EP1455052A2

EP1455052A2 - Improved packer with integrated sensors

Info

Publication number: EP1455052A2
Application number: EP04251246A
Authority: EP
Inventors: Juan Navarro-Sorroche
Original assignee: Halliburton Energy Services Inc
Current assignee: Halliburton Energy Services Inc
Priority date: 2003-03-04
Filing date: 2004-03-03
Publication date: 2004-09-08
Also published as: CA2458495A1; EP1455052A3; US20040173363A1; NO20040789L

Abstract

A packer (300) for use in a borehole, said packer (300) 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 (304,308) connected to detect a condition related to the deployment of said packer.

Description

The present invention relates to the detection of equipment status in a borehole. More specifically, the invention relates to detecting the amount of expansion and the pressure inside a hydraulically controlled packer, and, in particular, to a packer for use in a borehole.
In 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 1A shows a simplified schematic of a cross-section through a well, which can be nearing completion. A derrick 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 1A, showing the wall 116 of the borehole, casing 118, casing cement 120, 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 packer(s) 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.
In the innovative packer, sensors can be 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.
According to one aspect of the invention, there is provided 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.
In an embodiment, said sensor detects the pressure inside said inflatable portion.
In an embodiment, said sensor detects the location of the outer wall of said packer relative to the inner wall of said packer.
The sensor is preferably a rotary potentiometer, and ultrasound transducer, or a fibre optic pressure transducer.
In an embodiment, the inflatable portion is pressurized with magnetorheological fluid.
According to another aspect of the invention there is provided 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.
In an embodiment, said sensor detects the pressure inside said packer.
In an embodiment, said sensor detects the distance an outer wall of said inflatable packer has moved.
The sensor is preferably a rotary potentiometer, and ultrasound transducer, or a fibre optic pressure transducer.
The sensor is preferably a rotary potentiometer, and ultrasound transducer, or a fibre optic pressure transducer.
In an embodiment, the inflatable portion is pressurized with magnetorheological fluid.
According to another aspect of the invention there is provided 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.
In an embodiment, said sensor detects the pressure inside said packer.
In an embodiment, said sensor detects the distance an outer wall of said packer has moved.
The sensor is preferably a rotary potentiometer, an ultrasound transducer, or a fibre optic pressure transducer.
In an embodiment, the packer is pressurized with magnetorheological fluid.
According to another aspect of the invention there is provided 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.
In an embodiment, said packer is an inflatable packer.
In an embodiment, said sensor is chosen from the group comprising a rotary potentiometer, a fibre-optic pressure transducer, an ultrasound transducer, a quartz pressure transducer, and a pressure gauge transducer.
Reference is now made to the accompanying drawings in which:
Figure 1A shows a simplified schematic of a cross-section through a prior art well;
Figure 1B is an enlargement of a portion of Figure 1A;
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 a packer according to the invention;
Figure 4 shows an alternative embodiment of a packer according to the invention;
Figure 5 is a flowchart demonstrating an embodiment of a method of using a packer according to the invention; and
Figure 6 is an illustration of a rotary potentiometer for use in the invention.
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 GB2385871A.
Two sensors are included as part of this innovative packer. The first of these sensors is a fibre 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 springloaded 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 alternative embodiment of the innovative packer 300. In this embodiment, ultrasound transducer 330 bounces a signal off 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, further 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 packer(s) 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. Optionally, 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 signal 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 appreciated that the invention described above may be modified.

Claims

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 packer according to Claim 1, wherein said sensor detects the pressure inside said inflatable portion.
A packer according to Claim 1, wherein said sensor detects the location of the outer wall of said packer relative to the inner wall of said packer.
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 system according to Claim 4, wherein said sensor detects the pressure inside said packer.
A system according to Claim 4, wherein said sensor detects the distance an outer wall of said inflatable packer has moved.
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.
A method according to Claim 7, wherein said sensor detects the pressure inside said packer.
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.
A method according to Claim 9, wherein said packer is an inflatable packer.