CA2422348A1 - High torque rotatable progressive cavity drive rods and connectors - Google Patents
High torque rotatable progressive cavity drive rods and connectors Download PDFInfo
- Publication number
- CA2422348A1 CA2422348A1 CA002422348A CA2422348A CA2422348A1 CA 2422348 A1 CA2422348 A1 CA 2422348A1 CA 002422348 A CA002422348 A CA 002422348A CA 2422348 A CA2422348 A CA 2422348A CA 2422348 A1 CA2422348 A1 CA 2422348A1
- Authority
- CA
- Canada
- Prior art keywords
- connectors
- rods
- sucker
- pins
- drive rod
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
Classifications
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04C—ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT PUMPS
- F04C13/00—Adaptations of machines or pumps for special use, e.g. for extremely high pressures
- F04C13/008—Pumps for submersible use, i.e. down-hole pumping
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04C—ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT PUMPS
- F04C15/00—Component parts, details or accessories of machines, pumps or pumping installations, not provided for in groups F04C2/00 - F04C14/00
- F04C15/0057—Driving elements, brakes, couplings, transmission specially adapted for machines or pumps
- F04C15/0061—Means for transmitting movement from the prime mover to driven parts of the pump, e.g. clutches, couplings, transmissions
Landscapes
- Engineering & Computer Science (AREA)
- Mechanical Engineering (AREA)
- General Engineering & Computer Science (AREA)
- Reciprocating Pumps (AREA)
Abstract
A drive rod has pins on each end of its body. Each pin has tapered threading and little or no undercut thereby enhancing its ability to transfer rotational motion through the drive rod string by increasing the surface area through which torque is transferred.
The tapering of the threading on the pins allows for connectors having thicker walls. This means the connectors can withstand higher rotational stress. The drive rods and connectors are especially well suited for use with progressive pumps.
The tapering of the threading on the pins allows for connectors having thicker walls. This means the connectors can withstand higher rotational stress. The drive rods and connectors are especially well suited for use with progressive pumps.
Description
HIGH TORQUE ROTATABLE PROGRESSIVE CAVITY
DRIVE RODS AND CONNECTORS
BACKGROUND OF THE INVENTION
1. Field of the Invention.
The present invention relates to rotatable rods and connectors used with progressive cavity pumps for pumping oil or other fluids out of wells. More specifically, the present invention relates to drive rods having novel pins and connectors specially and uniquely designed for high torque rotation and suited for use with progressive cavity pumps.
DRIVE RODS AND CONNECTORS
BACKGROUND OF THE INVENTION
1. Field of the Invention.
The present invention relates to rotatable rods and connectors used with progressive cavity pumps for pumping oil or other fluids out of wells. More specifically, the present invention relates to drive rods having novel pins and connectors specially and uniquely designed for high torque rotation and suited for use with progressive cavity pumps.
2. Prior Art.
For over 100 years, sucker rods have been utilized to pump crude oil and other liquids out of wells. Sucker rods typically have threaded pins on each end that are screwed into connectors. Connectors attach to a sucker rod on either end. Sucker rods vary in length but typically have standard, common gauged threaded pins manufactured to API
Standard II B
specifications.
A string of sucker rods may extend several thou sand feet into a well. They must, therefore be very strong. Because of this, they are typically made of metal.
In addition, lighter sucker rods are typically included at the bottom of the string while the sucker rods at the top of the string are often heavier and stronger in oraler to support the string. The top of the sucker rod string is attached to a pump jack. The b~ttom of the string is attached to a pump. Pump jacks reciprocate the sucker rod string in ;an upward and downward motion and subjects the string to compression and tension forces. This reciprocating motion operates the pump located at the bottom of the well.
It is highly desirable that sucker rods do not become unscrewed and detach from the connectors between them. If this occurs, the pumping action halts. It is also difTicult and labor intensive to stop the pump jack and retrieve the portion of the sucker rod string in the bottom of the well. In order to prevent this, sucker rc~d pins and connectors have been designed so as not to come unscrewed when a reciprocating mation is applied.
In order to minimize the risk of detachment, sucker rod pins have evolved into a three part structure.
First, at the end of the pin is straight threading. This provides for maximum friction on the flanks ofthe threading. Just below the threading is an undercut, or stress relief. Finally, both the connectors and the sucker rods have shoulders designed to engage one another. The presence of the stress relief allows for greater friction between the engaged shoulders. The friction between the shoulders prevents the sucker rods and connectors from disengaging.
The straight threading increases the ability of the sucker rod string to withstand the stress of the reciprocating motion.
Recent advances in pump technology have made it desirable to utilize progressive cavity (PC) pumps in oil and water wells. PC pumps are well suited for very viscous liquids, such as crude oil and for liquids having solids, such as sand, therein They are also capable of operating under very high pressure. Examples ofthese pumps may be found in U. S. Patent Nos. 1,892,217; 2,085,115 and 2,483,370 issued to Moineau. These PC pumps have fewer moving parts than other pumps typically used in wells. They are both sturdier and less likely 2 o to malfunction. Existing sucker rods are well suiting to withstand the stress of reciprocating tension and compression motion. However, standard sucker rods are not ideal for use with PC pumps. PC pumps require a rotational motion instead of a reciprocating motion.
However, they are not ideally suited to withstand high torque rotation.
It is therefore desirable to provide a drive rod and connector for progressive cavity pumps capable of withstanding high torque rotation.
SLT~~MARY C~F THE INVENTI~I~1 The rods and connectors of the present invention have tapered, rather than straight, threading. In the existing art of sucker rods, tapered threading has generally been discouraged. When reciprocating motion is applied, it is typically easier to jar loose sucker rods having tapered threading. However, because the purpose of these sucker rods is to provide a superior rod string for use in high torque, rotational motion, tapered threading is actually preferred. The constant, high speed rotation ensures that the sucker rods and their connectors remain screwed 3;ogether tightly.
Another reason current sucker rods strings are not suitable for use with 1~C
pumps that require rotation is that the connectors are not well designed for this type of stress.
Though well designed to tolerate the stresses of reciprocating motion, the walls of a connector are generally too thin to withstand high torque. When exposed to high rotational pressure, these connectors will break in half. Because the present invention provides for tapered threading on the pins of the sucker rods, the walls of the connectors are thicker.
Connectors having thicker walls are capable of withstanding greater torsianal stress.
To further facilitate transfer of the rotational motion between sucker rods and connectors, the undercut found on sucker rod pins is eliminated in the present invention. The rotational motion of the string constantly tightens the pin within the connector, thereby reducing sucker rod's danger of disengagement. The need for the increased friction on the shoulders provided by an undercut is therefore eliminated. Furthermore, this additional 2 0 threading provides for a greater surface area over which the rotational motion is transferred.
This further enhances the sucker rod string's ability to withstand high torsional stress. The synergistic effect of tapered threading, thicker connector rods and elimination ofthe undercut provides for rods and connectors having superior tolerance to rotational stress.
In the present invention, the pins of sucker rods are modified so that they may better withstand the stress of high torque in excess of 1.,200 foot pounds.
5 It is therefore an object of the present invention to provide sucker rod strings capable of withstanding the stress of high torque rotation.
BRIEF DESCRIPTION OF THE IJRAWINGS
Figure 1 shows a diagrammatic illustration of a drive rod string and connector being utilized to drive a progressive cavity pump at the bottom o.f a well.
Figure 1 A shows an enlarged portion of the drive rod string of Figure 1.
Figure 2 shows a side plan view of one end of a typical sucker rod currently in use.
Figure 3 is a side plan view of the drive rod of the present invention.
Figure 4 is a cross sectional view of a drive rod connectar of the present invention.
DETAILED DESCRIPTION OF THE DRAWINC~rS
The present invention is an improved drive rod and connector capable of high torque rotation. Three of the key features of the present invention work together synergistically to improve the amount of rotational stress that a drive rod can withstand. These improvements consist of drive rod pins having tapered threading and little or no undercut.
This also results in strengthened connectors having thicker sidewalk. The lack of undercut increases the surface area by which rotational motion may be transferred from a drive rod to a connector to a subsequent drive rod. The present invention is especially useful for driving a progressive cavity pump.
Drive rods are comprised of approximately three components: The first, the body, is a long, usually metal, shaft typically about 40 feet in length. The other two components are the pins located at each end of the shaft. The pins are threaded so that they may be screwed into connectors. One rod is screwed into the bottom of a connector while another is screwed into the top. This is repeated until the rod string is of the dlesired length.
This can sometimes be several thousand feet and require numerous rods.
Recently, pumps known as progressive cavity pumps have been developed for use in pumping oil and other fluids out of wells. These pumps are especially suited for pumping thick viscous liquids such as crude oil. A relatively simple design makes them both sturdy and reliable. This has resulted in a need for a sucker rods better suited for rotational rather than reciprocating tension and compression motion.
2 0 Figure 1 illustrates a typical well having a progressive cavity pump wherein the present invention is employed. Oil well 10 has a PC pump located at the bottom of it. At the top of the well is a powered drive head 12. Drive head 12 is rotated by a motor. This results in rotation of the polished rod 14 which projects downward through stuffing box 16.
Stuffing box 16 creates a water proof seal such that pumped fluids will not exit through the top of stuffing box 16. Directly below the stuffing box is a Ilowline 18.
Pumped oil or other fluid exits the well through this flowline. Below this is a tubing head 19 located directly above casing head 20. Tho;>e skilled in the art of well drilling will be familiar with tubing head 19 and casing head 20 as well as the casing itself 26: The polished rod 14 is connected to the top end of drive rod string 22. Drive rods in the string are held together by connectors 24 as will be described.
Figure l A shows an enlarged view of sucker rod string 22 and a connector 2.4 holding 2 rods 30 and 32 together. For simplicity, this diagram shows use of only 2 sucker rods.
1 o Those skilled in the art will appreciate that in practically a:ll wells, the rod string is comprised of several rods and connectors. The pins of drive rods 30 and 32 are not seen in Figure 1 or Figure 1A. This is because the pins themselves have been screwed into the connector and are not visible.
Figure 2 shows a pin of a typical rod common in the art prior to introduction of the present invention. Sucker rod pin 36 is comprised of a cylindrical threaded portion 38 and an undercut portion 40. Cylindrical threaded portion 38 has a constant diameter and is known in the art as straight threading. Undercut 40 has a diameter slightly less than that of threaded portion 3 8 and extends to shoulder 42. Shoulder 42 has a greater diameter than the other portions of the shaft. It has an engaging portion 44~ that comes in firm contact with a 2 o complimentary shoulder on the connector. The friction created by the contact between engaging portion 44 or shoulder 42 and the shoulder of a connector discourages the unscrewing of a sucker rod from a connector. The presence of an undercut 40 allows threaded portion 3 8 to be screwed into a connector more tightly, thus increasing the static friction created by the shoulders. Without undercut 40; the connector and sucker rod are connected more loosely and are more likely to unscrew. Therefore, the present art teaches away from eliminating undercut 40. Underneath shoulder 42 is a square bolt portion of 46.
This is the portion of the shaft that is engaged by tools that tighten the sucker rods' connections to the connectors. Main body 48 of the sucker rod is substantially cylindrical and extends the length of the sucker rod. An identical pin, not shown, is located on the other end of the sucker rod main shaft 48.
connectors 24 are essentially elongated bolts having a bore and an interior threading complimentary to threaded portions 3 8. The bore has a length that is at least slightly greater than the length of two pins 36. This prevents pins 36 from contacting each other and allows the rods to be screwed into the connectors more tightly.
Figure 3 shows the drive rod of the present invention from a similar angle as the prior art in Figure 2. It shows modified pin 60 having a threaded portion 62. As shown in Figure 3, threaded portion 62 is slightly tapered and frustoconical. In a preferred embodiment, the threaded portion tapers slightly inward at about 3.5 °. In this particular embodiment, there is a very narrow undercut 64. This particular embodiment: shows slight undercut 64 in order to illustrate that it is possible in the present invention to utilize an undercut. It is desirable to have undercut 64 as small as possible. It is however substantially easier to machine a pin having a slight undercut than machining a pin having no undercut at all.
Tapered threading offers a variety of advantages. Threaded tapering offers better balance of strength from the 2 0 connection, easier stabbing during make-up, quicker release on break-out and greater ease of re-working.
In the past, the art has taught away from such tapering because they are easier to pull apart and become disconnected. However, when the sucker rods are rotated, the tapered threading and the pin tightens its engagement to the connector resulting in a very strong connection. Furthermore, tapering causes the pin to be placed in radial and circumferential compression and the socket to be placed in radial compression and circumferential tension.
This radial tension allows rotational movement to be transferred from a rod to a connector to a subsequent rod in a smoother fashion. This increases the amount of torque and rotational stress that the sucker rod string may be subjected to without failure.
In the present invention, rotational motion may be transferred not only by the shoulder, as in traditional sucker rods, but also by the entire pin itself.
This increase in surface area over which torque is transferred reduces overall stress on the pin and drive rod as a whole. Those skilled in the art will appreciate that b~y utilizing the entire pin as well as 1 o the shoulder to transfer rotational movement, overall strain on the drive rod is reduced.
Typical one inch rods cannot withstand more than 1,200 foot pounds of torque.
One inch drive rods according to the present invention, however, may withstand up to 1,500 foot pounds of torque. This provides sturdier, more reliable and faster withdrawal of oil or other fluids from a well.
Figure 4 shows a connector of the present invention suitable for use with a drive rod disclosed in Figure 3. Connector 70 is essentially an elongated bolt having a cylindrical outside wall 72 penetrated by bore 80. Bore 80 has tapered threading complimentary to pin 60 in Figure 3. In this particular embodiment, a slight undercut 76 is included in bore 80 in order to accommodate the slight undercut 64 on pin 60 shown in :Figure 3 , As stated above, 2 o this undercut is unnecessary but the invention may be easier to machine in this fashion. In this particular embodiment, connector 70 is approximately 4 inches long. This is more than long enough to adequately accommodate two pins 60 which are each approximately 1.75 inches long. This allows the threading inside the connector 70 to tighten upon rotation of the sucker rods string. One of the advantages of the design of the present invention is that 11.
connector wall 72 is thicker than those of more traditional connectors without increase of the outside diameter. This allows connector 70 to withstand more torsional stress than a standard connector. The added thickness of wall 72 adds strength to the connector. In addition, the tapered threading allows the connector to transfer a rotational motion through both shoulder 82 and bore 80. As explained above, spreading the transfer of rotational force over a larger surface area allows the connector, like the pin, to withstand more force.
Although these modifications may not appear significant, those skilled in the art will appreciate that the present invention has unique mechanical properties not found in existing sucker rods. Modifications made to the pins and connectors allow at least 25%
more torque to be safely supplied thraugll a rod string. Those skilled in the art will appreciate that this significantly improves the use of progressive cavity pumps.
The present progressive cavity rod will provide greater torque values than existing sucker rod strings as may be observed from the following table:
TYPICAL RECOMMENDED TORQUE VALUES
Atl torque values are in foot pounds Itod Size Grade D (78) Iiigt~ Strength (97) PC Rod 1" 1100 1200 1500' 1 " w 7/8 pin thread 1100 NIA N/A
1-1/8" 1570 1700 2200*
2 0 I- 1/4" 2000 2500 3000*
'Actual torque vatues from test data **Projected torque values - actual tests in process Whereas, the present invention has been described in relation to the drawings attached hereto, it should be understood that other and further modifications, apart from those shown or suggested herein, may be made within the spirit and scope of this invention.
For over 100 years, sucker rods have been utilized to pump crude oil and other liquids out of wells. Sucker rods typically have threaded pins on each end that are screwed into connectors. Connectors attach to a sucker rod on either end. Sucker rods vary in length but typically have standard, common gauged threaded pins manufactured to API
Standard II B
specifications.
A string of sucker rods may extend several thou sand feet into a well. They must, therefore be very strong. Because of this, they are typically made of metal.
In addition, lighter sucker rods are typically included at the bottom of the string while the sucker rods at the top of the string are often heavier and stronger in oraler to support the string. The top of the sucker rod string is attached to a pump jack. The b~ttom of the string is attached to a pump. Pump jacks reciprocate the sucker rod string in ;an upward and downward motion and subjects the string to compression and tension forces. This reciprocating motion operates the pump located at the bottom of the well.
It is highly desirable that sucker rods do not become unscrewed and detach from the connectors between them. If this occurs, the pumping action halts. It is also difTicult and labor intensive to stop the pump jack and retrieve the portion of the sucker rod string in the bottom of the well. In order to prevent this, sucker rc~d pins and connectors have been designed so as not to come unscrewed when a reciprocating mation is applied.
In order to minimize the risk of detachment, sucker rod pins have evolved into a three part structure.
First, at the end of the pin is straight threading. This provides for maximum friction on the flanks ofthe threading. Just below the threading is an undercut, or stress relief. Finally, both the connectors and the sucker rods have shoulders designed to engage one another. The presence of the stress relief allows for greater friction between the engaged shoulders. The friction between the shoulders prevents the sucker rods and connectors from disengaging.
The straight threading increases the ability of the sucker rod string to withstand the stress of the reciprocating motion.
Recent advances in pump technology have made it desirable to utilize progressive cavity (PC) pumps in oil and water wells. PC pumps are well suited for very viscous liquids, such as crude oil and for liquids having solids, such as sand, therein They are also capable of operating under very high pressure. Examples ofthese pumps may be found in U. S. Patent Nos. 1,892,217; 2,085,115 and 2,483,370 issued to Moineau. These PC pumps have fewer moving parts than other pumps typically used in wells. They are both sturdier and less likely 2 o to malfunction. Existing sucker rods are well suiting to withstand the stress of reciprocating tension and compression motion. However, standard sucker rods are not ideal for use with PC pumps. PC pumps require a rotational motion instead of a reciprocating motion.
However, they are not ideally suited to withstand high torque rotation.
It is therefore desirable to provide a drive rod and connector for progressive cavity pumps capable of withstanding high torque rotation.
SLT~~MARY C~F THE INVENTI~I~1 The rods and connectors of the present invention have tapered, rather than straight, threading. In the existing art of sucker rods, tapered threading has generally been discouraged. When reciprocating motion is applied, it is typically easier to jar loose sucker rods having tapered threading. However, because the purpose of these sucker rods is to provide a superior rod string for use in high torque, rotational motion, tapered threading is actually preferred. The constant, high speed rotation ensures that the sucker rods and their connectors remain screwed 3;ogether tightly.
Another reason current sucker rods strings are not suitable for use with 1~C
pumps that require rotation is that the connectors are not well designed for this type of stress.
Though well designed to tolerate the stresses of reciprocating motion, the walls of a connector are generally too thin to withstand high torque. When exposed to high rotational pressure, these connectors will break in half. Because the present invention provides for tapered threading on the pins of the sucker rods, the walls of the connectors are thicker.
Connectors having thicker walls are capable of withstanding greater torsianal stress.
To further facilitate transfer of the rotational motion between sucker rods and connectors, the undercut found on sucker rod pins is eliminated in the present invention. The rotational motion of the string constantly tightens the pin within the connector, thereby reducing sucker rod's danger of disengagement. The need for the increased friction on the shoulders provided by an undercut is therefore eliminated. Furthermore, this additional 2 0 threading provides for a greater surface area over which the rotational motion is transferred.
This further enhances the sucker rod string's ability to withstand high torsional stress. The synergistic effect of tapered threading, thicker connector rods and elimination ofthe undercut provides for rods and connectors having superior tolerance to rotational stress.
In the present invention, the pins of sucker rods are modified so that they may better withstand the stress of high torque in excess of 1.,200 foot pounds.
5 It is therefore an object of the present invention to provide sucker rod strings capable of withstanding the stress of high torque rotation.
BRIEF DESCRIPTION OF THE IJRAWINGS
Figure 1 shows a diagrammatic illustration of a drive rod string and connector being utilized to drive a progressive cavity pump at the bottom o.f a well.
Figure 1 A shows an enlarged portion of the drive rod string of Figure 1.
Figure 2 shows a side plan view of one end of a typical sucker rod currently in use.
Figure 3 is a side plan view of the drive rod of the present invention.
Figure 4 is a cross sectional view of a drive rod connectar of the present invention.
DETAILED DESCRIPTION OF THE DRAWINC~rS
The present invention is an improved drive rod and connector capable of high torque rotation. Three of the key features of the present invention work together synergistically to improve the amount of rotational stress that a drive rod can withstand. These improvements consist of drive rod pins having tapered threading and little or no undercut.
This also results in strengthened connectors having thicker sidewalk. The lack of undercut increases the surface area by which rotational motion may be transferred from a drive rod to a connector to a subsequent drive rod. The present invention is especially useful for driving a progressive cavity pump.
Drive rods are comprised of approximately three components: The first, the body, is a long, usually metal, shaft typically about 40 feet in length. The other two components are the pins located at each end of the shaft. The pins are threaded so that they may be screwed into connectors. One rod is screwed into the bottom of a connector while another is screwed into the top. This is repeated until the rod string is of the dlesired length.
This can sometimes be several thousand feet and require numerous rods.
Recently, pumps known as progressive cavity pumps have been developed for use in pumping oil and other fluids out of wells. These pumps are especially suited for pumping thick viscous liquids such as crude oil. A relatively simple design makes them both sturdy and reliable. This has resulted in a need for a sucker rods better suited for rotational rather than reciprocating tension and compression motion.
2 0 Figure 1 illustrates a typical well having a progressive cavity pump wherein the present invention is employed. Oil well 10 has a PC pump located at the bottom of it. At the top of the well is a powered drive head 12. Drive head 12 is rotated by a motor. This results in rotation of the polished rod 14 which projects downward through stuffing box 16.
Stuffing box 16 creates a water proof seal such that pumped fluids will not exit through the top of stuffing box 16. Directly below the stuffing box is a Ilowline 18.
Pumped oil or other fluid exits the well through this flowline. Below this is a tubing head 19 located directly above casing head 20. Tho;>e skilled in the art of well drilling will be familiar with tubing head 19 and casing head 20 as well as the casing itself 26: The polished rod 14 is connected to the top end of drive rod string 22. Drive rods in the string are held together by connectors 24 as will be described.
Figure l A shows an enlarged view of sucker rod string 22 and a connector 2.4 holding 2 rods 30 and 32 together. For simplicity, this diagram shows use of only 2 sucker rods.
1 o Those skilled in the art will appreciate that in practically a:ll wells, the rod string is comprised of several rods and connectors. The pins of drive rods 30 and 32 are not seen in Figure 1 or Figure 1A. This is because the pins themselves have been screwed into the connector and are not visible.
Figure 2 shows a pin of a typical rod common in the art prior to introduction of the present invention. Sucker rod pin 36 is comprised of a cylindrical threaded portion 38 and an undercut portion 40. Cylindrical threaded portion 38 has a constant diameter and is known in the art as straight threading. Undercut 40 has a diameter slightly less than that of threaded portion 3 8 and extends to shoulder 42. Shoulder 42 has a greater diameter than the other portions of the shaft. It has an engaging portion 44~ that comes in firm contact with a 2 o complimentary shoulder on the connector. The friction created by the contact between engaging portion 44 or shoulder 42 and the shoulder of a connector discourages the unscrewing of a sucker rod from a connector. The presence of an undercut 40 allows threaded portion 3 8 to be screwed into a connector more tightly, thus increasing the static friction created by the shoulders. Without undercut 40; the connector and sucker rod are connected more loosely and are more likely to unscrew. Therefore, the present art teaches away from eliminating undercut 40. Underneath shoulder 42 is a square bolt portion of 46.
This is the portion of the shaft that is engaged by tools that tighten the sucker rods' connections to the connectors. Main body 48 of the sucker rod is substantially cylindrical and extends the length of the sucker rod. An identical pin, not shown, is located on the other end of the sucker rod main shaft 48.
connectors 24 are essentially elongated bolts having a bore and an interior threading complimentary to threaded portions 3 8. The bore has a length that is at least slightly greater than the length of two pins 36. This prevents pins 36 from contacting each other and allows the rods to be screwed into the connectors more tightly.
Figure 3 shows the drive rod of the present invention from a similar angle as the prior art in Figure 2. It shows modified pin 60 having a threaded portion 62. As shown in Figure 3, threaded portion 62 is slightly tapered and frustoconical. In a preferred embodiment, the threaded portion tapers slightly inward at about 3.5 °. In this particular embodiment, there is a very narrow undercut 64. This particular embodiment: shows slight undercut 64 in order to illustrate that it is possible in the present invention to utilize an undercut. It is desirable to have undercut 64 as small as possible. It is however substantially easier to machine a pin having a slight undercut than machining a pin having no undercut at all.
Tapered threading offers a variety of advantages. Threaded tapering offers better balance of strength from the 2 0 connection, easier stabbing during make-up, quicker release on break-out and greater ease of re-working.
In the past, the art has taught away from such tapering because they are easier to pull apart and become disconnected. However, when the sucker rods are rotated, the tapered threading and the pin tightens its engagement to the connector resulting in a very strong connection. Furthermore, tapering causes the pin to be placed in radial and circumferential compression and the socket to be placed in radial compression and circumferential tension.
This radial tension allows rotational movement to be transferred from a rod to a connector to a subsequent rod in a smoother fashion. This increases the amount of torque and rotational stress that the sucker rod string may be subjected to without failure.
In the present invention, rotational motion may be transferred not only by the shoulder, as in traditional sucker rods, but also by the entire pin itself.
This increase in surface area over which torque is transferred reduces overall stress on the pin and drive rod as a whole. Those skilled in the art will appreciate that b~y utilizing the entire pin as well as 1 o the shoulder to transfer rotational movement, overall strain on the drive rod is reduced.
Typical one inch rods cannot withstand more than 1,200 foot pounds of torque.
One inch drive rods according to the present invention, however, may withstand up to 1,500 foot pounds of torque. This provides sturdier, more reliable and faster withdrawal of oil or other fluids from a well.
Figure 4 shows a connector of the present invention suitable for use with a drive rod disclosed in Figure 3. Connector 70 is essentially an elongated bolt having a cylindrical outside wall 72 penetrated by bore 80. Bore 80 has tapered threading complimentary to pin 60 in Figure 3. In this particular embodiment, a slight undercut 76 is included in bore 80 in order to accommodate the slight undercut 64 on pin 60 shown in :Figure 3 , As stated above, 2 o this undercut is unnecessary but the invention may be easier to machine in this fashion. In this particular embodiment, connector 70 is approximately 4 inches long. This is more than long enough to adequately accommodate two pins 60 which are each approximately 1.75 inches long. This allows the threading inside the connector 70 to tighten upon rotation of the sucker rods string. One of the advantages of the design of the present invention is that 11.
connector wall 72 is thicker than those of more traditional connectors without increase of the outside diameter. This allows connector 70 to withstand more torsional stress than a standard connector. The added thickness of wall 72 adds strength to the connector. In addition, the tapered threading allows the connector to transfer a rotational motion through both shoulder 82 and bore 80. As explained above, spreading the transfer of rotational force over a larger surface area allows the connector, like the pin, to withstand more force.
Although these modifications may not appear significant, those skilled in the art will appreciate that the present invention has unique mechanical properties not found in existing sucker rods. Modifications made to the pins and connectors allow at least 25%
more torque to be safely supplied thraugll a rod string. Those skilled in the art will appreciate that this significantly improves the use of progressive cavity pumps.
The present progressive cavity rod will provide greater torque values than existing sucker rod strings as may be observed from the following table:
TYPICAL RECOMMENDED TORQUE VALUES
Atl torque values are in foot pounds Itod Size Grade D (78) Iiigt~ Strength (97) PC Rod 1" 1100 1200 1500' 1 " w 7/8 pin thread 1100 NIA N/A
1-1/8" 1570 1700 2200*
2 0 I- 1/4" 2000 2500 3000*
'Actual torque vatues from test data **Projected torque values - actual tests in process Whereas, the present invention has been described in relation to the drawings attached hereto, it should be understood that other and further modifications, apart from those shown or suggested herein, may be made within the spirit and scope of this invention.
Claims (7)
1. A drive rod comprising an elongated body having a pin on each end of said body wherein each said pin has tapered threading.
2. A drive rod as set forth in Claim 1 wherein said pin is frustoconical.
3. A drive rod of Claim 1 wherein said pins have substantially no undercut.
4. A drive rod string comprising:
a plurality of drive rods connected by a plurality of connectors wherein said connectors attach to the ends of said drive rods by pins having tapered threading.
a plurality of drive rods connected by a plurality of connectors wherein said connectors attach to the ends of said drive rods by pins having tapered threading.
5. A drive rod string of Claim 3 wherein said pins have substantially no undercut.
6. A method of operating a progressive cavity pump comprising:
positioning a progressive cavity pump at the bottom of a well;
attaching a drive rod string having drive rods with tapered threading to said pump; and rotating said drive rod string thereby rotating said pump.
positioning a progressive cavity pump at the bottom of a well;
attaching a drive rod string having drive rods with tapered threading to said pump; and rotating said drive rod string thereby rotating said pump.
7. The method of Claim 6 wherein said rotating of said sucker rod string comprises placing between 1,200 and 1,500 foot pounds of torque to said sucker rod string.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US10/210,221 US20040022657A1 (en) | 2002-08-01 | 2002-08-01 | High torque rotatable progressive cavity drive rods and connectors |
| US10/210,221 | 2002-08-01 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2422348A1 true CA2422348A1 (en) | 2004-02-01 |
Family
ID=31187250
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002422348A Abandoned CA2422348A1 (en) | 2002-08-01 | 2003-03-17 | High torque rotatable progressive cavity drive rods and connectors |
Country Status (2)
| Country | Link |
|---|---|
| US (2) | US20040022657A1 (en) |
| CA (1) | CA2422348A1 (en) |
Families Citing this family (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20090252630A1 (en) * | 2005-08-12 | 2009-10-08 | Heishin Sobi Kabushiki Kaisha | Single-Shaft Eccentric Screw Pump |
| AR058961A1 (en) * | 2006-01-10 | 2008-03-05 | Siderca Sa Ind & Com | CONNECTION FOR PUMPING ROD WITH HIGHER RESISTANCE TO THE AFFECTION OBTAINED BY APPLYING DIAMETER INTERFERENCE TO REDUCE AXIAL INTERFERENCE |
| EP2325435B2 (en) | 2009-11-24 | 2020-09-30 | Tenaris Connections B.V. | Threaded joint sealed to [ultra high] internal and external pressures |
| JP6204496B2 (en) | 2013-01-11 | 2017-09-27 | テナリス・コネクシヨンズ・ベー・ブイ | Go-ring resistant drill pipe tool joint and corresponding drill pipe |
Family Cites Families (24)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US1605316A (en) * | 1925-05-19 | 1926-11-02 | Guiberson Corp | Pump-rod guide |
| US1776611A (en) * | 1927-11-12 | 1930-09-23 | Swan M Akeyson | Rotary underreamer |
| US1889866A (en) * | 1929-06-24 | 1932-12-06 | Gustavus A Montgomery | Tubular coupling |
| US2094491A (en) * | 1934-07-20 | 1937-09-28 | Janata Rudolph | Screw thread joint |
| US2021184A (en) * | 1934-10-22 | 1935-11-19 | Union Oil Co | Drilling structure and bit |
| US2161568A (en) * | 1936-12-24 | 1939-06-06 | Reed Roller Bit Co | Tool joint and method of making same |
| US2206166A (en) * | 1938-01-21 | 1940-07-02 | Nat Tube Co | Pipe or tube joint |
| US2320107A (en) * | 1941-07-14 | 1943-05-25 | Abegg & Reinhold Co | Aligning connection for drill collars |
| US2532632A (en) * | 1948-10-04 | 1950-12-05 | Hydril Corp | Tubing and tubing joint |
| US2745685A (en) * | 1952-02-15 | 1956-05-15 | Drill Collar Service Company I | Resilient drill collar joint |
| US3754609A (en) * | 1970-09-30 | 1973-08-28 | Smith International | Drill string torque transmission sleeve |
| US3933395A (en) * | 1973-12-13 | 1976-01-20 | Reamco, Inc. | Stabilizer |
| US3978933A (en) * | 1975-01-27 | 1976-09-07 | Smith International, Inc. | Bit-adjacent stabilizer and steel |
| US4205926A (en) * | 1977-08-15 | 1980-06-03 | Carlson Drexel T | Sucker rod and coupling therefor |
| US4360320A (en) * | 1980-08-04 | 1982-11-23 | D. W. Zimmerman Mfg., Inc. | Fluid driven successive stage bladder pump |
| US4506432A (en) * | 1983-10-03 | 1985-03-26 | Hughes Tool Company | Method of connecting joints of drill pipe |
| US4592427A (en) * | 1984-06-19 | 1986-06-03 | Hughes Tool Company | Through tubing progressing cavity pump |
| US4619472A (en) * | 1985-05-02 | 1986-10-28 | Nippon Steel Corporation | Pipe coupling |
| US5015017A (en) * | 1987-03-19 | 1991-05-14 | Geary George B | Threaded tubular coupling |
| US4982801A (en) * | 1989-01-04 | 1991-01-08 | Teleco Oilfield Services Inc. | Flexible coupling for downhole motor |
| US5015162A (en) * | 1989-11-28 | 1991-05-14 | Heppner Terry D | Attachment for an oil well screw pump system |
| US5031370A (en) * | 1990-06-11 | 1991-07-16 | Foresight Industries, Inc. | Coupled drive rods for installing ground anchors |
| JP3057857B2 (en) * | 1991-11-08 | 2000-07-04 | 日本鋼管株式会社 | High torque tool joint |
| US6213229B1 (en) * | 1998-10-13 | 2001-04-10 | Smith International Canada Limited | Drilling motor drill bit reaming stabilizer |
-
2002
- 2002-08-01 US US10/210,221 patent/US20040022657A1/en not_active Abandoned
-
2003
- 2003-03-17 CA CA002422348A patent/CA2422348A1/en not_active Abandoned
-
2004
- 2004-01-23 US US10/764,300 patent/US20040151608A1/en not_active Abandoned
Also Published As
| Publication number | Publication date |
|---|---|
| US20040151608A1 (en) | 2004-08-05 |
| US20040022657A1 (en) | 2004-02-05 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| US9127517B2 (en) | Drill pipe connector and method | |
| CA2157072C (en) | Safety coupling for rotary down hole pump | |
| US6834717B2 (en) | Tubing rotator | |
| US5427178A (en) | Tubing rotator and hanger | |
| CA2688801C (en) | Shear coupling assembly for use with rotary and reciprocating pumps | |
| CA2754645C (en) | Sucker rod centralizer | |
| CA2141510C (en) | Tubing string hanging apparatus | |
| US20160376851A1 (en) | Device For The Connection of Rods For A Downhole Pumping Apparatus | |
| US5370179A (en) | Drive head for rotary down hole pump | |
| US10041308B2 (en) | Oilfield tubular connection system and method | |
| US7004730B1 (en) | Integral shaft for use in mud pumps | |
| US20040022657A1 (en) | High torque rotatable progressive cavity drive rods and connectors | |
| US10030453B2 (en) | Device for the connection of rods for rotational drive of a downhole pumping apparatus | |
| US10190371B2 (en) | Sucker rod | |
| US20090065190A1 (en) | Oil well polish rod clamp for use with a rotator on a beam pumping unit | |
| CA2570700A1 (en) | A connector for use in a wellbore | |
| RU2354799C1 (en) | Device for connection of drill pipes | |
| CN114198040B (en) | Recoverable intraductal anchor mechanism of cover | |
| US10214979B2 (en) | Swivel pressure head and method of use | |
| US11066878B1 (en) | Downhole tubular disconnect assemblies | |
| CA3018816A1 (en) | Device for the connection of rods for rotational drive of a downhole pumping apparatus | |
| CN2190693Y (en) | Involutive smooth rod clip | |
| WO2015077408A2 (en) | Systems and methods for making and breaking threaded joints using orbital motions | |
| CN107965274A (en) | Spline slip-type drill string coupling arrangement |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request | ||
| FZDE | Discontinued |