter. Additionally, the subsea pipeline station may be configured to removably couple to one or more pig launching assemblies having different configurations.

Subsea pipeline station

A subsea connector assembly with flowmeter incorporated therein. The assembly is particularly configured for securing a flexible flowline at subsea production managing hardware such as at a manifold at a seabed or Christmas tree at a well head. Incorporating a flowmeter into the connector as opposed to such comparatively larger scale hardware ultimately saves substantial material, transport, installation, footspace and other costs.

Subsea flowmeter connector assembly

A technique facilitates controlling fluid flows with a modular manifold. The modular manifold has a manifold base which is positioned at a desired surface or subsea location. Various types of modular units may be deployed to and/or retrieved from the manifold base according to the desired control of fluid flows with respect to a well or a plurality of wells. Each modular unit may be selectively coupled or decoupled along the manifold base to adjust the configuration of the manifold for a given job or over time to accommodate changing conditions.

Modular manifold

A subsea flowline jumper connector includes at least one electronic connector deployed thereon. The sensor may provide data indicative of the connector state during installation and production operations.

Instrumented subsea flowline jumper connector

A technique for engaging a bore connector with a receptacle on subsea equipment. The technique may include providing an operator with a visual indication of acceptable alignment between the connector and the receptacle in advance of attaining engagement. In this way, a proper and reliably sealed engagement may be achieved. Further, the bore connector and techniques for use thereof include added indication of completed sealed engagement sufficient for testing and/or operational use of the connector in supporting a fluid application directed at the equipment through the receptacle.

Bore connector engagement technique

A technique facilitates clamping operations by providing mechanical advantage. According to an embodiment, a clamping system comprises a clamp having a plurality of clamp segments with surfaces oriented to securely hold and clamp mating features, e.g. mating hubs, of adjacent components. The clamping system also may comprise an actuator coupled to the clamp to enable selective shifting of the clamp between an open position to receive the mating features and a closed position in which the clamp segments are contracted together to secure engagement of those features. A driver is coupled to the actuator to enable movement, e.g. shifting, of the actuator when opening or closing the clamp. The actuator facilitates operation of the driver via, for example, an ROV by providing mechanical advantage and thus increasing the clamping force applied by the clamp to the mating features.

Growing community of inventors

Houston, TX, United States of America

Akshay Kalia