Abstract: An apparatus and system for accessing a flow system (such as a subsea tree) in a subsea oil and gas production system, and method of use. The apparatus comprises a body defining a conduit therethrough and a first connector for connecting the body to the flow system. A second connector is configured for connecting the body to an intervention apparatus, such as an injection or sampling equipment. In use, the conduit provides an intervention path from the intervention apparatus to the flow system. Aspects of the invention relate to combined injection and sampling units, and have particular application to well scale squeeze operations.

Abstract: The present invention provides a method and system for providing on-site electrical power to a fracturing operation, and an electrically powered fracturing system. Natural gas can be used to drive a turbine generator in the production of electrical power. A scalable, electrically powered fracturing fleet is provided to pump fluids for the fracturing operation, obviating the need for a constant supply of diesel fuel to the site and reducing the site footprint and infrastructure required for the fracturing operation, when compared with conventional systems.

Abstract: The present invention provides a method and system for providing on-site electrical power to a fracturing operation, and an electrically powered fracturing system. Natural gas can be used to drive a turbine generator in the production of electrical power. A scalable, electrically powered fracturing fleet is provided to pump fluids for the fracturing operation, obviating the need for a constant supply of diesel fuel to the site and reducing the site footprint and infrastructure required for the fracturing operation, when compared with conventional systems.

Abstract: A Jack-up drilling rig or land drilling rig riser system with quick connectors that can be used to rapidly install and de-install RCD housings between the BOP and the drill floor. The quick connector design can handle different bore diameters without changing the external design of the connector. The connector assembly may be used to connect a blowout preventer or rotating control device housing to a tubular riser, a blowout preventer housing to an RCD housing, or to join two tubular risers. A connector assembly connects a tubular pin end to a housing has a tubular connector body with a first end to receive the pin end and a second end secured to the housing. The connector assembly also includes a latching mechanism movable between a lock position to prevent the pin end from being removed and an unlock position in which the pin end can be removed.

Abstract: A system for driving a hydraulic fracturing pump includes an electric motor having a drive shaft configured to rotate at a constant speed and a power source electrically connected to the electric motor. The system also includes a motor controller operably connected to the electric motor via a relay, wherein the motor controller is operably connected to the electric motor by the relay to start the electric motor, and is operably disconnected from the electric motor by the relay once the drive shaft reaches the constant speed. The system further includes a pump coupled to the drive shaft via a transmission, wherein the transmission is configured to transfer rotational energy from the drive shaft to the pump via an output shaft of the transmission, the output shaft of the transmission being configured to drive the pump at varying speeds while the drive shaft rotates at the constant speed.

Abstract: An umbilical termination head (1) for connection of a multi-bore flying lead or umbilical (2) to a structure (10), the flying lead or umbilical comprising multiple conduits (7) leading to couplers (4) being arranged on a connector part (3), the umbilical (2) being provided with an end fitting (9) onto which a bracket arrangement (8, 19, 20) is mounted, the connector part (3) being mounted to a bracket (8) of the bracket arrangement. A guide means (11) is arranged on the bracket (8) in such a way that an interacting guide means (12) on the structure (10) lead the umbilical termination head (1) onto the structure (10) for connection of the couplers (4) to corresponding couplers (6) on the structure (10).

Abstract: An offshore platform slot recovery tool system and method. Here, the slot recovery tool system can include a body, wherein the body comprises a plurality of supports extending therefrom, wherein the plurality of supports are configured to engage an interior surface of a conductor pipe, and an articulating arm extending from the body, wherein the articulating arm is configured in either a stowed configuration or a deployed configuration. In addition, the articulating arm is further configured to couple to a seafloor oil well casing, such that the conductor pipe is moved in a direction away from the seafloor oil well casing.

Abstract: A method and system for enhancing petroleum production are provided, in which a fracturing operation can be conducted in a formation through a string and then petroleum is displaced from the fractured formation by selectively injecting fluid into selected fractures in the formation while other non-selected fractures remain without fluid injection. The injected fluid flows out into the fractured formation and enhances recovery from the non-selected fractures. Petroleum is selectively collected from the non-selected fractures.

Abstract: Aspects of the subject technology relate to systems and methods for pumping multiple wellbores from a common pumping source. A fluid pump of known operating pump capacity can be selected. The pump can be fluidly connected to a common pumping source that is fluidly connected with each of a plurality of cased wellbores in a subterranean formation for providing pumped fracturing fluid to each of the wellbores. Each of the plurality of wellbores can have at least one perforation through a casing of the wellbore with a known rate range within which fracturing fluid is required to be provided to the perforation to successfully fracture the subterranean formation outside the perforation, through the perforation. Further, the wellbores can be configured so that the common pumping source provides fracturing fluid to each of the perforations within the known rate range of the respective perforation to successfully fracture the subterranean formation.

Abstract: Aspects of the subject technology relate to systems and methods for pumping a wellbore with a pump operating in a damage avoidance mode during a hydraulic fracturing job. A fluid pump of known operating pump capacity measurable in barrels per minute is selected. The pump is fluidly connected with each of a cased wellbore in a subterranean formation for providing fracturing fluid to the wellbore. The wellbore has at least one perforation through a casing of the wellbore that has a known rate range within which fracturing fluid is required to successfully fracture the subterranean formation outside the perforation through the perforation. The pump is configured to provide fracturing fluid to each perforation within the known rate range of the respective perforation to successfully fracture the subterranean formation outside of the perforation while operating the pump in a damage avoidance mode.

Abstract: Disclosed herein are embodiments of an offshore drilling rig comprising: a drill floor (107) defining a well center (123); a hoisting system configured to advance a tubular string (128) downwards through the well center (123) and to the seafloor (124) and to apply a lifting force to a tubular string (128) extending through the well center (123) and to the seafloor (124), the lifting force being large enough to support at least a major part of an apparent weight of the tubular string (128); and an anti-recoil system (218) configured to cause, in case of a sudden reduction of a load suspended from the drilling rig, the hoisting system to raise the tubular string (128) while preventing damage to the hoisting system.

Abstract: A harsh environment integrated MPD riser joint includes a dynamic annular sealing system, a static annular sealing system disposed directly below the dynamic annular sealing system, and a flow spool, or equivalent thereof, disposed directly below the static annular sealing system. The dynamic annular sealing system may be a conventional ACD-type, RCD-type, or other conventional annular sealing system. The static annular sealing system may include one or more annular packer systems and one or more connection sealing elements that engage drill pipe during connection or non-rotation operations only. The dynamic annular sealing system may maintain annular pressure during drilling operations while the static annular sealing system is disengaged. The static annular sealing system may maintain annular pressure during connection operations while the dynamic annular sealing system is disengaged.

Abstract: Systems and methods presented herein enable coordinated pumping operations. An example system may include a treatment fluid system configured to pump a treatment fluid into a wellbore, a pump-down system configured to pump a pump-down fluid into the wellbore to convey a perforating tool, a fluid valve system configured to selectively fluidly connect and disconnect the treatment fluid system and the pump-down system to and from the wellbore, and a controller communicatively connected to the treatment fluid system, the pump-down system, and the fluid valve system. The controller may be configured to monitor operational status of the treatment fluid system, the pump-down system, and the fluid valve system, and control operations of the treatment fluid system, the pump-down system, and the fluid valve system based at least in part on the operational status of the treatment fluid system, the pump-down system, and the fluid valve system.

Abstract: One or more wellbore servicing operations may require the pulsed delivery of a wellbore servicing fluid. To optimize efficiency and effectives of a given wellbore servicing operation a concentrated proppant stimulation fluid may be pumped downhole at a predetermined time interval from dedicated pumping units or positive displacement pumps. The flow rate of proppant in the concentrated proppant stimulation fluid pumped from these dedicated pumps may simulate a square-wave. The desired or determined square-wave or output may be predetermined and any one or more dedicated pumps may be associated with a given time interval and pumping cycle or phasing such that the overall flow of proppant from all of the dedicated pumps simulates a square-wave. Clean fluid from one or more clean fluid pumps may be combined with the concentrated proppant stimulation fluid to maintain a target flow rate of fluid downhole.

Abstract: The embodiments herein relate generally to subterranean formation operations and, more particularly, systems and methods for achieving target downhole pressures having target downhole wave shapes for enhancement of subterranean formation stimulation and production. In particular, a treatment fluid is introduced into a subterranean formation and a downhole pressure wave in the subterranean formation having a downhole wave shape is determined, and a surface pressure wave having a surface wave shape is determined. The downhole wave shape and the surface wave shape are compared, followed by adjustment of the surface pressure to achieve a target downhole pressure wave in the subterranean formation having a target downhole wave shape. The target downhole pressure and target downhole wave shape may be selected to maximize production of the subterranean formation.

Abstract: A method sequence for handling tubulars into or out of a wellbore, the method comprising: moving a tubular string into or out of a wellbore via a top drive; moving tubular stands to and from a setback position and a stand handoff position via a transfer bridge racker and a setback guide arm; moving tubular stands to and from the stand handoff position and a well center position via a tubular delivery arm and a lower stabilizing arm; building stands and breaking down stands offline via a mousehole and operating a roughneck on joints between the tubular stands and the tubular string.

Abstract: A seal and bearing includes a seal and bearing housing, a rotatable mandrel disposed within an inner aperture of the seal and bearing housing, an upper seal carrier attached to a top side of the seal and bearing housing having a dynamic sealing element that contacts the rotatable mandrel, a plurality of tapered-thrust bearings to facilitate rotation of the rotatable mandrel including top tapered-thrust bearings indirectly mounted at a positive offset angle from a perpendicular line to a longitudinal axis of the rotating control device and bottom tapered-thrust bearings indirectly mounted at a negative offset angle from the perpendicular line to the longitudinal axis of the rotating control device, a preload spacer disposed between the top and bottom tapered-thrust bearings, and a lower seal carrier attached to a bottom side of the seal and bearing housing having a plurality of removable seal carrier trays.

Abstract: The disclosure provides a manifold comprising a trailer and a piping system. The piping system is disposed on top of the trailer, wherein the piping system comprises a first set of conduits and a second set of conduits. Each of the first set of conduits and the second set of conduits comprises a first line comprising an inlet disposed at a first side of the trailer and a second line comprising an inlet disposed at the first side of the trailer, wherein the first line is disposed above the second line. There is a plurality of outlets and a plurality of valves disposed along the second line.

Abstract: A hoisting system for a drilling rig, which has a crown block for attaching to a derrick, the crown block comprising a plurality of sheaves; a travelling block suspended from the crown block via a hoisting cable, the travelling block comprising a plurality of sheaves and being connectable with a payload, the travelling block being arranged to move along a workpath; the hoisting system further comprising: a floating block comprising a plurality of sheaves reeved on the hoisting cable; wherein the floating block is configured to move between: a first arrangement in which the floating block is fixed relative to the crown block; and a second arrangement in which the floating block is fixed relative to the travelling block; wherein the hoisting system is arranged such that, when the floating block is in one of the first or second arrangement, the sheaves of the floating block overlap a sheave of the crown block or travelling block in a direction of the workpath.

Abstract: A modular pumping pad skid may include a base with one or more high pressure fluid conduits and one or more low pressure conduits. Additionally, two or more pumps may be removably fixed to the base, and fluidly connected to the high pressure fluid conduits and the low pressure conduits.