Jet pump

Hydraulic Jet Pumps 1.0

General Jet Pumps are very important members in family of hydraulic pumps. Production and power fluid rates in Jet Pumps are controlled by a nozzle/venturi arrangement. Different geometry configurations are used for controlling the clearance between the nozzle and mixing tube orifices, as specified by a computer, to attain proper production rates.

2.0

Advantages  Jet Pumps have no moving parts, they are especially attractive because of low maintenance costs, long runs, and either high or low volumes. Usually, the main point of failure will be either a nozzle or mixing tube, either of which may be easily replaced, even at the well site.  Jet Pumps are available in 2-inch, 2.5-inch, 3-inch and 4-inch sizes, in standard materials or premium materials to fit almost every competitive bottom-hole assembly.  Jet Pumps are of the free-pump concept, which incorporate all the advantages previously listed for free pumps.  Capable of handling extremely high volumes.  Adjustable to varying production rates.  Low maintenance costs.  Pressure and temperature recording devices may be used as an integral addition to the pump  Suitable for low gravity and high-pour-point crude oils.  Adaptable for use with a sliding sleeve.  Can be run in crooked holes.  Handles gassy production  Handles solids and corrosive fluids

3.0

Limitations  Producing Rate Relative to Bottomhole Pressure  Some Require Specific Bottomhole Assemblies  Lower Horsepower Efficiency

4.0

How it works 1. Power fluid is pumped at a given rate (QN) to the down-hole jet pump where it reaches a nozzle with a total pressure, designated as PN. This high-pressure fluid (high potential energy) is then directed through the

nozzle, which converts the fluid stream to a high velocity (high kinetic energy) and low static pressure. 2. The low pressure (PS) allows well fluids to flow into the well bore and pump at the desired production rate (QS). The high-momentum power fluid is then mixed with the low-momentum production in a constant area mixing tube. It is in this mixing process that energy is transferred from the power fluid to the production. When the combined fluids reach the end of the mixing tube, they are at a low pressure and high velocity. 3. The fluid then exits the pump through a diffuser section which converts the fluid to a high-static-pressure, low velocity state. This high discharge pressure (PD) must be sufficient to lift the combined fluid rate (QD) to the surface.

4. The key components of the jet pump are the nozzle and mixing tube (throat). The area of the openings in these parts determines the performance characteristics of the pump. These areas are designated as AN and AT. 5. The ratio of these areas, AN/AT, is referred to as the area ratio. Pumps with the same area ratio have the same performance curve. 6. The volume of power fluid used will be proportional to the size of the nozzle. 7. The sizes of nozzles and throats determine the flow rate while the ratio of their flow areas determines tradeoff between produced head and flow rate. 8. If, for example, a throat is selected such that the area of the nozzle is 60% of the throat area, a relatively high head, low flow will result. There is a small area around the jet for well fluids to enter, leading to low production rates. 9.

10. If, on the other hand, a throat is selected such that the area of the nozzle is 20% of the throat area, more production flow is possible, but, since the nozzle energy is being transferred to a large amount of production, lower head will be developed. 11. The cavitation characteristics of the pump must be considered, cavitation

will occur when the velocity of the produced fluids entering the throat around the power fluid jet is high enough that static pressure in the fluid falls to its vapor pressure. This will choke the flow and damage the throat. 5.0

Selecting a Pump The Jet Pump selected to produce a well must have a capacity large enough to obtain the rate of production the well is capable of producing. At the same time, the required surface horsepower must be kept at a reasonable level. The task of selecting the proper jet pump involves finding a pump geometry capable of achieving the production rate, but capable of operating within given horsepower requirements, or at an optimum horsepower. The calculations on the following pages will provide the information necessary to select the correct pump for any application.

6.0

Jet pump design step by step 1. From well data for production, QS, and pump intake pressure, PS and GOR, calculate the minimum annular area to avoid cavitations.

2. From the table of annular area, select nozzle and throat combination which has an annular area greater than ASM 3. Calculate the pressure at the nozzle, PN, which is the sum of the operating pressure (known from the available Pump [triplex or horizontal pump]) plus the hydrostatic pressure in the tubing minus friction losses in the tubing.

4. The friction in the annular or tubing can be determined from.

D1 D2

Annular flow

Tubing flow

Casing I.D Tubing O.D

Tubing I.D 0

5. Determine the power fluid rate, QN from,

6. Determine the returned flow rate, QD,

7. Determine the production gradient (pump suction),

8. Determine the returned flow fluid gradient, GD, from,

9. Calculate the returned flow WC, WCD

10. Calculate the returned flow gas liquid ratio, GLR,

11. Determine the returned flow liquid viscosity for calculating friction loss, μD from,

12. Calculate the pump discharge pressur PD pressur which is the sum of hydrostatic pressure in the reurn conduit, the friction losses, and the well head back pressure,

13. Calculate N (dimensionless pressure recover ratio) from,

14. Calculate M (dimensionless mass flow ratio) from,

15. Calculate N (dimensionless pressure recover ratio), for the value of R selected, using of M from step 11

16. Compare the current value of N with the N value from step 13. if the difference is less than 0.5%, iteration is completed go to step 19 otherwise go to step 17. 17. If the required is power fluid pressure, calculate new nozzle pressure from equation,

Then go to step 5 18. If the required is PIP, calculate it from the equation, Then go to step 3 19. Determine the new surface operating pressure (triples) from equation, 20. Calculate the maximum non-cavitating flow from equation,

21. Calculate triplex HP assuming 90% efficiency from the equation,

7.0 Glossary AN = Nozzle flow area in2 AS = Throat annulus area (AT-AN) in2 ASM = Minimum throat annulus area to avoid cavitation in2 AT = Throat flow area in2 D = Vertical depth of well ft D1 = ID of tubing or casing in D2 = OD of inner tubing in annular flow in GD = Gradient of returned mixed power fluid and producing fluid psi/ft GLR = Returned flow gas liquid ratio scf/bbl GN = Power fluid gradient at nozzle psi/ft GO = Produced oil gradient psi/ft GOR = Gas oil ratio scf/bbl GS = Water gradient psi/ft KN = Nozzle loss coefficient KTD = Throat-diffuser loss coefficient L = Tubing length ft M = Dimensionless mass flow rate N = Dimensionless pressure recovery ratio PD = Pump discharge pressure psi PF = Friction loss in tubing psi/ft PFN = friction loss in power fluid tubing psi/ft PFD = Friction loss in returned conduit psi/ft PN = pressure at nozzle interance psi PS = pump suction pressure (Pwf) psi PT = Surface operating pressure (triplex pressure) psi PWH = Well head pressure psi QD = Flow rate from pump discharge bpd QG = Flow rate of gas through pump bpd QN = Flow rate through the nozzle bpd QS = Producing flow rate bpd QSC = Minimum non-cavitating pump suction flow rate bpd R = Nozzle throat areas ration (AN/AT) WC = Water cut (decimal) W CD = Returned flow water cut µD = Returned fluid viscosity cp µO = Viscosity of oil cp µW = Viscosity of water cp

Guiberson AN, AT, AS, and R as Example: Nozzle ↓

A

A+

B

B+

C

C+

D

E

F

G

H

I

Throat

1

2

3

R

0.38

0.29

0.23

AS

0.0088

0.0134

0.0186

Throat

1

2

3

4

5

R

0.52

0.4

0.31

0.24

0.2

AS

0.0068

0.0114

0.0166

0.0239

0.0305

Throat

1

2

3

4

5

6

R

0.66

0.5

0.39

0.3

0.25

0.21

AS

0.0048

0.0094

0.0146

0.0219

0.0285

0.0357

Throat

1

2

3

4

5

6

7

R

0.76

0.58

0.45

0.35

0.29

0.24

0.21

AS

0.0034

0.008

0.0132

0.0205

0.0271

0.0343

0.0422

Throat

1

2

3

4

5

6

7

R

0.86

0.65

0.51

0.39

0.32

0.27

0.23

AS

0.002

0.0066

0.0118

0.0191

0.0257

0.0329

0.0408

Throat

2

3

4

0.05

6

7

8

R

0.79

0.62

0.48

0.39

0.33

0.28

0.23

AS

0.0039

0.0091

0.0164

0.023

0.0302

0.0381

0.0511

Throat

3

4

5

6

7

8

9

R

0.73

0.56

0.47

0.39

0.33

0.27

0.22

AS

0.0064

0.0137

0.0203

0.0275

0.0354

0.0484

0.0627

Throat

4

5

6

7

8

9

10

11

R

0.77

0.63

0.53

0.45

0.36

0.3

0.25

0.2

AS

0.0073

0.0139

0.0211

0.029

0.042

0.0563

0.0721

0.0954

Throat

6

7

8

9

10

11

12

R

0.69

0.59

0.48

0.39

0.33

0.26

0.22

AS

0.0138

0.0217

0.0347

0.049

0.0648

0.0881

0.1138

Throat

8

9

10

11

12

13

14

R

0.68

0.56

0.47

0.38

0.31

0.26

0.21

AS

0.0209

0.0352

0.051

0.0743

0.1

0.132

0.1713

Throat

10

11

12

13

14

15

16

R

0.69

0.55

0.46

0.37

0.31

0.25

0.21

AS

0.0301

0.0534

0.0791

0.1111

0.1504

0.1945

0.2466

Throat

11

12

13

14

15

16

17

R

0.72

0.59

0.48

0.39

0.33

0.27

0.23

1

2

3

0.04

5

6

7

9

10

11

12

8

AS

0.034

0.0597

0.0917

0.131

0.1751

0.2272

0.2895

Throat

13

14

15

16

17

18

19

R

0.71

0.58

0.48

0.4

0.34

0.28

0.23

AS

0.0515

0.0908

0.1349

0.187

0.2493

0.3256

0.4167

Throat

15

16

17

18

19

20

R

0.61

0.51

0.42

0.35

0.29

0.24

AS

0.1016

0.1537

0.216

0.2923

0.3834

0.4928

Throat

16

17

18

19

20

R

0.63

0.52

0.43

0.36

0.3

AS

0.1164

0.1787

0.255

0.3461

0.4555

Throat

17

18

19

20

R

0.66

0.55

0.45

0.38

AS

0.1287

0.205

0.2961

0.4055

Throat

18

19

20

R

0.69

0.57

0.48

AS

0.1396

0.2307

0.3401

Throat

19

20

R

0.71

0.59

AS

0.1576

0.267

J

K

L

M

N

P

Throat

Nozzle

No.

Area

Nom.

Area

1

0.0143

A

0.0055

2

0.0189

A+

0.0075

3

0.0241

B

0.0095

4

0.0314

B+

0.0109

5

0.038

C

0.0123

6

0.0452

C+

0.015

7

0.0531

D

0.0177

8

0.0661

E

0.0241

9

0.0804

F

0.0314

10

0.0962

G

0.0452

11

0.1195

H

0.0661

12

0.1452

I

0.0855

13

0.1772

J

0.1257

14

0.2165

K

0.159

15

0.2606

L

0.1963

16

0.3127

M

0.2463

17

0.375

N

0.3117

18

17

16

15

14

13

18

0.4513

19

0.5424

20

0.6518

P

0.3848

8.0 Surface equipment package for hydraulic pumping applications. It provides complete fluid conditioning as well as a surface pump to provide pressurized power fluid to the down-hole pump. It is designed for continuous operation and will perform satisfactorily when properly set, adjusted and maintained. Periodic inspections and repairs will be required. The end-user of the equipment must determine the intervals of inspections. System Description The fluid and gas Check Valve received from the producing well are fluids from the formation and fluids that have been used to power the down-hole hydraulic pump which have been co-mingled down hole.  Check valve The fluids first enter the package through a check valve normally furnished by the user of the equipment.  Accumulator Surge Vessel The first entrance of fluids into the unit itself will be at the accumulator surge vessel (25) (vertical separator). See the drawing below. The purpose of the accumulator surge vessel (25) is to prevent excess gas from entering the cyclone desander (9) causing cyclone desander inefficiency. The vertical separator also serves as a surge chamber should the vessel be subjected to a high-pressure kick from the well. It prevents the surge from being transmitted to the cyclone desander and the conditioning vessel.  Surge Control Valve The surge control valve (13) is set to open whenever a high-pressure surge is sensed at the valve inlet (i.e. at the accumulation surge vessel). The valve is normally set to open at a differential pressure of 40 psi. It can be adjusted to sense other differentials if required. If too much fluid is being by-passed in front of the cyclone desander (9) with the surge valve (13) set to open at 40 psi differential, the surge valve (13) may be set for a higher differential pressure (up to 45 psi). This will by-pass less fluid through valve (13) and direct more fluid through the cyclone desander (9).

If no fluid or gas is being by-passed with the surge valve (13) is set to open at a differential of 40 psi, the surge valve (13) may be set to open at a lower differential pressure (35 psi minimum) so that gas and some liquid will bypass the cyclone desander. The surge control valve can be converted to a back-pressure regulator by isolating the pressure source to the top of the valve diaphragm and loosening the adjusting screw sealing nut. When a back pressure greater than 60 psi is required, a stronger spring must be installed.  Cyclone Desander The cyclone desander is considered to be the very heart of the 9Unit. Without excellent solids separation, unnecessarily short pump runs and excessive multiplex maintenance will result. The cyclone desander(s) (9) must be sized to effect maximum solid particle separation and furnish essentially clean fluid for the surface power fluid pump (29) and the down-hole hydraulic pump. The solids separated by cyclone desander (9) are discharged downward through the cyclone desander underflow and can be viewed through visual sight glass (22). The clean power fluid passes from the top (overflow) of the cyclone desander (9), through the cyclone desander outlet valve (20) and on into the fluid conditioning vessel (24) for further separation of gas, oil, and water.  Fluid Conditioning Vessel The retention time of the power fluid in the conditioning vessel is not really long enough for any appreciable settling of solids particles from the fluids, so most solids separation must be done by the cyclone desander. This is what makes proper installation, sizing, monitoring and operation of the cyclone desander so important to the entire system operation. Once the hydraulic system is operating, fluid in excess of that required by the surface and subsurface pumps is discharged from fluid conditioning vessel (24) through manual selector valve (3) (high outlet) for oil discharge, or through valve (4) (low outlet) for primarily water discharge. The amount of fluid discharge from conditioning vessel (24) is controlled by the pressure differential between conditioning vessel (24) and flow line pressure. The level of liquids in the conditioning vessel is maintained at a high enough level to supply the multiplex with adequate clean fluid.

 Safety Valves The Unit is equipped with two safety valves. There is a conditioning vessel safety valve (10) and an accumulator safety valve (14). Each valve is set to provide over-pressure protection for the vessels. CAUTIONS Never pipe the safety relief outlets back into the flow line. If a downstream valve is closed or the flow line plugs the whole system will be over pressured, possibly resulting in a ruptured vessel. The safety valves are factory set to meet vessel specifications and are sealed. They are not to be adjusted in the field.  Power Fluid Pump Fluid from the conditioning vessel is supplied to the surface power fluid pump (29) (multiplex pump) which provides pressurized liquid to operate the subsurface hydraulic pump. The power fluid pump is powered by an electric motor, diesel, or gas engine.  Pulsation Dampener A pulsation dampener (32) is installed near the multiplex discharge to dissipate "fluid hammer" in the system which can develop due to the pulsating multiplex output. If the pressure fluctuations from the multiplex are not damped out, the fluid hammer can become severe enough to actually break the wellhead connections. As the pulsating shock waves travel farther from the pump, the reflecting shock wave becomes amplified. These amplified pulsations, if not damped out, will also reflect back into the fluid power pump destroying the pump. For this reason the pulsation dampener must be located as close as possible to the multiplex discharge.  Manual By-pass Valve The power fluid manual by-pass valve (15) regulates the volume of power fluid which is diverted from the down-hole pump and circulated back into the Unit as excess power fluid.

Since the multiplex displacement is greater than the volume required to operate the subsurface hydraulic pump, some fluid must be by-passed. The amount by-passed fluid must be adjustable so that the volume of injected power fluid can be varied to regulate the hydraulic pumping speed.  Control Panel The control panel is a standard oil-field type Murphy panel with indicators and limit controls for safety, start up, operation, and shut down. Component Description  Accumulator Surge Vessel The accumulator surge vessel (25) provides ample storage capacity in the event the well "heads-up" with gas. It separates the gas and cushions abnormally high pressure surges.  Surge Control Valve The surge control valve (13) will open when the valve inlet receives a high surge of pressure. When the volume of fluid processed is great enough to cause a 40 psi pressure loss across the cyclone desander (9) the surge valve (13) will open and excess gas and fluid will be removed from the accumulator surge vessel (25). This results in a fluid level near the vessel top. The valve may also be set for other differential pressures.  Cyclone Desander The cyclone desander (9) cleans the fluid so it can be used in the pumps. The fluid must be cleaned sufficiently to prevent excessive wear to the surface multiplex pump and the sub-surface hydraulic pump.  Fluid Conditioning Vessel The fluid conditioning vessel is a storage container which separates the oil, water and gas. Fluid in excess of that required by the surface and sub-surface pumps is discharged from the vessel through valve (3) for oil discharge or valve (4) for water discharge. When the pre-set fluid level reaches approximately 5 inches from top of the fluid conditioning vessel, the fluid is passed into an over-flow line outside the vessel. The overflow is routed to a pipe leading to the flow line and lease tank battery.

 Vessel Safety Valves The fluid conditioning vessel safety valves (10 & 14) prevent excessive pressure inside each of the vessels.  Throttle Valve The manual throttle valve (21) beneath the cyclone desander underflow will control the fluid flow when properly adjusted. If the underflow fluid is very dirty it tends to plug the opening, therefore the valve must be opened as fully as possible. If too much fluid is lost from the system the valve must be partly closed. Caution must be exercised to prevent complete plugging which will cause the dirty fluid to go into the remainder of the system and contaminate the system.  By-pass Valve Manual by-pass valve (15) allows high-pressure fluid to be bypassed and returned to the low-pressure system. This valve controls the volume of fluid from the multiplex pump to the subsurface hydraulic pump. The manual by-pass valve (flow control valve) is a manually-variable, orificetype valve. The orifice consists of slots formed in a tungsten carbide sleeve with openings controlled by moving an integral carbide plug inside the sleeve to the desired position. The integral plug uncovers or covers the orifice slots allowing a greater or lesser volume of fluid to exit the by-pass valve (15) into the by-pass line. As more power fluid is by-passed, less fluid is injected down hole, slowing the pump strokes on a piston pump and reducing the operating pressure on a jet pump. The flow control valve (15) is a simple device which gives few problems in actual operation. The volume of by-passed fluid will remain very stable as long as there are no great pressure fluctuations in the system.  Safety Valve The safety valve (11) prevents excessive pressure in the power fluid line connected to the well head and protects the pump and motor from excessive overload.  Motor The motor (gas, diesel, or electric powered) provides power to the multiplex pump. Operation and maintenance manuals for the motor are provided by the motor manufacturer.

 Multiplex Pump The surface power fluid multiplex pump (29) provides pressurized fluid to the subsurface hydraulic pump. The pump shaft is properly aligned with the motor shaft and connected through a flexible coupling at the factory. However, it is necessary to check the gap and angular alignment after final installation on the job site.  Control Panel The control panel (12) is a standard oil-field type Murphy indicating and limit control for safe start-up, operation and shut-down. The control panel is mounted off of the unit skid to prevent vibrations from causing control panel malfunctions. The limit controls must be properly set, adjusted and maintained to assure adequate protection of personnel, equipment, and property.

Major Component Identification 1. 2. 3. 4.

Multiplex pump high level suction valve. Multiplex pump low level suction valve. Conditioning vessel high level outlet valve. Conditioning vessel low level outlet valve.

9. 10. 11. 12. 13. 14. 15. 16. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 29. 30. 31. 32.

Cyclone desander. Conditioning vessel safety relief valve. Multiplex pump discharge safety relief valve. Control panel. Well surge control valve. Accumulator surge vessel safety relief valve. Power fluid manual by-pass control valve. Manual valve. Manual valve. Desander inlet manual valve. Desander outlet manual valve. Desander underflow manual valve. Desander underflow visual flow sight glass. Conditioning vessel drain manual valve. Conditioning vessel. Accumulator surge vessel. Accumulator surge vessel pressure gauge. Conditioning vessel pressure gauge. Power fluid pump (multiplex). Electric motor, diesel, or gas engine. Chemical injection pump. Multiplex pump discharge pulsation dampener

9.0 Power oil Tank and Accessories. A typical power oil treating system which has proven adequate for most open power oil systems when "stock tank" quality oil is supplied, is illustrated in Figure below. The following paragraphs cover the functions of important components and recommended piping instructions for the power oil treating system. 9.1 Tank Construction The power oil settling tank in this system is usually a 24-foot high, threering, bolted steel tank. A tank of this height generally will provide adequate head for gravity flow of oil from the tank to the intake of the charge pump. If more than one plunger pump is required for this system, individual power oil tanks can be set for each pump, or a single large tank can be used; whichever is most economical and best meets the operating requirements. Ideal tank size would be large enough to allow for 24 hours settling time. This means that oil entering the tank would arrive at the suction or the multiplex pump 24 hours later.

The tank should be positioned between the heater treater and the stock tanks, so that total lease production comes across the power oil tank, ensuring that the power oil tank is full at all times. There should be two suction connections in the tank, one high and one low. High suction, the cleanest oil in the tank, is for normal operation. Low suction is for emergency. At the time of construction, a bypass line should be installed directly between the treater and the stock tanks by-passing the power oil tank for use in emergencies.

Standard Power Oil Facility Always check sizes and capacities of lease treaters. Over-loaded treaters will not do a thorough job of separating oil from water. This condition will show up in the power oil tank. Also check operation of water dump leg on treaters. These have been known to malfunction dumping everything to the pit, thereby pumping power oil tank dry. 9.2 Gas Boot The gas boot is essentially a part of the power oil tank. The purpose of the boot is to provide final gas-oil separation so that the oil will be stable at atmospheric pressure.

If the gas is not sufficiently separated from the oil, entrained free gas can enter the settling tank and destroy the settling process by causing the fluid in the tank to roll. The following piping specifications for the gas boot are necessary to insure undisturbed settling. o The gas boot inlet height should be 4 feet above the top of the settling tank. This will allow the incoming fluid to fall. The resulting agitation will encourage gas-oil separation. o The top section of the gas boot should be at least 3 feet in diameter and 8 feet higher than the top of the settling tank. These two factors will provide a reservoir that should absorb the surges. o The gas line out of the top of the boot should be tied into the settling tank and stock tank vent line. Should the gas boot become overloaded, thereby kicking fluid over through the gas line, this arrangement will prevent the raw or settled fluid from being dumped in the top of the settling tank. If this occurs, it may contaminate the oil drawn off to the multiplex. o The line connecting the gas boot to the settling tank should be at least 4 inches in diameter. This is necessary to minimize restrictions to flow during surge loadings of the boot. 9.3 Spreader Oil entering a large tank at the bottom and rising to be drawn off the top tends to channel from the tank inlet to the outlet. This is true because the channeling fluid moves more rapidly than the rest of the fluid in the tank which remains relatively undisturbed. The purpose of the spreader is to reduce the velocity of the incoming fluid by distributing the incoming volume over a large area. This allows the fluid to rise upward at a more even rate. The type of spreader recommended consists of a round flat plate, approximately a half of the diameter of the tank. (See Figure 5-4) It should have a 4-inch skirt, which has 60-degree, triangular "saw-tooth" slots cut in it. The slots provide automatic opening adjustment for varying amounts of flow. It is essential that the slots be cut to a uniform depth to obtain an even distribution of flow. This type spreader must be installed with the tops of all the slots in a level plane to prevent fluid from dumping out under a high side. The spreader should be mounted about 2 feet above the bottom rim of the tank.

Although this type spreader is relatively expensive, it will give satisfactory spreading of flow with a minimum of trouble and maintenance. 9.4 Stock Oil Take-off and Level Control The location of the stock tank take-off and level control is important in that it establishes the effective settling interval of the settling tank and controls the fluid level in the power oil tank. All fluid coming from the spreader rises to the stock tanks. Fluid rising above this level is only that amount required to replace the fluid withdrawn by the plunger pump. The stock take-off point should be located within six feet of the spreader. The height to which the stock oil must rise in the piping to overflow into the stock tank determines the fluid level in the settling tank. For this reason, the level control should be placed a minimum of 18 inches from the top of the settling tank. The diameter of piping used should be sufficient to provide negligible resistance for the required volume of flow. The extension at the top of the level control is connected to the gas line to provide a vent which keeps oil in the settling tank from being siphoned down to the level of the top of the stock tank. 9.5 Power Oil Outlets The power oil outlet should be located on the opposite side of the settling tank from the stock take-off outlet to balance the flow distribution within the tank. Since the fluid level in the tank is maintained approximately 18 inches from the top of the tank, the upper outlet should be located 3 feet below the top of the tank. This will ensure the oil level will be above the outlet at all times. The second, or emergency, power oil outlet should be located below the upper outlet for use in starting up or filling tubing strings. The location of this outlet will depend on estimated emergency requirements and the capacity per foot of tank. A distance of 7 feet from the top of the tank is usually sufficient. This lower outlet line contains a shut-off valve which is to be kept closed during normal operations in order that the full settling interval will be used.

10.0

Different Configurations of jet pump completion

Standard Configuration

Reverse Configuration

Offshore Configuration

Example of Lock mandrel assembly

Example of Jet pump with lower seal (Reverse)

Example of SSD Assembly