CA2458495A1 - Improved packer with integrated sensors - Google Patents
Improved packer with integrated sensors Download PDFInfo
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- CA2458495A1 CA2458495A1 CA002458495A CA2458495A CA2458495A1 CA 2458495 A1 CA2458495 A1 CA 2458495A1 CA 002458495 A CA002458495 A CA 002458495A CA 2458495 A CA2458495 A CA 2458495A CA 2458495 A1 CA2458495 A1 CA 2458495A1
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- packer
- sensor
- borehole
- string
- transducer
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- 239000012530 fluid Substances 0.000 claims description 16
- 238000000034 method Methods 0.000 claims description 12
- 238000002604 ultrasonography Methods 0.000 claims description 5
- 239000000835 fiber Substances 0.000 claims description 4
- 239000010453 quartz Substances 0.000 claims description 2
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N silicon dioxide Inorganic materials O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 2
- 229930195733 hydrocarbon Natural products 0.000 claims 1
- 150000002430 hydrocarbons Chemical class 0.000 claims 1
- 230000015572 biosynthetic process Effects 0.000 description 3
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 2
- 238000006073 displacement reaction Methods 0.000 description 2
- 238000005553 drilling Methods 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 229920001875 Ebonite Polymers 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 230000004913 activation Effects 0.000 description 1
- 239000004568 cement Substances 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 229910052742 iron Inorganic materials 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 229910052751 metal Inorganic materials 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 230000000284 resting effect Effects 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/127—Packers; Plugs with inflatable sleeve
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- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Geophysics (AREA)
- Geophysics And Detection Of Objects (AREA)
- Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
- Measuring Fluid Pressure (AREA)
Abstract
Sensors are included in an inflatable packer to measure the pressure inside the packer and the distance that the outside wall of the packer moves during inflation. This data is communicated to a control module that monitors and controls the operation of the packer, as well as to a central downhole and/or surface controller.
Description
IMPROVED PACKER WITH INTEGRATED SENSORS
Technical Field The present invention relates to the detection of equipment status in a borehole.
More specifically, it relates to detecting the amount of expansion and the pressure inside a hydraulically controlled packer.
Background of the Invention 1n the field of oil and gas drilling, where a borehole may extend a mile or further below the surface, it has long been desirable to have knowledge of the position and configuration of the equipment that one can no longer see. One specific case in point is the use of packers.
Figure lA shows a simplified schematic of a cross-section through a well, which can be nearing completion: A dernck 110 supports a string of pipe 112, which is run into a cased borehole 114: Figure 1B is an enlargement of a portion of Figure lA, showing the wall 116 of the borehole, casing 118, casing cement 12p, pipe 112, and packers 122.
The packers 122 provide a seal between the outside of the pipe 112 and the inside of the casing, so that one section of the cased borehole 114 can be isolated from another. This can be to allow pressure to be exerted in a specific formation, e.g., for fracturing a producing formation, to be able to separately draw out the oil and gas produced at different depths, or for other reasons There are numerous types of packers, which differ in their material and form, but an exemplary packer uses hard rubber parts to seal between the downhole tubing and the casing or borehole. These packers will have a toroidal, or doughnut-shaped, section of rubber on the outside wall of the drill string. Figure 2A shows a view of such a packer as it is inserted into the borehole. At this point in time, the rubber making up the packer lies close to the pipe supporting it, so that there is no interference with the walls of the borehole as the packer is inserted. A view looking downward at the packer is seen in Figure 2B. Once the packer is in position, the pipe supporting the packer is manipulated so that the rubber is compressed in a longitudinal direction. As the toroid is forced into a smaller distance longitudinally, it bulges outward to seal against the inside of the casing, as seen in Figure 2C. Figure 2D is a view looking down the borehole at the expanded packer. Another type of packer is inflatable and can be filled with a liquid, once it is in position. So far, however, this type of packer has been used much less as it will not hold against a large differential pressure across the packer.
As mentioned above, one of the problems in judging whether the packer is correctly seated is the inability to visualize the packer or to receive direct feedback about what is happening with the packer. Judging the proper seating of the packers) involves monitoring indirect feedback at the surface, primarily in the form of surface pressure changes. This can involve conducting pressure tests, where a liquid is pumped into the sealed portion to be sure that the packer holds under necessary pressures. No information is directly available from the packer on its displacement or its internal condition. It would be desirable to obtain information from the packer so that it could be more clearly determined if it is properly positioned.
SUMMARY OF THE INVENTION
In the innovative packer, sensors are included in an inflatable packer to measure the pressure inside the packer and the distance that the outside wall of the packer moves during inflation. This data is communicated to a control module that monitors and controls the operation of the packer; as well as to a central downhole and/or surface controller.
BRIEF DESCRIPTION OF THE DRAWINGS
The novel features believed characteristic of the invention are set forth in the appended claims. The invention itself, however, as well as a preferred mode of use, further objects and advantages thereof, will best be understood by reference to the following detailed description of an illustrative embodiment when read in conjunction with the accompanying drawings, wherein:
Figure lA shows a simplified schematic of a cross-section through a prior art well.
Figure 1B is an enlargement of a portion of Figure lA, Figures 2A and 2B show a prior art packer before and after activation.
Figures 2C and 2D show a top view of the packers of Figure 2A and 2B
respectively Figure 3 shows a first embodiment of the innovative packer.
Figure 4 shows an alternate embodiment of the innovative packer.
Figure 5 is a flowchart demonstrating a method of using the innovative packer.
DETAILED DESCRIPTION OF THE DRAWINGS
A first embodiment of the disclosed packer will now be discussed in further detail with reference to Figure 3. This drawing shows only the short section of the pipe string that contains the inflatable packer. It will be noted that this drawing is not done to scale so that the innovative features can be emphasized. Seen in the drawing is the inflatable packer 300, which wraps completely around the section of pipe 320 containing it. Not present in the drawing are the threaded ends to the pipe section by which the packer is made up as part of a string of tools. The pipe 320 contains a passageway 322 through which fluids can be pumped into the well or production fluids removed from the well.
Packer 300 is of the inflatable type, where a fluid can be pumped into the packer 300 through a hydraulic line 302 to expand the packer. In the presently preferred embodiment, the fluid used is a magnetorheological fluid, comprising iron particles in an oil base. With a magnetorheological hydraulic fluid, the flow of hydraulic fluid into and out of the packer can be controlled through the use of an electromagnet 303.
Further information regarding the use of magnetorheological fluids in drilling and production can be found in co-pending application 10/090,054, filed March 1, 2002.
Two sensors are included as part of this innovative packer. The first of these sensors is a fiber optic pressure transducer 304. This transducer has at least one surface that is positioned to detect the pressure within the interior of the packer 300. The pressure detected is transformed into an electrical signal, which is sent to controller 306. Another type of transducer is used to detect the inflation of the packer. In this embodiment, a rotary potentiometer 308 is used, the basic concept of which is shown in Figure 6. A
length of cable 310 is wound around a spindle 340, so that as cable 310 is pulled out of the potentiometer 308, the spindle is rotated a number of turns proportional to the distance the cable travels. These rotations are translated into another electrical signal, which is again sent to the controller 306. As seen in the figure, one end of cable 310 is attached to the outer wall 312 of the packer 300 by a cable clamp 314. The cable between the potentiometer 308 and cable clamp 314 runs over pulley 316, which allows a change of direction. As the packer is inflated, the cable 310 is pulled out of potentiometer 308, causing an appropriate signal to be generated. The shaft of the potentiometer 308 is spring-loaded so that it remains in its zero position until the packer is inflated. The sensors 304, 308, controller 306, and the electromagnet 303 that controls the flow of fluid into the packer 300 are connected by bus 318 to each other and to a battery 319, which provides power.
Figure 4 shows an alternate embodiment of the innovative packer 300. In this embodiment, ultrasound transducer 330 bounces a signal aff a metal plate 332 attached to the wall of the packer 300 to measure the inflation of the packer 300. From the signals bounced back from the device 332, the transducer 330 can determine the distance the wall of the packer 300 has moved during inflation. The pressure can be measured in this embodiment can be another form of pressure transducer 304, such as a quartz pressure transducer or a pressure gauge transducer. Like the prior embodiment, this information can be collected by a controller, which controls the electromagnetic valve used for inflating the packer 300. Additionally, a signal can be sent uphole via transmitter 334, where the pressure and displacement can be monitored and the action of the packer further controlled by the operator. This signal can be sent by any of the known methods of sending messages to the surface.
A method of using the disclosed embodiments of the invention will now be described with reference to the flowchart shown in Figure 5. The method begins with the packer being inserted into a string of tools (step 510) that will be used for finishing the hole or during production, depending on the type of packer used. A hydraulic line will be also be attached to the packer, as is well known in the art, although the valve to the packer will be closed so that the packer will not be unintentionally inflated.
Once the string of tools is completed, ftwther pipe is added to extend the string to the required depth (step 512). This depth will have been determined by the operator to place the packers) at appropriate locations relative to the formation of interest. In a presently preferred embodiment, the sensors are not powered at the time the packer is being installed and positioned, although tests may be run to sure that it is functioning correctly.
After positioning, a signal is sent (step 514) to the controller 306 to activate the packer and the sensors. At this time, the controller will open the electromagnetic valve (step 516) to allow hydraulic fluid into the interior of the packer chamber 300. At the same time, the sensors 304, 308 will be activated to detect the movement of the outside wall of the packer and the pressure within the packer itself. The controller 306 will monitor these signals. In a properly functioning packer, the pressure will rise gradually while the packer expands until the outside wall of the packer contacts the casing of the hole.
Once the sensor detecting the location of the outer wall of the packer indicates that the casing is contacted, the packer will continue to be filled and pressurized until pressure sensor indicates that the predetermined pressure for sealing is reached. At that point, the controller 306 will shut (step 518) the valve 303. Optionaliy, the controller will also send signals (step 520) back to the operator on the surface, so that the process can be monitored topside. If the packer installation is not permanent, then the packer can optionally be removed when necessary by reversing the steps. In this instance, a si~nal is sent (step 522) to the controller 306, instructing it to deflate the packer.
The valve is opened (step 524) so that the hydraulic fluid can be pumped out and the monitors are used to detect (step 526) when the packer is returned to its resting, deflated position.
When that point is reached, the string can be withdrawn (step 528) as is known in the art.
Thus, it can be seen that the innovative changes to a packer will provide much needed information, both to automatic controllers downhole and to the operators on the surface. The advantages of the innovative packer include the following: 1) a direct indication about the integrity of the packer seal is provided, 2) the safety of the overall packer operation is increased, and 3) operating time is saved by avoiding lengthy surface pressure tests to check the integrity of the packer seal.
It will be understood by one of ordinary skill in the art that numerous variations will be possible to the disclosed embodiments without going outside the scope of the invention as disclosed in the claims.
_ g _
Technical Field The present invention relates to the detection of equipment status in a borehole.
More specifically, it relates to detecting the amount of expansion and the pressure inside a hydraulically controlled packer.
Background of the Invention 1n the field of oil and gas drilling, where a borehole may extend a mile or further below the surface, it has long been desirable to have knowledge of the position and configuration of the equipment that one can no longer see. One specific case in point is the use of packers.
Figure lA shows a simplified schematic of a cross-section through a well, which can be nearing completion: A dernck 110 supports a string of pipe 112, which is run into a cased borehole 114: Figure 1B is an enlargement of a portion of Figure lA, showing the wall 116 of the borehole, casing 118, casing cement 12p, pipe 112, and packers 122.
The packers 122 provide a seal between the outside of the pipe 112 and the inside of the casing, so that one section of the cased borehole 114 can be isolated from another. This can be to allow pressure to be exerted in a specific formation, e.g., for fracturing a producing formation, to be able to separately draw out the oil and gas produced at different depths, or for other reasons There are numerous types of packers, which differ in their material and form, but an exemplary packer uses hard rubber parts to seal between the downhole tubing and the casing or borehole. These packers will have a toroidal, or doughnut-shaped, section of rubber on the outside wall of the drill string. Figure 2A shows a view of such a packer as it is inserted into the borehole. At this point in time, the rubber making up the packer lies close to the pipe supporting it, so that there is no interference with the walls of the borehole as the packer is inserted. A view looking downward at the packer is seen in Figure 2B. Once the packer is in position, the pipe supporting the packer is manipulated so that the rubber is compressed in a longitudinal direction. As the toroid is forced into a smaller distance longitudinally, it bulges outward to seal against the inside of the casing, as seen in Figure 2C. Figure 2D is a view looking down the borehole at the expanded packer. Another type of packer is inflatable and can be filled with a liquid, once it is in position. So far, however, this type of packer has been used much less as it will not hold against a large differential pressure across the packer.
As mentioned above, one of the problems in judging whether the packer is correctly seated is the inability to visualize the packer or to receive direct feedback about what is happening with the packer. Judging the proper seating of the packers) involves monitoring indirect feedback at the surface, primarily in the form of surface pressure changes. This can involve conducting pressure tests, where a liquid is pumped into the sealed portion to be sure that the packer holds under necessary pressures. No information is directly available from the packer on its displacement or its internal condition. It would be desirable to obtain information from the packer so that it could be more clearly determined if it is properly positioned.
SUMMARY OF THE INVENTION
In the innovative packer, sensors are included in an inflatable packer to measure the pressure inside the packer and the distance that the outside wall of the packer moves during inflation. This data is communicated to a control module that monitors and controls the operation of the packer; as well as to a central downhole and/or surface controller.
BRIEF DESCRIPTION OF THE DRAWINGS
The novel features believed characteristic of the invention are set forth in the appended claims. The invention itself, however, as well as a preferred mode of use, further objects and advantages thereof, will best be understood by reference to the following detailed description of an illustrative embodiment when read in conjunction with the accompanying drawings, wherein:
Figure lA shows a simplified schematic of a cross-section through a prior art well.
Figure 1B is an enlargement of a portion of Figure lA, Figures 2A and 2B show a prior art packer before and after activation.
Figures 2C and 2D show a top view of the packers of Figure 2A and 2B
respectively Figure 3 shows a first embodiment of the innovative packer.
Figure 4 shows an alternate embodiment of the innovative packer.
Figure 5 is a flowchart demonstrating a method of using the innovative packer.
DETAILED DESCRIPTION OF THE DRAWINGS
A first embodiment of the disclosed packer will now be discussed in further detail with reference to Figure 3. This drawing shows only the short section of the pipe string that contains the inflatable packer. It will be noted that this drawing is not done to scale so that the innovative features can be emphasized. Seen in the drawing is the inflatable packer 300, which wraps completely around the section of pipe 320 containing it. Not present in the drawing are the threaded ends to the pipe section by which the packer is made up as part of a string of tools. The pipe 320 contains a passageway 322 through which fluids can be pumped into the well or production fluids removed from the well.
Packer 300 is of the inflatable type, where a fluid can be pumped into the packer 300 through a hydraulic line 302 to expand the packer. In the presently preferred embodiment, the fluid used is a magnetorheological fluid, comprising iron particles in an oil base. With a magnetorheological hydraulic fluid, the flow of hydraulic fluid into and out of the packer can be controlled through the use of an electromagnet 303.
Further information regarding the use of magnetorheological fluids in drilling and production can be found in co-pending application 10/090,054, filed March 1, 2002.
Two sensors are included as part of this innovative packer. The first of these sensors is a fiber optic pressure transducer 304. This transducer has at least one surface that is positioned to detect the pressure within the interior of the packer 300. The pressure detected is transformed into an electrical signal, which is sent to controller 306. Another type of transducer is used to detect the inflation of the packer. In this embodiment, a rotary potentiometer 308 is used, the basic concept of which is shown in Figure 6. A
length of cable 310 is wound around a spindle 340, so that as cable 310 is pulled out of the potentiometer 308, the spindle is rotated a number of turns proportional to the distance the cable travels. These rotations are translated into another electrical signal, which is again sent to the controller 306. As seen in the figure, one end of cable 310 is attached to the outer wall 312 of the packer 300 by a cable clamp 314. The cable between the potentiometer 308 and cable clamp 314 runs over pulley 316, which allows a change of direction. As the packer is inflated, the cable 310 is pulled out of potentiometer 308, causing an appropriate signal to be generated. The shaft of the potentiometer 308 is spring-loaded so that it remains in its zero position until the packer is inflated. The sensors 304, 308, controller 306, and the electromagnet 303 that controls the flow of fluid into the packer 300 are connected by bus 318 to each other and to a battery 319, which provides power.
Figure 4 shows an alternate embodiment of the innovative packer 300. In this embodiment, ultrasound transducer 330 bounces a signal aff a metal plate 332 attached to the wall of the packer 300 to measure the inflation of the packer 300. From the signals bounced back from the device 332, the transducer 330 can determine the distance the wall of the packer 300 has moved during inflation. The pressure can be measured in this embodiment can be another form of pressure transducer 304, such as a quartz pressure transducer or a pressure gauge transducer. Like the prior embodiment, this information can be collected by a controller, which controls the electromagnetic valve used for inflating the packer 300. Additionally, a signal can be sent uphole via transmitter 334, where the pressure and displacement can be monitored and the action of the packer further controlled by the operator. This signal can be sent by any of the known methods of sending messages to the surface.
A method of using the disclosed embodiments of the invention will now be described with reference to the flowchart shown in Figure 5. The method begins with the packer being inserted into a string of tools (step 510) that will be used for finishing the hole or during production, depending on the type of packer used. A hydraulic line will be also be attached to the packer, as is well known in the art, although the valve to the packer will be closed so that the packer will not be unintentionally inflated.
Once the string of tools is completed, ftwther pipe is added to extend the string to the required depth (step 512). This depth will have been determined by the operator to place the packers) at appropriate locations relative to the formation of interest. In a presently preferred embodiment, the sensors are not powered at the time the packer is being installed and positioned, although tests may be run to sure that it is functioning correctly.
After positioning, a signal is sent (step 514) to the controller 306 to activate the packer and the sensors. At this time, the controller will open the electromagnetic valve (step 516) to allow hydraulic fluid into the interior of the packer chamber 300. At the same time, the sensors 304, 308 will be activated to detect the movement of the outside wall of the packer and the pressure within the packer itself. The controller 306 will monitor these signals. In a properly functioning packer, the pressure will rise gradually while the packer expands until the outside wall of the packer contacts the casing of the hole.
Once the sensor detecting the location of the outer wall of the packer indicates that the casing is contacted, the packer will continue to be filled and pressurized until pressure sensor indicates that the predetermined pressure for sealing is reached. At that point, the controller 306 will shut (step 518) the valve 303. Optionaliy, the controller will also send signals (step 520) back to the operator on the surface, so that the process can be monitored topside. If the packer installation is not permanent, then the packer can optionally be removed when necessary by reversing the steps. In this instance, a si~nal is sent (step 522) to the controller 306, instructing it to deflate the packer.
The valve is opened (step 524) so that the hydraulic fluid can be pumped out and the monitors are used to detect (step 526) when the packer is returned to its resting, deflated position.
When that point is reached, the string can be withdrawn (step 528) as is known in the art.
Thus, it can be seen that the innovative changes to a packer will provide much needed information, both to automatic controllers downhole and to the operators on the surface. The advantages of the innovative packer include the following: 1) a direct indication about the integrity of the packer seal is provided, 2) the safety of the overall packer operation is increased, and 3) operating time is saved by avoiding lengthy surface pressure tests to check the integrity of the packer seal.
It will be understood by one of ordinary skill in the art that numerous variations will be possible to the disclosed embodiments without going outside the scope of the invention as disclosed in the claims.
_ g _
Claims (21)
We claim:
1. A packer for use in a borehole, said packer comprising:
a base portion having a bore therethrough and having threaded ends for connection to a string of tools used in a borehole;
an inflatable portion connected to be pressurized by hydraulic fluid; and a sensor connected to detect a condition related to the deployment of said packer.
a base portion having a bore therethrough and having threaded ends for connection to a string of tools used in a borehole;
an inflatable portion connected to be pressurized by hydraulic fluid; and a sensor connected to detect a condition related to the deployment of said packer.
2. The packer of Claim 1, wherein said sensor detects the pressure inside said inflatable portion.
3. The packer of Claim 1, wherein said sensor detects the location of the outer wall of said packer relative to the inner wall of said packer.
4. The packer of Claim 1, wherein said sensor is a rotary potentiometer.
5. The packer of Claim 1, wherein said sensor is an ultrasound transducer.
6. The packer of Claim 1, wherein said sensor is a fiber optic pressure transducer.
7. The packer of Claim 1, wherein said inflatable portion is pressurized with magnetorheological fluid.
8. A system for working in a borehole, said system comprising:
a string of tools connected together to accomplish a task related to the production of hydrocarbons from said borehole;
a packer connected to be a part of said string of tools, said packer comprising a sensor connected to detect a condition related to the deployment of said packer.
a string of tools connected together to accomplish a task related to the production of hydrocarbons from said borehole;
a packer connected to be a part of said string of tools, said packer comprising a sensor connected to detect a condition related to the deployment of said packer.
9. The system of Claim 8, wherein said sensor detects the pressure inside said packer.
10. The system of Claim 8, wherein said sensor detects the distance an outer wall of said inflatable packer has moved.
11. The system of Claim 8, wherein said sensor is a rotary potentiometer.
12. The system of Claim 8, wherein said sensor is an ultrasound transducer.
13. The system of Claim 8, wherein said sensor is a fiber optic pressure transducer.
14. The system of Claim 8, wherein said inflatable portion is pressurized with magnetorheological fluid.
15. A method of using a packer in a borehole, said method comprising:
positioning said packer at a predetermined position within said borehole;
inflating said packer using hydraulic fluid; and receiving information regarding a condition related to the inflation of said packer from a sensor implanted in said packer.
positioning said packer at a predetermined position within said borehole;
inflating said packer using hydraulic fluid; and receiving information regarding a condition related to the inflation of said packer from a sensor implanted in said packer.
16. The method of Claim 15, wherein said sensor detects the pressure inside said packer.
17. The system of Claim 15, wherein said sensor detects the distance an outer wall of said packer has moved.
18. The system of Claim 15, wherein said sensor is a rotary potentiometer, an ultrasound transducer, or a fiber optic pressure transducer.
19. The system of Claim 8, wherein said packer is pressurized with magnetorheological fluid.
20. A method of using a packer in a borehole, said method comprising the steps of attaching a packer containing at least one sensor to a string of tools;
lowering said string of tools, containing said packer, into a cased borehole;
setting said packer while utilizing said at least one sensor to detect the state of said packer.
21. The method of Claim 20, wherein said packer is an inflatable packer.
lowering said string of tools, containing said packer, into a cased borehole;
setting said packer while utilizing said at least one sensor to detect the state of said packer.
21. The method of Claim 20, wherein said packer is an inflatable packer.
21. The method of Claim 20, wherein said sensor is chosen from the group comprising a rotary potentiometer, a fiber-optic pressure transducer, an ultrasound transducer, a quartz pressure transducer, and a pressure gauge transducer.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US10/379,267 US20040173363A1 (en) | 2003-03-04 | 2003-03-04 | Packer with integrated sensors |
| US10/379,267 | 2003-03-04 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2458495A1 true CA2458495A1 (en) | 2004-09-04 |
Family
ID=32824767
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002458495A Abandoned CA2458495A1 (en) | 2003-03-04 | 2004-02-24 | Improved packer with integrated sensors |
Country Status (4)
| Country | Link |
|---|---|
| US (1) | US20040173363A1 (en) |
| EP (1) | EP1455052A3 (en) |
| CA (1) | CA2458495A1 (en) |
| NO (1) | NO20040789L (en) |
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|---|---|---|---|---|
| US6924745B2 (en) * | 2002-06-13 | 2005-08-02 | Halliburton Energy Services, Inc. | System and method for monitoring packer slippage |
| DE202006000943U1 (en) * | 2005-09-03 | 2007-01-11 | Trumpf Grüsch AG | Feed module for hand-held power tool has first motion converter to convert rotation into linear motion and second one coupled to it to convert other way |
| US7631697B2 (en) * | 2006-11-29 | 2009-12-15 | Schlumberger Technology Corporation | Oilfield apparatus comprising swellable elastomers having nanosensors therein and methods of using same in oilfield application |
| US8091634B2 (en) * | 2008-11-20 | 2012-01-10 | Schlumberger Technology Corporation | Single packer structure with sensors |
| US9091133B2 (en) * | 2009-02-20 | 2015-07-28 | Halliburton Energy Services, Inc. | Swellable material activation and monitoring in a subterranean well |
| GB0909086D0 (en) * | 2009-05-27 | 2009-07-01 | Read Well Services Ltd | An active external casing packer (ecp) for frac operations in oil and gas wells |
| US8322415B2 (en) * | 2009-09-11 | 2012-12-04 | Schlumberger Technology Corporation | Instrumented swellable element |
| US8960313B2 (en) * | 2010-03-15 | 2015-02-24 | Schlumberger Technology Corporation | Packer deployed formation sensor |
| GB201012175D0 (en) * | 2010-07-20 | 2010-09-01 | Metrol Tech Ltd | Procedure and mechanisms |
| US8955606B2 (en) * | 2011-06-03 | 2015-02-17 | Baker Hughes Incorporated | Sealing devices for sealing inner wall surfaces of a wellbore and methods of installing same in a wellbore |
| EP2599955A1 (en) * | 2011-11-30 | 2013-06-05 | Welltec A/S | Pressure integrity testing system |
| EP2599956A1 (en) | 2011-11-30 | 2013-06-05 | Welltec A/S | Annular barrier system with flow lines |
| DK2607614T3 (en) * | 2011-12-21 | 2015-02-02 | Welltec As | Annular barrier with an expansion detection device |
| SG11201501844UA (en) | 2012-09-26 | 2015-04-29 | Halliburton Energy Services Inc | Single trip multi-zone completion systems and methods |
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| BR122020005690B1 (en) | 2012-09-26 | 2021-07-06 | Halliburton Energy Services, Inc | METER CONVEYOR |
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|---|---|---|---|---|
| US4191383A (en) * | 1979-02-02 | 1980-03-04 | Halliburton Company | Inflatable packer and method of constructing same |
| US4253676A (en) * | 1979-06-15 | 1981-03-03 | Halliburton Company | Inflatable packer element with integral support means |
| CA1249772A (en) * | 1986-03-07 | 1989-02-07 | David Sask | Drill stem testing system |
| CA2155918C (en) * | 1994-08-15 | 2001-10-09 | Roger Lynn Schultz | Integrated well drilling and evaluation |
| US5706892A (en) * | 1995-02-09 | 1998-01-13 | Baker Hughes Incorporated | Downhole tools for production well control |
| DE69636665T2 (en) * | 1995-12-26 | 2007-10-04 | Halliburton Co., Dallas | Apparatus and method for early assessment and maintenance of a well |
| US5791414A (en) * | 1996-08-19 | 1998-08-11 | Halliburton Energy Services, Inc. | Early evaluation formation testing system |
| US5890542A (en) * | 1997-04-01 | 1999-04-06 | Halliburton Energy Services, Inc. | Apparatus for early evaluation formation testing |
| US5925879A (en) * | 1997-05-09 | 1999-07-20 | Cidra Corporation | Oil and gas well packer having fiber optic Bragg Grating sensors for downhole insitu inflation monitoring |
| US6065355A (en) * | 1997-09-23 | 2000-05-23 | Halliburton Energy Services, Inc. | Non-flashing downhole fluid sampler and method |
| GB2372277B (en) * | 1997-11-26 | 2002-10-02 | Baker Hughes Inc | Inflatable packer inflation verification system |
| US6340062B1 (en) * | 2000-01-24 | 2002-01-22 | Halliburton Energy Services, Inc. | Early formation evaluation tool |
-
2003
- 2003-03-04 US US10/379,267 patent/US20040173363A1/en not_active Abandoned
-
2004
- 2004-02-23 NO NO20040789A patent/NO20040789L/en not_active Application Discontinuation
- 2004-02-24 CA CA002458495A patent/CA2458495A1/en not_active Abandoned
- 2004-03-03 EP EP04251246A patent/EP1455052A3/en not_active Withdrawn
Also Published As
| Publication number | Publication date |
|---|---|
| EP1455052A2 (en) | 2004-09-08 |
| NO20040789L (en) | 2004-09-06 |
| EP1455052A3 (en) | 2005-03-23 |
| US20040173363A1 (en) | 2004-09-09 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| FZDE | Discontinued |