Artificial Lift Division Catalog

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Artificial Lift Division

Gas Lift Products Catalog

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Wireline Retrievable

Gas Lift Valves

And

Gas Lift Accessories

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Superior Energy Services Gas Lift Division Products Catalog

SUPERIOR GBK INJECTION

PRESSURE OPERATED GAS LIFT VALVE

INTRODUCTION

The Superior GBK gas lift valve is a 1” OD slickline retrievable, injection pressure operated valve designed for use in either continuous flow or intermittent gas lift installations. The valve is run on a GBK Series latch in a KB Series style side pocket mandrel.

FEATURES

• Nitrogen charged bellows

• Floating seat to promote positive stem/seat • Injection pressure operated

• Dual seal nitrogen containment

• Special bellows treatment to prolong life • Available in various alloys and elastomers • Integral reverse check

• 1/8” - 5/16” port sizes

APPLICATION AND OPERATION

The bellows of the GBK gas lift valve is constructed of three-ply Monel®. During manufacture, the bellows is placed in a hydrostatic pressure chamber and subjected to external pressure. This special hydraulic forming process seats all the convolutions of the valve bellows so that each convolution accepts an equal amount of stress during valve operation. The component parts of the bellows assembly are unitized by induction brazing that enables the nitrogen charge to be sealed in the bellows without the use of elastomers. To provide additional protection against alteration of the valve

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pressure charge, the tail plug of the GBK valve is fitted with a copper gasket. These two seals offer double protection against fluid leakage into the bellows housing.

GBK seats are available with 1/8” to 5/16” ports. These sizes enable the operator to inject gas at rates suited to changing well conditions and operator needs. The seats are available in either Monel or tungsten carbide.

Before installation, the dome of the GBK gas lift valve is charged with nitrogen to establish the valve operating pressure. The valve is made up to a Superior GBK Series top latch. The valve and latch are run by slickline into the pocket of a Superior KB Series style side pocket mandrel. The two packing sets on the GBK valve isolate the ports in the mandrel pocket.

In gas lift operations, high-pressure injection gas enters the port in the valve body from the casing annulus and acts on the bellows. When the combined force resulting from the injection gas pressure on the bellows area less, the port area and the production pressure operating over the port area is greater than the force caused by the nitrogen charge in the bellows, the bellows is compressed. The valve stem tip is lifted off the valve seat, opening the valve. The injection gas flows through the seat and into the production tubing. When the pressure of the injection gas in the casing annulus at valve depth drops below the valve set pressure, the valve bellows extends downward, causing the ball of the stem tip to seat and closes the valve. An integral check valve in the nose of the GBK gas lift valve prevents reverse flow through the valve. The check valve seals tightly against a hard/soft seat combination.

The stem tip, seat, and bellows, of the GBK valve are protected from damage during valve operation by a special silicone fluid dampening feature. The non-compressible silicone fluid that is injected into the valve bellows during

manufacture prevents vibration and chattering during valve operation. When the valve is in the closed position the silicone fluid remains in the lower chamber of the bellows. As the bellows is compressed to open the valve, the viscous silicone fluid is forced out of the lower chamber of the bellows, through a bore drilled in the cushion rod, and finally through a metering port installed in the upper end of the cushion rod. The small diameter of the metering port in the cushion rod permits only a gradual passage of the silicone fluid. Therefore, the ball of the stem tip can lift off the valve seat only as rapidly as the thick silicone fluid can pass through the small port. While the valve remains open, the silicone fluid remains in the core of the cushion rod. When the bellows extends to close the valve, the silicone fluid is drawn back through the port in the cushion rod and finally into the lower chamber of the bellows adapter.

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Valve Specifications PPEF*

Type Ab (Effective Bellows Area (sq. in) Port Size (in) Ab – Area of Port With Bevel (sq. in) Ap/Ab 1-(Ap/Ab) ) A / A ( 1 A / A PPEF b p b p − = Standard Monel Solid Carbide Standard Monel Solid Carbide Standard Monel Solid Carbide Standard Monel Solid Carbide GBK 0.31 1/8 0.013 0.021 0.042 0.068 0.958 0.932 0.044 0.073 3/16 0.029 0.037 0.094 0.119 0.906 0.881 0.104 0.135 1/4 0.051 0.058 0.165 0.187 0.835 0.813 0.198 0.230 5/16 0.079 0.097 0.255 0.313 0.745 0.687 0.342 0.456

*PPEF (production pressure effect factor) was formerly referred to as TEF (tubing effect factor).

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SUPERIOR GR-20 INJECTION PRESSURE OPERATED GAS LIFT VALVE

INTRODUCTION

The Superior GR-20 gas lift valve is a 1-1/2” OD slickline retrievable valve

designed for use in either continuous flow or intermittent gas lift installations. The valve is run on the appropriate GR series latch in an M series style side pocket mandrel.

FEATURES

• Nitrogen charged three-ply bellows

• Floating seat to promote positive stem/seat

alignment

• Injection pressure-operated • Dual seal nitrogen containment

• Special bellows treatment to prolong life • Available in stainless steel or high nickel

alloys

• Various packing materials • Integral reverse check • 1/8” - 1/2” port sizes

The bellows of the GR-20 gas lift valve is constructed of three ply Monel®. During

manufacture, the bellows is placed in a hydrostatic pressure chamber and subjected to external pressure. This special hydraulic forming process seats all the convolutions of the valve bellows so that each convolution accepts an equal amount of stress during valve operation. The component parts of the bellows assembly are unitized by induction

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brazing that enables the nitrogen charge to be sealed in the bellows without the use of elastomers. To provide additional protection against altering the valve charge, the tail plug of the GR-20 valve is fitted with a copper gasket. These two seals offer double protection against fluid leakage into the bellows housing. GR-20 seats are available with 3/16” to 1/2” ports. These sizes enable the operator to inject gas at rates suited to changing well conditions and operator needs. The seats are available in either Monel or tungsten carbide.

Before installation, the dome of the GR-20 gas lift valve is charged with nitrogen to establish the valve operating pressure. The valve is made up to a Superior GR series top latch. The valve and latch are run by slickline into the pocket of a Superior M series style side pocket mandrel. The two packing sets on the GR-20 valve isolate the ports in the mandrel pocket.

In gas lift operations, high-pressure injection gas enters the port in the valve body from the casing annulus and acts on the bellows. When the combined force resulting from the injection gas pressure on the bellows area less the port area and the production pressure operating over the port area is greater than the force caused by the nitrogen charge in the bellows, the bellows is compressed. The valve stem tip is lifted off the valve seat, opening the valve. The injection gas flows through the seat and into the production tubing. When the pressure of the injection gas in the casing annulus at valve depth drops below the valve set pressure, the valve bellows extends downward, causing the ball of the stem tip to seat and closes the valve. An integral check valve in the nose of the GR-20 prevents reverse flow through the valve. The check valve seals tightly against a hard/soft seat combination.

The stem tip, seat, and bellows, of the GR-20 valve are protected from damage during valve operation by a special silicone fluid dampening feature. The non-compressible silicone fluid that is injected into the valve bellows during

manufacture prevents vibration and chattering during valve operation. When the valve is in the closed position the silicone fluid remains in the lower chamber of the bellows. As the bellows is compressed to open the valve, the viscous silicone fluid is forced out of the lower chamber of the bellows, through a bore drilled in the cushion rod, and finally through a metering port installed in the upper end of the cushion rod. The small diameter of the metering port in the cushion rod permits only a gradual passage of the silicone fluid. Therefore, the ball of the stem tip can lift off the valve seat only as rapidly as the thick silicone fluid can pass through the small port. While the valve remains open, the silicone fluid remains in the core of the cushion rod. When the bellows extends to close the valve, the silicone fluid is drawn back through the port in the cushion rod and finally into the lower chamber of the bellows adapter.

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Valve Specifications PPEF* Type Ab (Effective Bellows Area) (sq. in) Port Size (in)

Ap: Area of Port with

Bevel (sq. in) Ap/Ab 1-(Ap/Ab) ) A / A ( 1 A / A PPEF b p b p − = Standard Monel Solid Carbide Standard Monel Solid Carbide Standard Monel Solid Carbide Standard Monel Solid Carbide GR-20 0.77 1/8 0.013 0.021 0.017 0.027 0.983 0.973 0.017 0.028 3/16 0.029 0.037 0.038 0.048 0.962 0.952 0.040 0.050 1/4 0.051 0.058 0.066 0.075 0.934 0.925 0.071 0.081 5/16 0.079 0.097 0.103 0.126 0.897 0.874 0.115 0.144 3/8 0.113 0.129 0.147 0.168 0.853 0.832 0.172 0.202 7/16 0.154 0.166 0.200 0.216 0.800 0.784 0.250 0.276 1/2 0.200 0.230 0.260 0.299 0.740 0.701 0.351 0.427 *PPEF (production pressure effect factor) was formerly referred to as TEF (tubing effect factor).

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SUPERIOR GBKRF PRODUCTION PRESSURE OPERATED GAS LIFT VALVE

INTRODUCTION

The Superior GBKRF Gas Lift Valve is a 1" OD slickline retrievable gas lift valve. The GBKRF is production pressure operated and is used in continuous flow gas lift installations. The production-pressure sensitive GBKRF valve is used to enhance production by injecting high-pressure gas from the casing/tubing annulus, into the production fluid. Carefully controlled quantities of gas lighten the fluid column allowing natural reservoir pressure to push the fluid up the tubing.

FEATURES

• Externally adjusted spring • Cross-over seat design • Integral reverse check

• Simple design, modular construction • Available in various alloys and elastomers • Unitized bellows nitrogen containment • Port sizes 1/8" - 1/4”

The GBKRF is bellows actuated; spring loaded, and normally closed. The valve components are available in either stainless steel or nickel alloys for corrosion resistance in wells with high concentrations of H2S and/or CO2. The metal used conforms to NACE standard MR0175 for sulfide stress cracking resistant metallic materials.

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Constructed of multi-ply Monel®, the bellows of the GBKRF is subjected to a special hydraulic forming process to set all the convolutions of the bellows so that each convolution accepts an equal amount of stress during valve operation. Also, during the manufacturing process, the component parts of the bellows assembly are unitized by induction brazing which enables the bellows to isolate pressure without the use of elastomers.

The GBKRF floating seat is available with a choice of 1/8" to 1/4” port sizes. An internal guide precisely aligns the stem tip with the valve seat during every operation of the valve. Before installation, the spring of the GBKRF gas lift valve is adjusted to establish the valve’s operating pressure. The GBKRF valve is installed in the side pocket of a KB series style mandrel either at the surface, before the tubing string is installed in the well or by standard slickline methods in a completed well.

The GBKRF is designed to accept a GBK-2 top latch that locks the valve in the mandrel pocket. When the valve has been located in the mandrel pocket, the latch ring of the GBK-2 engages the latch lug located above the mandrel pocket and secures the valve in the pocket. When set in the mandrel pocket, the two packing sets on the GBKRF valve seal above and below the casing ports in the mandrel pocket. Tubing pressure enters the valve nose, is routed past the velocity-closed reverse flow check disk and upward through the crossover seat. The GBKRF crossover seat is designed with bypass holes to allow production pressure to act on the effective area of the valve’s bellows. When the production fluid pressure, acting on the effective area of the bellows minus the port area plus the injection pressure working on the port area overcomes the force produced by the valve’s spring, the bellows is expanded. This compresses the spring and the valve stem tip is lifted off the valve seat, opening the valve. High-pressure injection gas in the casing annulus enters the valve through the external port in the seat housing. As the valve is opened, the injection gas flows upward through the bore of the seat housing and then travels downward through the holes in the crossover seat. The injection gas flows downward, past the reverse flow check dart, out the nose of the valve and into the production tubing. When the

production pressure at valve depth drops below the valve’s set pressure, the valve spring pushes the bellows downward causing the ball of the stem tip to seat and close the valve. The check dart, installed in the valve’s check body, prevents reverse flow through the valve. The check dart seals against a hard/soft seat combination.

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Valve Specifications PPEF*

Type Ab (Effective Bellows Area) (sq. in) Port Size (in)

Ab – Area of Port with

Bevel (sq. in) Ap/Ab 1-(Ap/Ab) ₁ ₍_A_/_A₎ A / A PPEF b p b p − = Standard Monel Solid Carbide Standard Monel Solid Carbide Standard Monel Solid Carbide Standard Monel Solid Carbide GBKRF 0.31

1/8 N/A 0.021 N/A 0.068 N/A 0.932 N/A 0.073 3/16 N/A 0.037 N/A 0.119 N/A 0.881 N/A 0.135

1/4 N/A 0.058 N/A 0.187 N/A 0.813 N/A 0.230 9/32 N/A 0.083 N/A 0.268 N/A 0.732 N/A 0.366 5/16 N/A 0.097 N/A 0.313 N/A 0.687 N/A 0.456 3/8 N/A 0.129 N/A 0.416 N/A 0.584 N/A 0.712

*PPEF (production pressure effect factor) was formerly referred to as TEF (tubing effect factor).

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SUPERIOR GBKO-3 GAS LIFT ORIFICE VALVE

INTRODUCTION

The Superior GBKO-3 Orifice Valve is a 1" OD slickline retrievable valve designed for use in continuous flow gas lift

installations. When installed in a KB series style mandrel, the GBKO-3 is used to control the flow of gas from the casing annulus to the tubing. When installed in a KB series style mandrel with the EC feature for annular lift, the GBKO-3 valve controls flow from the tubing to the

casing. The valve consists of two primary housing components, a floating seat, a check dart, a valve nose, and two sets of external packing.

FEATURES

• Simple design, modular construction • Available in various alloys

• Many packing materials available

• Wide selection of orifice sizes (1/8” - 5/16”) • Integral reverse check

The integral reverse flow check element prevents the backflow of gas or well fluids. The GBKO-3 is available with 1/8" to 5/16" port sizes. This wide selection of port sizes enables the operator to inject gas at selected volumes and rates of flow to suit changing well conditions and operator needs.

The GBKO-3 orifice valve is available in stainless steel or nickel alloys for

corrosion resistance in wells with high

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concentrations of H2S and/or CO2. The metal used conforms to NACE standard MR0175 for sulfide stress cracking resistant metallic materials. The simple design and modular construction of the valve allows for easy redress and rapid, low cost repair of valve components. The rugged solid construction and the use of premium materials provide a long service life.

The GBKO-3 orifice valve is used to control the flow of gas from the injection conduit to the production conduit at valve depth. Before installation in the mandrel, the GBKO-3 should be fitted with a floating seat orifice of the

appropriate size. The valve, with the GBK-2 top latch, is installed in the pocket of a Superior KB series style side pocket mandrel. The valve and latch are installed in the pocket of the selected mandrel either at the surface before the tubing string is run into the well or by standard slickline methods into an already completed well.

NOTE: If the initial installation includes a hydraulic set packer, the GBKO-3 should not be run in the mandrel. A GDK-1 or E dummy should be used to attain the pressure integrity required to set the packer.

When set in the mandrel pocket, the two packing sets on the valve seal above and below the casing ports in the mandrel pocket. In operation, the injection gas enters the valve though the mandrel ports at the midpoint of the valve, travels through the valve port, past the integral check element, out the nose and into the production conduit. The volumes, injection cycles and injection pressure through the valve are regulated at the surface by an adjustable choke. Reverse flow through the valve is prevented by an integral check element.

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SUPERIOR GRDO-5 GAS LIFT ORIFICE VALVE

INTRODUCTION

The Superior GRDO-5 Orifice Valve is a 1-1/2” OD slickline retrievable valve designed for use in continuous flow gas lift installations. When installed in an M series mandrel, the GRDO-5 is used to control the flow of gas from the casing annulus to the tubing. When installed in an M series style mandrel with the EC feature for annular lift, the GRDO-5 valve controls flow from the tubing to the

casing. The valve consists of two primary housing components, a floating seat, an integral reverse flow check element, a valve nose and two sets of external packing.

FEATURES

• Simple design, modular construction • Available in various alloys

• Many packing materials available

• Wide selection of orifice sizes (3/16” - 3/4”) • Integral reverse check

The integral reverse flow check dart prevents the backflow of gas or well fluids. GRDO-5 seats are available with 3/16” to 3/4” orifice sizes. This wide selection of sizes enables the operator to inject gas at selected volumes and rates of flow to suit changing well conditions and operator needs. The GRDO-5 orifice valve is available in stainless steel or nickel alloys for corrosion resistance in wells with high concentrations with high

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concentrations of H2S and/or CO2. The metal used conforms to NACE standard MR0175 for sulfide stress cracking resistant metallic materials. The simple

design and modular construction of the valve allows for easy redress and rapid, low-cost repair of valve components. The rugged, solid construction and the use of premium materials provide a long service life.

The GRDO-5 orifice valve is used to control the flow of gas from the injection conduit to the production conduit at valve depth. Before installation in the

mandrel, the GRDO-5 should be fitted with a floating seat of the appropriate port size. The valve, with the appropriate GR series top latch is installed in the pocket of a Superior M series style side pocket mandrel. The valve and the selected latch are installed in the pocket of the selected mandrel either at the surface before the tubing string is run into the well or by slickline methods into an already completed well.

The GRDO-5 is used in applications where it is necessary to closely control the injection of gas from the casing into the tubing, or tubing to casing when used with an M series style mandrel that has the EC feature. This valve is also used when varying well conditions may dictate a change in choke diameters.

NOTE: if the initial installation includes a hydraulic set packer the GRDO-5 should not be run in the mandrel. A GRD dummy should be used to attain the pressure integrity required to set the packer.

When set in the mandrel pocket, the two packing sets on the valve seal above and below the casing ports in the mandrel pocket. In operation, the injection gas enters the valve through the mandrel ports at the midpoint of the valve, travels through the valve port, past the check dart, out the nose and into the production conduit. The volumes, injection cycles, and injection pressures through the valve are regulated at the surface by an adjustable choke. An integral check dart prevents reverse flow through the valve.

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SUPERIOR E DUMMY VALVE INTRODUCTION

The Superior E dummy valve is a 1" OD slickline retrievable non-equalizing

dummy valve designed to be installed in a KB series style side pocket mandrel. The dummy consists of two packing sections installed on two pieces of bar stock. The dummy valve is threaded to accept a GBK series top latch. The valve is available in either high-nickel alloys or stainless steel for corrosion resistance in wells with high concentrations of H2S and/or CO2.

FEATURES

• Rugged, solid construction

• Available in stainless steel or high nickel

alloys

• Various packing materials available • Accepts top latch

Packing materials for the E dummy are available for standard or high-temperature service to suit individual well conditions. The simple design of the dummy valve allows for easy replacement of the packing and for rapid low-cost

replacement of components. The valve's rugged, solid construction and quality materials provide a long service life. The E dummy valve is a multi-purpose tool used to:

• Blank off the side pocket mandrel to allow production by natural flow before installing gas lift valves.

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• Blank off the side pocket mandrel to allow pressure to be applied to the tubing to set a hydraulic-set packer.

• Isolate tubing flow from annular flow for test purposes during multi-point waterflood or gas injection.

The E dummy valve, with a Superior GBK series latch, is installed in a Superior KB series style side pocket mandrel. The valve and latch are installed in the side pocket mandrel either at the surface, before the tubing string is run into the well or by standard slickline methods into a completed tubing string. The two sets of packing on the dummy valve straddle and pack off the casing ports of the

mandrel. Communication between the tubing and casing is positively isolated. The E dummy valve is non-equalizing and should only be used when the operator can equalize the casing and tubing pressures at valve depth before pulling the dummy valve from the mandrel pocket by standard slickline methods. If differential pressure between the casing and the tubing cannot be equalized, a Superior equalizing dummy valve should be installed in one mandrel in the string in place of a non-equalizing dummy valve.

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SUPERIOR GRD DUMMY VALVE INTRODUCTION

The Superior GRD dummy valve is a 1-1/2" OD slickline retrievable

non-equalizing dummy valve designed to be installed in an M series style side pocket mandrel. The dummy consists of two packing sections installed on two pieces of bar stock. The dummy valve is

threaded to accept a GR series top latch. The valve is available in either high-nickel alloys or stainless steel for corrosion resistance in wells with high

concentrations of H2S and/or CO2. Packing materials for the GRD dummy are available for standard or

high-temperature service to suit individual well conditions. The simple design of the dummy valve allows for easy replacement of the packing and for rapid low-cost replacement of components. The valve's rugged, solid construction and quality materials provide a long service life.

FEATURES

• Rugged solid construction

alloys

• Various packing materials available • Accepts top latch

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The GRD dummy valve is a multi-purpose tool used to:

• Blank off the mandrel pocket to allow production by natural flow before installing gas lift valves.

• Blank off the side pocket mandrel to allow pressure to be applied to the tubing to set a hydraulic-set packer.

• Isolate tubing flow from annular flow for test purposes during multi-point waterflood or gas injection.

The GRD dummy valve, with a Superior GR series latch, is installed in a Superior M series style side pocket mandrel. The valve and latch are installed in the side pocket mandrel either at the surface, before the tubing string is run into the well or by standard slickline methods into a completed tubing string. The two sets of packing on the dummy valve straddle and pack off the casing ports of the

mandrel. Communication between the tubing and casing is positively isolated. The GRD dummy valve is non-equalizing and should only be used when the operator can equalize the casing and tubing pressures at valve depth before pulling the dummy valve from the mandrel pocket by standard slickline methods. If differential pressure between the casing and the tubing cannot be equalized, a Superior equalizing dummy valve should be installed in one mandrel in the string in place of a non-equalizing dummy valve.

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SUPERIOR GBK-2 LATCH INTRODUCTION

The Superior GBK-2 latch is a 1” OD, spring loaded, and ring-style latch that anchor Superior retrievable gas lift valves and side pocket accessories in the

appropriate Superior KB series style mandrels.

FEATURES

• Compact and simple design latch ring

design

• Minimum amount of force to install in

deviated wells

• Latch components are made of premium

materials for stress cracking resistance APPLICATION AND OPERATION

The GBK-2 latch is installed and removed from the side pocket mandrel using

standard slickline methods. A minimum amount of force is required to install the latch. This is particularly important in deviated wells where forceful downward jarring is not possible.

Latch components are available in either stainless steel or nickel alloys for

corrosion resistance in wells with high concentrations of H2S and/or CO2. The Superior GBK-2 latch secures 1” OD gas lift valves, chemical injection valves, and other side pocket devices in KBM, KBMM, KBMG, or KBTG series style side pocket mandrels.

Before installation, the GBK-2 latch is threaded onto the upper end of the

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selected device and then secured to the JK running tool. The running tool, latch, and side pocket device are attached to the appropriate K series kickover tool in non-orienting mandrels and the TMP-HD, or OK series kickover tool in orienting mandrels and run by slickline to the depth of the selected mandrel.

The industry standard GBK-2 latch components include a running head, latch body with integral fishing neck, latch spring, latch ring, and latch stop. A brass shear pin positioned through the running head shank and latch body maintains the latch ring in the locked position until the latch and attachments are removed.

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SUPERIOR GRA LATCH INTRODUCTION

The Superior GRA latch is a 1-1/2” OD retrievable valve top latch which anchors Superior retrievable gas lift valves and side pocket accessories in the appropriate M series style Superior side pocket

mandrels with an A-Type pocket. This latch is designed with a spring-loaded rotating latch cam.

FEATURES

• Rugged field proven design • Cam type latch

alloys

The GRA latch is installed and removed from the mandrel pocket using standard slickline methods. A minimum amount of force is required to install the latch. The latch components are available in either stainless steel or nickel alloys for corrosion resistance in wells with high concentrations of H2S and/or C02.

The GRA latch secures 1-1/2” OD gas lift valves and other side pocket devices mandrel pockets.

Prior to installation, the latch is assembled onto the upper end of the selected device and then secured to the GJC-5 running tool. The running tool, latch and side pocket device are attached to the R or L series kickover tool in non-orienting mandrels and the OM series or TP-HD

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kickover tools in orienting mandrels and run by slickline to the depth of the selected mandrel.

Downward jarring will drive the side pocket device into the mandrel pocket and set the latch. As the latch and device are jarred downward into the pocket, the spring-loaded latch cam rotates into the latch body. This enables the latch cam to travel past the narrow bore at the top of the pocket. When the no-go shoulder of the latch contacts the top of the pocket, the latch cam will be located at the locking recess. The latch cam will snap-outward and engaged the locking recess which will secure the latch and the attached device in the pocket.

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SUPERIOR GRK LATCH INTRODUCTION

The Superior GRK latch is a 1-1/2” OD, spring loaded, and ring-style latch that anchor Superior retrievable gas lift valves and side pocket accessories in the

appropriate Superior M series style mandrels.

FEATURES

• Compact and simple latch ring design • Minimum amount of force to install in

deviated wells

• Latch components are made of premium

materials for stress cracking resistance

• Pocket debris barrier

The GRK latch is installed and removed from the side pocket mandrel using standard slickline methods. A minimum amount of force is required to install the latch. This is particularly important in deviated wells where forceful downward jarring is not possible.

Latch components are available in either stainless steel or nickel alloys for

corrosion resistance in wells with high concentrations of H2S and/or CO2. The Superior GRK latch secures 1-1/2” OD gas lift valves, chemical injection valves, and other side pocket devices in MMM, MMG, MMRG or MTG series style side pocket mandrels.

Before installation, the GRK latch is threaded onto the upper end of the

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selected device and then secures to the GRK running tool. The running tool, latch, and side pocket device are attached to the appropriate TP-HD or OM series kickover tool in orienting mandrels and run by slickline to the depth of the selected mandrel.

The industry standard GRK latch components include a running head, latch body with integral fishing neck, latch spring, latch ring, and latch stop. A brass shear pin positioned through the running head shank and latch body maintains the latch ring in the locked position until the latch and attachments are removed.

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SUPERIOR JR SERIES CONVENTIONAL GAS LIFT MANDRELS

INTRODUCTION

The Superior JR Series Conventional Gas Lift Mandrels are installed as part of the tubing string and have an exterior ported lug which accepts a 1” OD conventional subsurface control device and a reverse flow check valve. All Superior JR series mandrels are internally drifted to standard drifted specifications and hydrostatically tested to 6,000 psi.

FEATURES

• Standard API connections and grades • Robust construction

• Accepts standard 1” conventional gas lift

valves and checks

Superior JR mandrels are designed for single-string installations and are normally used injection-pressure operated tubing flow applications.

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Engineering Data for JR Series Conventional Gas Lift Mandrels Tubing Size (in./mm) Type Maximum OD (in./mm) ID (in./mm) Length (ft.) 1.315 EUE 33.4 JR 2.669 67.8 1.049 26.6 4 1.660 EUE 42.2 JR 3.000 76.2 1.380 35.1 4 JR Defector Lug 3.148 79.9 1.380 35.1 4 1.990 EUE 48.3 JR 3.262 82.9 1.610 40.9 4 JR Deflector Lug 3.418 86.8 1.610 40.9 4 JR-R Deflector Lug 3.305 83.9 1.610 40.9 4 2.063 IJ* 52.4 JR Deflector Lug 3.454 86.8 1.751 44.5 4 JR-R Deflector Lug 3.625 83.9 1.751 44.5 4 2.375 EUE 60.3 JR 3.781 96.0 1.995 50.7 4 JR Deflector Lug 3.937 99.9 1.995 50.7 4 JR-R Deflector Lug 4.093 103.9 1.995 50.7 4 2.875 EUE 73.0 JR 4.335 110.1 2.441 62.0 4 JR Deflector 4.489 114.0 2.441 62.0 4 JR 5.062 128.6 2.992 75.9 4

*IJ represents an integral joint thread, an API thread in which the box is integral to the tubing and no coupling is required.

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SUPERIOR SR DEFLECTOR LUG CONVENTIONAL GAS LIFT MANDRELS

INTRODUCTION

The Superior SR Deflector Lug Conventional Gas Lift Mandrels are installed as part of the tubing string and have an exterior ported lug which accepts a 1-1/2” OD conventional subsurface control device and a reverse flow check valve. All Superior SR series mandrels are internally drifted to standard drifted specifications and hydrostatically tested to 6,000 psi.

FEATURES

• Standard API connections and grades • Robust construction

• Accepts standard 1-1/2” conventional gas

lift valves and checks

Superior SR deflector lug mandrels are designed for dual-string installations and are normally used in injection-pressure-operated tubing flow applications. These mandrels feature long, tapered, welded-in line with the exterior ported lug to protect the installed subsurface control device and allow the mandrel to easily pass other mandrels during installation in dual-string applications.

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Engineering Data for SR Series Conventional Gas Lift Mandrels Tubing Size (in/mm) Type Maximum OD (in/mm) ID (in/mm) Length (ft.) 1.900 EUE 48.3 SR-R Deflector Lug 4.200 106.7 1.610 40.9 4 2.375 EUE 60.3 SR 4.375 110.1 1.995 50.7 4 SR Deflector Lug 4.531 114.0 1.995 50.7 4 SR-R Defector Lug 4.719 119.6 1.995 50.7 4 2.875 EUE 73.0 SR 4.929 110.1 2.441 62.0 4 SR Deflector Lug 5.084 114.0 2.441 62.0 4 SR-R Deflector Lug 5.281 119.6 2.441 62.0 4 3.500 EUE 88.9 SR 5.655 143.6 2.992 75.9 4 4.500 EUE 114.3 SR 6.875 174.6 3.958 100.5 4

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SUPERIOR CONVENTIONAL WASHOVER GAS LIFT MANDRELS

INTRODUCTION

The Superior Conventional Washover Gas Lift Mandrels are installed as part of the tubing string and have an exterior ported lug which accepts a 1” OD conventional subsurface control device and a reverse flow check valve. All Superior Washover mandrels are internally drifted to standard drifted specifications and hydrostatically tested to 3,000 psi.

FEATURES

• 2-3/8” 4.7 ppf EUE 8RD connections

• Accepts standard 1” conventional gas lift

valves and checks

Superior Washover mandrels are designed for single-string installations and are normally used injection-pressure operated tubing flow applications. ENGINEERING DATA MAXIMUM OUTSIDE DIAMETER (IN) (RUNNING CLEARANCE) 3.454”

OVERALL LENGTH (IN) 36.500”

ID FLOW 2.00”

WEIGHT (LBS) 32.0 LBS THREAD 2-3/8” EUE 8RD

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Conventional

Gas Lift Valves

And

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SUPERIOR GJ-20 INJECTION PRESSURE OPERATED GAS LIFT VALVE

INTRODUCTION

The Superior GJ-20 Gas Lift Valve is a 1-1/2” OD conventional gas lift valve

designed for use in either continuous flow or intermittent flow gas lift installations. The valve is bellows-operated, nitrogen-charged and normally closed. The simplicity of the GJ-20 design assures a long operating life.

FEATURES

• Conventional type valve • Nitrogen charged bellows

• Dual seat nitrogen containment

• Special bellows treatment to prolong life • Available in various alloys and elastomers • 3/16” – 1/2” port sizes

The bellows of the GJ-20 Gas Lift Valve is constructed of three-ply Monel. During manufacture, the bellows is placed in a hydrostatic pressure chamber and subjected to external pressure. This special hydraulic forming process seats all the convolutions of the valve bellows so that each convolution accepts an equal amount of stress during valve operation. The bellows of the GJ-20 valve can accept a wide range of internal set pressures to suit individual well

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conditions. During manufacture, the component parts of the GJ-20 bellows assembly are unitized by a silver soldering process that enables the nitrogen pressure charge to be sealed within the bellows without the use of elastomers. To provide additional protection against alteration of the valve pressure charge, the tail plug of the GJ-20 valve is fitted with both a copper gasket and an o-ring. These two sealing elements offer double protection against fluid leaking into the bellows housing.

The design of the GJ-20 Gas Lift Valve includes a bubble-tight seal between the valve stem tip and floating seat. GJ-20 seats are available in six port sizes: 3/16”, 1/4”, and 5/16” 3/8”, 7/16” and 1/2". This selection of port sizes enables the operator to inject gas at selected volumes and rates of flow to suit changing well conditions and operator needs. The seats are available in either Monel or tungsten carbide. All tungsten carbide seats are lapped with the tungsten carbide stem tips as matched pairs to ensure a leak proof seal. An additional feature of the GJ-20 valve is an internal stem guide that guides the tungsten carbide ball into precise alignment with the valve seat with every operation of the valve. The GJ-20 valve is designed so that the valve seat and stem tip can be replaced without disassembling the entire valve.

VALVE APPLICATION

Prior to installation, the dome of the GJ-20 valve is charged with nitrogen to establish the valve operating pressure. The valve is then attached either to a Superior GJ-20 Reverse Flow Check Valve, and installed on one of two Superior conventional gas lift mandrels, the standard GC or GC Deflector Lug Mandrels. The operator can assemble the GJ-20 valve, the reverse flow check valve and the selected mandrel in any one of four completion designs. The GJ-20 valve can operate either by injection pressure or production pressure and well fluids may be produced either through the tubing or the casing.

In the standard completion design, the GJ-20 valve is operated by injection pressure and well fluids are produced through the tubing. In this design, the GJ-20 Gas Lift Valve and the GJ-GJ-20 Reverse Flow Check Valve are installed on the selected mandrel. In operation, the high-pressure injection gas enters the ports in the valve body from the casing annulus and acts upon the bellows. When the high-pressure injection gas overcomes the pre-set nitrogen charge pressure within the bellows, the bellows is compressed and the valve stem tip is lifted off the valve seat, opening the valve. The injection gas flows through the bore of the seat, down through the check valve and into the production tubing. If the high-pressure injection gas in the casing annulus at valve depth drops below the valve set pressure, the valve bellows extends downward, causing the ball of the stem tip to seat and close the valve. The GB-1 Reverse Flow Check Valve prevents reverse flow thought the valve. The check elements in the GJ-20 check valve seats tightly against both a soft seat and a metal-to-metal seat.

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Valve Specifications PPEF*

Type Ab: Effective Bellows Area (sq. in.) Port Size (in.) Ap : Area of Port With Bevel (sq. in.) Ap/Ab 1-(Ap/Ab) ) A / A ( 1 A / A PPEF b p b p − = GJ-20 0.77 3/16 0.029 0.038 0.962 0.040 1/4 0.051 0.066 0.934 0.070 5/16 0.079 0.103 0.897 0.115 7/16 0.154 0.200 0.800 0.250 1/2 0.200 0.260 0.740 0.351

*PPEF (production pressure effect factor) was formerly referred to as TEF (tubing effect factor).

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SUPERIOR GJ-40 INJECTION PRESSURE OPERATED GAS LIFT VALVE

INTRODUCTION

The Superior GJ-40 Gas Lift Valve is a 1” OD conventional gas lift valve designed for use in either continuous flow or

intermittent flow gas lift installations. The valve is bellows-operated, nitrogen-charged and normally closed. The simplicity of the GJ-40 design assures a long operating life.

FEATURES

• Conventional type valve • Nitrogen-charged bellows

• Dual seat nitrogen containment

• Special bellows treatment to prolong life • Available in various alloys and elastomers • 1/8” – 3/8” port sizes

The bellows of the GJ-40 Gas Lift Valve is constructed of three-ply Monel. During manufacture, the bellows is placed in a hydrostatic pressure chamber and subjected to external pressure. This special hydraulic forming process seats all the convolutions of the valve bellows so that each convolution accepts an equal amount of stress during valve operation The bellows of the GJ-40 valve can accept a wide range of internal set pressures to suit individual well conditions.

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During manufacture, the component parts of the GJ-40 bellows assembly are unitized by a silver soldering process that enables the nitrogen pressure charge to be sealed within the bellows without the use of elastomers. To provide

additional protection against alteration of the valve pressure charge, the tail plug of the GJ-40 valve is fitted with both a copper gasket and an o-ring. These two sealing elements offer double protection against fluid leaking into the bellows housing.

The design of the GJ-40 Gas Lift Valve includes a bubble-tight seal between the valve stem tip and floating seat. GJ-40 seats are available in five port sizes: 1/8”, 3/16”, 1/4”, 5/16” and 3/8”. This selection of port sizes enables the operator to inject gas at selected volumes and rates of flow to suit changing well

conditions and operator needs. The seats are available in either Monel or tungsten carbide. All tungsten carbide seats are lapped with the tungsten carbide stem tips as matched pairs to ensure a leak proof seal. An additional feature of the GJ-40 valve is an internal stem guide that guides the tungsten carbide ball into precise alignment with the valve seat with every operation of the valve. The GJ-40 valve is designed so that the valve seat and stem tip can be replaced without disassembling the entire valve.

VALVE OPERATION

Prior to installation, the dome of the GJ-40 valve is charged with nitrogen to establish the valve operating pressure. The valve is then attached either to a Superior GBF or GB-1 Reverse Flow Check Valve, and installed on one of four Superior conventional gas lift mandrels. The Superior gas lift mandrels available for GJ-40 well completion designs are: GJ-40 Mandrel, GJ-40 Pack-off Mandrel, GB Mandrel and GBR Mandrel. The operator can assemble the GJ-40 valve, the reverse flow check valve and the selected mandrel in any one of four completion designs. The GJ-40 valve can operate either by injection pressure or production pressure and well fluids may be produced either through the tubing or the casing. In the standard completion design, the GJ-40 valve is operated by injection

pressure and well fluids are produced through the tubing. In this design, the GJ-40 Gas Lift Valve and the GB-1 Reverse Flow Check Valve are installed on the selected mandrel. The Superior conventional gas lift mandrels which may be used in the standard GJ-40 completion design are the GJ-40 Mandrel, the GJ-40 Pack-off Mandrel or the GB Mandrel. In operation, the high-pressure injection gas enters the ports in the valve body from the casing annulus and acts upon the bellows. When the high-pressure injection gas overcomes the pre-set nitrogen charge pressure within the bellows, the bellows is compressed and the valve stem tip is lifted off the valve seat, opening the valve. This injection gas flows through the bore of the seat, down through the check valve and into the production tubing. If the high-pressure injection gas in the casing annulus at valve depth drops below the valve set pressure, the valve bellows extends downward, causing the ball of the stem tip to seat and close the Valve.

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The GB-1 Reverse Flow Check Valve prevents reverse flow through the valve. The check valve seats tightly against both a soft seat and a metal-to-metal seat.

Valve Specifications PPEF*

Type Ab (Effective Bellows Area) (sq. in.) Port Size (in.) AP: Area of Port With Bevel (sq. in.) Ap/Ab 1-(Ap/Ab) ) A / A ( 1 A / A PPEF b p b p − = Standard Monel Solid Carbide Standard Monel Solid Carbide Standard Monel Solid Carbide Standard Monel Solid Carbide GJ-40 0.31 1/8 0.013 0.021 0.042 0.068 0.958 0.932 0.044 0.073 3/16 0.029 0.037 0.094 0.119 0.906 0.881 0.104 0.135 1/4 0.051 0.058 0.165 0.187 0.835 0.813 0.198 0.230 5/16 0.079 0.097 0.255 0.313 0.745 0.687 0.342 0.456 3/8 0.113 0.129 0.365 0.416 0.635 0.584 0.575 0.712

*PPEF (production pressure effect factor) was formerly referred to as TEF (tubing effect factor).

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SUPERIOR GJ-40 CONVENTIONAL REVERSE FLOW CHECK VALVES INTRODUCTION

The Superior GJ-40 Conventional Reverse Flow Check Valves are 1” velocity check valves used with Superior conventional gas lift valves that do not have integral reverse flow check valves. These check valves protect the casing from backflow through valves below the working valve, allow application of pressure to the tubing for circulation or acidizing and prevent commingling of production fluids in dual gas lift installations.

FEATURES

• Integral reverse check • Includes hard and soft seats

• Available in standard or premium materials

Superior reverse flow check valves require flow to close. As the differential pressure across the valve’s check dart increases, the dart contacts the soft seat and then the hard seat to form a seal and close the check valve.

These valves each have an elastomeric soft seat and stainless steel hard seat. The initial seal is between the valve’s stainless steel check dart and the soft seat. These check valves can withstand 10,000-psi differential pressure and can be converted from velocity check valves to positive check valves by the addition of a spring. The flow area for the 1” OD GB-1 check valve is equivalent to a 5/GB-16” port.

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Engineering Data for GJ-40 Conventional Reverse Flow Check Valves Type OD (in./mm) Equivalent Port Size (in./mm) Connecting Thread (in. – TPI) Spring GJ-40 1.000 25.4 0.3125 7.9 1/2 - 14 NPT G1081-002

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SUPERIOR

SUPERIOR GJ-20 CONVENTIONAL REVERSE FLOW CHECK VALVES INTRODUCTION

The Superior GJ-20 Conventional Reverse Flow Check Valves are 1-1/2” velocity check valves used with Superior conventional gas lift valves that do not have integral reverse flow check valves. These check valves protect the casing from backflow through valves below the working valve, allow application of pressure to the tubing for circulation or acidizing and prevent commingling of production fluids in dual gas lift installations.

FEATURES

• Integral reverse check • Includes hard and soft seats

• Available in standard or premium materials

Superior reverse flow check valves require flow to close. As the differential pressure across the valve’s check dart increases, the dart contacts the soft seat and then the hard seat to form a seal and close the check valve.

These valves each have an elastomeric soft seat and stainless steel hard seat. The initial seal is between the valve’s stainless steel check dart and the soft seat. These check valves can withstand 10,000-psi differential pressure and can be converted from velocity check valves to positive check valves by the addition of a spring. The flow area for the 1-1/2” OD GJ-20 check valve is equivalent to a 9/16” port.

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Engineering Data for GJ-20 Conventional Reverse Flow Check Valves Type OD (in./mm) Equivalent Port Size (in./mm) Connecting Thread (in. – TPI) Optional Spring GJ-20 1.500 38.1 0.5625 14.3 1/2-14 NPT G1612-001

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Superior Energy Services Well Solutions Group

Artificial Lift Division

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INTRODUCTION

The Superior single pad plunger is designed for optimum performance in wells with damaged or defective tubing.

APPLICATION & OPERATION The spring loaded pads expand and contract to compensate for any

inconsistencies in the tubing thus creating a consistent seal against the walls of the tubing and maximizing efficiency. The plunger has the ability to collapse the outside diameter so that the plunger can pass through tight spots in the tubing. In addition, the plunger can be used without broaching the tubing.

The pads restrict leakage or slippage which capitalizes on the well’s pressure to

maximize lift efficiency. The pads are made from 17-4ph stainless steel. This makes the Superior Single Pad Plunger more resistant to wear caused by bad or worn production tubing. The life expectancy of the pads depends on the number of cycles that the plunger runs.

ENGINEERING DATA MAXIMUM OUTSIDE

DIAMETER (IN)

1.900” OVERALL LENGTH (IN) 9.820”

WEIGHT (LBS) 6.0 LBS

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SUPERIOR DUAL PAD PLUNGER

INTRODUCTION

The Superior dual pad plunger is designed for optimum performance in wells with damaged or defective tubing.

APPLICATION & OPERATION

The spring loaded pads expand and contract to compensate for any inconsistencies in the tubing thus creating a consistent seal against the walls of the tubing and maximizing

efficiency. The plunger has the ability to collapse the outside diameter so that the plunger can pass through tight spots in the tubing. In addition, the plunger can be used without broaching the tubing.

The pads restrict leakage or slippage which capitalizes on the well’s pressure to maximize lift efficiency. The pads are made from 17-4ph stainless steel. This makes the Superior Dual Pad Plunger more resistant to wear caused by bad or worn production tubing. The life

expectancy of the pads depends on the number of cycles that the plunger runs.

ENGINEERING DATA MAXIMUM OUTSIDE

DIAMETER (IN)

1.900” OVERALL LENGTH (IN) 14.406”

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INTRODUCTION

The Superior dual pad plunger is designed for optimum performance in wells that produce sand, salt and/or coal fines.

If a well is producing sand, salt and coal fines, a brush plunger provides an effective seal for these marginally producing wells.

The brush plunger is covered with a flexible nylon brush that allows the plunger to travel in the tubing despite foreign materials. The brush effectively removes sand, salt and coal fines that accumulate on the walls of the tubing. The diameter of the brush is slightly larger than the plunger body, so it creates an effective seal by adapting to deviations in the tubing. The brush design affords heavy durability in harsh well conditions.

The Superior Brush Plunger is designed for optimal operations in:

• Low pressure wells

• Wells with tubing irregularities

• Wells that produce salt, sand or coal fines • Wells requiring high seal efficiency

. ENGINEERING DATA MAXIMUM OUTSIDE DIAMETER (IN) 1.900” OVERALL LENGTH (IN) 15.0625”

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SUPERIOR SPIRAL PLUNGER

INTRODUCTION

The Superior spiral plunger is designed for optimum performance in high GLR wells that make formation sand, frac sand and paraffin.

The spiral plunger is a solid plunger designed and machined to tolerances of the tubing ID to allow for maximum durability and efficiencies. The spiral plunger is most appropriate for wells that make solids.

The spiral plunger is available in 2” and 2-1/2” sizes. All spiral plungers are available in 10”, 12” and 17” lengths. Standard metallurgy is 4140 heat-treated, cold rolled steel – it is also available in 17-4ph stainless steel for wells with harsher environments.

ENGINEERING DATA MAXIMUM OUTSIDE DIAMETER (IN) 1.900” 2.340” OVERALL LENGTH (IN) 10.0”, 12.0”, 17.0” 10.0”, 12.0”, 17.0” PULLING TOOL 2” JDC 2” JDC

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INTRODUCTION

The Superior spiral plunger with rifling is designed for optimum performance in wells with that make formation sand, frac sand and paraffin.

The spiral plunger is designed with rifling to improve the gas turbulence and increase sealing efficiencies. The rifling on the upper shoulder and bottom

increases the efficiencies by creating a vortex of gas and fluid, causing the plunger to spin and provide better sealing and travel velocities.

The spiral plunger with rifling is available in 2” and 2-1/2” sizes. All spiral plungers are available in 10”, 12” and 17” lengths. Standard metallurgy is 4140 heat-treated, cold rolled steel – it is also available in 17-4ph stainless steel for wells with harsher

environments. ENGINEERING DATA MAXIMUM OUTSIDE DIAMETER (IN) 1.900” 2.340” OVERALL LENGTH (IN) 10.0”, 12.0”, 17.0” 10.0”, 12.0”, 17.0” PULLING TOOL 2” JDC 2” JDC

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SUPERIOR BYPASS PLUNGER

INTRODUCTION

The Superior bypass plunger is designed to fall in the well against flow at a higher rate than a conventional plunger.

APPLICATION & OPERATION The bypass plunger bypass locking

mechanism allows the plunger to be locked in the open or closed position to

accommodate movement. In the locked open position, the plunger will fall thru flow provided by the well and the bypass

remains open until the plunger strikes the bottom hole bumper spring. In the closed position, the plunger return to the surface with a full load of fluid and not open until it strikes the lubricator. The locking

mechanism will prevent premature shifting of the bypass rod to the other position during movement. ENGINEERING DATA MAXIMUM OUTSIDE DIAMETER (IN) 1.900” OVERALL LENGTH (IN) 13.750”

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INTRODUCTION

The Superior Bottom Hole Bumper Spring (BHBS) is installed at the bottom of the well in the tubing and absorbs the impact of the plunger when it hits bottom to prevent damage to the seating nipple and tubing.

The BHBS minimizes downhole restrictions which yields increased production. A BHBS is either dropped from the surface or

installed by wireline. If needed, a ball and seat can be added to retain liquid in the tubing.

The BHBS has evolved from field application and testing with input from various operators. Because of its importance in protecting the well and extending the life of the plunger lift system, the BHBS is designed for maximum

durability and is engineered to actually minimize downhole restrictions and sand cutting. The results: increased production and profits.

Improvements to the spring design and metallurgy guarantees the longest life BHBS available on the market today. The elimination of the ball in the flow stream has provided increased flow area to reduce pressure drop thru the seat area while in operation.

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SUPERIOR BOTTOM HOLE BUMPER SPRING

Standard metallurgy is 4140 heat-treated, cold rolled steel – it is also available in 17-4ph stainless steel for wells with harsher environments.

The Superior Bottom Hole Bumper Spring can be modified for installation into wells with:

• Wells with a seating nipple and/or plunger lift system

• Wells without a seating nipple that require a plunger lift system

• Wells with low liquids that require a standing valve to hold liquids in the tubing

• Adaptable to various nipple profiles and ID’s

ENGINEERING DATA

MAXIMUM OUTSIDE DIAMETER (IN) 1.900”

OVERALL LENGTH (IN) 28.1875”

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INTRODUCTION

The Superior Star Stop is a cost effective bottom stop for a plunger lift installation.

The Star Stop is installed in a No-Go nipple and provides a cost effective bottom stop for a plunger lift installation. The stop is made from 4140 hardened steel and is easy to install and remove from the well.

ENGINEERING DATA MAXIMUM OUTSIDE DIAMETER (IN) 1.900” OVERALL LENGTH (IN) 8.000”

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SUPERIOR STAGE TOOL

INTRODUCTION

The Superior stage tool is a cost effective solution to optimize production from deep and/or low GLR wells.

The Superior stage tool is designed to be a low-cost and efficient method of lift to increase and optimize production form deep and/or low GLR oil and gas wells. The installation utilizes two plungers – one installed below the stage tool and one above it. The stage tool acts as an interface between the upper and lower plunger lift installation. The stage tool has a standing valve built into it and it eliminates the fallback of fluids, while a corresponding reduction in the flowing bottomhole pressure increases the flow of fluid from the formation.

Primary applications of the Superior stage tool: • Low volume wells that may require longer

shut-in times to allow for fluid inflow

• Wells that do not have sufficient gas production to allow a one plunger system to cycle the plunger to the surface

• Wells that have a production packer

• Older wells that have a single plunger system that does not cycle to the surface • Low GLR wells ENGINEERING DATA MAXIMUM OUTSIDE DIAMETER (IN) 1.900” 2.340” MINIMUM INSIDE DIAMETER (IN) 0.875” 1.500” OVERALL LENGTH (IN) 42.500” 45.000”

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SUPERIOR DUAL OUTLET LUBRICATOR – LOW PRESSURE

INTRODUCTION

The Superior dual outlet low pressure lubricator is designed to operate in plunger lift wells with working pressures up to 3000 psig.

FEATURES & BENEFITS

• Dual 2” flow outlets for maximum flow and minimum pressure drops

• ½” NPT outlet for needle valve installation

• Available for 2-3/8” and 2-7/8”

plunger lift installations with EUE 8rd threads standard

• Trigger style catcher mechanism • Stub Acme thread on cap provides

easy access to spring

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INTRODUCTION

The Superior dual outlet high pressure/heavy duty lubricator with Bowen Union top connection is designed to operate in plunger lift wells with working pressures up to 5000 psig and is tested to 7500 psig.

FEATURES & BENEFITS

• Dual 2-1/6” 5M RTJ XXM flow outlet flanges for maximum flow and minimum pressure drops • ½” NPT outlet for needle valve

installation

• 2-1/6” 5M RTJ XXM bottom flange for installation to the tree

• Available for 2-3/8” and 2-7/8”

plunger lift installations with EUE 8rd threads standard

• Trigger style catcher mechanism • Stub Acme thread on cap provides

easy access to spring

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Flow Data, Inc. • 3184 Mesa Avenue • Grand Junction, CO 81504 • T 970.523.7744 • F 970.523.7744 • www.flow-data.com

Features

Well Automation and

SMARTER Plunger Lift Solution

The Superior Energy solution powered by Flow Data is the intelligent choice in well automation. Our solution generates a lifetime of efficiencies and productivity that make it the smarter choice. Our programmers and engineers with input from end users have

developed a complete Plunger Lift software solution that can be used in Basic and Expert mode. The software can be customized to meet the needs of each customer. This customization is possible with the use of the proven and powerful SCADAPack PLC hardware. Utilizing reliable open protocol platforms, our solution is highly flexible allowing for communication with most all field devices on the market. In addition, our smarter architecture has no single point of failure – we have built in redundancy.

The Complete Solution • Basic mode for operating wells

• Expert Plunger Lift Mode for dynamic well optimization • Full wireless Well Automation, EFM and Plunger Lift for 30+

wells per controller

• RapidTrend SCADAlog application for efficient high density Modbus trending to an SQL database

• Owner Add-On Application Capability • Redundant Communications

• Standardized Modbus Register Configuration Wizard • Pad Wide - Well Synchronization

• Future Proof Programmable Solution

• Interface with ClearSCADA, CygNet, Intellution, Wonderware and other major applications

Pad-Wide Solutions

• Intelligent multi-well synchronization algorithm

• Wireless or wired instrumentation capable

• Tank level monitoring: pad-wide shutdown, daily liquid production, and well test feature

• Pulsed meter liquids measurement and daily production reports • Braden Head monitoring and shut-in • Dump line Pressure

• Local Operator Interface – Controls all wells from one location

• Remote and Local acknowledge and reset

• Remote pad shut-in – Emergency Shutdown

• Pad Manager laptop application: allows for complete functionality well-site operations

• Pad Manager EZ well configuration – No Programming

• High density trending with adjustable recording frequency

Auto Intermitted – Dynamic Features • Emulates plunger control without plunger

hardware

• Early startup based on pressures

• Extended flow time based on calculated or fixed critical flow velocity

• Minimum Tubing / Static differential flow permissive

• Minimum / Critical flow permissive • Maximum static pressure override with

adjustable reset

Complete Plunger Lift Application • Plunger Safety: Fast and Critical Arrival

Alarm and Shutdown

• Proportional auto-adjust optimizer • Dynamic No-show Modifier • Extended After Flow • Dynamic critical flow rate • Static Margin Permissive • Minimum Flow Permissive

• Static Pressure Override with auto reset • Complete Plunger Cycle History Record • Early Startup on Tubing and Casing • Adjustable No-show shut-in

Open Conditions

• Normal off cycle expires • High Casing Pressure • High Tubing Pressure

• High Tubing and Casing Pressure • Tubing – Line above set point • Casing – Tubing above set point

Close Conditions

• Normal after flow cycle expires • Flow rate below critical flow rate • Extended flow cycle below critical flow

rate

• Tubing – Line below set point • Casing – Tubing below set point • Line pressure above set point

703 23 2/10 Road. • Grand Junction, CO 81505 • Phone: (970) 263-0400 • Fax: (970) 263-0411 www.superiorenergy.com