mud <a href='https://www.ruidapetroleum.com/product/49'>pump</a> with eletric motor free sample

Cameron AC electric motors improve the performance of your mud pumps, drawworks, and rotary tables. Custom configuration is available, and ATEX, ABS, and DNV certification can be provided for new motors. Our flexible design offers you a choice between a tapered shaft or BullShaft to meet specific application requirements.

Cameron AC traction motors are designed and manufactured to handle deep drilling applications. Available in 400-hp, 550/600-hp, 1,150-hp, and 1,500/1,600-hp models, these inverter motors are designed specifically for 460-V to 690-V duty and deliver maximum efficiency. To meet varying installation requirements, our AC motors are available in vertical or horizontal designs.

Unlike conventional traction motors, Cameron AC motors have a unique design that meets the requirements of oil and gas applications. A key characteristic of the motor is the ability to provide a high level of torque at speeds ranging from 0 to 800 rpm (select motors can achieve a maximum speed up to 3,000 rpm). The torque generated at a wide range of speeds can enhance the performance of a broad array of drilling equipment driven by these motors.

mud <a href='https://www.ruidapetroleum.com/product/49'>pump</a> with eletric motor free sample

As a manufacturer of mobile pumps, we see electric motors becoming increasingly popular. They have numerous advantages over internal combustion engines. Minimal maintenance costs, no weekly trips to the construction site to fill the fuel tank, super silent and zero emissions.

BBA Pumps offers a wide range of electric BA centrifugal pumps with priming systems for temporary pumping installations. All the way up to the 8-inch electric powered sewer bypass pumps, you can configure the final version yourself on the basis of the specification sheet. Video BBA Pumps Electrically Driven Mobile Pumps »

Electric PT wellpoint pumps and mobile ATEX certified pumps are fully standardized packages. For the electrically driven high-flow dewatering units and high-head mining pumps we can build customer-specific setups on request.

A mobile electric BBA pump has always enough motor power available for operation up to a frequency of 50 Hz. At a higher frequency the speed and required pump power increase, in such cases we recommend to use a more powerful electric motor in order to prevent overloading.

Electric BA pumps with a soft starter or VFD (variable-frequency drive) are fitted as standard with an automatic level control including two float switches. You can order an additional pressure sensor – transducer – and easily apply it to both motor controllers. With the variable frequency drive, the motor can even run automatically at a higher or lower speed based on a set level point.

The vacuum pump is driven by its own electric motor. Depending on the pumpset version, it can be switched on and off automatically or set to run permanently.

On request, BBA Pumps can enhance the control panel with an option that allows your electric mobile pump to start automatically after a power failure, for example when using an emergency power generator.

BBA Pumps uses international standardised electric motors and switching components for the assembly so that you can rely on worldwide service and support.

Open-frame electric pumps are becoming a rare sight. Sound attenuated pumps in canopies are the new standard. The price difference is small, and the advantages are great: low noise, optimal safety, good protection against the elements and a high trade-in value.

Comprehensive user manuals for the soft starter and the variable frequency drive can be downloaded free of charge via this link https://www.bbapumps.com/en/support.

mud <a href='https://www.ruidapetroleum.com/product/49'>pump</a> with eletric motor free sample

Triplex mud pumps pump drilling mud during well operations. An example of a typical triplex mud pump 10 shown in FIG. 1A has a power assembly 12, a crosshead assembly 14, and a fluid assembly 16. Electric motors (not shown) connect to a pinion shaft 30 that drives the power assembly 12. The crosshead assembly 14 converts the rotational movement of the power assembly 12 into reciprocating movement to actuate internal pistons or plungers of the fluid assembly 16. Being triplex, the pump"s fluid assembly 16 has three internal pistons to pump the mud.

As shown in FIG. 1B, the pump"s power assembly 14 has a crankshaft 20 supported at its ends by double roller bearings 22. Positioned along its intermediate extent, the crankshaft 20 has three eccentric sheaves 24-1 . . . 24-3, and three connecting rods 40 mount onto these sheaves 24 with cylindrical roller bearings 26. These connecting rods 40 connect by extension rods (not shown) and the crosshead assembly (14) to the pistons of the pump"s fluid assembly 16.

In addition to the sheaves, the crankshaft 20 also has a bull gear 28 positioned between the second and third sheaves 24-2 and 24-3. The bull gear 28 interfaces with the pinion shaft (30) and drives the crankshaft 20"s rotation. As shown particularly in FIG. 1C, the pinion shaft 30 also mounts in the power assembly 14 with roller bearings 32 supporting its ends. When electric motors couple to the pinion shaft"s ends 34 and rotate the pinion shaft 30, a pinion gear 38 interfacing with the crankshaft"s bull gear 28 drives the crankshaft (20), thereby operating the pistons of the pump"s fluid assembly 16.

When used to pump mud, the triplex mud pump 10 produces flow that varies by approximately 23%. For example, the pump 10 produces a maximum flow level of about 106% during certain crankshaft angles and produces a minimum flow level of 83% during other crankshaft angles, resulting in a total flow variation of 23% as the pump"s pistons are moved in differing exhaust strokes during the crankshaft"s rotation. Because the total flow varies, the pump 10 tends to produce undesirable pressure changes or “noise” in the pumped mud. In turn, this noise interferes with downhole telemetry and other techniques used during measurement-while-drilling (MWD) and logging-while-drilling (LWD) operations.

In contrast to mud pumps, well-service pumps (WSP) are also used during well operations. A well service pump is used to pump fluid at higher pressures than those used to pump mud. Therefore, the well service pumps are typically used to pump high pressure fluid into a well during frac operations or the like. An example of a well-service pump 50 is shown in FIG. 2. Here, the well service pump 50 is a quintuplex well service pump, although triplex well service pumps are also used. The pump 50 has a power assembly 52, a crosshead assembly 54, and a fluid assembly 56. A gear reducer 53 on one side of the pump 50 connects a drive (not shown) to the power assembly 52 to drive the pump 50.

As shown in FIG. 3, the pump"s power assembly 52 has a crankshaft 60 with five crankpins 62 and an internal main bearing sheave 64. The crankpins 62 are offset from the crankshaft 60"s axis of rotation and convert the rotation of the crankshaft 60 in to a reciprocating motion for operating pistons (not shown) in the pump"s fluid assembly 56. Double roller bearings 66 support the crankshaft 60 at both ends of the power assembly 52, and an internal double roller bearing 68 supports the crankshaft 60 at its main bearing sheave 64. One end 61 of the crankshaft 60 extends outside the power assembly 52 for coupling to the gear reducer (53; FIG. 2) and other drive components.

As shown in FIG. 4A, connecting rods 70 connect from the crankpins 62 to pistons or plungers 80 via the crosshead assembly 54. FIG. 4B shows a typical connection of a connecting rod 70 to a crankpin 62 in the well service pump 50. As shown, a bearing cap 74 fits on one side of the crankpin 62 and couples to the profiled end of the connecting rod 70. To reduce friction, the connection uses a sleeve bearing 76 between the rod 70, bearing cap 74, and crankpin 62. From the crankpin 62, the connecting rod 70 connects to a crosshead 55 using a wrist pin 72 as shown in FIG. 4A. The wrist pin 72 allows the connecting rod 70 to pivot with respect to the crosshead 55, which in turn is connected to the plunger 80.

In use, an electric motor or an internal combustion engine (such as a diesel engine) drives the pump 50 by the gear reducer 53. As the crankshaft 60 turns, the crankpins 62 reciprocate the connecting rods 70. Moved by the rods 70, the crossheads 55 reciprocate inside fixed cylinders. In turn, the plunger 80 coupled to the crosshead 55 also reciprocates between suction and power strokes in the fluid assembly 56. Withdrawal of a plunger 80 during a suction stroke pulls fluid into the assembly 56 through the input valve 82 connected to an inlet hose or pipe (not shown). Subsequently pushed during the power stroke, the plunger 80 then forces the fluid under pressure out through the output valve 84 connected to an outlet hose or pipe (not shown).

In contrast to using a crankshaft for a quintuplex well-service pump that has crankpins 62 as discussed above, another type of quintuplex well-service pump uses eccentric sheaves on a direct drive crankshaft. FIG. 4C is an isolated view of such a crankshaft 90 having eccentric sheaves 92-1 . . . 92-5 for use in a quintuplex well-service pump. External main bearings (not shown) support the crankshaft 90 at its ends 96 in the well-service pumps housing (not shown). To drive the crankshaft 90, one end 91 extends beyond the pumps housing for coupling to drive components, such as a gear box. The crankshaft 90 has five eccentric sheaves 92-1 . . . 92-5 for coupling to connecting rods (not shown) with roller bearings. The crankshaft 90 also has two internal main bearing sheaves 94-1, 94-2 for internal main bearings used to support the crankshaft 90 in the pump"s housing.

In the past, quintuplex well-service pumps used for pumping frac fluid or the like have been substituted for mud pumps during drilling operations to pump mud. Unfortunately, the well-service pump has a shorter service life compared to the conventional triplex mud pumps, making use of the well-service pump as a mud pump less desirable in most situations. In addition, a quintuplex well-service pump produces a great deal of white noise that interferes with MWD and LWD operations, further making the pump"s use to pump mud less desirable in most situations. Furthermore, the well-service pump is configured for direct drive by a motor and gear box directly coupling on one end of the crankshaft. This direct coupling limits what drives can be used with the pump. Moreover, the direct drive to the crankshaft can produce various issues with noise, balance, wear, and other associated problems that make use of the well-service pump to pump mud less desirable.

One might expect to provide a quintuplex mud pump by extending the conventional arrangement of a triplex mud pump (e.g., as shown in FIG. 1B) to include components for two additional pistons or plungers. However, the actual design for a quintuplex mud pump is not as easy as extending the conventional arrangement, especially in light of the requirements for a mud pump"s operation such as service life, noise levels, crankshaft deflection, balance, and other considerations. As a result, acceptable implementation of a quintuplex mud pump has not been achieved in the art during the long history of mud pump design.

What is needed is an efficient mud pump that has a long service life and that produces low levels of white noise during operation so as not to interfere with MWD and LWD operations while pumping mud in a well.

A quintuplex mud pump is a continuous duty, reciprocating plunger/piston pump. The mud pump has a crankshaft supported in the pump by external main bearings and uses internal gearing and a pinion shaft to drive the crankshaft. Five eccentric sheaves and two internal main bearing sheaves are provided on the crankshaft. Each of the main bearing sheaves supports the intermediate extent of crankshaft using bearings. One main bearing sheave is disposed between the second and third eccentric sheaves, while the other main bearing sheave is disposed between the third and fourth eccentric sheaves.

One or more bull gears are also provided on the crankshaft, and the pump"s pinion shaft has one or more pinion gears that interface with the one or more bull gears. If one bull gear is used, the interface between the bull and pinion gears can use herringbone or double helical gearing of opposite hand to avoid axial thrust. If two bull gears are used, the interface between the bull and pinion gears can use helical gearing with each having opposite hand to avoid axial thrust. For example, one of two bull gears can be disposed between the first and second eccentric sheaves, while the second bull gear can be disposed between fourth and fifth eccentric sheaves. These bull gears can have opposite hand. The pump"s internal gearing allows the pump to be driven conventionally and packaged in any standard mud pump packaging arrangement. Electric motors (for example, twin motors made by GE) may be used to drive the pump, although the pump"s rated input horsepower may be a factor used to determine the type of motor.

Connecting rods connect to the eccentric sheaves and use roller bearings. During rotation of the crankshaft, these connecting rods transfer the crankshaft"s rotational movement to reciprocating motion of the pistons or plungers in the pump"s fluid assembly. As such, the quintuplex mud pump uses all roller bearings to support its crankshaft and to transfer crankshaft motion to the connecting rods. In this way, the quintuplex mud pump can reduce the white noise typically produced by conventional triplex mud pumps and well service pumps that can interfere with MWD and LWD operations.

Turning to the drawings, a quintuplex mud pump 100 shown in FIGS. 5 and 6A-6B has a power assembly 110, a crosshead assembly 150, and a fluid assembly 170. Twin drives (e.g., electric motors, etc.) couple to ends of the power assembly"s pinion shaft 130 to drive the pump"s power assembly 110. As shown in FIGS. 6A-6B, internal gearing within the power assembly 110 converts the rotation of the pinion shaft 130 to rotation of a crankshaft 120. The gearing uses pinion gears 138 on the pinion shaft 130 that couple to bull gears 128 on the crankshaft 120 and transfer rotation of the pinion shaft 130 to the crankshaft 120.

For support, the crankshaft 120 has external main bearings 122 supporting its ends and two internal main bearings 127 supporting its intermediate extent in the assembly 110. As best shown in FIG. 6A, rotation of the crankshaft 120 reciprocates five independent connecting rods 140. Each of the connecting rods 140 couples to a crosshead 160 of the crosshead assembly 150. In turn, each of the crossheads 160 converts the connecting rod 40"s movement into a reciprocating movement of an intermediate pony rod 166. As it reciprocates, the pony rod 166 drives a coupled piston or plunger (not shown) in the fluid assembly 170 that pumps mud from an intake manifold 192 to an output manifold 198. Being quintuplex, the mud pump 100 has five such pistons movable in the fluid assembly 170 for pumping the mud.

Five connector rods 140 use roller bearings 126 to fit on the eccentric sheaves 124-1 . . . 124-5. Each of the roller bearings 126 preferably uses cylindrical bearings. The rods 140 extend from the sheaves 124-1 . . . 124-5 (perpendicular to the figure) and couple the motion of the crankshaft 120 to the fluid assembly (170) via crossheads (160) as is discussed in more detail below with reference to FIGS. 10A-10B.

As shown in FIG. 9, the pinion shaft 130 mounts with roller bearings 132 in the power assembly 110 with its free ends 134 extending on both sides of the assembly 110 for coupling to drive components (not shown). As noted previously, the pinion gears 138 on the shaft 130 interface with the bull gears 128 on the crankshaft (120). Preferably, the interface uses helical gearing of opposite hand. In particular, the two pinion gears 138 on the pinion shaft 130 have helical teeth that have an opposite orientation or hand relative to one another. These helical teeth couple in parallel fashion to oppositely oriented helical teeth on the complementary bull gears 128 on the crankshaft 120. (The opposing orientation of helical teeth on the bull gears 128 and pinion gears 138 can best be seen in FIGS. 6A-6B). The helical gearing transfers rotation of the pinion shaft 130 to the crankshaft 120 in a balanced manner. In an alternative embodiment, the pinion shaft 130 can have one pinion gear 138, and the crankshaft 120 can have one bull gear 128. Preferably, these single gears 138/128 use herringbone or double helical gearing of opposite hand to avoid imparting axial thrust to the crankshaft 120.

The cross-section in FIG. 10A shows a crosshead 160 for the quintuplex mud pump. The end of the connecting rod 140 couples by a wrist pin 142 and bearing 144 to a crosshead body 162 that is movable in a crosshead guide 164. A pony rod 166 coupled to the crosshead body 162 extends through a stuffing box gasket 168 on a diaphragm plate 169. An end of this pony rod 166 in turn couples to additional components of the fluid assembly (170) as discussed below.

The cross-section in FIG. 10B shows portion of the fluid assembly 170 for the quintuplex mud pump. An intermediate rod 172 has a clamp 174 that couples to the pony rod (166; FIG. 10A) from the crosshead assembly 160 of FIG. 10A. The opposite end of the rod 172 couples by another clamp to a piston rod 180 having a piston head 182 on its end. Although a piston arrangement is shown, the fluid assembly 170 can use a plunger or any other equivalent arrangement so that the terms piston and plunger can be used interchangeably herein. Moved by the pony rod (166), the piston head 182 moves in a liner 184 communicating with a fluid passage 190. As the piston 182 moves, it pulls mud from a suction manifold 192 through a suction valve 194 into the passage 190 and pushes the mud in the passage 190 to a discharge manifold 198 through a discharge valve 196.

As noted previously, a triplex mud pump produces a total flow variation of about 23%. Because the present mud pump 100 is quintuplex, the pump 100 offers a lower variation in total flow, making the pump 100 better suited for pumping mud and producing less noise that can interfere with MWD and LWD operations. In particular, the quintuplex mud pump 100 can produce a total flow variation as low as about 7%. For example, the quintuplex mud pump 100 can produce a maximum flow level of about 102% during certain crankshaft angles and can produce a minimum flow level of 95% during other crankshaft angles as the pump"s five pistons move in their differing strokes during the crankshaft"s rotation. Being smoother and closer to ideal, the lower total flow variation of 7% produces less pressure changes or “noise” in the pumped mud that can interfere with MWD and LWD operations.

Although a quintuplex mud pump is described above, it will be appreciated that the teachings of the present disclosure can be applied to multiplex mud pumps having at least more than three eccentric sheaves, connecting rods, and fluid assembly pistons. Preferably, the arrangement involves an odd number of these components so such mud pumps may be septuplex, nonuplex, etc. For example, a septuplex mud pump according to the present disclosure may have seven eccentric sheaves, connecting rods, and fluid assembly pistons with at least two bull gears and at least two bearing sheaves on the crankshaft. The bull gears can be arranged between first and second eccentric sheaves and sixth and seventh eccentric sheaves on the crankshaft. The internal main bearings supporting the crankshaft can be positioned between third and fourth eccentric sheaves and the fourth and fifth eccentric sheaves on the crankshaft.

The foregoing description of preferred and other embodiments is not intended to limit or restrict the scope or applicability of the inventive concepts conceived of by the Applicants. In exchange for disclosing the inventive concepts contained herein, the Applicants desire all patent rights afforded by the appended claims. Therefore, it is intended that the appended claims include all modifications and alterations to the full extent that they come within the scope of the following claims or the equivalents thereof.

mud <a href='https://www.ruidapetroleum.com/product/49'>pump</a> with eletric motor free sample

This invention generally relates to the testing and evaluation of underground formations or reservoirs. More particularly, this invention relates to maximizing fluid pumping output capacity in situations where limited electrical power is available downhole and where space is also limited as a result of a need for reduced diameter testing tools.

Wells drilled into the ground to recover deposits of oil, gas or other desirable minerals trapped in geological formations often need to be evaluated as to the presence and particular characteristics of those deposits or as to the characteristics of the formations in which those deposits are found. After the presence of such deposits has been confirmed and a portion has been produced, additional evaluations may be performed to determine the quantity and condition of that portion of the original deposit remaining within the geological formation.

One technique for evaluating deposits and formations is to lower an evaluation tool into the well on a wireline. The purpose of some wireline tools is to measure the pressure characteristics of the formation and to retrieve a fluid sample for later analysis in a laboratory. These wireline tools have come to be known as Wireline Formation Testers or WFT"s. Other methods of conveyance also exist. The term Drill Stem Testing or DST is frequently used when drill pipe or coiled tubing is used to convey the formation test tool into the well. WFT"s and DST"s may employ pumps to withdraw fluids from the formation or to inject fluids into the formation.

WFT"s can be conveyed on a variety of different types of wireline with some standards for wireline sizes and for the number of electrical conductors having developed within the industry. Wireline sizes typically vary from 0.100 inches to 0.520 inches outer diameter, containing between 1 and 7 internal conductors. Normally two layers of external steel armour surround the conductors to provide protection and strength.

Another requirement is for high voltage ratings between the conductors and ground, as well as between the conductors themselves, if a plurality of conductors is desired. This requirement tends to increase the thickness of the insulating material that surrounds the conductors, further decreasing the amount of space available for the conducting material. Finally, the current carrying capacity of wireline increases with the diameter of the conducting material and electrical power is the product of voltage times current.

Conventional wirelines were first developed before the existence of WFT"s and at a time when electronic technology was not in the advanced state it is today. The 7-conductor (heptacable) wireline which has become fairly standard for openhole wireline operations provided early tool designers with a plurality of signal pathways that enabled several measurements to be transmitted to the surface concurrently. Today, the need for multiple signal pathways is reduced or eliminated by the use of telemetry communications between the downhole tools and the surface equipment.

First generation WFT"s did not provide for direct continuous pumping of formation fluids or of borehole fluids. Pressure drawdown measurements were made indirectly using pressurized hydraulic fluid to drive pre-test pistons moving within chambers or test-volumes. Continuous pumping capacity was not a design consideration, so that standard heptacable wireline was adequate for the purpose and hydraulic fluid pumping efficiencies were not of great concern.

While some second generation of WFT"s tools do provide for direct continuous pumping of formation and of borehole fluids, the use of pressurized hydraulic fluid actuation continues. In these newer tools, the pressurized hydraulic fluid is often employed to actuate reciprocating downhole pumps, commonly referred to as mud-pumps, in addition to actuating pre-test pistons within pre-test volumes.

Hydraulic systems are known to be inherently inefficient. The overall efficiency of a hydraulic system can be calculated as the product of the individual efficiencies of all of the system components. These components necessarily include a hydraulic fluid pump with both mechanical and volumetric losses, in addition to piping, valves and other sources of frictional loss that cause heat generation in the hydraulic fluid. These hydraulic losses further diminish an already limited amount of downhole power that can be delivered to the mud-pump.

A second disadvantage of hydraulic actuation is the lack of ability to directly determine the position of the component being actuated. First generation WFT"s employed pre-test designs with fixed volume chambers to address this limitation. Some second generation WFT"s employing hydraulic actuation techniques require complex sensing apparatus to determine pre-test volumes or to control mud-pump through-put volumes. Frequently, this lack of ability to accurately control the volume of fluid being pumped has resulted in tool designs that continue to include pre-test volume capabilities, even though this is approach is functionally redundant in combination with a mud-pump.

A third disadvantage of hydraulically actuated mud-pumps is that the best commercially available axial piston pumps to pressurize hydraulic fluid do not provide adequate output volumes in the small diameter sizes that would be required to manufacture a high mud-pump capacity WFT of a small enough diameter to be suitable for slim boreholes. In this case it is hydraulic fluid output capacity that may become the overall limiting design constraint.

A fourth disadvantage of hydraulically actuated mud-pumps is that inherent design difficulties exist in routing power and communication links through the electric motor and hydraulic pump sub-assembly. While hollow-shafted electric motors are commercially available, hollow bore hydraulic pumps are neither commercially available nor conceptually practical to design. For hydraulically actuated mud-pump designs, this restriction necessitates the routing of power and communication links around the outside of the electric motor and hydraulic pump sub-assembly. This in turn limits the maximum outer diameter of the motor and hydraulic pump sub-assembly, reducing its potential output power, as well as greatly complicating overall assembly and maintenance tasks. While this maximum outer diameter constraint may be mitigated by routing some of the power and communication lines through the motor stator windings rather than around the outside of the motor, such approach introduces additional difficulties due to line cross-talk and transient noise from motor switching, while it further increases assembly and maintenance complexity.

Some of the other limitations of the currently available WFT"s are described in the literature. W097/08424 teaches a method of well testing and intervention that combines wireline with coiled tubing to overcome the fluid injection and discharge limitations of conventional WFT"s. While the method in W097/08424 might be an effective option, it is complex, costly and time consuming due to the need for large amounts of speciality surface equipment.

A second example of a limitation of existing WFT mud-pumps can be found in U.S. Pat. No. 7,395,703, which teaches the use of a complex system of controls to overcome the limitations of pre-tests that are performed in variable test volumes. U.S. Pat. No. 7,395,703 does not indicate how such pre-testing might be done as part of a continuous, rather than a discrete process.

A third example of a limitation of existing WFT mud-pumps can be found in U.S. Pat. No. 6,964,301, which teaches a method of formation sampling that uses two separate flow pathways. The first flow pathway is used to collect the sample while the second flow pathway, concentric around the first flow pathway at the inlet port, acts as a guard to limit the amount of drilling fluid filtrate entering into the first flow pathway. The intent of this arrangement is to minimize contamination of formation fluid samples. While this scheme might be partially effective, such a complex arrangement would not likely be necessary if a mud-pump of sufficient capacity were employed to ensure adequate cleanup of drilling fluid filtrate in the invaded zone prior to collecting the sample.

A recent patent which discloses formation testing while connected to a pipe string, instead of a wireline, is U.S. Pat. No. 7,594,541 (Ciglenec et al) entitled “Pump Control for Formation Testing”.

What is still needed, therefore, are simple downhole pumping techniques which make optimum use of the limited amount of power that can be supplied over wireline cables, while providing higher capacity output with pumping characteristics that are inherently useful for WFT"s and that are designed in ways that make them amenable to deployment in smaller diameter formation test tools.

There is provided a high efficiency fluid pumping apparatus and methods having of an electronic motor controller controlling at least one electric motor that is directly coupled to the input of a hollow helical mechanism. The output of the hollow helical mechanism is directly coupled to the shaft of a reciprocating piston pump. Each moving component of the apparatus is designed with a hollow central bore, so that the apparatus assembly will accept a continuous, stationary, hollow conduit containing electrical through wiring and or fibre optics for power and communication to devices physically positioned below the apparatus. Check valves are provided to allow for pump intake and exhaust strokes and a 4-way valve is provided to permit the sources of the pump intake and exhaust to be reversed.

In some embodiments the invention relates to a wireline formation test tool that includes a high efficiency downhole fluid pump. The wireline formation tester may be of a small diameter such as 3⅜″ outer diameter, or even smaller.

FIG. 3bis a schematic cross-sectional view of the electric motor section 300 of the embodiments of the wireline formation test tools of FIG. 1 and FIG. 2.

FIG. 5ais a schematic cross-sectional view of the reciprocating piston pump section 500 of the embodiments of the wireline formation test tools of FIG. 1 and FIG. 2, shown at the upper limit of the range of its travel.

FIG. 5bis a schematic cross-sectional view of the reciprocating piston pump section 500 of the embodiments of the wireline formation test tools of FIG. 1 and FIG. 2, shown at the lower limit of the range of its travel.

In one or more embodiments, the invention relates to a high efficiency fluid pump that may be used in a downhole tool for formation evaluation or for well stimulation purposes. In some embodiments, the invention relates to methods for using a high efficiency fluid pump. In one or more embodiments, the invention relates to a wireline formation evaluation tool that includes a high efficiency fluid pump. The invention will now be described with reference to FIG. 1 through FIG. 7

FIG. 1 shows one embodiment of the invention that relates to a wireline formation evaluation tool 100 that includes a high efficiency fluid pump. A borehole 101 is shown to have penetrated two impermeable geological formations 102, in addition to a permeable geological formation 103. In order to evaluate the reservoir characteristics of the permeable formation 103, the wireline formation evaluation tool 100 is conveyed into borehole 101, via wireline 110, so that an upper hydraulic isolation packer 160 is positioned above the permeable formation 103 and a lower hydraulic isolation packer 162 is positioned below the permeable formation 103. The spacing between the upper and lower packers may vary. The packers are shown in their activated position, where their sealing elements have been brought into contact with the borehole wall, in order to provide fluid isolation of the interval of the borehole between the packers.

The wireline formation evaluation tool 100 further comprises an electronics section that includes a motor controller 120; an electrical motor section 300 that is more fully described in FIG. 3aand FIG. 3b; a hollow helical mechanism section 400 that is more fully described in FIG. 4aand FIG. 4b; a pump section 500 that is more fully described in FIG. 5aand FIG. 5b; an optional fluid sampling section 130; a fluid property measurement section 140; and an optional well stimulation fluid carrier section 170.

A first internal fluid pathway is connected to a 4-way valve 503 and passes through internal components, devices and valves appropriate to the optional tool configurations being employed. The first internal fluid pathway may be connected to a first external fluid port 161, placing it in fluid communication with the isolated interval of borehole between the isolation packers, or in the alternative it may be connected to an internal chamber in the optional fluid sampling section 130 or to an internal chamber in the optional well stimulation fluid carrier section 170. By changing the 4-way valve setting, the first internal fluid pathway can either be connected to the high efficiency fluid pump intake 501 or it can be connected to the high efficiency fluid pump exhaust 502. A second internal fluid pathway is connected to the 4-way valve 503 and passes through internal tool components, devices and valves appropriate to the optional tool configurations being employed. The second internal fluid pathway may be connected to a second external fluid port 141, placing it in fluid communication with the borehole annulus above upper hydraulic isolation packer 160, or in the alternative it may be connected to an internal chamber in the optional fluid sampling section 130 or to an internal chamber in the optional well stimulation fluid carrier section 170. Construction of the 4-way valve 503 is such that the second internal fluid pathway is connected to either the high efficiency fluid pump intake 501 or to the high efficiency fluid pump exhaust 502, but in a manner opposite to that of the first internal fluid pathway.

FIG. 2 shows an alternative embodiment of the invention that relates to a wireline formation evaluation tool 200 that includes a high efficiency fluid pump. A borehole 101 is shown to have penetrated two impermeable geological formations 102, in addition to a permeable geological formation 103. In order to evaluate the reservoir characteristics of the permeable formation 103, a wireline formation evaluation tool 200 is conveyed into borehole 101, via wireline 110, so that a probe 250 is positioned at a point within the interval of the permeable formation 103.

The probe is shown in its extended position, where the sealing element has been brought into contact with the borehole wall, in order to provide fluid isolation of a small, essentially circular area of the borehole. The probe 250 is held firmly against the wall of the borehole by a backup arm or similar device 252, also shown in the extended position.

The wireline formation evaluation tool 200 further comprises an electronics section that includes a motor controller 120; an electrical motor section 300 that is more fully described in FIG. 3aand FIG. 3b; a hollow helical mechanism section 400 that is more fully described in FIG. 4aand FIG. 4b; a pump section 500 that is more fully described in FIG. 5aand FIG. 5b; an optional fluid sampling section 130; a fluid property measurement section 140; and an optional well stimulation fluid carrier section 170.

A first internal fluid pathway is connected to a 4-way valve 503 and passes through internal components, devices and valves appropriate to the optional tool configurations being employed. The first internal fluid pathway may be connected to a first external fluid port 251, placing it in fluid communication with the isolated interval of borehole at the tip of the probe 250, or in the alternative it may be connected to an internal chamber in the optional fluid sampling section 130 or to an internal chamber in the optional well stimulation fluid carrier section 170. By changing the 4-way valve setting, the first internal fluid pathway can either be connected to the high efficiency fluid pump intake 501 or it can be connected to the high efficiency fluid pump exhaust 502. A second internal fluid pathway is connected to the 4-way valve 503 and passes through internal tool components, devices and valves appropriate to the optional tool configurations being employed. The second internal fluid pathway may be connected to a second external fluid port 141, placing it in fluid communication with the borehole annulus, or in the alternative it may be connected to an internal chamber in the optional fluid sampling section 130 or to an internal chamber in the optional well stimulation fluid carrier section 170. Construction of the 4-way valve 503 is such that the second internal fluid pathway is connected to either the high efficiency fluid pump intake 501 or to the high efficiency fluid pump exhaust 502, but in a manner opposite to that of the first internal fluid pathway.

FIG. 3ais a schematic view of one embodiment of an electrical motor section 300. FIG. 3bis a corresponding schematic cross-sectional view of the same embodiment of an electrical motor section 300. Other embodiments comprising at least one electrical motor are possible. Referring to FIG. 3b, an upper electrical motor 310 is comprised of a hollow motor shaft 312, a permanent magnet rotor 313 and an electrically wound stator 314. Similarly, a lower electrical motor 320 is comprised of a hollow motor shaft 322, a permanent magnet rotor 323 and an electrically wound stator 324. The upper hollow motor shaft 312 is mechanically coupled to the lower hollow motor shaft 322 by a hollow shaft coupler 315. The mechanical output of the electrical motor section 300 is coupled to a hollow helical mechanism section 400 that is more fully described in FIG. 4aand FIG. 4b, via a hollow shaft spider-coupler 330 and a hollow détente-ball torque limiter 340. A hollow tubular conduit 350 is provided for electrical wiring and fibre optic connections of any devices positioned below the electrical motor section 300. Construction of electrical motor section 300 is such that a single rotational position resolver 311 is able to provide rotational position feedback for both the upper electrical motor 310 and the lower electrical motor 320. It will be recognized by those skilled in the art that this control arrangement can be easily extended to control a plurality of motors.

FIG. 4ais a schematic cross-sectional view of an embodiment of a hollow helical mechanism section 400, shown at the upper limit of the range of its travel. FIG. 4bshows the same embodiment of a hollow helical mechanism section 400 at the lower limit of the range of its travel. A hollow helical screw 410 is held in position by roller bearings 411 and by roller thrust bearings 412. A helical nut assembly 413 is prevented from rotating by guide sleeve 414 but is free to travel along the length of the hollow helical screw 410. The internal central bore of the hollow helical mechanism 400 is designed to accept a hollow tubular conduit containing electrical wiring and fibre optic connections for any devices positioned below the hollow helical mechanism section. A hollow sleeve 415 and a hollow coupler 416 move with the helical nut assembly 413, providing a means for connection to the reciprocating piston pump section that is more fully described in FIG. 5aand FIG. 5b.

FIG. 5ais a schematic cross-sectional view of an embodiment of a reciprocating piston pump section 500, shown at the upper limit of the range of its travel. FIG. 5bshows the same embodiment of a reciprocating piston pump section 500, at the lower limit of the range of its travel. Pump body 800 forms a core upon which two intake check valves 523 and two exhaust check valves 513 are mounted. Each intake check valve 523 comprises an intake piston 520, an intake piston seal 521, and an intake return spring 522. Fluid intake is provided via an intake fluid tube 524 and low profile intake elbow 525. Each exhaust check valve 513 comprises an exhaust piston 510, an exhaust piston seal 511, and an exhaust return spring 512. Fluid exhaust is provided via an exhaust fluid tube 514 and low profile exhaust elbow 515. A reciprocating piston shaft 551 is disposed within the bore of a pressure tube 550 and provides a means of mounting for a piston assembly 540 and two opposing piston seals 541. Both ends of the reciprocating piston shaft 551 are constrained to run through seal assemblies 530 and opposing rod seals 531. A hollow tubular conduit 552 is provided for electrical wiring and fibre optic connections of any devices positioned below the reciprocating piston pump section 500.

FIG. 6 shows a method for operating a fluid pumping system 600 in accordance with one embodiment of the invention. The method first includes providing a downhole motor controller 601 with a desired motor torque reference value 602 or alternatively with a range of motor torque reference values. Similarly, the method includes providing the downhole motor controller 601 with a desired motor speed reference 603 or alternatively with a range of motor speed reference values. Utilizing the desired values for motor torque and motor speed, in conjunction with motor rotational position data supplied by the rotational position resolver 311, the motor controller adjusts the characteristics of the power supplied to the electric motor section 300. After taking into consideration the individual efficiencies of the electric motor section 300, the hollow helical mechanism section 400, and the reciprocating piston pump section 500, precise control of desired pumping characteristics can be achieved. This arrangement eliminates any need of additional feed-back control loops such as those based on pump output pressure measurement or based on pump piston displacement measurement. In one embodiment, motor torque is held constant by the motor controller 601, while motor speed is controlled within an acceptable range of values. After including calculated allowances for the efficiencies of all components of the high efficiency assembly 610, this method of fluid pump control has the effect of providing control over pump output pressure within the range of the capacity of the pump, and without the need to measure pump output pressure directly. In a second embodiment, motor speed is held constant by the motor controller 601, while motor torque is controlled within an acceptable range of valves. After including calculated allowances for the efficiencies of all components of the high efficiency assembly 610, this method of fluid pump control has the effect of providing control over pump output rate, within the range of the capacity of the pump, and without the need to measure pump output rate directly. In a third embodiment, the electric motor section 300 is first started and then stopped after a desired time interval has elapsed or alternatively after a desired number of motor shaft revolutions has occurred, while both motor torque and motor speed are controlled within desired ranges of values. This method of pump control has the effect of providing control of discrete pump output volumes, at desired output pressures and at desired pump output rates, within the range of the capacity of the pump.

FIG. 7ais a schematic cross-sectional view of an embodiment of a planetary roller screw 700 with a hollow central bore. Planetary roller screws with solid central cores are commercially available. A plurality of roller screws with helical splines on the outer surfaces 704 thereof are disposed between a nut 701 and a lead screw 705 comprising a helical spline on the outer surface thereof. Gear teeth are provided on each end of the roller screws to mate with two ring gears 702 while circumferential spacing of the plurality of roller screws is maintained by two spacer inserts 703.

FIG. 7bis a schematic cross-sectional view of an embodiment of a recirculating roller screw 710 with a hollow central bore. Recirculating roller screws with solid central cores are commercially available. A plurality of roller screws with circumferential grooves on the outer surfaces 712 thereof are disposed between a nut 711 and a lead screw 715 comprising a helical spline on the outer surface thereof. Engagement between the roller screw circumferential grooves and the lead screw helical spline is made possible through the use of even multiples of multi-start threading for the helical spline. Circumferential spacing of the plurality of roller screws is maintained by a roller cage 713 which is held in position by two retainers 714.

FIG. 7cis a schematic cross-sectional view of an embodiment of a lead screw 720 with a hollow central bore. Lead screws with solid central cores are commercially available. A nut 721 comprising a helical spline on the inner surface thereof is directly engaged with a lead screw 722 comprising a helical spline on the outer surface thereof.

Referring now to FIG. 1 and to FIG. 2, in a first embodiment the high efficiency fluid pump intake 501 is brought into fluid communication with a hydraulically isolated area of the geological formation 103 via external fluid port 161, while the high efficiency fluid pump exhaust 502 is brought into fluid communication with the borehole annulus via external fluid port 141. This first embodiment permits fluid to be extracted from the formation 103 and expelled into the borehole annulus while pressure measurements are recorded. In a second embodiment the high efficiency fluid pump intake 501 is brought into fluid communication with the borehole annulus via external fluid port 141, while the high efficiency fluid pump exhaust 502 is brought into fluid communication with a hydraulically isolated area of a geological formation 103 via external fluid port 161. This second embodiment permits borehole fluid to be injected into the formation 103 while pressure measurements are recorded. In a third embodiment the high efficiency fluid pump intake 501 is brought into fluid communication with a hydraulically isolated area of a geological formation 103 via external fluid port 161, while the high efficiency fluid pump exhaust 502 is brought into fluid communication with a sample chamber disposed in the optional fluid sampling section 130. This third embodiment permits fluid to be extracted from the formation 103 and expelled into the sample chamber while pressure measurements are recorded. In a fourth embodiment the high efficiency fluid pump intake 501 is brought into fluid communication with a cushioning fluid contained in a first isolated volume in a fluid sample chamber disposed in the optional fluid sampling section 130, while the high efficiency fluid pump exhaust 502 is brought into fluid communication with the borehole annulus via external fluid port 141. This fourth embodiment permits the cushioning fluid to be extracted from the first isolated volume in the fluid sample chamber while formation fluid is simultaneously drawn into a second isolated volume in the sample chamber that is separated from the first isolated volume by means of a moveable piston. This arrangement permits the collection of formation fluid samples without the risk such formation fluid samples becoming contaminated through direct contact with internal pump components. In a fifth embodiment the high efficiency fluid pump intake 501 is brought into fluid communication with a stimulation fluid contained in a chamber disposed within the optional well stimulation fluid carrier section 170, while the high efficiency fluid pump exhaust 502 is brought into fluid communication with a hydraulically isolated area of a geological formation 103 via external fluid port 161. This fifth embodiment permits stimulation fluid to be injected into the formation 103 while pressure measurements are recorded. In a sixth embodiment the high efficiency fluid pump intake 501 is brought into fluid communication with the borehole annulus via external fluid port 141, while the high efficiency fluid pump exhaust 502 is brought into fluid communication with a first isolated fluid chamber disposed within the optional well stimulation fluid carrier section 170. This sixth embodiment permits borehole fluid to be expelled into the first isolated fluid chamber, while stimulation fluid contained within a second isolated fluid chamber that is separated from the first isolated volume by means of a moveable piston is simultaneously injected into the hydraulically isolated area of a geological formation 103. This arrangement permits the handling of corrosive stimulation fluids such as acids without such corrosive fluids coming into direct contact with internal pump components.

In all embodiments, the desired pumping parameters are determined and appropriate reference values or ranges of values for motor torque 602 and for motor speed 603 are calculated and transmitted by telemetry link to the downhole motor controller 601. The downhole motor controller 601 may use a commercially available method of motor control such as “Field Oriented Control” or “Flux Vector Control” to regulate both motor torque and motor speed independently. After an acknowledgment that the reference values have been received by the motor controller 601 a command is sent to start the motor section 300. On motor start up, the initial direction for motor rotation is determined by the position of the reciprocating piston assembly 540 in relation to the limits of its travel, and is selected to be the greater of the two available distances. Mechanical power from the output shaft of the motor assembly is transmitted via the spider coupler 330 and the détente ball torque limiter 340 to the lead screw 410 of the hollow helical mechanism 400. The rotating lead screw 410 induces linear motion in the helical nut assembly 413 and consequently transmits this linear motion to the reciprocating piston shaft 551 which is connected to the helical nut assembly 413 by hollow coupler 416. This linear movement of the reciprocating piston shaft 551 causes the piston assembly 540 to move within the bore of the pressure tube 550 resulting in the displacement of fluid. This fluid displacement causes an increase in fluid pressure on one side of the moving piston assembly 540, defeating the exhaust return spring 512 of the exhaust valve 513 located on the higher pressure end of the pump to permit an exhaust of the pressurized fluid. Simultaneously, there is a drop in fluid pressure on the opposite side of the moving piston assembly 540, defeating the intake return spring 522 of the intake valve 523 located on the lower pressure end of the pump to permit an intake of the unpressurized fluid. As a safety precaution against loss of communications, the motor controller 601 will only continue to operate the motor section 300 for a fixed period of time, unless it receives a further command to continue for another fixed period of time. This scheme has the effect of permitting semi-autonomous downhole motor control with a built in failsafe mechanism. Whenever the piston assembly 540 approaches the end of its permitted travel in either direction, the motor controller 601 applies a proprietary algorithm to decelerate motor speed to zero and then to reverse the direction of motor rotation and accelerate once again to the motor reference speed 603 or to the previous speed setting within the permissible range of values. Whenever the direction of travel of the piston assembly 540 changes, both intake check valves 523 and both exhaust check valves 513 change their state, opening or closing as required. As pumping progresses, pertinent data are transmitted from downhole to a surface display that can be viewed by the operator. Adjustments may be made to the motor torque 602 and motor speed 603 reference values by the operator and the new values may be sent downhole to the motor controller 601 in order to fine tune the characteristics of the pumping. At the conclusion of the pumping operation a stop command is sent to the downhole motor controller 601.

The following claims are to be understood to include what is specifically illustrated and described above, what is conceptually equivalent, and what can be obviously substituted. Those skilled in the art will appreciate that various adaptations and modifications of the described embodiments can be configured without departing from the scope of the claims. The illustrated embodiments have been set forth only as examples and should not be taken as limiting the invention. It is to be understood that, within the scope of the following claims, the invention may be practiced other than as specifically illustrated and described.

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The global electric submersible pumps market size stood at USD 9.43 billion in 2018 and is projected to reach USD 14.76 billion by 2026, exhibiting a CAGR of 5.8% during the forecast period.

Increasing demand for hydrocarbon fuel along with rising need to recycle & distill wastewater will boost the electric submersible pumps market size. A rapid upsurge in construction activities coupled with increasing residential & commercial complexes water needs will further enhance the product demand. The electric submersible pump (ESP) works while submerged in water and acts as a centrifugal pump accompanied by an electric motor with different output capacities. It is majorly preferred over other counterparts as it does not rely upon external factors but pumps the fluid to the surface without creating problematic conditions like pump cavitation. Consequently, it is readily installed across the wide range of applications to provide pumping needs in shallow and deep depth wells.

Rapidly expanding oil & gas and mining sectors along with substantially rising water management needs to support various establishments, is anticipated to propel the electric submersible pumps market. Asia Pacific is projected to dominate the market over the forecast period owing to an increasing number of residents in urban areas along with rich agricultural heritage in various countries. Numerous players are also present across the region with significant manufacturing capabilities to deliver complete units or different components incorporated in the units. Additionally, considerably rising oil & gas activities to produce more fossil fuel across China, India, and other Southeast Asian countries is set to support the installation of ESPs.

The design of these units are inclusive of a motor that is hermetically sealed with the body to keep any external fluid out of the system effectively. This layout further ensures the safe operation of pumps with mitigate leakage chances and safeguard no electricity short out. Furthermore, these units do not need priming for initial starting up, thus offer a higher output of pumped water with energy consumption.

Electric submersible pumps are widely installed to function sewage treatment plant to pump fibrous sludge, solid sludge, and gaseous liquids. It is also incorporated at the drainage and irrigation locations to serve water pumping needs. A submersible type of pump is generally placed at little over the bottom of the well and has a thin, long, and cylindrical shape operating at various water heads and flow rates.

On the basis of operation, the electric submersible pump market can be bifurcated into single-stage and multi-stage. Multi-stage operated products are anticipated to hold a major share owing to its diverse application potential, along with high reliability and efficiency. Besides this, the single-stage segment is projected to witness significant growth owing to its cost-effective design to pump under low head conditions for extensive usage in various locations.

Based on the power rating, the market can be segregated into below low, medium, and high. High rated electric submersible pumps are anticipated to observe substantial growth over the forecast timeline. High capacity pumps are readily used to handle heavyweight material and offer high abrasion resistance to efficiently operate in harsh environments like oil & gas and mining applications. The ability to significantly handle contaminated water and deliver efficient sewage and drainage outputs is projected to boost the adoption of medium capacity products. Low capacity pumps are majorly installed in small commercial & residential establishments for the collection of groundwater, removal of wastewater, and many other operations.

On the basis of type, the market can be primarily divided into open well and borewell. Borewell type pumps are anticipated to account for a major share across the forecast timeframe. Continuous water supply for irrigation & agricultural usages along with easy installation in domestic, residential, and industrial establishments are among the main reasons complementing the adoption of these products. Better handling of acidic and sandy water coupled with an air-tight design for enhanced efficiency will further propel the demand. Subsequently, the open well type is projected to witness considerable growth due to easy transportation, compact design, efficient handling, and better cooling characteristics.

Based on end-user, the market can be majorly divided into residential & commercial, water & wastewater, mining, agriculture, oil & gas, chemicals, construction, and others. Water & wastewater segment is likely to account for a major portion due to its high installations to solve sewage problems and pump untreated effluents across the globe. The increasing number of old wells and deployment of secondary & tertiary recovery techniques in these wells to improve the overall production is set to propel the oil & gas sector. Rising need to extract minerals from deep beneath the earth’s surface in order to optimize the manufacturing of different components and products is set to influence the mining segment positively. The construction end-user sector is projected to observe positive growth owing to the frequent adoption of pumps to move extra water from building sites & basements along with pumping slurry to support the construction needs.

Chemicals segment is set to rise at a considerable pace as various units are manufactured with selected raw materials to offers corrosion-resistant operations to pump chemical fluids. The agriculture end-use industry is anticipated to be one of the majorly flourishing divisions across the forecast timeline. Low maintenance requirements, coupled with easy transportation and placement of the units, are supporting the segment growth. High inclination towards the installation of efficient drainage and water pumping among consumers is likely to augment the residential & commercial sector expansion.

Geographically, the electric submersible pumps market has been analyzed across five major regions, which are North America, Europe, Asia Pacific, Latin America, and Middle East & Africa. Asia Pacific is subjected to lead the market due to a rapid shift in the urban population, rich agricultural heritage, and increasing hydrocarbon extraction & mining activities. Additionally, expanding construction expenditure and the presence of various small pumps producing companies will further complement the regional landscape. Key countries that are currently participating in the region are Australia, China, Japan, India, and Southeast Asian nations.

Increasing investments in the oil & gas sectors along with increasing production from existing and new hydrocarbon reserves will foster the North America ESP market size. Additionally, flourishing construction and mining industries, along with the implementation of definite standards to support specific application sectors, is set to supplement the regional outlook further. Major countries actively operating in the region are Canada and the U.S.

Europe"s electric submersible pumps market is projected to unveil substantial growth owing to the ever-increasing requirement of water & wastewater recovery needs. Different types of units are widely installed across the region to irrigate dry lands, extract groundwater, pumping agriculture fields, and to mitigate flood risks. Furthermore, several associations are internationally operating across various countries to improve tools and programs to support the requirements of different fluid system technologies. Key countries actively participating in the expanse are the UK, Russia, Italy, France, and Germany.

Rapid development to improve existing infrastructure along with building new advanced structures with proper water management systems is expected to foster the Middle East & Africa industry size. Besides, high investments to produce more oil & gas coupled with the presence of old wells with reduced formation pressure has proposed high potential for the installation of innovative products. Major countries present in the pumps industry across the region are Gulf Cooperation Council nations and South Africa.

Various companies operating in the market are scattered across different regions having local or global product coverage. Major companies are focused on delivering advanced products with pioneering automation features to improve monitoring and operational characteristics.

In July 2021, Aramco, a Saudi Technologies Company, declared a global commercialization agreement in partnership with AccessESP for the well cleanup service and JumpStart flowback. The JumpStart service uses a tubing electric submersible pump (ESP) system to safely, rapidly, and efficiently clean out gas and oil wells after workover operations or drilling.

In June 2021, Recon Technology, Ltd. declared to secure a couple of contracts through its subsidiary, Beijing BHD Petroleum Technology Limited in China. The company signed contracts worth around USD 0.5 million with a division of China Petroleum & Chemical Corporation (Sinopec) to deliver ultra-deep electric submersible progressing cavity pumps along with other technical services for two gas wells.

In April 2021, Halliburton, one of the leading suppliers of products and services for the energy industry, announced its first electric submersible pump (ESP) contract expected to start in the second half of 2021 in the Middle East. The company plans to invest in the region, as many mature fields come across the natural flow and need ESP systems to sustain production.

In January 2021, Sawafi Borets announced a headquarters and production facility in a 21,000 square meter area in the King Salman Energy Park (SPARK) situated in Saudi Arabia’s Eastern province. The facility is expected to start operation in 2022 and serve as a hub for the testing, service, and manufacturing of the submersible pump systems, with a yearly production capacity of about 500 electrical submersible pumps (ESP).

Electric submersible pump is operated completely underwater and is a category of centrifugal pump manufactured with suitable sealing methods to prevent fluid contact among components. The electrical motor has a firmly attached impeller at the end of its shaft and pump casing coupled to the motor frame. It finds usage in a wide range of applications as it doesn’t need priming for starting operations and helps in preventing the occurrence of pump cavitation. The devices generally operate in the vertical position and are highly efficient over alternatives like jet pumps.

The report provides detailed information regarding various insights i