The invention provides a subsea oil and gas production installation, methods of installing the installation and methods of use. The installation comprises a subsea production system comprising a first production pipeline and a second production pipeline, a first subsea manifold in fluid communication with the first production pipeline comprising a fluid access interface and a flowline connector, a removable module fluidly connected to the fluid access interface of the first subsea manifold and configured to receive production fluid from one or more subsea wells and a second subsea manifold in fluid communication with the second production pipeline. The first subsea manifold defines a first flow path between the fluid access interface and the first production pipeline and a second bypass flow path between the fluid access interface and the flowline connector. The first and the second subsea manifolds are fluidly coupled to one another by a connecting flowline which is connected at a first end to the flowline connector of the first subsea manifold. The removable module comprises a flow control means operable to selectively route the production fluid from one or more subsea wells into the first production pipeline via the first flow path defined by the manifold, and/or into the second production pipeline via the second bypass flow path, the connecting flowline and the second subsea manifold.

This disclosure includes flow spool riser segment assemblies that are suitable for managed pressure drilling (MPD) and that can be lowered (e.g., when connected to other riser segment assemblies) through a rotary of a drilling rig. Some embodiments are configured to have portions of the flow spool connected (e.g., without welding) below the rotary.

This disclosure includes flow spool riser segment assemblies that are suitable for managed pressure drilling (MPD) and that can be lowered (e.g., when connected to other riser segment assemblies) through a rotary of a drilling rig. Some embodiments are configured to have portions of the flow spool connected (e.g., without welding) below the rotary.

A subsea connection system for connecting to a hub has a body with an interior passageway, a collet having a plurality of collet segments, an outer sleeve overlying the collet, and a poppet valve assembly positioned within the interior passageway of the body. The plurality of collet segments are movable between a locked position and an unlocked position. The poppet valve assembly is movable between an open position and a closed position in which the open position allows a fluid to flow through the interior passageway and the closed position blocks a flow of fluid through the interior passageway. The outer sleeve is movable so as to cause the plurality of collet segments to join to a hub.

A subsea connection system for connecting to a hub has a body with an interior passageway, a collet having a plurality of collet segments, an outer sleeve overlying the collet, and a poppet valve assembly positioned within the interior passageway of the body. The plurality of collet segments are movable between a locked position and an unlocked position. The poppet valve assembly is movable between an open position and a closed position in which the open position allows a fluid to flow through the interior passageway and the closed position blocks a flow of fluid through the interior passageway. The outer sleeve is movable so as to cause the plurality of collet segments to join to a hub.

A subsea chemical injection system and method for injecting chemicals into a hydrocarbon production assembly adjacent the seabed wherein a seawater volume flowmeter is utilized to measure seawater pumped through the system and a chemical subsea mass flowmeter is used to measure a chemical injected into the seawater, where the chemical subsea mass flowmeter measures the chemical at a pressure less than the seawater pumped through the system. Based on the chemical subsea mass flowmeter measurement, the flowrate of a chemical injected into the seawater can be adjusted to a predetermined setpoint corresponding to the flowrate of seawater pumped through the system. The chemical subsea mass flowmeter includes a Coriolis tube and chemical injection process pump housed within a pressure vessel. The subsea chemical injection system may be carried on a skid.

A subsea chemical injection system and method for injecting chemicals into a hydrocarbon production assembly adjacent the seabed wherein a seawater volume flowmeter is utilized to measure seawater pumped through the system and a chemical subsea mass flowmeter is used to measure a chemical injected into the seawater, where the chemical subsea mass flowmeter measures the chemical at a pressure less than the seawater pumped through the system. Based on the chemical subsea mass flowmeter measurement, the flowrate of a chemical injected into the seawater can be adjusted to a predetermined setpoint corresponding to the flowrate of seawater pumped through the system. The chemical subsea mass flowmeter includes a Coriolis tube and chemical injection process pump housed within a pressure vessel. The subsea chemical injection system may be carried on a skid.

A system in some embodiments includes sealing system including an energizing member that simultaneously seats a plurality of sealing elements about a plurality of control lines, respectively. Further embodiments provide a method including disposing a plurality of sealing elements about a plurality of control lines, respectively, and fastening an energizing member to simultaneously seat each of the sealing elements.

A method for treating the formation of hydrates in a fluid system includes pumping a fluid at a substantially constant fluid flow rate through a hydrate removal system including a pressure modulator, communicating a vacuum pressure to a piece of subsea equipment from a pressure port of the pressure modulator, closing a valve in the hydrate removal system to cease the fluid flow through the hydrate removal system at the substantially constant fluid flow rate, and communicating a positive pressure greater than the vacuum pressure to the piece of subsea equipment in response to closing the valve of the hydrate removal system.

A method for treating the formation of hydrates in a fluid system includes pumping a fluid at a substantially constant fluid flow rate through a hydrate removal system including a pressure modulator, communicating a vacuum pressure to a piece of subsea equipment from a pressure port of the pressure modulator, closing a valve in the hydrate removal system to cease the fluid flow through the hydrate removal system at the substantially constant fluid flow rate, and communicating a positive pressure greater than the vacuum pressure to the piece of subsea equipment in response to closing the valve of the hydrate removal system.