Abstract: A pump can include a plunger and a barrel, at one stroke extent flow being substantially restricted between the plunger and the barrel at spaced apart positions and a plunger interior passage in filtered communication with a fluid chamber between the positions, and at an opposite stroke extent the fluid chamber being in communication with the standing valve. A method can include displacing a plunger in one direction, thereby receiving filtered liquid into a fluid chamber, and b) displacing the plunger in an opposite direction, thereby transferring the liquid to a barrel interior passage. A system can include an actuator that reciprocates a rod string, and a pump including a plunger with a traveling valve, a barrel with a standing valve, and a filter that filters liquid which flows from a tubing string to a compression chamber disposed between the traveling valve and the standing valve.

Abstract: A wellbore completion is configured for multiple forms of artificial lift. A downhole assembly on production tubing defines a production port communicating a throughbore with the wellbore annulus. A bypass, such as a snorkel or riser tube, on the assembly also communicates the throughbore between the packer and the production port with the annulus. A packer on the assembly seals in the annulus downhole of the production port and bypass. The assembly can then be configured for any selected artificial lift. To do this, at least one isolation (a sleeve insert, a sliding sleeve, a check valve, or a rupture disk) selectively prevents/allows communication via one or both of the production port and the bypass as needed. Additionally, removable lift equipment, including jet pump, gas lift valve, plunger assembly, rod pump, piston pump, or standing valve, is selectively inserted into the assembly's throughbore as needed.

Abstract: Aspects of the present disclosure generally relate to attenuating the effects of slugging based on one or more measurements of parameters from one or more locations in one or more wells. In some cases, a controller may be configured to attenuate the effects of slugging based on the one or more parameters, for example, by controlling a choke or an artificial lift. In certain aspects, the one or more locations may include downhole or at the surface of the one or more wells.

Abstract: A pump can include a plunger and a barrel, at one stroke extent flow being substantially restricted between the plunger and the barrel at spaced apart positions and a plunger interior passage in filtered communication with a fluid chamber between the positions, and at an opposite stroke extent the fluid chamber being in communication with the standing valve. A method can include displacing a plunger in one direction, thereby receiving filtered liquid into a fluid chamber, and b) displacing the plunger in an opposite direction, thereby transferring the liquid to a barrel interior passage. A system can include an actuator that reciprocates a rod string, and a pump including a plunger with a traveling valve, a barrel with a standing valve, and a filter that filters liquid which flows from a tubing string to a compression chamber disposed between the traveling valve and the standing valve.

Abstract: A pump can include a plunger and a barrel, at one stroke extent flow being substantially restricted between the plunger and the barrel at spaced apart positions and a plunger interior passage in filtered communication with a fluid chamber between the positions, and at an opposite stroke extent the fluid chamber being in communication with the standing valve. A method can include displacing a plunger in one direction, thereby receiving filtered liquid into a fluid chamber, and b) displacing the plunger in an opposite direction, thereby transferring the liquid to a barrel interior passage. A system can include an actuator that reciprocates a rod string, and a pump including a plunger with a traveling valve, a barrel with a standing valve, and a filter that filters liquid which flows from a tubing string to a compression chamber disposed between the traveling valve and the standing valve.

Abstract: A wellbore completion is configured for multiple forms of artificial lift. A downhole assembly on production tubing defines a production port communicating a throughbore with the wellbore annulus. A bypass, such as a snorkel or riser tube, on the assembly also communicates the throughbore between the packer and the production port with the annulus. A packer on the assembly seals in the annulus downhole of the production port and bypass. The assembly can then be configured for any selected artificial lift. To do this, at least one isolation, such as a sleeve insert, a sliding sleeve, a check valve, or a rupture disk, selectively prevents/allows communication via one or both of the production port and the bypass as needed. Additionally, removable lift equipment, including jet pump, gas lift valve, plunger assembly, rod pump, piston pump, or standing valve, is selectively inserted into the assembly's throughbore as needed.

Abstract: A long-stroke pumping unit includes a tower; a counterweight assembly movable along the tower; a drum connected to an upper end of the tower and rotatable relative thereto. The unit also includes a belt having a first end connected to the counterweight assembly, extending over the drum, and having a second end connectable to a rod string. The unit further includes a prime mover for reciprocating the counterweight assembly along the tower; a sensor for detecting sudden acceleration of the counterweight assembly due to failure of the rod string; and a controller in communication with the sensor and operable to activate the braking or arrestor system in response to detection of the sudden acceleration. The unit further includes at least one of a braking system for halting free-fall of the counterweight assembly; and an arrestor system for absorbing kinetic energy of the falling counterweight assembly.

Abstract: A pump can include a plunger and a barrel, at one stroke extent flow being substantially restricted between the plunger and the barrel at spaced apart positions and a plunger interior passage in filtered communication with a fluid chamber between the positions, and at an opposite stroke extent the fluid chamber being in communication with the standing valve. A method can include displacing a plunger in one direction, thereby receiving filtered liquid into a fluid chamber, and b) displacing the plunger in an opposite direction, thereby transferring the liquid to a barrel interior passage. A system can include an actuator that reciprocates a rod string, and a pump including a plunger with a traveling valve, a barrel with a standing valve, and a filter that filters liquid which flows from a tubing string to a compression chamber disposed between the traveling valve and the standing valve.

Abstract: A long-stroke pumping unit includes: a tower; a counterweight assembly movable along the tower; a drum connected to an upper end of the tower and rotatable relative thereto; a belt having a first end connected to the counterweight assembly, extending over the drum, and having a second end connectable to a rod string; a prime mover for reciprocating the counterweight assembly along the tower; a sensor for detecting sudden acceleration of the counterweight assembly due to failure of the rod string; at least one of: a braking system for halting free-fall of the counterweight assembly; and an arrestor system for absorbing kinetic energy of the falling counterweight assembly; and a controller in communication with the sensor and operable to activate the braking or arrestor system in response to detection of the sudden acceleration.

Abstract: Aspects of the present disclosure generally relate to attenuating the effects of slugging based on one or more measurements of parameters from one or more locations in one or more wells. In some cases, a controller may be configured to attenuate the effects of slugging based on the one or more parameters, for example, by controlling a choke or an artificial lift. In certain aspects, the one or more locations may include downhole or at the surface of the one or more wells.

Abstract: A velocity string deploys in production tubing of a gas well (or a gassy oil well) to help lift fluid toward the surface. The velocity string reduces flow area in the production tubing so that a critical flow velocity can be reached to lift liquid. Overtime, the reservoir pressure and resulting gas flow may decrease such that less liquid is produced toward the surface. At such a stage, operators then expand the velocity string to further decrease the flow area in the production tubing, which can produce the needed critical flow velocity to allow produced liquid to be lifted toward the surface.

Abstract: A downhole pump has a barrel and a plunger movably disposed therein. The gap between the barrel and plunger has first and second seals. The barrel and plunger each have a one-way valve restricting fluid passage out of it. A filter or screen is disposed on the plunger between the first and second seals. In a downstroke, fluid and particulate in the barrel transfers into the plunger. In an upstroke, fluid and particulate in the plunger lifts uphole. At the same time, a volume in the barrel fills with fluid and particulate. During either stroke, the first seal prevents particulate uphole of the plunger from passing into the gap. The filter or screen, however, prevents at least some particulate (i.e., most or larger particulate) inside the plunger from passing out of the plunger with fluid flowing into the gap between the first and second seals.

Abstract: A velocity string deploys in production tubing of a gas well (or a gassy oil well) to help lift fluid toward the surface. The velocity string reduces flow area in the production tubing so that a critical flow velocity can be reached to lift liquid. Overtime, the reservoir pressure and resulting gas flow may decrease such that less liquid is produced toward the surface. At such a stage, operators then expand the velocity string to further decrease the flow area in the production tubing, which can produce the needed critical flow velocity to allow produced liquid to be lifted toward the surface.

Abstract: A downhole pump has a barrel and a plunger movably disposed therein. The gap between the barrel and plunger has first and second seals. The barrel and plunger each have a one-way valve restricting fluid passage out of it. A filter or screen is disposed on the plunger between the first and second seals. In a downstroke, fluid and particulate in the barrel transfers into the plunger. In an upstroke, fluid and particulate in the plunger lifts uphole. At the same time, a volume in the barrel fills with fluid and particulate. During either stroke, the first seal prevents particulate uphole of the plunger from passing into the gap. The filter or screen, however, prevents at least some particulate (i.e., most or larger particulate) inside the plunger from passing out of the plunger with fluid flowing into the gap between the first and second seals.

Abstract: The present invention relates to a split seal for a progressive cavity pump (PCP) drive head stuffing box. In one embodiment, a mechanical seal assembly for a pump is provided. The mechanical seal assembly includes a seal housing; first and second semi-annular mechanical seals, each at least partially disposed in the seal housing bore, and a seal sleeve rotatable relative to the seal housing; third and fourth semi-annular mechanical seals, each disposed at least partially in the seal sleeve bore, at least one of the third and fourth seals rotationally coupled to the seal sleeve; and one or more biasing members biasing the mechanical seals into engagement.

Abstract: Apparatus and methods for improving production from a wellbore are provided. In one embodiment, a downhole pump for use in a wellbore includes a chamber for accumulating formation fluids and a valve assembly for filling and venting gas to and from the chamber. In another embodiment, a gas operated pump for moving wellbore fluids in a wellbore includes a chamber for accumulating wellbore fluids, wherein the chamber in fluid communication with a production tubular and a surface mounted valve assembly in fluid communication with the chamber, wherein the valve assembly adapted to regulate gas flow to or from the chamber. In another embodiment, the valve assembly comprises a removable control valve disposed in a housing.

Abstract: The present invention relates to a split seal for a progressive cavity pump (PCP) drive head stuffing box. In one embodiment, a mechanical seal assembly for a pump is provided. The mechanical seal assembly includes a seal housing; first and second semi-annular mechanical seals, each at least partially disposed in the seal housing bore, and a seal sleeve rotatable relative to the seal housing; third and fourth semi-annular mechanical seals, each disposed at least partially in the seal sleeve bore, at least one of the third and fourth seals rotationally coupled to the seal sleeve; and one or more biasing members biasing the mechanical seals into engagement.

Abstract: Oil is recovered from a borehole using a pump having limited high temperature breakdown resistance. The pump is located in a borehole having a cooling zone, in which the temperature of the well fluid is reduced to, or below, the temperature at which the temperature breakdown resistance of the pump is commercially acceptable. In one embodiment, the pump is a positive displacement pump which is mechanically driven from the well head location, such as through a rotating rod. The cooling zone is provided by positioning and controlling the pump to maintain a sufficiently low pressure at the pump intake to cause a portion of the liquid well fluid to vaporize prior to entry of the liquid into the pump, creating bubbles which pass upwardly in the wellbore in a zone passing the pump. The evolution of the vapor cools the well fluid to the acceptable temperature.

Abstract: The present invention generally relates to an apparatus and method for improving production from a wellbore. In one aspect, a downhole pump for use in a wellbore is provided. The downhole pump includes two or more chambers for the accumulation of formation fluids and a valve assembly for filling and venting gas to and from the two or more chambers. The downhole pump further includes a fluid passageway for connecting the two or more chambers to a production tube. In another aspect, a downhole pump including a chamber for the accumulation of formation fluids is provided. In another aspect, a method for improving production in a wellbore is provided. In yet another aspect, a method for improving production in a steam assisted gravity drainage operation is provided. Additionally, a pump system for use in a wellbore is provided.

Abstract: The present invention generally relates to an apparatus and method for improving production from a wellbore. In one aspect, a downhole pump for use in a wellbore is provided. The downhole pump includes two or more chambers for the accumulation of formation fluids and a valve assembly for filling and venting gas to and from the two or more chambers. The downhole pump further includes a fluid passageway for connecting the two or more chambers to a production tube. In another aspect, a downhole pump including a chamber for the accumulation of formation fluids is provided. In another aspect, a method for improving production in a wellbore is provided. In yet another aspect, a method for improving production in a steam assisted gravity drainage operation is provided. Additionally, a pump system for use in a wellbore is provided.