US20040112597A1 - Packer set monitoring and compensating system and method - Google Patents
Packer set monitoring and compensating system and method Download PDFInfo
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- US20040112597A1 US20040112597A1 US10/319,094 US31909402A US2004112597A1 US 20040112597 A1 US20040112597 A1 US 20040112597A1 US 31909402 A US31909402 A US 31909402A US 2004112597 A1 US2004112597 A1 US 2004112597A1
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- Prior art keywords
- packer
- compression
- output signal
- sensor
- fluid
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B33/128—Packers; Plugs with a member expanded radially by axial pressure
- E21B33/1285—Packers; Plugs with a member expanded radially by axial pressure by fluid pressure
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B33/1208—Packers; Plugs characterised by the construction of the sealing or packing means
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
Definitions
- Downhole packers are commonly used in many oilfield applications for the purpose of sealing against the flow of fluid to isolate one or more portions of a wellbore for the purposes of testing, treating, or producing the well.
- the packers are suspended from a tubing string, or the like, in the wellbore, or in a casing in the wellbore, and extend between the inner surface of the wellbore, or casing and the outer surface of the carrier tubing.
- Each packer includes one or more elastomer elements which are activated, or set, so that the packer elements are forced against the inner surface of the wellbore, or casing, and the outer surface of the carrier tubing, and compressed to seal against the flow of fluid and therefore to permit isolation of certain zones in the well.
- packer elements Under normal circumstances the packer elements retain their compression, or set, for a significant duration. However, packers often suffer from “set loss” in which they lose their compression for a number of reasons including, for example, an improper setting, material creep, and the like. This compromises the integrity of the seal and can lead to downhole leakage, requiring a workover operation which is expensive and time-consuming.
- FIG. 1 is a sectional view of a packer utilized in an embodiment of the invention.
- FIGS. 2 and 3 are diagrammatic views of a monitoring and compensating system for the packer of FIG. 1.
- a downhole tool is referred to, in general, by the reference numeral 10 and is shown installed in a casing 12 . It is understood that the casing 12 is disposed in a well and that the tool 10 is lowered to a predetermined depth in the casing 12 as part of a workstring, or the like, (not shown) which often includes other tools used to perform various oil recovery and completion operations.
- the tool 10 includes a tubular member 14 connected as part of the workstring and a packer 16 surrounds a portion of the outer surface of the tool 10 and consists of a series (in the example shown, three) of axially-spaced, annular packer elements 16 a , 16 b , and 16 c .
- the packer elements 16 a , 16 b , and 16 c can be fabricated, at least in part, from an elastomeric material so that they can be compressed, in a manner to be described.
- the packer 16 also includes a series (in the example shown, two) of annular, axially-spaced anchoring slips 20 a and 20 b that are also disposed on the outer surface of the tubular member 14 downstream and slightly spaced from the packer elements 16 a , 16 b , and 16 c .
- the anchoring slips 20 a and 20 b can be fabricated from a relatively hard material which is adapted to engage the inner wall of the casing 12 , as will be described.
- Two annular backup shoes 24 a and 24 b are disposed at the upper end of the upper packer element 16 a and the lower end of the lower packer element 16 c , respectively, as viewed in FIG. 1.
- the backup shoes 24 a and 24 b when installed, compress the packer elements 16 a , 16 b , and 16 c during the packer setting process.
- packer elements 16 a , 16 b , and 16 c ; the anchoring slips 20 a and 20 b ; and the backup shoes 24 a and 24 b all are conventional and are connected to the tubular member 14 in a conventional manner they will not be described in further detail.
- FIG. 2 depicts the packer 16 connected to a monitoring and compensating system, including a sensor 30 mounted between the upper backup shoe 24 a and the corresponding end of the packer element 16 a to measure, or sense, the amount of compressive stress on the packer element 16 a .
- the sensor 30 can be in the form of a strain gage, for example, in which case it could be mounted on the backup shoe 24 a ; or it could be in the form of a pressure sensor, for example, in which case it could be mounted on the corresponding end of the packer element 16 a .
- the sensor 30 is connected in an electrical circuit including a controller 32 and a solenoid operated valve 34 connected in series by conventional electrical conductors in a conventional manner.
- the controller 32 can be a classical PID controller or an adaptive controller and, as such, receives the above output signal from the sensor 30 and compares the signal with a desired threshold value or a “set-point” which corresponds to a reduction in the compression of the packer element 16 a from its original set, or a predetermined reduction from its original set. If the signal falls below the set-point, the controller 32 generates an output signal which is passed to the valve 34 .
- the valve 34 is normally closed but is adapted to open when it receives the above signal from the controller 32 .
- the valve 34 is part of an apparatus which increases the compression of the packer 16 and which also includes a conduit system 36 through which fluid from a source 38 flows.
- the valve 34 is connected in the conduit system 36 and controls the flow of the fluid through the conduit system 36
- a fluid compressor 40 is also connected in the conduit system 36 downstream of the valve 34 .
- the compressor 40 can be of any conventional design such as, for example, a piston mounted for reciprocal movement in a cylinder to compress the fluid.
- the compressor 40 is adapted to receive the fluid from the source 38 and increase the pressure of the fluid, and can be activated automatically upon receipt of the fluid, or it can be activated by the controller 32 in a conventional manner.
- a cavity is formed in the packer element 16 a and is connected to the compressor 40 by the conduit system 36 .
- pressurized fluid flows from the compressor 40 to the cavity in the packer element 16 a to increase its compression, or set, and thus compensate for the reduction in the compression sensed by the sensor 30 .
- the flow can continue in this manner until the set of the packer 16 is re-established.
- a check valve 42 is provided in the conduit system 36 for preventing the flow of fluid from the packer element 16 a back to the compressor 40 .
- the packer 16 is located at a predetermined location in the casing 12 and is set, or activated, in a conventional manner. This causes the packer elements 16 a , 16 b , and 16 c to be forced against the inner wall of the casing 12 as well as the outer wall of the tubular member 14 in compression and, along with the anchoring slips 20 a and 20 b , to engage the inner surface of the casing 12 . A seal is thus formed against the flow of fluids in the annular space between the outer surface of the tubular member 14 and the inner wall of the casing 12 which isolates the corresponding zone in the well.
- the sensor 30 continuously monitors the compressive stress on the packer element 16 a and outputs a corresponding signal. If the output signal falls below the set-point value described above, the controller 32 generates a corresponding output signal which is passed to the valve 34 and causes the valve to open and fluid to flow though the conduit system 36 , as indicated by the flow arrows. The pressure of the flowing fluid is increased by the compressor 40 , and the pressurized fluid is passed to the cavity in the packer element 16 a to increase its compression and re-establish its set. When the compressive stress on the packer element 16 a returns to normal, as sensed by the sensor 30 , the controller 32 responds to a corresponding signal from the sensor 30 and closes the valve 34 .
- the senor 30 can be embedded in the packer element 16 a ; mounted on, or embedded in, the packer elements 16 b and 16 c ; or mounted on either backup shoe 24 a or 24 b .
- multiple sensors 30 are provided in accordance with the foregoing they could be connected in the above electrical circuit, including the controller 32 , or connected in separate, identical, electrical circuits.
- the electrical circuit, including the sensor 30 , the controller 32 , the valve 34 , and the associated electrical conductors can also be either mounted on, or embedded in, the packer element 16 a or mounted on either backup shoe 24 a or 24 b .
- the operation described above in connection with the packer element 16 a is equally applicable to the packer elements 16 b and 16 c.
- FIG. 3 An alternate embodiment of the monitoring system is shown in FIG. 3 in connection with the tool 10 of the embodiment of FIG. 2.
- an actuator 50 is provided which includes a piston 52 mounted for reciprocal movement in a cylinder 54 in a conventional manner.
- One end of an actuator rod 56 is connected to an end of the piston 52 and extends though the housing of the cylinder 54 .
- the other end of the actuator rod 56 is connected to the backup shoe 24 a of the tool 10 .
- a fluid line 58 connects a fluid source 60 to the inlet of a hydraulic pump 62 .
- a fluid line 64 extends from the outlet of the pump 62 into the chamber of the cylinder 54 defined, in part, by the piston 52 ; and a check valve 66 is disposed in the line 64 to prevent fluid flow from the chamber to the pump 62 .
- An electrical motor 68 is operatively connected to the pump 62 for driving it to pump fluid from the source 60 , via the line 58 , through the pump 62 , and, through the line 64 to the chamber of the cylinder 54 , as indicated by the flow arrows.
- An electrical circuit which includes a sensing unit 70 connected to the line 64 , and a controller 72 electrically connected in series between the sensing unit 70 and the motor 68 .
- the sensing unit 70 senses pressure in the line 64 in a conventional manner and outputs a corresponding signal to the controller 72 .
- the controller 72 is identical to the controller 32 of the previous embodiment and, as such, is adapted to control the operation of the motor 68 in response to the signals received from the sensing unit 70 in a manner to be described.
- the packer 16 is located at a predetermined location in the casing 12 and is set, or activated, in a conventional manner. This causes the packer elements 16 a , 16 b , and 16 c to be forced against the inner wall of the casing 12 as well as the outer wall of the tubular member 14 in compression.
- the backup shoe 24 a is forced against the packer element 16 a , and the anchoring slips 20 a and 20 b are forced against the inner wall of the casing 12 .
- a seal is thus formed to prevent the flow of fluids in the annular space between the outer surface of the tubular member 14 and the inner wall of the casing 12 which isolates a corresponding zone in the well.
- the motor 68 and therefore the pump 62 , are normally inactive, and the sensing unit 70 continuously monitors the fluid pressure in the chamber of the cylinder 54 , via the fluid line 64 , and outputs a corresponding signal. If the compression of the packer element 16 a is reduced from its original set, the actuator rod 56 , and therefore the piston 52 , move downwardly, as viewed in FIG. 3. This, in effect, enlarges the chamber in the cylinder 54 and causes an attendant reduction in the fluid pressure in the chamber and in the line 64 . This reduced pressure is sensed by the sensing unit 70 and a corresponding signal is outputted from the sensing unit 70 to the controller 72 .
- the controller 72 compares the signal received from the sensing unit 70 with a desired threshold value, or “set-point”, of the fluid pressure in the chamber, which corresponds to a reduction in the compression of the packer element 16 a from its original set, or a predetermined reduction from its original set. If the signal received from the sensing unit 70 falls below the set-point, the controller 72 generates an output signal which is passed to the motor 68 to activate the motor 68 and drive the pump 62 . Fluid is thus pumped from the source 60 , through the lines 58 and 64 and the pump 62 and to the chamber of the cylinder 54 to increase the pressure in the chamber and cause the piston 52 , and therefore the actuator rod 56 , to move in a downwardly direction, as viewed in FIG. 3.
- a desired threshold value or “set-point”
- any set loss of the packer 16 exceeding a predetermined valve is immediately determined and compensated for to insure that the original set conditions of the packer 16 are maintained.
- the casing 12 can be eliminated and the tool 10 can be inserted directly in the well.
- the anchoring slips 20 a and 20 b can extend upstream from the packer elements 16 a , 16 b , and 1 6 c .
- the controllers 32 and 72 can respond to increases or decreases in the compression of the packer 16 from a predetermined value, and generate a corresponding output signal.
- fluid can be withdrawn from the cavity in the packer 16 and from the cylinder 54 as needed.
- spatial references such as “downwardly”, “downstream”, “between”, etc., are for the purpose of illustration only and do not limit the specific orientation or location of the components or fluid flow described above.
Abstract
A packer set monitoring and compensation system and method according to which the compression of the packer is sensed and a corresponding output signal is generated. The compression of the packer is changed in response to the sensed compression deviating from a predetermined value.
Description
- Downhole packers are commonly used in many oilfield applications for the purpose of sealing against the flow of fluid to isolate one or more portions of a wellbore for the purposes of testing, treating, or producing the well. The packers are suspended from a tubing string, or the like, in the wellbore, or in a casing in the wellbore, and extend between the inner surface of the wellbore, or casing and the outer surface of the carrier tubing. Each packer includes one or more elastomer elements which are activated, or set, so that the packer elements are forced against the inner surface of the wellbore, or casing, and the outer surface of the carrier tubing, and compressed to seal against the flow of fluid and therefore to permit isolation of certain zones in the well.
- Under normal circumstances the packer elements retain their compression, or set, for a significant duration. However, packers often suffer from “set loss” in which they lose their compression for a number of reasons including, for example, an improper setting, material creep, and the like. This compromises the integrity of the seal and can lead to downhole leakage, requiring a workover operation which is expensive and time-consuming.
- Some prior art techniques have addressed this problem by determining in a laboratory the amount of compression required to correctly set a given packer design, under the assumption that similar conditions are present downhole. However, in many instances the packer setting process (loading rate, for example) and conditions (such as the presence of fluids, debris, and the condition of the tubing/casing inner diameter and the surface) cannot be replicated in the laboratory. As a result, the actual setting behavior of the packer may be different from that experienced in the laboratory and the problem is not solved.
- Therefore, what is needed is a system that can monitor the packer and compensate for set loss without having to resort to laboratory testing.
- FIG. 1 is a sectional view of a packer utilized in an embodiment of the invention.
- FIGS. 2 and 3 are diagrammatic views of a monitoring and compensating system for the packer of FIG. 1.
- Referring to FIG. 1, a downhole tool is referred to, in general, by the
reference numeral 10 and is shown installed in acasing 12. It is understood that thecasing 12 is disposed in a well and that thetool 10 is lowered to a predetermined depth in thecasing 12 as part of a workstring, or the like, (not shown) which often includes other tools used to perform various oil recovery and completion operations. - The
tool 10 includes atubular member 14 connected as part of the workstring and apacker 16 surrounds a portion of the outer surface of thetool 10 and consists of a series (in the example shown, three) of axially-spaced,annular packer elements packer elements - The
packer 16 also includes a series (in the example shown, two) of annular, axially-spacedanchoring slips tubular member 14 downstream and slightly spaced from thepacker elements anchoring slips casing 12, as will be described. - Two
annular backup shoes upper packer element 16 a and the lower end of thelower packer element 16 c, respectively, as viewed in FIG. 1. Thebackup shoes packer elements - Since the
packer elements anchoring slips backup shoes tubular member 14 in a conventional manner they will not be described in further detail. - FIG. 2 depicts the
packer 16 connected to a monitoring and compensating system, including asensor 30 mounted between theupper backup shoe 24 a and the corresponding end of thepacker element 16 a to measure, or sense, the amount of compressive stress on thepacker element 16 a. Thesensor 30 can be in the form of a strain gage, for example, in which case it could be mounted on thebackup shoe 24 a; or it could be in the form of a pressure sensor, for example, in which case it could be mounted on the corresponding end of thepacker element 16 a. Thus, if there is a change in the packer set, i.e., a change in the amount of compressive stress on thepacker elements sensor 30 which outputs a corresponding electrical signal, in a conventional manner. - The
sensor 30 is connected in an electrical circuit including acontroller 32 and a solenoid operatedvalve 34 connected in series by conventional electrical conductors in a conventional manner. Thecontroller 32 can be a classical PID controller or an adaptive controller and, as such, receives the above output signal from thesensor 30 and compares the signal with a desired threshold value or a “set-point” which corresponds to a reduction in the compression of thepacker element 16 a from its original set, or a predetermined reduction from its original set. If the signal falls below the set-point, thecontroller 32 generates an output signal which is passed to thevalve 34. Thevalve 34 is normally closed but is adapted to open when it receives the above signal from thecontroller 32. - The
valve 34 is part of an apparatus which increases the compression of thepacker 16 and which also includes aconduit system 36 through which fluid from asource 38 flows. Thevalve 34 is connected in theconduit system 36 and controls the flow of the fluid through theconduit system 36, and afluid compressor 40 is also connected in theconduit system 36 downstream of thevalve 34. Thecompressor 40 can be of any conventional design such as, for example, a piston mounted for reciprocal movement in a cylinder to compress the fluid. Thecompressor 40 is adapted to receive the fluid from thesource 38 and increase the pressure of the fluid, and can be activated automatically upon receipt of the fluid, or it can be activated by thecontroller 32 in a conventional manner. - A cavity is formed in the
packer element 16 a and is connected to thecompressor 40 by theconduit system 36. Thus, pressurized fluid flows from thecompressor 40 to the cavity in thepacker element 16 a to increase its compression, or set, and thus compensate for the reduction in the compression sensed by thesensor 30. The flow can continue in this manner until the set of thepacker 16 is re-established. Acheck valve 42 is provided in theconduit system 36 for preventing the flow of fluid from thepacker element 16 a back to thecompressor 40. - In operation, the
packer 16 is located at a predetermined location in thecasing 12 and is set, or activated, in a conventional manner. This causes thepacker elements casing 12 as well as the outer wall of thetubular member 14 in compression and, along with theanchoring slips casing 12. A seal is thus formed against the flow of fluids in the annular space between the outer surface of thetubular member 14 and the inner wall of thecasing 12 which isolates the corresponding zone in the well. - The
sensor 30 continuously monitors the compressive stress on thepacker element 16 a and outputs a corresponding signal. If the output signal falls below the set-point value described above, thecontroller 32 generates a corresponding output signal which is passed to thevalve 34 and causes the valve to open and fluid to flow though theconduit system 36, as indicated by the flow arrows. The pressure of the flowing fluid is increased by thecompressor 40, and the pressurized fluid is passed to the cavity in thepacker element 16 a to increase its compression and re-establish its set. When the compressive stress on thepacker element 16 a returns to normal, as sensed by thesensor 30, thecontroller 32 responds to a corresponding signal from thesensor 30 and closes thevalve 34. - Although not shown in the drawings for the convenience of presentation, it is understood that the
sensor 30 can be embedded in thepacker element 16 a; mounted on, or embedded in, thepacker elements backup shoe multiple sensors 30 are provided in accordance with the foregoing they could be connected in the above electrical circuit, including thecontroller 32, or connected in separate, identical, electrical circuits. In either case, the electrical circuit, including thesensor 30, thecontroller 32, thevalve 34, and the associated electrical conductors can also be either mounted on, or embedded in, thepacker element 16 a or mounted on eitherbackup shoe packer element 16 a is equally applicable to thepacker elements - An alternate embodiment of the monitoring system is shown in FIG. 3 in connection with the
tool 10 of the embodiment of FIG. 2. According to the embodiment of FIG. 3, anactuator 50 is provided which includes apiston 52 mounted for reciprocal movement in acylinder 54 in a conventional manner. One end of anactuator rod 56 is connected to an end of thepiston 52 and extends though the housing of thecylinder 54. The other end of theactuator rod 56 is connected to thebackup shoe 24 a of thetool 10. - A
fluid line 58 connects afluid source 60 to the inlet of ahydraulic pump 62. Afluid line 64 extends from the outlet of thepump 62 into the chamber of thecylinder 54 defined, in part, by thepiston 52; and acheck valve 66 is disposed in theline 64 to prevent fluid flow from the chamber to thepump 62. - An
electrical motor 68 is operatively connected to thepump 62 for driving it to pump fluid from thesource 60, via theline 58, through thepump 62, and, through theline 64 to the chamber of thecylinder 54, as indicated by the flow arrows. - An electrical circuit is provided which includes a
sensing unit 70 connected to theline 64, and acontroller 72 electrically connected in series between thesensing unit 70 and themotor 68. Thesensing unit 70 senses pressure in theline 64 in a conventional manner and outputs a corresponding signal to thecontroller 72. Thecontroller 72 is identical to thecontroller 32 of the previous embodiment and, as such, is adapted to control the operation of themotor 68 in response to the signals received from thesensing unit 70 in a manner to be described. - In operation of the embodiment of FIG. 3, the
packer 16 is located at a predetermined location in thecasing 12 and is set, or activated, in a conventional manner. This causes thepacker elements casing 12 as well as the outer wall of thetubular member 14 in compression. Thebackup shoe 24 a is forced against thepacker element 16 a, and theanchoring slips casing 12. A seal is thus formed to prevent the flow of fluids in the annular space between the outer surface of thetubular member 14 and the inner wall of thecasing 12 which isolates a corresponding zone in the well. - The
motor 68, and therefore thepump 62, are normally inactive, and thesensing unit 70 continuously monitors the fluid pressure in the chamber of thecylinder 54, via thefluid line 64, and outputs a corresponding signal. If the compression of thepacker element 16 a is reduced from its original set, theactuator rod 56, and therefore thepiston 52, move downwardly, as viewed in FIG. 3. This, in effect, enlarges the chamber in thecylinder 54 and causes an attendant reduction in the fluid pressure in the chamber and in theline 64. This reduced pressure is sensed by thesensing unit 70 and a corresponding signal is outputted from thesensing unit 70 to thecontroller 72. Thecontroller 72 compares the signal received from thesensing unit 70 with a desired threshold value, or “set-point”, of the fluid pressure in the chamber, which corresponds to a reduction in the compression of thepacker element 16 a from its original set, or a predetermined reduction from its original set. If the signal received from thesensing unit 70 falls below the set-point, thecontroller 72 generates an output signal which is passed to themotor 68 to activate themotor 68 and drive thepump 62. Fluid is thus pumped from thesource 60, through thelines pump 62 and to the chamber of thecylinder 54 to increase the pressure in the chamber and cause thepiston 52, and therefore theactuator rod 56, to move in a downwardly direction, as viewed in FIG. 3. This, in turn, forces thebackup shoe 24 a further against thepacker element 16 a to increase its compression and re-establish its set. When this is achieved, the fluid pressure in theline 64 is increased to the extent that thesensing unit 70 outputs a corresponding signal to thecontroller 72 which, in turn, deactivates themotor 68 and therefore thepump 62. - Thus, according to the embodiments of FIGS. 2 and 3, any set loss of the
packer 16 exceeding a predetermined valve is immediately determined and compensated for to insure that the original set conditions of thepacker 16 are maintained. - It is understood that although components of the system of the embodiments of FIGS. 2 and 3 are shown diagrammatically, and therefore out of scale, for the convenience of presentation, they can be located downhole in the
casing 12 or the wellbore. - It is understood that variations may be made in the foregoing without departing from the scope of the invention. For example, the
casing 12 can be eliminated and thetool 10 can be inserted directly in the well. Also, the anchoring slips 20 a and 20 b can extend upstream from thepacker elements controllers packer 16 from a predetermined value, and generate a corresponding output signal. Still further, in the unlikely event that the compression of thepacker 16 needs to be decreased, fluid can be withdrawn from the cavity in thepacker 16 and from thecylinder 54 as needed. It is also understood that spatial references, such as “downwardly”, “downstream”, “between”, etc., are for the purpose of illustration only and do not limit the specific orientation or location of the components or fluid flow described above. - The foregoing descriptions of specific embodiments of the present invention have been presented for purposes of illustration and description. They are not intended to be exhaustive or to limit the invention to the precise forms disclosed, and obviously many modifications and variations are possible in light of the above teaching. The embodiments were chosen and described in order to best explain the principles of the invention and its practical application, to thereby enable others skilled in the art to best utilize the invention and various embodiments with various modifications as are suited to the particular use contemplated. It is intended that the scope of the invention be defined by the claims appended hereto and their equivalents.
Claims (29)
1. A system for controlling the compression of a packer disposed in a well, comprising:
a sensor disposed in the well for sensing the compression of the packer and generating a corresponding output signal; and
an apparatus responsive to the output signal for changing the compression of the packer in response to the sensed compression deviating from a predetermined value.
2. The system of claim 1 wherein the sensor senses any decrease in the compression of the packer below a predetermined value, and in response the apparatus increases the compression of the packer to raise it back to the predetermined value.
3. The system of claim 1 further comprising a controller for receiving the output signal from the sensor, processing the signal, and providing an output signal corresponding to the compression of the packer, wherein the apparatus is responsive to the output signal provided by the controller.
4. The system of claim 1 wherein the sensor is a strain gauge.
5. The system of claim 1 wherein the sensor is a pressure sensor.
6. The system of claim 1 wherein the sensor is located on, or embedded in, the packer.
7. The system of claim 1 wherein the packer comprises:
a packer element; and
a shoe engaging the packer element;
wherein the sensor is mounted on the packer element and is located between the packer element and the shoe.
8. The system of claim 1 wherein the packer comprises a packer element, and the sensor is embedded in the packer element.
9. The system of claim 1 wherein the packer has a cavity for receiving fluid, and the apparatus comprises a valve responsive to the output signal for controlling the flow of fluid to the cavity to change the compression of the packer.
10. The system of claim 9 wherein the apparatus further comprises a compressor for compressing the fluid before it flows to the cavity.
11. The system of claim 9 wherein the packer comprises a packer element, and the cavity is formed in the packer element.
12. The system of claim 9 wherein the output signal is generated in response to the compression of the packer falling below a predetermined value, and the apparatus increases the pressure in the cavity to restore the compression.
13. The system of claim 1 wherein the sensor comprises:
a hydraulic cylinder; and
a piston moveable in the hydraulic cylinder in response to the deviation in compression of the packer.
14. The system of claim 13 wherein the sensor further comprises a rod extending from the piston and engaging the packer so that changes in the compression of the packer causes movement of the rod and therefore the piston.
15. The system of claim 14 wherein movement of the piston causes changes in fluid pressure in the hydraulic cylinder, and the sensor further comprises a fluid pressure sensor responsive to the pressure in the hydraulic cylinder for generating the output signal.
16. The system of claim 14 wherein the apparatus comprises:
a source of fluid; and
a pump responsive to the output signal for controlling the flow of fluid to the hydraulic cylinder to control the movement of the piston and therefore the compression of the packer.
17. The system of claim 16 further comprising a motor for driving the pump, wherein the motor is responsive to the output signal for driving the pump.
18. A method for controlling the compression of a packer disposed in a well, comprising the steps of:
sensing the compression of the packer;
generating a corresponding output signal; and
changing the compression of the packer in response to the sensed compression deviating from a predetermined value.
19. The method of claim 18 wherein the step of changing comprises the step of increasing the compression of the packer to raise it back to the predetermined value.
20. The method of claim 18 further comprising the steps of:
receiving the output signal from the sensor;
processing the output signal from the sensor; and
providing a processed output signal corresponding to the compression of the packer;
wherein the step of changing is in response to the processed output signal.
21. The method of claim 18 wherein the step of sensing comprises the step of sensing the compressive strain on the packer.
22. The method of claim 18 wherein the step of sensing comprises the step of sensing the pressure on the packer.
23. The method of claim 18 wherein the step of sensing is done by a sensor mounted on, or embedded in, the packer.
24. The method of claim 18 further comprising the step of forming a cavity in the packer for receiving fluid, wherein the step of changing comprises the step of controlling the flow of fluid to the cavity for increasing the pressure of the packer.
25. The method of claim 24 wherein the step of changing further comprises the step of compressing the fluid before it flows to the cavity.
26. The method of claim 18 wherein the step of sensing comprises the step of providing a piston moveable in a hydraulic cylinder in response to the deviation in compression of the packer.
27. The method of claim 26 wherein movement of the piston causes changes in fluid pressure in the hydraulic cylinder, and the step of sensing further comprises the step of sensing the fluid pressure in the hydraulic cylinder.
28. The method of claim 26 wherein the step of changing comprises the step of pumping fluid into the hydraulic cylinder to control the movement of the piston and therefore the compression of the packer.
29. A system for controlling the compression of a packer disposed in a well, comprising:
means disposed in the well for sensing the compression of the packer and generating a corresponding output signal; and
means responsive to the output signal for changing the compression of the packer in response to the sensed compression deviating from a predetermined value.
Priority Applications (4)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/319,094 US20040112597A1 (en) | 2002-12-13 | 2002-12-13 | Packer set monitoring and compensating system and method |
DE60302635T DE60302635T2 (en) | 2002-12-13 | 2003-10-03 | Packer activation control and monitoring |
EP03256255A EP1428975B1 (en) | 2002-12-13 | 2003-10-03 | Packer set monitoring and control |
NO20034477A NO20034477L (en) | 2002-12-13 | 2003-10-07 | Method and system for controlling the compression of a gasket in a drilling well |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/319,094 US20040112597A1 (en) | 2002-12-13 | 2002-12-13 | Packer set monitoring and compensating system and method |
Publications (1)
Publication Number | Publication Date |
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US20040112597A1 true US20040112597A1 (en) | 2004-06-17 |
Family
ID=29420255
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US10/319,094 Abandoned US20040112597A1 (en) | 2002-12-13 | 2002-12-13 | Packer set monitoring and compensating system and method |
Country Status (4)
Country | Link |
---|---|
US (1) | US20040112597A1 (en) |
EP (1) | EP1428975B1 (en) |
DE (1) | DE60302635T2 (en) |
NO (1) | NO20034477L (en) |
Cited By (17)
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US20030231117A1 (en) * | 2002-06-13 | 2003-12-18 | Schultz Roger L. | System and method for monitoring packer slippage |
US20080236271A1 (en) * | 2007-03-29 | 2008-10-02 | Haoyue Zhang | Downhole seal assembly having embedded sensors and method for use of same |
US20110061862A1 (en) * | 2009-09-11 | 2011-03-17 | Schlumberger Technology Corporation | Instrumented swellable element |
CN102121367A (en) * | 2011-01-30 | 2011-07-13 | 蒯泽明 | Underground steam injection sealing, heat insulation and compensation integrated device |
WO2011079169A3 (en) * | 2009-12-23 | 2011-10-06 | Schlumberger Canada Limited | Hydraulic deployment of a well isolation mechanism |
US20120175135A1 (en) * | 2010-03-15 | 2012-07-12 | Schlumberger Technology Corporation | Packer deployed formation sensor |
WO2014088550A1 (en) * | 2012-12-04 | 2014-06-12 | Halliburton Energy Services, Inc | Packer setting tool |
WO2016099457A1 (en) * | 2014-12-16 | 2016-06-23 | Halliburton Energy Services, Inc. | Packer setting tool with internal pump |
US20170107782A1 (en) * | 2014-03-31 | 2017-04-20 | Romar International Limited | Method and System for Controlling Slip Joint Packer Activation |
US9689221B2 (en) | 2012-12-04 | 2017-06-27 | Halliburton Energy Services, Inc. | Packer setting tool |
CN107829705A (en) * | 2017-11-03 | 2018-03-23 | 西南石油大学 | A kind of inflatable packer component and packer |
ES2659836R1 (en) * | 2014-12-31 | 2018-05-08 | Halliburton Energy Services, Inc. | GRAVEL PACKAGING SYSTEM IN A WELL AND RELATED METHOD |
US10087698B2 (en) | 2015-12-03 | 2018-10-02 | General Electric Company | Variable ram packer for blowout preventer |
US10214986B2 (en) | 2015-12-10 | 2019-02-26 | General Electric Company | Variable ram for a blowout preventer and an associated method thereof |
US10428641B2 (en) * | 2015-04-17 | 2019-10-01 | Landmark Graphics Corporation | Draw-down pressure apparatus, systems, and methods |
US11125037B2 (en) * | 2018-04-30 | 2021-09-21 | Halliburton Energy Services, Inc. | Packer setting and real-time verification method |
US11230902B1 (en) * | 2020-10-07 | 2022-01-25 | Cnpc Usa Corporation | Interactive packer module and system for isolating and evaluating zones in a wellbore |
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ES2546432T3 (en) * | 2011-02-17 | 2015-09-23 | HYTORC Division Unex Corporation | Apparatus for adjusting threaded fasteners |
US20160130929A1 (en) * | 2014-11-06 | 2016-05-12 | Baker Hughes Incorporated | Property monitoring below a nonpenetrated seal |
US10731762B2 (en) | 2015-11-16 | 2020-08-04 | Baker Hughes, A Ge Company, Llc | Temperature activated elastomeric sealing device |
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Cited By (29)
Publication number | Priority date | Publication date | Assignee | Title |
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US6924745B2 (en) * | 2002-06-13 | 2005-08-02 | Halliburton Energy Services, Inc. | System and method for monitoring packer slippage |
US20030231117A1 (en) * | 2002-06-13 | 2003-12-18 | Schultz Roger L. | System and method for monitoring packer slippage |
US20080236271A1 (en) * | 2007-03-29 | 2008-10-02 | Haoyue Zhang | Downhole seal assembly having embedded sensors and method for use of same |
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US20120175135A1 (en) * | 2010-03-15 | 2012-07-12 | Schlumberger Technology Corporation | Packer deployed formation sensor |
US8960313B2 (en) * | 2010-03-15 | 2015-02-24 | Schlumberger Technology Corporation | Packer deployed formation sensor |
CN102121367A (en) * | 2011-01-30 | 2011-07-13 | 蒯泽明 | Underground steam injection sealing, heat insulation and compensation integrated device |
US9689221B2 (en) | 2012-12-04 | 2017-06-27 | Halliburton Energy Services, Inc. | Packer setting tool |
WO2014088550A1 (en) * | 2012-12-04 | 2014-06-12 | Halliburton Energy Services, Inc | Packer setting tool |
US8783340B2 (en) | 2012-12-04 | 2014-07-22 | Halliburton Energy Services, Inc. | Packer setting tool |
US20170107782A1 (en) * | 2014-03-31 | 2017-04-20 | Romar International Limited | Method and System for Controlling Slip Joint Packer Activation |
US10145200B2 (en) * | 2014-03-31 | 2018-12-04 | Romar International Limited | Method and system for controlling slip joint packer activation |
GB2545133A (en) * | 2014-12-16 | 2017-06-07 | Halliburton Energy Services Inc | Packer setting tool with internal pump |
GB2545133B (en) * | 2014-12-16 | 2020-12-23 | Halliburton Energy Services Inc | Packer setting tool with internal pump |
WO2016099457A1 (en) * | 2014-12-16 | 2016-06-23 | Halliburton Energy Services, Inc. | Packer setting tool with internal pump |
US10408005B2 (en) | 2014-12-16 | 2019-09-10 | Halliburton Energy Services, Inc. | Packer setting tool with internal pump |
ES2659836R1 (en) * | 2014-12-31 | 2018-05-08 | Halliburton Energy Services, Inc. | GRAVEL PACKAGING SYSTEM IN A WELL AND RELATED METHOD |
US10323488B2 (en) | 2014-12-31 | 2019-06-18 | Halliburton Energy Services, Inc. | Gravel pack service tool with enhanced pressure maintenance |
US10428641B2 (en) * | 2015-04-17 | 2019-10-01 | Landmark Graphics Corporation | Draw-down pressure apparatus, systems, and methods |
US10087698B2 (en) | 2015-12-03 | 2018-10-02 | General Electric Company | Variable ram packer for blowout preventer |
US10214986B2 (en) | 2015-12-10 | 2019-02-26 | General Electric Company | Variable ram for a blowout preventer and an associated method thereof |
CN107829705A (en) * | 2017-11-03 | 2018-03-23 | 西南石油大学 | A kind of inflatable packer component and packer |
US11125037B2 (en) * | 2018-04-30 | 2021-09-21 | Halliburton Energy Services, Inc. | Packer setting and real-time verification method |
US11230902B1 (en) * | 2020-10-07 | 2022-01-25 | Cnpc Usa Corporation | Interactive packer module and system for isolating and evaluating zones in a wellbore |
Also Published As
Publication number | Publication date |
---|---|
DE60302635T2 (en) | 2006-06-29 |
NO20034477L (en) | 2004-06-14 |
EP1428975B1 (en) | 2005-12-07 |
DE60302635D1 (en) | 2006-01-12 |
NO20034477D0 (en) | 2003-10-07 |
EP1428975A1 (en) | 2004-06-16 |
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Owner name: HALLIBURTON ENERGY SERVICES, INC., TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:HAMID, SYED;BAYH, RUSSELL, III;ZHANG, HAOYUE;REEL/FRAME:013878/0026;SIGNING DATES FROM 20030217 TO 20030218 |
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STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO PAY ISSUE FEE |