National Oilwell Varco, L.p.

Oceaneering International, Inc.

Travis Lee Bolt

Brandon Harman

Eric O'Reilly Sears

Kenneth R Newman

Jonathan Tyler Maxwell

Neil C Crawford

Robert L Ewen

John R Cook

Ian R Still

Zachary Daniel Baker

Lewis Paul Callaway

A close coupled processing system may include a fluid processing system for producing frac fluid for frac operations, a fluid distribution system for distributing the frac fluid to a plurality of pressurization units, and a large bore fluid connection connecting the fluid processing system and the fluid distribution system.

Close coupled fluid processing system

A pump monitoring system may include a sensor for monitoring a parameter of a pump system. The sensor may include at least one of an ammeter in electrical communication with an electric motor driving a pump and a torque sensor on a drive shaft that drives a pump. The system may also include a controller in data communication with the sensor to receive sensor data. The controller may be configured to assess the performance of the respective pump in one or more ways. At least one of the one or more ways may include reliance on the sensor data from only one sensor to identify valve or seat wear or failure. Alternatively or additionally, at least one of the one or more ways may identify valve or seat wear or failure without reliance on pump output pressure.

Pump wear detection system

A smart manifold for frac operations may include a support structure and a fluid management system arranged on the support structure. The fluid management system may be configured for receiving low-pressure frac fluid from a fluid processing system, delivering the low-pressure fluid to a plurality of pressurization units, receiving high-pressure fluid from the plurality of pressurization units, and delivering the high-pressure fluid to a well head. The smart manifold may also include a power management system arranged on the support structure. The power management system may be configured for receiving power for frac operations and for delivering power to each of the plurality of pressurization units.

Smart manifold

A hydraulic fracturing system can include valve apparatuses that control the delivery of fluid to high-pressure pumps that supply the fluid to a wellhead. The valve apparatuses can receive electronic signals from a control system to regulate the flow rate of the fluid to the high-pressure pumps. In one or more examples, the flow rate of the fluid can be controlled such that proppant in the fluid remains in solution.

Controlling the flow of fluid to high pressure pumps

The guide apparatus for tubular members prevents buckling, when a snubbing unit inserts the tubular member into a well. The guide apparatus includes a lower slotted cylinder having a plurality of rib extensions projecting upward so as to form lower slots, and an upper slotted cylinder a plurality of complementary rib extensions projecting downward so as to form upper slots. The lower slotted cylinder engages the upper slotted cylinder by sliding the rib extensions into the upper slots and the complementary rib extensions into the lower slots. The guide apparatus coordinates the slotted cylinders with traveling slip bowls and stationary slip bowls of a snubbing unit so that relative movement of the slotted cylinders corresponds to movement of the slip bowls. The rib extensions, the complementary rib extensions, or both support the entire length of tubular member between the slip bowls, when being snubbed.

Guide apparatus for tubular members in a snubbing unit

The system for inserting a tubular member from a surface into a subsea well includes a riserless vessel, a surface injector being mounted on the vessel at the surface and delivering tubular member, such as coiled tubing, to the subsea well from the surface, a subsea snubbing jack releasably engaged to the tubular member, a subsea hydraulic power unit connected to the snubbing jack, and a device to maintain tension of the tubular member between the surface injector and the snubbing jack. The dynamic control of the subsea snubbing jack provides either active additional force for pipe light and pipe heavy conditions or passive support of the tubular member for equilibrium conditions without a riser. The method is responsive to transitions between well conditions. A riserless system without a subsea injector can more efficiently and reliably insert coiled tubing under various well conditions and during changes in the well conditions.

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Conroe, TX, United States of America

Travis Lee Bolt