Pumping equipment comprising an electric submersible pump (ESP) along with gas and sand separation accessories when the well has no space for shrouds or capsules, and mechanical pumping equipment comprising a sucker rod pump (SRP)

Abstract

Pumping equipment comprising an electric submersible pump (ESP) or an electric submersible progressing cavity pump (ESPCP) along with accessories for separating gas and sand when the well has no space for shrouds or capsules, wherein said pumping equipment further comprises the following accessories, from bottom to top, a sensor (2A), one or more three-phase electric motors in tandem (2B), a power cable (5) that delivers electrical energy to the one or more motors by means of a three-phase electrical connection (2C), one or more seals (2D), an intake (7) that admits already degassed fluid from a tubing of one or more tubes (6) of different geometry that are directed to the lower or upper portion of the pumping equipment with ESP or ESPCP, wherein these accessories have to be placed above or below the pumping equipment with the ESP or ESPCP depending on the location of the perforations (3). Mechanical pumping equipment with a sucker rod pump (SRP) (16) comprising one or more bypass tubes (6) and an inverted shroud (13) placed on the upper portion of said pump.

Description

[0001] PUMPING EQUIPMENT COMPRISING AN ELECTRIC SUBMERSIBLE PUMP (ESP) ALONG WITH GAS AND SAND SEPARATION ACCESSORIES WHEN THE WELL HAS NO SPACE FOR SHROUDS OR CAPSULES, AND MECHANICAL PUMPING EQUIPMENT COMPRISING A SUCKER ROD PUMP (SRP)

[0002] SPECIFICATION

[0003] Field of the Invention

[0004] The present invention belongs to the oil industry technological field. In particular, it is related to oil well extraction wherein the extraction is performed with electric submersible pumping (ESP) equipment, and the well diameters are small. Particularly, the present invention allows for extending the pump intake to areas that facilitate the addition of desanders such as cyclone filters or screens, or gas separators such as inverted shrouds or gas anchors. More particularly, the present invention allows for increasing the service life and efficiency of the extraction systems.

[0005] Background of the Invention

[0006] There are oil wells where it is necessary to move hydrocarbons for extraction in an efficient manner. Depending on their production status, they may be flowing wells or they may require artificial lift equipment, such as a pumping system comprising an electric submersible pump (ESP), an electric submersible progressive cavity pump (ESPCP), and a sucker rod pump (SRP) for extracting / pumping fluid from a producing well.

[0007] These systems must be installed at great depths, from 1 ,000 to 4,000 meters depending on the requirements, within a small-diameter casing.Since the fluid to be extracted comes directly from a formation, it may contain water, oil, and other elements that affect the efficiency of the system, such as gas and sand from the formation or fracture. The latter present a challenge in small spaces because it is not easy to place an efficient filtration device to prevent sand from entering the pump impellers and ultimately eroding or wearing down their internal parts, which leads to system failure. Placing a gas separation system is not easy either. This can be mitigated with a rotary gas separator in the case of an ESP pumping system, but it has a limit on the amount of free gas.

[0008] In unconventional wells, the intermittent gas pocket coming from the formation can be prolonged, causing the pump to become completely blocked by the gas and preventing the pumping thereof. This can lead to lack of lubrication in the pump stages, lack of cooling of the down-hole motor, and consequently, the occurrence of failures.

[0009] For the removal of large amounts of gas from oil wells, US Patent 9,631 ,472B2 discloses the use of capsules that enclose an entire electric submersible pump (ESP), ensuring a single entry point from the top portion. In some cases, from the bottom portion via a deep tube, the gas-laden fluid will rise outside the capsule and make a 180-degree turn at the top portion. This turn causes the free gas to continue its upward path and enter only through the capsule, ensuring that the ESP is submerged only in liquid, i.e., water and oil (see Figure 1 of US Patent 9,631 ,472B2).

[0010] Another additional way implies that the lower portion of the capsule be of a minor section and coupled to an inverted shroud at the bottom (see Figure 3 of US9,631 ,472B2) which naturally separates the gas that may occur in pockets. Otherwise, the capsule may simply have a long deep tube extending from the topto the bottom of the well, wherein gas separation also occurs due to the smaller diameter thereof (see Figure 4 of US9,631 ,472B2).

[0011] The main drawbacks of this configuration are the following:

[0012] 1. Placing the ESP inside a capsule significantly increases the diameter of the assembly in its entirety, making it impossible to install in small-diameter wells in many cases. In order to overcome this, very small-diameter pumping equipment may be required, and consequently, under these conditions, the ESP lacks the power and thrust necessary to lift the hydrocarbons to the surface.

[0013] 2. Placing an ESP inside a capsule, where the fluid in most cases enters from the top, requires the ESP to recirculate part of its output to the lower part of the motor for cooling. This is because the liquid to be extracted, which is the cooling source, enters from the higher part via the intake of the pump, bypassing the motor. This results in system inefficiency, as some hydraulic power is wasted in this recirculation process. Besides, it is not possible to easily determine how much fluid is being recirculated. The recirculated fluid may stay permanently recirculating in the zone without fresh fluid entering, which causes an indefinite temperature increase of said fluid. Consequently, the motor temperature rises, leading to failures due to the lack of fresh fluid in the cooling loop.

[0014] 3. For sand removal, it does not imply any accessories that allow for effective sand filtration, such as screens or other effective elements like cyclone filters.

[0015] Patent Application US2018291721 A1 refers to a well pump assembly consisting of a housing with an inlet element. A barrel has a head attached to and extending downward from the inlet element. A plunger is reciprocally housed in the orifice of the barrel. An intake conduit extends coaxially from the intakeelement and the barrel head to the barrel orifice, above the plunger. An intake port extends from the outside of the intake element into the intake conduit. A nozzle is attached to the intake conduit. The nozzle has an orifice with a downward-converging section that extends to a constant-diameter section. This constant-diameter section has a smaller diameter than the intake conduit.

[0016] 1. The pump assembly described above only works with a certain amount of free gas, as the gas separators cannot operate without liquid and separate a certain amount of free gas. More free gas causes the separator to block, malfunction, and potentially be damaged due to lack of lubrication given the absence of liquid.

[0017] 2. The solution is located at a short distance from the gas separator and it does not extend beyond the seal or the pump, including their respective inlet and outlet extension tubes.

[0018] On the other hand, US patent 12,152,474B2 discloses an electric submersible pump (ESP) assembly. The ESP assembly comprises an electric motor; a seal section coupled to an uphole end of the electric motor; a fluid inlet coupled to an uphole end of the seal section, wherein the fluid inlet defines a plurality of inlet ports; a gas separator coupled to an uphole end of the fluid inlet, wherein the gas separator has a plurality of gas-phase discharge ports; and a pump assembly coupled to an uphole end of the gas separator; and an inlet extension tube, wherein an uphole end of the inlet extension tube is coupled to the fluid inlet of the inlet ports, and wherein an annulus defined between the inside of the inlet extension tube and the outside of the seal section defines a fluid flow path from the downhole end of the inlet extension tube to the inlet ports of the fluid inlet.1. This patent proposes physically separating both the inlet and outlet, preventing gas recirculation in a gas separator. These devices have a fluid intake and an outlet where the gas is centrifugally removed before entering the pump. If the gas exiting the annulus is near the main intake, it will re-enter the system, causing inefficiencies. This simple system prevents the recirculation of separated gas and is only applicable when the ESP already has a gas separator in the structure thereof. In fact, it only improves upon this component.

[0019] 2. So, it would be as if the system were working with a greater amount of free gas as a result of this recirculation. In order to improve this, a twisted path is added to this separated gas recirculation, extending the main inlet orifices downwards with a shroud or a series of pipes, and extending the separated gas outlet, located at the upper portion of the gas separator, with another shroud or pipes. Neither extension exits above or below the entire ESP system; rather, the extension is short. The main inlet extends no lower than the seal before the motor, and the separated gas outlet can be extended only slightly beyond the pump.

[0020] Therefore, it is desirable to have ESP, ESPCP, or SRP-type pumping systems wherein sand and gas separation is efficient, the pumping system can operate without liquid for extended periods of time due to high gas content in pockets or slugs, the system allows handling a much larger amount of gas, that is, handling larger gas pockets for longer periods, the pumping system is efficient regardless it has a gas separator or not, i.e., with a normal intake, and the pumping system can work even with a greater amount of free gas resulting from eventual recirculation that occurs when the gas exiting through the upper orifices, due to turbulence, descends to the main production liquid inlet orifices.

[0021] Summary of the InventionAn object of the present invention is a pumping equipment comprising an electric submersible pump (ESP) or an electric progressive cavity submersible pump (ESPCP), as shown in Figures 2a and 3a, along with gas and sand separation accessories when the well has no space for shrouds or capsules, wherein said pumping equipment further comprises the following accessories: from bottom to top, a sensor 2A, one or more three-phase electric motors in tandem 2B, a power cable 5 that delivers electrical energy to the one or more motors by means of a three-phase electrical connection 2C, of the MLC-type (Motor Lead Cable), MLE-type (Motor Lead Extension) or an extension, one or more seals 2D, an intake 7 that admits already degassed fluid coming from a tubing of one or more tubes 6 of different geometry that are directed to the upper or lower section of the ESP equipment 2, wherein these accessories have to be located above or below the ESP equipment 2 depending on the location of the perforations 3.

[0022] Another object of the present invention is a mechanical pumping equipment with a sucker rod pump (SRP), comprising one or more bypass tubes 6 and an inverted shroud 13, such that the fluid coming from the perforations will rise to the inverted shroud 13 wherein the gas will continue its upward course, filtering both the gas and the sand at the inlet of said inverted shroud 13, and the mechanical pump with sucker rod pump (SRP) 16 receives only liquid from the intake 8 and from the lateral bypass tubes 6, which in turn receive the filtered liquid from the upper inverted shroud module 13.

[0023] Brief Description of the Drawings

[0024] Figure 1a shows a traditional electric submersible pump-type extraction and pumping system when the production perforations are below the same.Traditionally, there should not be a large amount of gas or sand here. If a small amount of gas is present, it can be separated using a vortex or rotary separator.

[0025] Figure 1b shows a traditional electric submersible pump-type extraction and pumping system when the production perforations are above the same. In this case, it is necessary to place cooling jackets to ensure the fluid is forced through the motor, cooling it to facilitate production. This model endures a greater volume of gas because gas separates naturally as it exits the upper perforations. However, it offers no solution for the presence of sand. The sand traps are difficult to hang from the jackets.

[0026] Figure 1c shows a cross-section view looking upward of Figure 1b at the seal level, illustrating the spaces between the ESP equipment and the cooling jacket, and between said jacket and the well casing. The direction of fluid flow in the well is also shown, with the "x" markings indicating outflow and the dots "." indicating inflow.

[0027] Figure 2a shows a proposed configuration for production below the perforations in confined wellbore spaces by extending the main intake to the base of the motor or sensor. This is achieved using lateral bypass tubes instead of jackets. This results in a more robust system and extends the fluid intake only to the lower portion.

[0028] Figure 2b shows an alternative to the previous Figure 2a, by placing an extension pipe to the lower intake, in which a gas anchor or inverted shroud is placed to remove gas and sand in case there are also perforations at the lower portion.

[0029] Figure 2c shows an alternative to that shown in Figure 2a, wherein the sand problem is resolved by adding a cyclone filter and tailpipe.Figure 2d shows a cross-section view looking upward of Figure 2a at the seal level, illustrating the spaces between the ESP equipment and the well casing. Also, where the bypass tubes and power cable could potentially be located. Finally, the direction of fluid flow in the well is also shown, with the "x" markings indicating outflow and the dots "." indicating inflow.

[0030] Figure 3a shows a configuration that proposes placing an inverted shroudtype gas separator on top of the ESP, thus making better use of the space in the well and achieving effective natural gas separation. In this case, the perforations are located on the lower portion of the ESP equipment.

[0031] Figure 3b shows an alternative to the configuration in Figure 3a, wherein several hydraulically connected gas separators are placed in series.

[0032] Figure 3c shows an alternative wherein the inverted shroud and the production tubing are not concentric but parallel, side by side.

[0033] Figure 3d shows a cross-section view looking downward of Figure 3a at the midpoint of the liquid reservoir inverted shroud, illustrating the spaces between the production tubing and the shroud, and between the latter and the well casing. Also, where the bypass tubes and power cable could potentially be located. Finally, the direction of fluid flow in the well is also shown, with the "x" markings indicating outflow and the dots "." indicating inflow.

[0034] Figure 3e shows a cross-section view looking downward of Figure 3c at the midpoint of the liquid reservoir inverted shroud, illustrating the spaces between the production tubing and the shroud, and between the latter and the well casing. Also, where the bypass tubes and power cable could potentially be located. Finally, the direction of fluid flow in the well is also shown, with the "x" markings indicating outflow and the dots "." indicating inflow.Figure 4a shows an alternative using a mechanical pumping system with a sucker rod pump (SRP) wherein gas and sand separation is carried out by means of one or more inverted shrouds placed at the top.

[0035] Figure 4b shows a cross-section view looking downward of Figure 4a at the midpoint of the liquid reservoir inverted shroud, illustrating the spaces between the production tubing and the shroud, and between the latter and the well casing. Also, where the bypass tubes and pump rods could potentially be located. Finally, the direction of fluid flow in the well is also shown, with the "x" markings indicating outflow and the dots "." indicating inflow.

[0036] Detailed Description of the Invention

[0037] With the purpose of overcoming the drawbacks of the prior art, the object of the present invention is proposed which consists of two main variants that are identified as follows: whether the production comes from production perforations 3 in the lower portion where the ESP equipment is installed (Figure 3a) or in the upper portion with the same system (Figure 2a). Traditionally, if there are no serious gas or sand issues, the respective configurations are those shown in Figure 1a and Figure 1b.

[0038] It is possible to use these systems in combination if there are perforations both above and below, although it is necessary to know the flow rates of both to ensure adequate motor cooling.

[0039] In the case where the production perforations 3 are located at the upper portion of the ESP equipment 2, as shown in Figure 2a, the production flow will descend from these perforations, passing outside the pump 2F, seals 2D, motors 2B, and downhole sensor 2A. Finally, it will make a turn below the intake 8. This special intake is connected to the pump inlet 2F via the fitting 7, called the intake,and the communication is through one or more bypass tubes 6. These tubes can be round or of various shapes as long as they fit inside the well.

[0040] Once the fluid is inside the pump 2F, it raises the fluid pressure sufficiently for it to exit through the pump discharge portion 2G, allowing it to reach the surface via the production tubing 4.

[0041] It should be noted that, unlike the configuration in Figure 1b, in this way the fresh fluid in Figure 2a always flows downwards, passing through the seals and then through the hottest point of the motor, which is the top, ensuring more effective cooling.

[0042] The advantage of having the intake 8 at the lower portion of the motor, below sensor 2A, is that accessories can be easily coupled to further aid in gas and sand separation, as detailed below.

[0043] The architecture in Figure 2b allows for a configuration with perforations also located below the ESP equipment 2. Therefore, an extension pipe can be coupled to a bottom inverted shroud 13b. This shroud can have a filter screen 12 at the upper portion to filter sand. In this particular case, if the production from the lower perforation or opening 3 comes with a significant amount of gas and sand, it will necessarily enter the inverted shroud 13b. During this inlet turn, a natural separation will occur, wherein inside the shroud 13b, there will only be liquid and no gas, as the gas continues its upward path. Inside the shroud, there will be another turn to enter the extension tube that connects to the intake 8, from where the product will be extracted to the surface. If any sand passes through the screen 12 inside the inverted shroud 13b, it will be deposited in the tailpipe 9 by segregation, preventing it from entering the ESP equipment. The sand gets trapped in said pipe and retained by the plug 10.Another option, in case there is a large amount of sand, as shown in Figure 2c, is to use a cyclone filter 11, which separates the sand grains centrifugally, sending them to the tailpipe 9. The sand gets retained within this pipe because it has a bottom plug 10 that prevents it from falling to the bottom of the well. The production fluid entering the cyclone desander, now free of sand, will rise to the intake 8 and be extracted through the ESP to the surface. In the case shown in Figure 2c, it is assumed that the gas separated naturally as soon as it exited the upper perforations or openings 3.

[0044] If the perforations 3 are located at the lower portion of the ESP equipment 2, as shown in Figure 3a, the produced fluid containing the gas will rise, passing outside the motor 2B, the seals 2D, and the pump 2J, continuing to rise until it reaches the inverted shroud 13. Upon reaching the top of this shroud, the produced fluid makes a 180° turn to enter the same. At this point, the gas separates naturally and continues its upward path. Meanwhile, the liquid passes through the desander screen 12 and descends to the base of the inverted shroud internally. It should be noted that this inverted shroud has a production pipe 4 in the center, connecting the discharge portion of pump 2G to the surface. On its downward path, the liquid enters the bypass tube 6, which directs it to the intake 7, which only allows liquid coming from said tube 6. Once inside pump 2J, the liquid is pressurized and, under high pressure, passes through the interior of discharge portion 2G and into the production pipe 4 to the surface, passing before through crossover 13c.

[0045] Both the production tubing 4 and the volume within the inverted shroud 13 are isolated. The former is a high-pressure circuit, and the latter is a relatively low-pressure circuit.It is to be noted that tubing 6 enters a space 14 within the inverted shroud 13 so as to create a potential reservoir for sand or fines that were not fully filtered by the screen 12.

[0046] The length of the inverted shroud 13 will depend on the desired volume of accumulated liquid to ensure that pump 2J always has liquid available in the event of a large gas pocket.

[0047] In the case of Figure 3a, the inverted shroud 13 can be a seamless or welded tube made of various types of steel or some other material resistant to the well conditions. It can also consist of a production tubing with a larger diameter than that indicated in Figure 4, such that they can be arranged concentrically and the assembly does not occupy a large diameter, which is the purpose of this invention. At the base of the inverted shroud 13 is crossover 13c, which connects the discharge portion 2G to the inner production tubing 4, and supports the inverted shroud 13, and additionally connects the bypass tube 6.

[0048] One alternative is to use a plurality of inverted shrouds, as shown in Figure 3b, wherein a plurality of inverted shroud modules 13, or chambers, can be installed and hydraulically connected. Each shroud can admit fluid at the upper portion through the filter or screen 12, but it can also be fed via the upper chamber using a section of the bypass tube 6 that has been previously degassed in said upper chamber.

[0049] Another alternative that can maintain the space reduction is the use of a double production tubing, side by side, as shown in Figure 3c. One of the tubing sections 13 acts as an inverted shroud, receiving the production liquid and separating the gas as it enters at the top, filtering out the sand through the screen or filter 12. At the lower portion of the module, we have the one or more bypasstubes 6, which connect to the receiving port or intake 7. The other similar tube, parallel to 13, corresponds to the production tubing 4. In this case, both tubes are not concentric, but parallel. The production tubing 4 transports the pressurized liquid fluid through pump 2J to the surface. The separation module has adapter crossovers 13c at both ends to support both tubes and create the routing and coupling paths: on the upper side to the production tubing string 4 that reaches the surface, and on the lower side to the pump discharge portion and tubing 6. The power cable 5 can run alongside one of these tubes or between them.

[0050] Another alternative, detailed in Figure 4a, involves using mechanical pumping equipment with a sucker rod pump (SRP). This system requires a series of coupled rods 15 located inside the production tubing 4. These rods alternately move an up-and-down plunger 20, which operates within a barrel 17 of a downhole pump 16. Inside this pump are a series of valves: a traveling valve 19 in the plunger 20 and a standing valve 18 in the barrel 17, which generate suction and then pump the fluid to the surface through the production tubing 4. In this case, much like the previous ones, the oil and gas production fluid flows from the lower perforations 3, rises to the inverted shroud or gas anchor 13, wherein the gas continues its upward flow, undergoing natural separation. The liquid makes a 180-degree turn, entering shroud 13, and the sand is filtered through screen 12. Inside the shroud, only liquid will be present. This travels through the bypass tube 6 to the intake 7 located below the pump 16. In this way, only liquid enters the system. If any sand enters the shroud 13, there is an accumulation reservoir 14, as described in the previous systems. This configuration is useful when there is no space at the rat hole to place gas anchors and it is convenient to place them above the SRP pump.References in the figures

[0051] 1- Well casing

[0052] 2- Electric submersible pumping equipment (ESP) or progressive cavity electric submersible pumping equipment (ESPCP)

[0053] 2A- Motor base or bottom sensor

[0054] 2B- Motor

[0055] 2C- Three-phase electrical connection, of the MLC-type (Motor Lead Cable), MLE-type (Motor Lead Extension), or an extension.

[0056] 2D- Seal

[0057] 2E- Intake

[0058] 2F- Multistage centrifugal pump or progressing cavity pump (PCP, Progressing Cavity Pump)

[0059] 2G- Pump discharge

[0060] 2H- Cooling jacket

[0061] 2I- Gas separator selected from: centrifugal gas separator, rotary gas separator and vortex gas separator

[0062] 2J- Separator gas outlet

[0063] 3- Production perforations

[0064] 4- Production tubing

[0065] 5- Three-phase power cable

[0066] 6- Bypass tube

[0067] 7- Receiving port (Intake)

[0068] 8- Admission port (Intake)

[0069] 9- Tailpipe or sand reservoir

[0070] 10- Tailpipe plug- Desander (cyclone filter)

[0071] - Sand screen or filter

[0072] - Inverted shroud or tube for liquid storage (or gas anchor) b- Inverted shroud or tube for lower liquid storage

[0073] c- Crossover

[0074] d- External casing of inverted shroud or tube

[0075] - Sand reservoir inside the inverted shroud or tube

[0076] - Rods

[0077] - Sucker rod pump (SRP)

[0078] - Barrel

[0079] - Standing Valve

[0080] - Traveling Valve

[0081] - Plunger

Claims

CLAIMS1. Pumping equipment comprising an electric submersible pump (ESP) along with gas and sand separation accessories when the well has no space for shrouds or capsules, wherein said pumping equipment further comprises the following accessories, from bottom to top, a sensor, one or more three-phase electric motors in tandem, a power cable that delivers electrical energy to the one or more motors by means of a three-phase electrical connection, one or more seals, an intake that admits already degassed fluid from a tubing of one or more tubes of different geometry that are directed to the lower or upper portion of the ESP equipment, wherein these accessories have to be placed above or below the pumping equipment with the ESP depending on the location of the perforations.

2. The pumping equipment of claim 1 , wherein the three-phase electrical connection is of the MLC-type (Motor Lead Cable), MLE-type (Motor Lead Extension), or an extension.

3. The pumping equipment of claim 1 or 2, wherein the intake feeds the base of an optional gas separator and the multistage centrifugal pump imparts the pressure necessary for the fluid to rise to the surface, passing through the discharge portion and the production tubing.

4. The pumping equipment of claim 3, wherein the gas separator is selected from a centrifugal gas separator, a rotary gas separator and a vortex gas separator.

5. The pumping equipment of claim 1, wherein the pump may be a progressing cavity pump (PCP) in the case of a pumping system with an electric submersible progressing cavity pump (ESPCP).

6. The pumping equipment of claim 1, wherein the intake is located between the seal and the base of the pump, which has an inlet on only one side and is fed by one or more bypass tubes.

7. The pumping equipment of claim 6, wherein the tubes are of different shapes and sizes, and as many are arranged as fit in the well.

8. The pumping equipment of claim 6 or 7, wherein the bypass tubes are directed to the lower or upper portion of the pumping equipment with the ESP, extending the fluid intake to be produced to both ends of the pumping equipment with the ESP.

9. The pumping equipment of claim 1, wherein, when the bypass tubes are directed downwards, a lower intake is included, normally coupled to the base of the motor or sensor, such as from this intake a series of tubes are coupled that aredirected to the lower portion of the well generating a deep tube that helps to separate gas if there are perforations below the ESP equipment.

10. The pumping equipment of claim 9, wherein the tubing end comprises an inverted shroud for separating gas and, optionally, a sand filter and a tailpipe for accumulating sand.

11. The pumping equipment of claim 10, wherein the tailpipe has a plug to prevent sand from falling to the bottom of the well.

12. The pumping equipment of claim 10, wherein, alternatively, a sand cyclone separator is arranged with the tailpipe for accumulating sand, the sand cyclone separator being hung from the lower intake.

13. The pumping equipment of claim 1, wherein, when the bypass tubes are directed upwards, said bypass tubes are connected to the base of an inverted shroud located at the upper portion of the pump discharge portion by means of the crossover, the inverted shroud having a length that guarantees the volume of liquid produced during a prolonged time of gas pockets.

14. The pumping equipment of claim 13, wherein the bypass tubes penetrate the inverted shroud, creating a sand chamber or reservoir for the sand not retained by the sand filter.1815. The pumping equipment of claim 13 or 14, wherein the production tubing passes concentrically or laterally through the inverted shroud.

16. The pumping equipment of claim 13, wherein the production fluid enters only through the upper portion of the inverted shroud, wherein the liquid makes a 180° turn and the gas continues its upward path.

17. The pumping equipment of claim 10 or 14, comprising a plurality of inverted shroud separation modules connected to each other, wherein each separation module has its inlet from the well at the upper portion with a sand filter, and wherein the separation of natural gas proceeds by reversing the rotation, having a feed of pure liquid without gas from the upper separation chamber.

18. The pumping equipment of claim 17, wherein the modules are in hydraulic series with several inlets in parallel and several gas and sand separations.

19. Mechanical pumping equipment with a sucker rod pump (SRP), comprising one or more bypass tubes, wherein the intake is located at the base of the pump, which has an inlet from only one side and is fed by one or more bypass tubes, wherein the bypass tubes are of different shapes and sizes, and as many are installed as fit in the well, wherein the bypass tubes are directed towards the upper portion of the pumping equipment with the ESP, extending the inlet of fluid to be19produced, and an inverted shroud located at the upper portion of the pump discharge portion by means of a crossover, the inverted shroud having a length that guarantees the volume of liquid produced during a prolonged period of gas pockets, such that the fluid from the perforations will rise to the inverted shroud where the gas will continue its upward course, filtering both the gas and sand at the inlet of said inverted shroud, and the mechanical or sucker rod pump (SRP) receives liquid only from the intake and from the lateral bypass tubes, which in turn receive the filtered liquid from the upper inverted shroud module.

20. The mechanical pumping equipment of claim 19, comprising a plurality of inverted shroud modules located on the upper portion of the mechanical pump with sucker rod pump (SRP).20

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