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Abstract: A gas separator assembly generates an artificial sump in a production casing receiving a production tubing string with a downhole pump at the bottom.


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Gas separator assembly with degradable material - Blackjack Production Tools, LLC
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Tu Blinder (Figures Taken from 'Tu Blinder') Production Notes A total of Blinders of all types were built at Z in Tu Blackjack Production Notes.


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Guided missile destroyer (DDG) production increased to four units in , Fullscale BLACKJACK production is expected to take place in the new complex.


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Abstract: A gas separator assembly generates an artificial sump in a production casing receiving a production tubing string with a downhole pump at the bottom.


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Guided missile destroyer (DDG) production increased to four units in , Fullscale BLACKJACK production is expected to take place in the new complex.


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Tu Blinder (Figures Taken from 'Tu Blinder') Production Notes A total of Blinders of all types were built at Z in Tu Blackjack Production Notes.


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Guided missile destroyer (DDG) production increased to four units in , Fullscale BLACKJACK production is expected to take place in the new complex.


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Get informed about BlackJack Production Tools. List of all current job openings, an overview of hiring trends, and all relevant company information.


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RAF FAIRFORD — Completion of initial operational test and evaluation and the subsequent full-rate production decision for the U.S.


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A pump is preferably connected to the tubing 11 , but may not be within the gas separator So long as the pump pulls fluid into the tubing 11 as shown in FIG. The inner casing member 20 is an elongate cylindrical tubular member which defines a primary passage extending longitudinally along the full length thereof between a top first end 26 and a bottom second end 28 of the assembly. The invention is directed to an assembly. An annular space 21 is formed between the inner diameter of the outer casing member 22 and the outer diameter of the inner casing member A plurality of top ports, or first ports 36 communicate through the wall of the inner casing member 20 for communication between the annular space 21 and the inside of the inner casing member. The inlet to the pump 13 is preferably located typically at the bottom of the sump area 42 and spaced directly above or in close proximity to the barrier {/INSERTKEYS}{/PARAGRAPH} Materials and processes may be used to achieve the desired degradation speed of the sleeves Once all sleeves are dissolved such that a continuous path exists within the annular space 21 , fluids and gas may then pass across the sleeves The sleeves will preferably completely dissolve in time, creating an open annular flowpath. Without the ability to stop free flow of materials into the annular space 21 , materials like cement would invade the annulus 21 during pump down. With reference to FIG. The sleeve 50 is in place, preventing cement from intruding in the annular space Once a casing is completed, other elements of the separator 10 , such as the barrier 24 and the pump 13 may be moved into place. The degradable sleeve or sleeves 50 is formed of a degradable material, such as a polymer or dissolvable metal. Further, the sleeve 50 eliminates the need for a downhole actuator that would require a mechanical or hydraulic actuation such as a latch assembly or a ball and seat. {PARAGRAPH}{INSERTKEYS}The present invention relates to a gas separator assembly with a degradable sleeve formed thereon. The first and second ends are configured for connection to a well casing. This is a costly method of separation due to added drilling and completion costs and there are risks involved such as wellbore stability and integrity issues, possibility to have issues running tools into the lateral, etc. As the cement wiper plug passes by the gas separator assembly 10 it could pack the annular space 21 with cement that would set up solid and permanently block the desired open annular space 21 , rendering the gas separator 10 non-functional. Balancing of pressure from the interior of the inner casing member 20 to the annular space 21 through the ports 38 limits any pressure deferential across the wall of the inner casing. The pump inlet is located within the hollow region between the first port and the barrier at a distal end of the production tubing. In another embodiment, the inner casing member may be sized to be smaller than the well casing 12 , with the outer casing member 22 being approximately equal to the well casing The well casing 12 below the separator 10 will be designated as lower well casing 12 A. Upon installation, drilling fluids are preferred to enter the annular space 21 between the outer casing member 22 and the inner casing member 20 once submerged in the ground and when the well is full of drilling fluids. The sleeve 50 forms a temporary obstruction to block certain fluids as well as other potential plugging materials from entering and clogging the annular space The sleeve 50 degrades or dissolves in the presence of well fluids, acids, or other accelerants, opening the annular space 21 to flow in the separator assembly The sleeves 50 may be constructed of a polymer-based material called Decathane. If enough gas builds up, it may form a bubble below the sleeve Such a bubble would prevent fluids from reaching the sleeve 50 and seriously retarding the intended degradation of the sleeve. A gas separator assembly 10 is shown in FIG. When pumping from a hydrocarbon producing well containing gas and liquid it is known to be desirable to separate the gas from the liquid in order for the pump to operate effectively. A second port is formed between the annular passage and the hollow region. In use, the inner 20 and outer casing members 22 are installed when completing the outer casing of the well. The production tube string is positioned within a wellbore. The assembly comprises a production tube string, a hollow inner member, an outer member supported outside the inner member, a barrier, a degradable sleeve, and a pump inlet. The longitudinally opposed ends of the inner casing member 20 at the first 26 and second ends 28 of the overall assembly 10 may be connected in series with corresponding connections within the well casing In one embodiment, shown in FIG. The sleeve 50 as formed and described herein eliminates failure modes and additional processes and costs associated with mechanical or hydraulic movement of a movable sleeve. With reference again to FIG. The outer member defines an annular region extending longitudinally and externally of the inner member. Most horizontal wells are completed with 5. Preferably, no gap exists between the sleeves 50 and the abutting walls of the casing members 20 , In this way, the sleeves 50 are not contacted by well fluids or other dissolving fluids, except along the top and bottom edges, or along a longitudinal slot 52 as described in more detail below. A first port is formed between the annular passage and the hollow region. This material is made into sleeve form and placed between the inner diameter of the outer casing member 22 and the outer diameter of the inner casing member 20 in the separator assembly The open annulus 21 is formed between the two strings, yet with one or more sleeves in place between the two, pressure on either side of the sleeve 50 is essentially isobaric. Additional examples of gas separators are described in U. The sleeve 50 is used to straddle the lowermost ports 38 , which would be considered the intake of the gas separator The straddling and blocking of the annulus 21 above these bottom intake ports 38 prevents fluids, cement, or other foreign matter to flow freely in and through the annular space 21 until the dissolvable material has disappeared over time and the annular space is free and able to communicate with the remainder of the inner casing 20 inner diameter. Thus, the wall thickness of the inner casing member 20 can be thinner than the outer casing member The barrier member 24 is supported within the inner casing member The barrier member 24 may be a conventional plug for forming a seal. The barrier member 24 is directly above the second ports 38 towards the bottom end of the assembly The barrier member 24 defines an artificial sump area 42 within the inner casing member 20 which spans longitudinally from the barrier 24 to the first ports The cross sectional area of the artificial sump area corresponds to the full interior diameter of the inner casing member As shown, this corresponds approximately to the full interior diameter of the outer casing 12 of the well. The well casing between the separator and the surface will be designated upper well casing 12 B. A coupler 60 may be utilized on each end 26 , 28 of the assembly 10 to facilitate connection with the well casing The coupler may seat with the well casing 12 and the inner casing member 20 at a shoulder 62 , or other attachment means may be used. To accelerate and ensure reliability of this process and to allow any trapped gas to escape, the upper sleeve 50 may be cut such that an axial slit 52 would be made to serve as a vent for the gas to escape and for wellbore fluids to enter the space as well. In the embodiment of FIGS. The second end 32 of the annular space 21 only communicates with the downhole portion of the inner casing member 20 and attached lower well casing 12 A through the second ports Larger ports 36 , 38 may cause the annular space 21 , rather than the size of ports 36 , 38 , to limit flow through the assembly As shown by arrows in FIG. The sleeve is disposed in the annular space between the first port and the second port. In FIG. Prior to submergence, the annular space 21 would likely be filled with air. It may be advantageous to use slotted sleeves 51 where gas accumulation is likely, while not using such slots with other sleeves. The slot 52 provides a path for the escape of gas such that well liquids contact the sleeve, enabling its degradation. The barrier is positioned within the hollow region between the first port and the second port. This leaves roughly 4. The slot 52 will provide additional surface area during degradation of the sleeve 50 with fluid. This is not always a desired process to deploy, namely if a much longer dissolve time is desired. The most effective form of separation in horizontal wells has come by way of a sump or an extended section off the primary production casing that is drilled post completion, often at a tangent in the curves build section typically at 30 to 60 degrees, allowing for fluids to fall to a pump set below and allowing gas to break and travel upward. As shown in FIG. In one embodiment, the sleeve 50 is a slotted sleeve The slotted sleeve 51 is an annular ring filling of all of the annular space 21 except for the longitudinal slot The longitudinal slot 52 allows for a small amount of fluid to pass through the annular space 21 even when the sleeve 50 is intact. The assembly 10 is particularly suited for use with a downhole pump inlet 13 supported on the bottom end of a production tubing string 11 and arranged to be received within the longstring, or well casing 12 of a well containing liquid and gas. An epoxy layer 54 may be provided on an upper or lower surface of the degradable sleeve. Use of sleeves 50 between top ports 36 keeps the cement wiper from stalling during transit through the inner casing member A sleeve at the base of the upper slots prevents cement and debris from packing the annular space 21 below their placement. This will allow the degradable material to dissolve at a known rate both from top and from bottom as to achieve desired and controlled dissolve time. It should be understood that first ports 36 may be spaced apart both circumferentially and longitudinally on the inner member 36 , and are located on a first side of the barrier A first end 30 of the annular space 21 only communicates with the inside of the inner casing member 20 and attached upper well casing 12 B through the first ports Second ports 38 are similarly located in close proximity to a second end 32 of the annular space The second ports 38 are openings located at a common longitudinal position at evenly spaced apart locations. There are numerous gas separation techniques used for each form of artificial lift, but most are moderately successful at best and some do a very poor job, but may be the only option. Further, gas, whether production gas or air, may exist below the sleeve 50 and barrier 24 within the well. The first ports 36 , as shown, are rectangular openings. Once the barrier 24 is installed and the degradable sleeve 50 dissolved, the downhole pump inlet 13 can be located within the artificial sump area The pump may take various forms including an electrical submersible pump, a progressive cavity pump, a reciprocating rod pump, a hydraulic reciprocating pump, or a jet pump for example. Gas separators have various deficiencies such that gas interference, resultant gas-locking, and potential resultant damages to downhole pumping equipment, as well as downtime and deferred production is an ongoing problem. The epoxy layer 54 retards the degradation of the sleeve 50 on the top of the sleeve, causing the degradation to progress from the exposed surfaces of the sleeve 50 , including slot 52 , that have no epoxy layer. The assembly 10 generally includes an inner casing member 20 , an outer casing member 22 concentrically receiving the inner casing extending longitudinally therethrough, and a barrier member The barrier member 24 may be received within the inner casing member 20 to selectively seal the passage through the inner casing member as described in further detail below. The sleeves 50 may not shift within the annular space, and are machined to hold their position. The inner member has opposed first and second ends and a hollow region extending end to end.