Abstract: Rotating control device related oilfield pressure control is accomplished by upper and lower seal members configured to seal around a tubular, a chamber defined between the upper and lower seal members; and wherein fluid enters and/or exits the chamber via some device or structure. Such a device or structure could be a relief valve, a first accumulator, a pressure control valve, an orifice, and/or a void space in a seal member in a location which contacts the tubular.

Abstract: A rotating control device (RCD) for use with a drilling unit includes a body having a flange formed at an end thereof for coupling to the drilling unit; a seal assembly for receiving and sealing against a tubular; a bearing assembly for supporting rotation of the seal assembly relative to the body; a releasable connection connecting the bearing assembly to the body; a transmitting assembly rotatable with the seal assembly; and a receiving assembly attached to a non-rotating portion of the RCD.

Abstract: A mill for use in a wellbore includes a tubular housing having a bore therethrough and a plurality of eccentrically arranged pockets formed in a wall thereof and an arm disposed in each pocket. Each arm has a body portion and a blade portion extending from an outer surface of the body portion and is movable between an extended position and a retracted position. The mill further includes cutters disposed along each blade portion and a block disposed in each pocket and connected to the housing. Each block has a guide engaged with a mating guide of the respective body portion and an inner passage for providing fluid communication between the housing bore and the respective pocket. The mill further includes an actuator for extending the arms.

Abstract: A Drill-To-The-Limit (DTTL) drilling method variant to Managed Pressure Drilling (MPD) applies constant surface backpressure, whether the mud is circulating (choke valve open) or not (choke valve closed). Because of the constant application of surface backpressure, the DTTL method can use lighter mud weight that still has the cutting carrying ability to keep the borehole clean. The DTTL method identifies the weakest component of the pressure containment system, such as the fracture pressure of the formation or the casing shoe leak off test (LOT). With a higher pressure rated RCD, such as 5,000 psi (34,474 kPa) dynamic or working pressure and 10,000 psi (68,948 kPa) static pressure, the limitation will generally be the fracture pressure of the formation or the LOT. In the DTTL method, since surface backpressure is constantly applied, the pore pressure limitation of the conventional drilling window can be disregarded in developing the fluid and drilling programs.

Abstract: A system and method is provided for converting a drilling rig between conventional hydrostatic pressure drilling and managed pressure drilling or underbalanced drilling using a docking station housing mounted on a marine riser or bell nipple. This docking station housing may be positioned above the surface of the water. When a removable rotating control device is remotely hydraulically latched with the docking station housing, the system and method allows for interactive lubrication and cooling of the rotating control device, as needed, along with a supply of fluid for use with active seals.

Abstract: Latch position indicator systems remotely determine whether a latch assembly is latched or unlatched. The latch assembly may be a single latch assembly or a dual latch assembly. An oilfield device may be positioned with the latch assembly. Non-contact (position), contact (on/off and/or position) and hydraulic (flowmeter), both direct and indirect, embodiments include fluid measurement systems, an electrical switch system, a mechanical valve system, and proximity sensor systems.

Abstract: A pressure control device for sealing about a tubular at a wellsite can include a rotatable member, at least two radial seals that sealingly contact the rotatable member, at least two fluid chambers, one chamber being exposed to the rotatable member between the radial seals, and a pump that pumps fluid between the chambers in response to rotation of the rotatable member. A method of operating a pressure control device at a wellsite can include providing at least two chambers in a bearing assembly of the pressure control device, and regulating pressures in the chambers via a valve system in communication with both of the chambers.

Abstract: A running tool and delivery and/or retrieving apparatus, and method for use, are designed for optionally delivering and optionally retrieving an oilfield device down a borehole. A kelly extends into the borehole. The tool has a journal configured for slidable movement along the kelly, an engagement disk mounted around the journal configured for engaging the device, and a plurality of fins attached perpendicular to an outer circumference of the journal. The proximal fins extend radially from the outer circumference of the journal toward the engagement disk, are butted against the engagement disk and extend to a diameter complementary to an outer diameter of the engagement disk. The plurality of proximal fins surround and are arranged concentric with the journal.

Abstract: A latch and method for use is provided for latching an item of oilfield equipment. The latch has a housing containing a latch member, and the latch member is movable between a radially engaged position in which it is engaged with the item of oilfield equipment, and a radially retracted position in which it is disengaged from the item of oilfield equipment. An actuator is configured to drive the latch member into the radially engaged position. Further, the actuator is configured to drive the latch member toward the radially retracted position.

Abstract: A rotating control device (RCD) for use with a drilling unit includes a body having a flange formed at an end thereof for coupling to the drilling unit; a seal assembly for receiving and sealing against a tubular; a bearing assembly for supporting rotation of the seal assembly relative to the body; a releasable connection connecting the bearing assembly to the body; a transmitting assembly rotatable with the seal assembly; and a receiving assembly attached to a non-rotating portion of the RCD.

Abstract: A method for drilling a wellbore includes disposing a tubular string in the wellbore, wherein the tubular string includes a drill bit disposed at a bottom and a flow sub disposed on a top; injecting drilling fluid through a bore valve in the flow sub to rotate the drill bit; moving a sleeve in the flow sub to engage and close the bore valve; moving the sleeve independently from the bore valve to expose a flow port formed through a wall of the flow sub; and injecting the drilling fluid into the flow port while adding a stand to the top of the tubular string, wherein injection of drilling fluid into the tubular string is continuously maintained between drilling and adding the stand to the tubular string.

Abstract: A wellbore cleaning tool for removing irregularities along the inner surface of a wellbore tubular may include a top sub, a cutting assembly, and a bottom sub. The tool is operable to remove irregularities, such as debris, burrs, and jagged edges, along the inside of the wellbore tubular, and thereby provide a clean, inner surface finish. The tool may be actuated into a retracted position, an extended position, and/or a deactivated position.

Abstract: An acoustic control system wirelessly operates a subsea latching assembly or other subsea device, such as an active seal. The acoustic control system may control a subsea first accumulator to release its stored hydraulic fluid to operate the latch assembly or other subsea device, such as an active seal. An RCD or other oilfield device may be unlatched or latched with the latching assembly. The acoustic control system may have a surface control unit, a subsea control unit, and two or more acoustic signal devices. A valve may allow switching from an umbilical line system to the acoustic control system accumulator.

Abstract: A method for drilling a wellbore includes drilling the wellbore by advancing the tubular string longitudinally into the wellbore; stopping drilling by holding the tubular string longitudinally stationary; adding a tubular joint or stand of joints to the tubular string while injecting drilling fluid into a side port of the tubular string, rotating the tubular string, and holding the tubular string longitudinally stationary; and resuming drilling of the wellbore after adding the joint or stand.

Abstract: A Drill-To-The-Limit (DTTL) drilling method variant to Managed Pressure Drilling (MPD) applies constant surface backpressure, whether the mud is circulating (choke valve open) or not (choke valve closed). Because of the constant application of surface backpressure, the DTTL method can use lighter mud weight that still has the cutting carrying ability to keep the borehole clean. The DTTL method identifies the weakest component of the pressure containment system, such as the fracture pressure of the formation or the casing shoe leak off test (LOT). With a higher pressure rated RCD, such as 5,000 psi (34,474 kPa) dynamic or working pressure and 10,000 psi (68,948 kPa) static pressure, the limitation will generally be the fracture pressure of the formation or the LOT. In the DTTL method, since surface backpressure is constantly applied, the pore pressure limitation of the conventional drilling window can be disregarded in developing the fluid and drilling programs.

Abstract: Latch position indicator systems remotely determine whether a latch assembly is latched or unlatched. The latch assembly may be a single latch assembly or a dual latch assembly. An oilfield device may be positioned with the latch assembly. Non-contact (position), contact (on/off and/or position) and hydraulic (flowmeter), both direct and indirect, embodiments include fluid measurement systems, an electrical switch system, a mechanical valve system, and proximity sensor systems.

Abstract: The present invention generally relates to an apparatus and a method of transmitting data from a rotating control device. In one aspect, a method of transmitting data from a rotating control device coupled to an offshore drilling unit is provided. The method includes the step of generating data relating to a parameter associated with the rotating control device. The method further includes the step of transmitting the data from a transmitting assembly coupled to the rotating control device to a receiving assembly positioned proximate the transmitting assembly. Additionally, the method includes the step of transmitting the data from the receiving assembly to the offshore drilling unit. In another aspect, a data gathering and transmitting system for use with a rotating control device coupled to an offshore drilling unit is provided. In a further aspect, a method for transmitting data generated in a rotating control device coupled to a riser is provided.

Abstract: An acoustic control system wirelessly operates a subsea latching assembly or other subsea device, such as an active seal. The acoustic control system may control a subsea first accumulator to release its stored hydraulic fluid to operate the latch assembly or other subsea device, such as an active seal. An RCD or other oilfield device may be unlatched or latched with the latching assembly. The acoustic control system may have a surface control unit, a subsea control unit, and two or more acoustic signal devices. A valve may allow switching from an umbilical line system to the acoustic control system accumulator.

Abstract: A flow sub for use with a drill string includes: a tubular housing having a longitudinal bore formed therethrough and a flow port formed through a wall thereof; a bore valve operable between an open position and a closed position, wherein the bore valve allows free passage through the bore in the open position and isolates an upper portion of the bore from a lower portion of the bore in the closed position; and a sleeve disposed in the housing and movable between an open position where the flow port is exposed to the bore and a closed position where a wall of the sleeve is disposed between the flow port and the bore; and a bore valve actuator operably coupling the sleeve and the bore valve such that opening the sleeve closes the bore valve and closing the sleeve opens the bore valve.

Abstract: A pressure control apparatus and methodology related to a drilling operation has a housing such as, for example, a bearing assembly configured to engage an item of oilfield equipment being delivered through the oilfield pressure control apparatus. The housing has an upper and/or a lower portion with a seal element coupled to the upper and/or lower portion and configured to seal around the item of oilfield equipment. A guide is coupled proximate the seal element. The guide is configured to support and/or limit lateral deflection of the seal element during the lateral deflection of the seal element created by movement of the item of oilfield equipment.