Abstract: Systems and methods for specifying one or more operational parameters for a pumping system are disclosed. A first suction pressure loss profile for a first pump in a pumping system is determined. A second suction pressure loss profile for a second pump in the pumping system is determined. The first suction pressure loss profile is compared with the second suction pressure loss profile. One or more operational parameters are specified based, at least in part, on the comparison.

Abstract: A wellbore servicing apparatus, comprising an inlet space, a central space adjacent and in fluid communication with the inlet space along a central axis, a dome space adjacent and in fluid communication with the central space along the central axis, and a plurality of channels adjacent to and in fluid communication with the dome space, wherein the plurality of channels are radially spaced about the central axis, and wherein a channel axis of the at least one of the plurality of channels is incident the central axis by less than ninety degrees.

Abstract: Of the methods provided herein, one includes a method comprising: providing a turbid treatment fluid having a first microorganism count; placing the turbid treatment fluid in a self-contained, road mobile UV light treatment manifold that comprises a UV light source; irradiating the turbid treatment fluid with the UV light source in the self-contained, road mobile UV light treatment manifold that comprises an attenuating agent so as to reduce the first microorganism count of the turbid treatment fluid to a second microorganism count to form an irradiated treatment fluid, wherein the second microorganism count is less than the first microorganism count; and placing the irradiated treatment fluid having the second microorganism count in a subterranean formation, a pipeline or a downstream refining process.

Abstract: Systems and methods for specifying one or more operational parameters for a pumping system are disclosed. A first suction pressure loss profile for a first pump in a pumping system is determined. A second suction pressure loss profile for a second pump in the pumping system is determined. The first suction pressure loss profile is compared with the second suction pressure loss profile. One or more operational parameters are specified based, at least in part, on the comparison.

Abstract: A wellbore servicing apparatus, comprising an inlet space, a central space adjacent and in fluid communication with the inlet space along a central axis, a dome space adjacent and in fluid communication with the central space along the central axis, and a plurality of channels adjacent to and in fluid communication with the dome space, wherein the plurality of channels are radially spaced about the central axis, and wherein a channel axis of the at least one of the plurality of channels is incident the central axis by less than ninety degrees.

Abstract: A fluid supply system having a plurality of tanks in fluid communication via one or more fluid paths with at least one pump, a ball and socket coupling disposed in at least one of the fluid paths, and a wellhead in fluid communication with the pump is disclosed. Placing a plurality of tanks at a well site and pumping a fluid from at least one of the tanks into the wellbore via a fluid path comprising at least one ball and socket coupling is disclosed. Positioning a plurality of tanks at a well site having a wellhead connected to a wellbore penetrating a shale formation, preparing a fracturing fluid by connecting at least one of the tanks to a blender via a fluid path comprising a ball and socket coupling, pumping the fracturing fluid into the wellbore and fracturing the shale formation, and recovering natural gas from the wellbore is disclosed.

Abstract: A multiple piece valve plug insert is disclosed. The valve plug insert has an insert body and an insert cover. The valve plug insert may be used with a valve having a valve seat and a valve plug that is movable into and out of sealing engagement with the valve seat. The valve plug insert along with a valve plug body comprise the valve plug.

Abstract: An apparatus for rotating a threaded tightening device includes a guide and an anvil utilized to impact a lug on the threaded tightening device to rotate the tightening device onto or off of a threaded member. The guide has a frame with a support sleeve attached thereto. A reciprocating device is received in and is supported by the support sleeve. The anvil is attached to the reciprocating device. When the reciprocating device is received in and is supported by the support sleeve, actuation of the reciprocating device will cause the anvil to repeatedly impact a lug to rotate the threaded tightening device in the desired direction.

Abstract: A retrievable bridge plug assembly having an internal “pump through” bypass passage and a wedge assembly, slips and seals disposed thereon. A retrieving tool is provided for running, setting, releasing and retrieving the bridge plug assembly. A tubing sensor is included to prevent setting of the bridge plug assembly in improper size tubing. When the bridge plug is properly located, the wedge assembly can actuated by manipulation of the retrieving tool to force the slips radially outward into gripping engagement with the well tubular and to force the seals into sealing engagement with the well tubular. A ball valve on the bridge plug assembly is movable to selectively open and close the bypass passage. The retrieving tool can maintain the valve and passageway open to facilitate circulation during run in and setting and also open during retrieving for pressure equalization. A service packer can be connected to and run with the bridge plug assembly.

Abstract: A plug valve and fluid control method according to which a cylindrical plug is provided in a bore of a body member and has a through passage formed therein. The plug is adapted to be rotated about its axis to move the passage between an open position in which it is in alignment with passages in the body member to permit fluid flow through the body member, and a closed position in which it is out of alignment with the passages to prevent the fluid flow.

Abstract: A foaming apparatus and method according to which a mixture of gas and a liquid is introduced into a vessel and passes through a passage in the vessel. The flow of the mixture through the passage is increased to increase the velocity of the mixture and cause corresponding shearing forces on the mixture to create a turbulance and form foam from the mixture. The restrictor can be moved in the passage to vary the amount of restriction and therefore the amount of the foam.

Abstract: A plug valve and fluid control method according to which a cylindrical plug is provided in a bore of a body member and has a through passage formed therein. The plug is adapted to be rotated about its axis to move the passage between an open position in which it is in alignment with passages in the body member to permit fluid flow through the body member, and a closed position in which it is out of alignment with the passages to prevent the fluid flow.

Abstract: A foaming apparatus and method according to which a mixture of gas and a liquid is introduced into a vessel at a predetermined velocity and passes through a passage in the vessel. The flow of the mixture through the passage is increased to increase the velocity of the mixture and cause corresponding shearing forces on the mixture to create a turbulance and form foam from the mixture. The restrictor can be moved in the passage to vary the amount of restriction and therefore the amount of the foam.

Abstract: A foaming apparatus and method according to which a mixture of gas and a liquid is introduced into a vessel at a predetermined velocity and passes through a passage in the vessel. The flow of the mixture through the passage is increased to increase the velocity of the mixture and cause corresponding shearing forces on the mixture to create a turbulance and form foam from the mixture. The restrictor can be moved in the passage to vary the amount of restriction and therefore the amount of the foam.

Abstract: A retrievable bridge plug assembly having an internal “pump through” bypass passage and a wedge assembly, slips and seals disposed thereon. A retrieving tool is provided for running, setting, releasing and retrieving the bridge plug assembly. A tubing sensor is included to prevent setting of the bridge plug assembly in improper size tubing. When the bridge plug is properly located, the wedge assembly can actuated by manipulation of the retrieving tool to force the slips radially outward into gripping engagement with the well tubular and to force the seals into sealing engagement with the well tubular. A ball valve on the bridge plug assembly is movable to selectively open and close the bypass passage. The retrieving tool can maintain the valve and passageway open to facilitate circulation during run in and setting and also open during retrieving for pressure equalization. A service packer can be connected to and run with the bridge plug assembly.

Abstract: A high temperature, high pressure retrievable packer adapted for service under extreme operating conditions when the packer apparatus is held in the wellbore with a mechanical slip and a barrel slip. The barrel slip has a barrel slip body with a plurality of openings defined in the outer surface of the body. Cylindrical inserts are received in the openings. The cylindrical inserts define upward facing and downward facing gripping edges that will engage casing when the barrel slip body is radially expanded. The inserts are preferably tungsten carbide inserts. A sufficient number of inserts are included along the length and around the circumference of the barrel slip so that the barrel slip can get a good grip in the casing wall. Separate metals may be used for the barrel slip body and the inserts so that a higher yield strength alloy steel may be utilized than is possible with other barrel slip arrangements.

Abstract: A high temperature, high pressure retrievable packer adapted for service under extreme operating conditions when the packer apparatus is held in the wellbore with a mechanical slip and a barrel slip. The barrel slip has a barrel slip body with a plurality of openings defined in the outer surface of the body. Cylindrical inserts are received in the openings. The cylindrical inserts define upward facing and downward facing gripping edges that will engage casing when the barrel slip body is radially expanded. The inserts are preferably tungsten carbide inserts. A sufficient number of inserts are included along the length and around the circumference of the barrel slip so that the barrel slip can get a good grip in the casing wall. Separate metals may be used for the barrel slip body and the inserts so that a higher yield strength alloy steel may be utilized than is possible with other barrel slip arrangements.

Abstract: A high temperature, high pressure retrievable packer adapted for service under extreme operating conditions when the packer apparatus is held in the wellbore with a mechanical slip and a barrel slip. The barrel slip has a barrel slip body with a plurality of openings defined in the outer surface of the body. Cylindrical inserts are received in the openings. The cylindrical inserts define upward facing and downward facing gripping edges that will engage casing when the barrel slip body is radially expanded. The inserts are preferably tungsten carbide inserts. A sufficient number of inserts are included along the length and around the circumference of the barrel slip so that the barrel slip can get a good grip in the casing wall. Separate metals may be used for the barrel slip body and the inserts so that a higher yield strength alloy steel may be utilized than is possible with other barrel slip arrangements.

Abstract: Improved methods and apparatus for placing and cementing a casing string in a horizontal well bore section are provided. A float shoe is attached to the end of the casing string and a float collar is connected in the casing string for trapping air in a first portion of the casing string thereby causing it to be buoyed up during placement by drilling fluid contained in the well bore. A selectively openable and releasable closed baffle assembly is connected within the casing string for trapping air or a low density fluid in a second portion of the casing string thereby causing it to also be buoyed up by drilling fluid in the well bore. The buoying up of the casing string reduces placement drag and consequent compressive loading on the casing string. After placement, the closed baffle means is opened to allow fluid circulation and conditioning of the annulus. A bottom cementing plug is then landed on the baffle assembly and the baffle assembly is released and moved to the float collar.