A PUMP WITH A MOTOR FOR PUMPING FLUIDS

Field of the Invention

This invention relates to pumps for pumping fluid, and more particularly but not limited to gas compressors/pumps for use at the wellhead of an oil and/or gas well.

Background of the Invention

The structure in a wellbore of an oil and/or gas well generally consists of an outer production casing and inner production tubing installed inside the production casing. The space between the production tubing and the casing is generally referred to as the annular space.

Oil and/or gas wells generally produce both liquids and gas. The produced liquids are produced through production tubing installed in the wellbore. The production casing can be used to introduce downhole equipment or other fluids into the wellbore. The annular space allows for free gas to be separated from the produced liquids and provides a conduit for the gas to flow to surface.

For wells that produce both liquid and gas, a pump positioned at the bottom of the well pumps the produced liquids to the surface through the production tubing. The pump is typically a liquid pump and any amount of gas that is produced through the pump reduces its efficiency and can damage the pump. Rather than the gas being pumped up through the production tubing, the gas is allowed to flow to the surface through the annular space. If a gas well does not produce liquids (or only small amounts of liquids) , then gas can be produced up the production tubing.

As the free gas accumulates in the annular space, it increases in pressure and can negatively influence the production of the well. To deal with this problem, some oil well wellhead installations have a system for venting or for burning off the gas, which has been produced. However, the venting or the burning of the gas is a waste of this resource and can cause undesirable environmental problems.

A second option is to provide a connection from the annular space to a gas compressor or pump to direct the gas out of the annular space. Know gas compressors are skid mounted units installed in proximity to the wellhead assembly and connected to the wellhead assembly through piping. A problem with known gas compression systems is that they can be bulky. The space available for the wellhead assembly is often limited. The addition of a compressor to a surface assembly will increase the footprint of the well and can result in a surface assembly which is too large for the available space.

Summary of the Invention

According to one broad aspect, the invention provides a pump for pumping fluid comprising: a conduit for carrying fluid, a fluid displacer means positioned externally of the fluid conduit and having a plurality of portions which are arranged to act on fluid at different positions about the fluid conduit, means for introducing fluid to the fluid displacer means to be pumped thereby and means for directing pumped fluid from the fluid displacer.

In some embodiments, the fluid dispenser means comprises an impeller.

In some embodiments, the fluid displacer means is substantially uniformly distributed around the conduit.

In some embodiments, the fluid displacer means comprises at least two meshing screw rotors and the plurality of portions comprises lobes of at least one of the meshing screw rotors .

In some embodiments, the axis of rotation of at least one of the meshing screw rotors is within the conduit.

In some embodiments, an axis of rotation of the impeller is within the conduit.

In some embodiments, the pumped fluid is directed external to the conduit.

In some embodiments, the pump further comprises a motor coupled to the fluid displacer means and positioned externally of the fluid conduit, the motor including a drive member wherein the drive member is positioned to rotate about the fluid conduit.

In some embodiments the motor is directly coupled to the fluid displacer means.

According to another broad aspect, the invention provides a pump for pumping fluid comprising: a conduit for carrying fluid, a fluid displacer means positioned externally of the fluid conduit and having a plurality of portions which are arranged to act on fluid, means for introducing fluid to the fluid displacer means to be pumped thereby, and means for directing pumped fluid from the fluid displacer external to the conduit.

In some embodiments, the means for introducing fluid to the fluid displacer is an internal bore.

In some embodiments, the pump further comprises a sleeve defining at least part of the conduit and separating the conduit from the fluid displacer means.

In some embodiments, the pump is adapted to mate with a wellhead and the central bore comprises a segment of the wellhead internal bore.

In some embodiments, the pump is adapted to mate with a pipeline and the central bore comprises a segment of the pipeline .

In some embodiments, the pump further comprises a second fluid displacer means wherein fluid is directed from the fluid displacer means to the second fluid displacer means.

In some embodiments, portions of the pump comprising the fluid displacer means are modular.

In some embodiments, the pump further comprises a motor wherein the motor is modular.

According to another broad aspect, the invention provides a motor for use with a fluid conduit, the motor including a drive means wherein the drive means is distributed about the fluid conduit.

In some embodiments, the drive means is a rotor.

In some embodiments, the rotor is positioned to rotate about the fluid conduit .

In some embodiments, the conduit comprises a central bore.

In some embodiments, the motor further comprises a sleeve defining at least part of the conduit and separating the conduit from the drive means.

In some embodiments, the motor is adapted to mate with a wellhead and the central bore comprises a segment of the wellhead internal bore.

In some embodiments, the motor is adapted to mate with a pipeline and the central bore comprises a segment of the pipeline .

Brief Description of the Drawings

Preferred embodiments of the invention will now be described with reference to the attached drawings in which:

Figure 1 is a side inlet partial sectional view of an embodiment of the invention;

Figure 2 is a side outlet partial sectional view of the embodiment of Figure 1 ;

Figure 3 is a top outlet cross-sectional view of the embodiment of Figure 1 ;

Figure 4 is a schematic view of the embodiment of Figure 1 shown as part of a wellhead assembly;

Figure 5 is a side inlet partial sectional view of a second embodiment of the invention;

Figure 6 is a schematic view of the embodiment of

Figure 5 shown as part of a wellhead assembly;

Figure 7 is a side partial section view of the a third embodiment of the invention;

Figure 8 is a sectional view of a fourth embodiment of the invention;

Figure 9 is a cross- sectional view taken along the line indicated in Figure 8;

Figure 10 is a cross-sectional view taken along the line indicated in Figure 8 ;

Figure 11 is a cross-sectional view taken along the line indicated in Figure 8 ;

Figure 12 is a cross-sectional view taken along the line indicated in Figure 8;

Figure 13 is a cross-sectional view taken along the line indicated in Figure 8;

Figure 14 is a sectional view of the embodiment of Figure 8 showing the intake ports;

Figure 15 is a sectional view of the embodiment of Figure 8 showing the output ports; and

Figure 16 is a sectional view of a fifth embodiment of the invention.

Detailed Description of the Preferred Embodiments

Figures 1 to 4 show a pump, also known as a gas compressor, a fluid pump or multiphase pump 10, according to the invention.

It will be understood that "fluid" includes gas, liquid, and combinations thereof. "Multiphase" indicates at least two phases, such as liquid and gas.

The pump 10 has a housing with a upper end and a lower end as seen in Figures 1 and 2. A conduit is defined by a through bore 54 through the housing between the upper and the lower ends. The pump includes a fluid displacer, such as an impeller 46 or a pair of compressor screws (see Figures 8 to 16) external to the conduit, a means for introducing fluid to the impeller, in the form of an inlet 56 from the conduit to

the fluid displacer, and a means for directing fluid from the fluid displacer, in the form of an outlet 62 from the impeller. A plurality of portions of the fluid displacer may be arranged around the conduit to act on fluid at different positions about the conduit. The pump may also include a motor coupled to the fluid displacer. The motor may be directly coupled to the pump (i.e. without a transmission) . A rotor or other drive member of the motor may also be positioned around the conduit. Where the drive member is a rotor, it may be positioned to rotate around the conduit. The outlet from the fluid displacer may be independent of the conduit .

More particularly, Figure 1 shows the gas compressor 10 which is comprised of a power section 12 which makes up the upper portion of the gas compressor 10 and a compressor section 14 which makes up the lower portion of the gas compressor 10.

The power section 12 has two housing components, an upper power housing 16 and a lower power housing 18. Similarly, the compressor section 14 has two housing components, an upper compressor housing 20 and a lower compressor housing 22. The power section 12 is made up of the two power housings 16, 18 and the compressor section 14 is made up of the two compressor housings 20, 22 primarily for manufacturing, service and assembly purposes. The housings may alternatively be manufactured in one piece or other numbers of pieces .

The upper power housing 16, the lower power housing

18, the upper compressor housing 20 and the lower compressor housing 22 are vertically aligned. Bolt holes are defined vertically through the upper power housing 16, the lower power housing 18, the upper compressor housing 20 and the lower compressor housing 22 around the perimeter. These bolt holes are aligned so that long studs 26 can extend through the bolt holes of all four housing 16, 18, 20 and 22. Nuts 24 are screwed to the top and the bottom of the long studs 26 to hold

the housings 16, 18, 20 and 22 together. An upper flange 28 is provided at the top of the upper power housing 16. Bolt holes 32 are defined vertically through the upper flange 28 and are spaced around the perimeter of the upper flange 28. Similarly, a lower flange 30 is provided at the bottom of the lower compressor housing 22. Bolt holes 33 are defined vertically through the lower flange 30 around the perimeter of the lower flange 30. Other fastening means for interconnecting the housing components may alternatively be used. Rather than being flanged, the ends of the gas compressor 10 may be threaded or provided with other fastening means.

The through bore 54 extends vertically through the center of the gas compressor 10. Other gas flow path shapes and locations may alternatively be provided. In this embodiment, the through bore 54 is advantageously sized to match the internal diameter of a well casing and the lower compressor housing 22 defines a casing shoulder 58 to accommodate the exterior of the casing when the gas compressor 10 is mounted on a wellhead to mate with the wellhead internal bore.

A sleeve 34 is provided on an interior of the gas compressor 10. The sleeve 34 comprises a hollow tube with an interior dimension sized to be the same as the interior of the well casing. The sleeve 34 sits within a recess defined in the housings 16, 18, 20 and 22. This allows for the through bore 54 to have a uniform diameter through the sleeve 34.

A top seal 52 and a bottom seal 53 are provided adjacent the top and the bottom of the sleeve 34 respectively. The top seal 52 provides a seal between the sleeve 34 and the upper power housing 16. The bottom seal 53 provides a seal between the lower compressor housing 22 and the sleeve 34. The seals 52 and 53 and the sleeve 34 isolate the through bore 54 from the interior of the power section 12 and the compressor

_ Q _

section 14. The seals 52 and 53 may provide a hermedic seal so that the power section 12 and the compressor section 14 are hermedically sealed from the through bore 54. The sleeve advantageously provides isolation of moving parts of the impeller and motor from the annular space and from equipment being run in and out of the well. However, in some embodiments, the sleeve may not be present, may have a different diameter than the bore 54 or may not extend the entire length of the moving parts of the impeller and the motor.

Internal to the power section 12, is a power mandrel 48. The power mandrel 48 is rotatably held within the power section 12. Taper roller bearings 40 are provided at the top and bottom of the power mandrel 48. The taper roller bearings 40 rotatably support the power mandrel 48. The taper roller bearings 40 are surrounded by lubricant to enable smooth rotation of the power mandrel 48.

The power section 12 also includes the motor comprised of the rotor 38 and a stator in the form of field windings 36. The rotor 38 is fastened around the outer circumference of the power mandrel 48. The field windings 36 are fastened to an inner circumference of the upper power housing 16. The field windings 36 and the rotor 38 are vertically aligned. The field windings 36 and the rotor 38 are centered between the taper roller bearings 40 of the power section 12. Seals 42 are provided between the taper roller bearings 40 and the field windings 36 and the rotor 38. The seals 42 prevent the lubricant surrounding the taper roller bearings 40 from entering the area of the field windings 36 and the rotor 38.

External power is provided (not shown) to power the field windings 36 to provide power to the power section 12.

The field windings 36 and the rotor 38 together form a motor for driving the gas compressor 10. The field winds 36 and the rotor 38 together define an energy conversion means for converting electrical energy to mechanical energy. Other motor configurations utilizing other drive means and/or utilizing comparable or different energy conversion means may alternatively be used (i.e. a hydraulic or internal combustion motors) .

A Seal 44 is also provided between the upper power housing 16 and the lower power housing 18. The seal 44 seals the field windings 36 and the rotor 38 from external contaminants .

The compressor section 14 is provided with a compressor mandrel 50. Taper roller bearings 41 are provided at the top and bottom of the compressor mandrel 50 as with the power mandrel 48. The taper roller bearings 41 rotatably support the compressor mandrel 50. The taper roller bearings 41 are surrounded by lubricant to enable smooth rotation of the compressor mandrel 50.

The compressor section 14 is also provided with the impeller 46. The impeller 46 is attached radially outward from the compressor mandrel 50. A circumferential space is defined through the compressor section 14 and the impeller 46 occupies this space. The impeller 46 is comprised of a series of protrusions which, when rotated about a vertical axis of the gas compressor 10, pump the gas through the space.

The impeller 46 is isolated from the lubricant surrounding the taper roller bearings 41 of the compressor section 14 by seals 43. A seal 45 is provided to seal the upper compressor housing 20 and the lower compressor housing 22 from the exterior of the gas compressor 10 to prevent gas leakage. A seal 47 is provided between the lower power housing

18 and the upper compressor housing 20. The seal 47 contains a lubricant and prevents contamination from outside.

The inlet 56 is provided which connects the through bore 54 to the circumferential space occupied by the impeller 46. A first portion of the inlet 56 is angled upwardly to the through bore 54 and a second section of the inlet 56 is vertical. The inlet 56 is generally tubular in shape. The inlet 56 enables direct suction to the impeller 46 without the need for external piping.

A top extension of the compressor mandrel 50 and a lower extension of the power mandrel 48 overlap around the circumference of gas compressor 10. The overlapping extensions of the power mandrel 48 and the compressor mandrel 50 contain mating splines 60 which allow the power mandrel 48 and the compressor mandrel 50 to be slid together and held securely.

The power mandrel 48 and the compressor mandrel 50 are thereby directly coupled without the use of a transmission. Other coupling means may alternatively be used. The compressor mandrel and the power mandrel in the embodiment of figure 1 are coupled axially to rotate about the same rotational axis which extends through the longitudinal axis of bore 54.

Figure 2 shows a partial section of the gas compressor 10 rotated about the vertical axis in relation to the section shown in Figure 1 so that the outlet 62 from the impeller 46 is shown. The outlet 62 is a circular orifice extending outwardly laterally from the impeller 46. The relative positions of the outlet 62, the inlet 56 and the impeller 46 can be seen more clearly in Figure 3.

In operation, the compressor 10 is placed in line at the top of a casing head of a production well. The through bore 54 is aligned with the wellbore and the casing sits in the shoulder 58. The power section 12 and in particular the field

windings 36 power the rotor 38. The rotor 38 rotates about the longitudinal axis of the through bore 54 to rotate the power mandrel 48. The power mandrel 48 is coupled to the compressor mandrel 50 by splines 60. The compressor mandrel 50 rotates at the same speed as the power mandrel 48. The rotation of the compressor mandrel 50 causes the impeller 46 to also rotate. Gas which enters the inlet 56, is pumped by the impeller 46 in the direction A (see Figure 3) around the circumference of the compressor 10 and exits through the outlet 62.

The gas compressor 10 is shown in Figure 4 assembled as part of a wellhead assembly 80. The lower flange 30 of gas compressor 10 is bolted to the upper flange 71 of the casing head 70. At an upper end of the gas compressor 10, the upper flange 28 is bolted to a flange 73 of a tubing head 72. The outlet 62 of the compressor 10 connects to a casing line 76. In the configuration shown in Figure 4, the casing line 76 is connected to the main flow line 74 through a jet pump 99 such that both the production fluid and the casing gas may be pumped together. A variable frequency drive controller 88 provides and regulates the power to the gas compressor 10.

The gas compressor 10 acts as a segment of the wellhead. The production tubing can extend through the gas compressor 10. The gas compressor 10 allows gas to be removed from the annular space without restricting the production casing so that tools can be run in and out of the well and production stimulation fluid can be pumped through the annular space defined by the bore 54 through the gas compressor 10.

Although the embodiment of Figures 1 to 3 is shown and described as vertically oriented, it will be understood that the gas compressor 10 can be oriented at an angle, such as

45° for slant wells, or oriented horizontally.

The configuration shown in Figure 4 shows the compressor 10 as part of the wellhead assembly which allows full bore access to the casing. Figures 5 and 6 show an alternative embodiment of the invention. The reference characters in Figure 5 indicate the same components as the reference characters in Figure 1. A gas compressor 110 of Figure 5 will be described only with respect to how it differs from the gas compressor 10 of Figure 1. The gas compressor 110 of Figure 5 is intended to be positioned in the casing line 90 (see Figure 6) which extends from the annular space rather than being positioned on the casing head. Accordingly, the gas compressor 110 is sized smaller than the compressor 10 of Figure 1. The through bore 154 of the gas compressor 110 has a smaller inside diameter than the through bore 54 of the gas compressor 10. The diameter of the through bore 154 is sized to match the size of the casing line at the wellhead. The top end 128 and the bottom end 130 of the gas compressor 110 (as oriented in Figure 5) are not flanged. Instead, they are internally threaded for mating with the casing line. However, they can alternatively be flanged.

The gas compressor 110 includes an inlet 156. The inlet 156 is not angled in the manner of the inlet 56 of Figure 1. Instead, the inlet 156 first extends perpendicular to the through bore 154 and then extends vertically upward as seen in Figure 5. For manufacturing reasons, the horizontal portion of the inlet 156 is drilled from the exterior of the gas compressor 110 and then the exterior outlet is plugged with a plug 81.

Figure 6 can be contrasted to Figure 4 with regard to the positioning of the gas compressor 110. In Figure 6, the gas compressor 110 is not aligned with the casing head 70. Instead, the gas compressor 110 is positioned in the casing line 90 and connected at ends 130 and 128. The gas compressor

110 is shown as horizontally oriented for illustration. The gas compressor 110 can operate at any angle. The gas outlet of the gas compressor 110 connects to a gas flow line 84. The through bore 154 connects the flow line 82 to the annular space to allow the pumping of production stimulation fluids into the annular space. As with the system of Figure 4, the gas and production fluid can be recombined in the main flow line 86 through the jet pump 99. A check valve 85 provides a control to, for example, allow production stimulation fluids through the flow line 82 but to prevent the fluid in the main flow line 86 from entering the flow line 82.

Figure 6 also shows the variable frequency drive controller 88 which supplies power to the power section of the gas compressors.

Both the first and second embodiments show a compact gas compressor which can be integrated into the wellhead assembly for minimal footprint. The compressor optionally may have the impeller and the rotor rotating about a conduit resulting in a compressor which is substantially uniformly distributed around the conduit. The conduit allows access to the annular space.

As can be seen from the figures, gas compressors 10 and 110 are modular, with separate and distinct power and compressor sections. This enables multiple compressor modules to be powered by a single power section for increased compression. Also, power sections can be interchanged.

Figure 7 shows an embodiment of the invention with two compressor modules . The reference characters in Figure 7 indicate the same components as the reference characters in Figure 1. A gas compressor 210 of Figure 7 will be described only with respect to how it differs from the gas compressor 10 of Figure 1. The gas compressor 210 of Figure 7 includes a

first compressor section 214A and a second compressor section 214B. Each of the first and second compressor sections 214A, 214B has two housing components, upper housing components 220A, 220B and lower housing components 222A, 222B, respectively. The second compressor section 214B has an input 56 (not shown) as depicted in Figure 1. The second compressor section 214B does not have an outlet 62 as shown in Figure 2. The first compressor section 214A has an outlet 62 (not shown) as depicted in Figure 2. However, the first compressor section 214A does not have an inlet 56 as shown in Figure 1. The outlet from the second compressor section 214B is a conduit 256. The conduit 256 is also the inlet to the first compressor section 214A.

The first compressor section 214A includes a first compressor mandrel 250A. The second compressor section 214B includes a second compressor mandrel 250B. The first compressor mandrel 250A is connected to the power mandrel 48 through the splines 60 as described with respect to Figure 1. The first compressor mandrel 250A is connected to the second compressor mandrel 250B by splines 260.

Seals 245 are positioned around the conduit 256 between the first compressor section 214A and the second compressor section 214B to prevent gas leakage from the conduit 256. The conduit 256 extends between the circumferential space defined around the impellers 46 of the compressor sections

214A, 214B. In operation, the power section 12 provides power which rotates the power mandrel 48 and consequently the first compressor mandrel 250A and second compressor mandrel 250B. Gas enters the compressor 210 through the inlet 56 (not shown) . The gas is accelerated by the impeller 46 of the second compressor section 214B and then exits the second compressor section 214B through the conduit 256. Gas enters the first compressor section 214A through the conduit 256 to the

circumferential space and is accelerated by the impellers 46 of the first compressor section 214A and exits the compressor 210 via the outlet 62 (not shown) from the first compressor section 214A. Thus, Figure 7 shows two compressor sections which act on the gas rather than a single compressor section as shown in Figure 1. With minor adaptations additional compressor sections may be added. Since the power section is also modular, the power section may also be replaced.

Figures 8 through 16 show other embodiments of a pump according to the invention. Figure 8 shows a compressor or multiphase pump 310 which comprises five housing sections namely an input housing 302, a screw end-plate housing 304, a compressor screw housing 306, an output housing 308, and flanged housing 312. As with the embodiment of Figure 1, the number of the housing sections is dictated primarily by manufacturing, service and assembly requirement. Other numbers of housings or housings made in several pieces are also contemplated by the invention.

Each of housings 302, 304, 306, 308 and 312 are vertically aligned and bolt holes are defined therethrough around the perimeter. These bolt holes are aligned to enable the insertion of bolts 350 which are screwed into or otherwise fastened into position to hold the housings together.

The outer end of the input housing 302 is fastened to a flanged adapter 324. The flanged adapter 324 and the flanged housing 312 have holes defined therethrough for connection of the pump 310 to other elements of the system.

As with the fluid pumps depicted in Figures 1 to 7, a through bore 354 extends through the centre of the pump 310. A sleeve 322 is fitted within the through bore 354 in a similar manner as the sleeve 34 described with respect to Figure 1.

Internal to the pump 310 are a male screw rotor 314 and two female screw rotors 316. The through bore 354 extends through the male screw rotor 314. The female screw rotors 316 are positioned symmetrically on opposite sides of the male screw rotor 314. Although only two female screw rotors 316 are shown in the embodiment of Figures 8 to 15, it will be appreciated that the pump could function with a plurality of female screw rotors 316. Additionally, it will be appreciated that although the embodiment of Figures 8 to 15 shows the central bore 354 extending through the male screw rotor 314, the central bore could also extend instead through one of the female screw rotors 316.

In the embodiment of Figures 8 to 15, a motor is not depicted. Instead what is shown in Figure 8 is a motor connection spline 356 which is around, and not blocking, the bore 354. Accordingly, in this embodiment, the motor is provided in a separate housing which can be connected to the pump 310. The male screw rotor 314 is fixed to the motor connection spline 356 which drives the rotation of the male screw rotor 314. The female screw rotors 316 are not driven by mating contact with the male screw rotor 314. Instead, the female screw rotors 316 are connected to the male screw rotor 314 by gears 346 and 348. These gears enable rotation of the female screw rotors 316 with the male screw rotor 314 and provide proper timing of the rotation. Retaining nuts 336 and 340 are supplied to properly position and secure the gears 346 and 348 onto the female screw rotors 316 and the male screw rotor 314 respectively. Lock washers 338 and 341 are provided to help secure the retaining nuts 336 and 340 onto the screw rotors 316 and 314 respectively. Bearings 344, 332 and 330 are provided to allow smooth rotation of the male and female screw rotors 314 and 316.

At the top of the rotors 314 and 316, thrust bearings 326 and 328 are provided. The bearings 328 are separated from the gears 346 by bearing spacers 347. The thrust bearings 326 and 328 support the weight of the rotors 314 and 316 and the forces generated by the higher fluid pressure at the top of the rotors 314 and 316.

Figure 9 shows the manner in which the male screw rotor 314 meshes with the female screw rotors 316. The male screw rotor 314 is comprised of lobes 362 and a central shaft 376. Similarly, the female screw rotors 316 are comprised of lobes 360 and a central shaft 372. The female screw rotors 316 rotate within circular chambers 368 and the male screw rotor 314 rotates within a circular chamber 366. The central bore 354 is defined through the male screw rotor 314. The lobes on the male screw rotor 314 and the female screw rotor 316 mate or mesh in rotation as can be seen from the Figure 9, i.e. the lobes 362 fit in the spaces between the lobes 360 and vice versa as they rotate together. The male screw rotor 314 and the female screw rotor 316 can be screw rotors of the type utilized in screw compressors such that the lobes define a screw path spiralling around the shafts 372 and 376 of the female screw rotors 316 and the male screw rotor 314 respectively. The co-operation of such meshing screw rotors to act together as a pump will be appreciated by one skilled in the art of screw compressors.

Figure 10 depicts the inlet chambers 364 at the inlet to the pumping chamber defined by the cooperation of the lobes 362 of the male screw rotor 314 and the lobes 360 of the female screw rotor 316.

Figure 11 shows a view downward which shows the openings of inlet orifices 374 into the inlet chambers 364.

Also visible are the shafts 372 and 376 of the screw rotors 314 and 316 without the lobes.

Figure 12 is a section through the input housing 302 which shows input conduits 380 which lead from the central bore 354 to the inlet orifices 374 which lead to the input chamber 364 and thus into the pump 310.

Finally, Figure 13 is a section at the outlet of the pump which shows a portion of an outlet chamber 382.

Figures 14 and 15 show the inlet port 380 and outlet port 382 respectively, in a vertical section. The reference numbers on Figures 14 and 15 are otherwise the same as those in Figure 13. The section of Figure 15 is not through the longitudinal axis of the bore 354. Thus the bore 354 appears of smaller diameter than in Figures 8 to 14. In fact, the bore of the embodiment of Figures 8 to 15 is circular.

Various seals 355 and face seals 352 are positioned throughout the pump to maintain fluid tight connections and allow hermetic sealing of the pump.

In operation, the motor functions to rotate the male screw rotor 314. The rotation of the male screw rotor 314 is translated through the gears 346 and 348 to the female screw rotors 316 such that the screw rotors 314 and 316 rotate in cooperation. Fluid, i.e., gas, liquid or multiphase fluid, which flows through the central bore 354 enters the inlet port 380 then travels through the inlet chamber 364 into the chambers defined by the meshing screw rotors 314 and 316. The fluid is thereby moved upward through these chambers around bore 354 and pumped out through the outlet port 382.

Figure 16 depicts a further embodiment of the invention. The only difference between this embodiment and the

embodiment of Figures 8 to 15 is that only one female screw rotor 316 is present. Otherwise, the connections and operation of the pump 410 is the same as described with respect to Figures 8 to 15.

The screw rotors of Figures 8 through 16 are intended to be dry screw rotors meaning that the rotors are not intended to physically contact each other and there is no lubricant in between the screw rotors . Other types of screw rotors and other numbers and assembly other than those shown are also contemplated by the invention. It is also contemplated that the central bore 354 be subdivided to pass through each of the rotors .

The pumps depicted in Figures 8 through 16 are comparable to the pump depicted in Figures 5 and 6 such that the central bore is sized for a pipeline. The embodiment of Figures 7 through 16 can also be sized for a wellbore.

The pumps 310 and 410 of Figures 8 to 16 are applicable to use with multiphase fluids which contain both liquid and gaseous elements.

Although the embodiments have been described with respect to use at a gas and/or oil wellhead, it will be appreciated that the pump is applicable to numerous other applications. For example, the pump could be used for the production of gas from a coal seam.

From the depiction of Figures 8 to 16 it will be appreciated that the motor can comprise a complete sub-assembly which can be connected to the pump by use of a flange or screw or other form of connection.

The motor may be utilized in other applications other than for the purpose of powering a pump.

The motor shown in the embodiments is an electric motor. However, other powering systems, including hydraulic or internal combustion systems may alternatively be used.

The fluid displacers shown are impellers and meshing screw rotors; however, alternative pumping systems may also be used such as short stroke piston type compressors.

The orientation of the inlet and the positioning of various seals are options not essential to invention.

Other types of bearings may be used throughout the pump .

The fluid pumps of the present invention can have the full pressure rating of the wellhead which is an important safety feature.

The various seals allow the pumps to be hermetically sealed from inside and outside, for use, for example, in subsea applications .

The drive member of the motor may comprise a drive shaft such as a crank shaft of an internal combustion engine or a power mandrel .

Numerous modifications and variations of the present invention are possible in light of the above teachings. It is therefore to be understood that within the scope of the appended claims, the invention may be practiced otherwise than as specifically described herein.