CA2373498C - Pressure sensor assembly for wellbore - Google Patents
Pressure sensor assembly for wellbore Download PDFInfo
- Publication number
- CA2373498C CA2373498C CA002373498A CA2373498A CA2373498C CA 2373498 C CA2373498 C CA 2373498C CA 002373498 A CA002373498 A CA 002373498A CA 2373498 A CA2373498 A CA 2373498A CA 2373498 C CA2373498 C CA 2373498C
- Authority
- CA
- Canada
- Prior art keywords
- sensor
- sub
- passage
- formation
- pressure
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired - Lifetime
Links
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 45
- 239000012530 fluid Substances 0.000 claims abstract description 22
- 230000005540 biological transmission Effects 0.000 claims abstract description 14
- 239000004568 cement Substances 0.000 claims abstract description 11
- 238000004891 communication Methods 0.000 claims abstract description 8
- 239000002800 charge carrier Substances 0.000 claims description 8
- 239000003921 oil Substances 0.000 claims description 5
- 239000004519 grease Substances 0.000 claims description 4
- XUIMIQQOPSSXEZ-UHFFFAOYSA-N Silicon Chemical compound [Si] XUIMIQQOPSSXEZ-UHFFFAOYSA-N 0.000 claims description 3
- 229910052710 silicon Inorganic materials 0.000 claims description 3
- 239000010703 silicon Substances 0.000 claims description 3
- 238000005474 detonation Methods 0.000 claims description 2
- 239000002360 explosive Substances 0.000 description 4
- 238000012544 monitoring process Methods 0.000 description 4
- 230000003213 activating effect Effects 0.000 description 3
- 239000012212 insulator Substances 0.000 description 3
- 230000000149 penetrating effect Effects 0.000 description 3
- 230000000712 assembly Effects 0.000 description 2
- 238000000429 assembly Methods 0.000 description 2
- 238000009530 blood pressure measurement Methods 0.000 description 2
- 239000004020 conductor Substances 0.000 description 2
- 230000001012 protector Effects 0.000 description 2
- 238000005553 drilling Methods 0.000 description 1
- 238000010304 firing Methods 0.000 description 1
- 230000009545 invasion Effects 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 238000000034 method Methods 0.000 description 1
- 230000001681 protective effect Effects 0.000 description 1
Classifications
-
- 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
-
- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/11—Perforators; Permeators
-
- 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
- E21B47/01—Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
Abstract
A casing-conveyed downhole pressure sensor assembly is provided. The assembly comprises a first sub that forms a charge chamber and a passage in fluid communication with the adjacent external formation. A second sub forms a sensor chamber containing a pressure sensor. The sensor is connected by a conduit with the passage so that the conduit and passage together form a passageway for transmitting formation pressure to the sensor. A shaped charge is positioned in the charge chamber and is oriented so that, when the charge is detonated, it forms a perforation intersecting the passage and extending through the cement layer into the formation. Thus an optional 'back up' pressure transmission passageway is available.
Description
1 "PRESSURE SENSOR ASSEMBLY FOR WELLBORE"
2
3 FIELD OF THE INVENTION
4 The present invention relates to a casing - conveyed sensor assembly for use in a wellbore to measure a subterranean formation condition, such as pressure.
9 Casing-conveyed downhole pressure sensors are presently used in the oil/gas industry, to monitor pressure in a subterranean formation. A conventional downhole 11 pressure monitoring system comprises:
12 = a pad or housing which is secured at ground surface to the exterior surface of a 13 joint of tubular casing - the joint is run into a wellbore as part of a casing string with 14 the result that the housing is located opposite the subterranean formation whose pressure is to be monitored;
16 = the side wall of the housing forms an interior chamber in which is mounted the 17 pressure sensor;
18 = a cable extends down the wellbore and is secured to the outside surface of the 19 casing string - wiring in the cable is connected to the sensor, for providing power to it and conveying signals indicative of pressure measurement to recording means at 21 ground surface;
22 = the sensor is sealed within the sensor chamber by suitable seal means, to keep it 23 dry; and {E5160467.DOC;5}
1 = a pressure port or passageway extends from the sensor chamber through the 2 housing side wall to the exterior surface of the housing - the port and sensor chamber 3 are packed with a filling of oil and grease, which function to isolate the sensor means 4 from wellbore or formation fluid and which act as a pressure transmission medium.
The casing string is cemented in place within the wellbore. As a result, a layer 6 of cement fills the annular space defined between the casing string and the wellbore.
7 The layer of cement is usually sufficiently porous and thin enough so that formation 8 fluid pressure can penetrate therethrough to reach and pressurize the pressure 9 transmission medium. As a result, measurements of formation pressure can be taken by the sensor.
11 However, in some cases it has been found that formation pressure does not 12 reach the sensor. This may be due to invasion by the cement out into the formation 13 or plugging of the pressure port with cement or an impermeable drilling fluid filter 14 cake. It therefore is desirable to provide a sensor assembly adapted to overcome this problem, should it arise.
18 The present invention is preferably concerned with a pressure sensor assembly 19 for use downhole in a wellbore as part of a pressure monitoring system. A
preferred embodiment of the sensor assembly comprises:
21 = housing means for conveyance on well casing, the housing means forming a 22 sensor chamber and a separate charge chamber;
{E5160467.DOC;5}
1 = a pressure sensor positioned in the sensor chamber, operative to measure 2 formation pressure for transmittal to ground surface, for example through a 3 monitoring system cable;
4= = a shaped explosive perforating charge positioned in the charge chamber.
The perforating charge can be detonated from ground surface using means such as suitable 6 wiring incorporated in the monitoring system cable;
7 = the housing means forms a passageway, containing pressure transmission 8 medium, connecting the sensor with the exterior surface of the housing means; and 9 = the passageway is positioned in the path of the jet produced by detonating the perforating charge.
11 As a result of this combination, if desired one can detonate the perforating charge to 12 produce a jet which creates a perforation extending through the housing side wall and 13 the cement layer to penetrate the formation. This perforation will cross or intersect 14 the pressure transmission passageway. As a result, formation fluid may enter through the jet perforation and reach the passageway to apply its pressure to the sensor 16 through the pressure transmission medium.
17 A single housing may be used to form both the sensor and perforating 18 chambers. Alternatively, the perforating chamber and part of the pressure 19 transmission passageway can be provided in a second housing, forming part of the housing means.
{E5160467.DOC;5}
1 While the invention is described in connection with a pressure sensor, it will 2 be understood that it can be applied with other instrumentation for measuring another 3 formation condition, such as temperature. Therefore the words "formation condition 4 measuring", used to modify "sensor" or "sensor assembly", are to be widely interpreted.
6 In accordance with the invention, therefore, a casing-conveyed condition 7 measuring sensor, contained in a protective housing means, is combined with 8 selectively activatable means for forming a perforation (for example, a shaped 9 explosive perforating charge). The perforation-forming means is capable of forming an outwardly directed perforation extending through the external cement layer and 11 into the formation. The charge is oriented so that the perforation produced will 12 intersect the pressure transmission passageway. The perforation and passageway will 13 thus combine to enable formation pressure or the like to reach the sensor.
The 14 perforation-forming means may be contained within the housing means or may be external of it.
16 Broadly stated, in one embodiment the invention is concerned with an 17 apparatus for measuring a condition of a subterranean formation, comprising: a first 18 sub having a passage in fluid communication with the formation fluid outside of the 19 first sub, the first sub adapted to be fixed on a casing for positioning in a wellbore; a second sub for positioning adjacent to the first sub, the second sub including a sensor 21 for measuring a condition of the formation and a conduit hydraulically coupled to the 22 first sub passage, the sensor communicating with the formation fluid via the conduit 23 and the passage; and a charge carrier disposed adjacent the first sub passage, the 24 charge carrier including at least one selectively activatable means for forming a {E5160467.DOC;5) 1 perforation that intersects the passage and extends into a cement surrounding the first 2 sub upon detonation, the at least one selectively activatable means being activated to 3 increase the fluid communication between the sensor and the formation fluid.
4 In another embodiment, the invention is concerned with a method for
9 Casing-conveyed downhole pressure sensors are presently used in the oil/gas industry, to monitor pressure in a subterranean formation. A conventional downhole 11 pressure monitoring system comprises:
12 = a pad or housing which is secured at ground surface to the exterior surface of a 13 joint of tubular casing - the joint is run into a wellbore as part of a casing string with 14 the result that the housing is located opposite the subterranean formation whose pressure is to be monitored;
16 = the side wall of the housing forms an interior chamber in which is mounted the 17 pressure sensor;
18 = a cable extends down the wellbore and is secured to the outside surface of the 19 casing string - wiring in the cable is connected to the sensor, for providing power to it and conveying signals indicative of pressure measurement to recording means at 21 ground surface;
22 = the sensor is sealed within the sensor chamber by suitable seal means, to keep it 23 dry; and {E5160467.DOC;5}
1 = a pressure port or passageway extends from the sensor chamber through the 2 housing side wall to the exterior surface of the housing - the port and sensor chamber 3 are packed with a filling of oil and grease, which function to isolate the sensor means 4 from wellbore or formation fluid and which act as a pressure transmission medium.
The casing string is cemented in place within the wellbore. As a result, a layer 6 of cement fills the annular space defined between the casing string and the wellbore.
7 The layer of cement is usually sufficiently porous and thin enough so that formation 8 fluid pressure can penetrate therethrough to reach and pressurize the pressure 9 transmission medium. As a result, measurements of formation pressure can be taken by the sensor.
11 However, in some cases it has been found that formation pressure does not 12 reach the sensor. This may be due to invasion by the cement out into the formation 13 or plugging of the pressure port with cement or an impermeable drilling fluid filter 14 cake. It therefore is desirable to provide a sensor assembly adapted to overcome this problem, should it arise.
18 The present invention is preferably concerned with a pressure sensor assembly 19 for use downhole in a wellbore as part of a pressure monitoring system. A
preferred embodiment of the sensor assembly comprises:
21 = housing means for conveyance on well casing, the housing means forming a 22 sensor chamber and a separate charge chamber;
{E5160467.DOC;5}
1 = a pressure sensor positioned in the sensor chamber, operative to measure 2 formation pressure for transmittal to ground surface, for example through a 3 monitoring system cable;
4= = a shaped explosive perforating charge positioned in the charge chamber.
The perforating charge can be detonated from ground surface using means such as suitable 6 wiring incorporated in the monitoring system cable;
7 = the housing means forms a passageway, containing pressure transmission 8 medium, connecting the sensor with the exterior surface of the housing means; and 9 = the passageway is positioned in the path of the jet produced by detonating the perforating charge.
11 As a result of this combination, if desired one can detonate the perforating charge to 12 produce a jet which creates a perforation extending through the housing side wall and 13 the cement layer to penetrate the formation. This perforation will cross or intersect 14 the pressure transmission passageway. As a result, formation fluid may enter through the jet perforation and reach the passageway to apply its pressure to the sensor 16 through the pressure transmission medium.
17 A single housing may be used to form both the sensor and perforating 18 chambers. Alternatively, the perforating chamber and part of the pressure 19 transmission passageway can be provided in a second housing, forming part of the housing means.
{E5160467.DOC;5}
1 While the invention is described in connection with a pressure sensor, it will 2 be understood that it can be applied with other instrumentation for measuring another 3 formation condition, such as temperature. Therefore the words "formation condition 4 measuring", used to modify "sensor" or "sensor assembly", are to be widely interpreted.
6 In accordance with the invention, therefore, a casing-conveyed condition 7 measuring sensor, contained in a protective housing means, is combined with 8 selectively activatable means for forming a perforation (for example, a shaped 9 explosive perforating charge). The perforation-forming means is capable of forming an outwardly directed perforation extending through the external cement layer and 11 into the formation. The charge is oriented so that the perforation produced will 12 intersect the pressure transmission passageway. The perforation and passageway will 13 thus combine to enable formation pressure or the like to reach the sensor.
The 14 perforation-forming means may be contained within the housing means or may be external of it.
16 Broadly stated, in one embodiment the invention is concerned with an 17 apparatus for measuring a condition of a subterranean formation, comprising: a first 18 sub having a passage in fluid communication with the formation fluid outside of the 19 first sub, the first sub adapted to be fixed on a casing for positioning in a wellbore; a second sub for positioning adjacent to the first sub, the second sub including a sensor 21 for measuring a condition of the formation and a conduit hydraulically coupled to the 22 first sub passage, the sensor communicating with the formation fluid via the conduit 23 and the passage; and a charge carrier disposed adjacent the first sub passage, the 24 charge carrier including at least one selectively activatable means for forming a {E5160467.DOC;5) 1 perforation that intersects the passage and extends into a cement surrounding the first 2 sub upon detonation, the at least one selectively activatable means being activated to 3 increase the fluid communication between the sensor and the formation fluid.
4 In another embodiment, the invention is concerned with a method for
5 connecting a subterranean formation with a formation condition measuring sensor,
6 comprising: providing a downhole sensor assembly, externally conveyed on a string
7 of casing cemented in a wellbore so that the sensor assembly is located opposite the
8 formation, the sensor assembly comprising housing means containing a sensor for
9 measuring the formation condition and means for forming, when activated, an outwardly directed perforation penetrating into the formation and operative to enable 11 the formation condition to reach the sensor; and activating the perforation-forming 12 means from ground surface, when required, to form the perforation.
Figure 1 is a schematic side view showing a wellbore, cemented casing string, 16 and casing-conveyed downhole pressure sensor assembly positioned opposite a 17 subterranean formation;
18 Figure 2 is a partly sectional side elevation showing a perforating charge in a 19 separate lower housing; and Figure 3 is a partly sectional side elevation showing a pressure sensor in a 21 separate upper housing, for use with the assembly of Figure 2.
{85160467.DOC;5}
2 The invention involves the concept of 3 = providing perforation-forming means, such as a shaped explosive perforating 4 charge, in association with a downhole sensor assembly having housing means containing a sensor, such as a pressure sensor, in a sensor chamber, the sensor 6 assembly being mounted to the exterior surface of a casing string, often 7 cemented, in a wellbore penetrating a subterranean formation, said housing 8 means having a passageway connecting the sensor with the outside surface of the 9 housing means; and = activating the perforation-forming means from ground surface, when required, to 11 form a perforation intersecting the passageway and extending into the formation, 12 the perforation therefore being in conimunication with the sensor to enable 13 pressure transmission between the formation and the sensor.
14 Figures 1- 3 show a preferred embodiment for implementing the invention.
However, it will be apparent to those skilled in the art that various alternatives can be 16 used to implement the steps just described.
17 In this embodiment, a downhole pressure sensor assembly 1 is provided. The 18 sensor assembly 1 will have been secured to the exterior surface 2 of a casing joint 4 19 forming part of a casing string 5, prior to running the string into a wellbore 6. The casing string 5 is cemented in place in the wellbore 6. The sensor assembly 1 is 21 positioned opposite a subterranean formation 7, whose pressure is to be monitored. A
22 layer 8 of cement surrounds the casing joint 4 and sensor assembly 1. A
cable 9 23 extends from ground surface 10 along the outer surface of the casing string 5. The 24 cable 9 is operatively connected with the sensor assembly 1 to power the electronics {E5160467.DOC;5 }
1 (not shown) of a conventional pressure sensor 11 and convey pressure measurement 2 signals back to a data recorder 12 at ground surface 10.
3 The sensor assembly 1 comprises a charge housing 13 formed by a bottom 4 protector nose sub 14, a standoff pressure port sub 15 and a top protector nose sub 16.
The subs 14, 15, 16 are connected together by socket bolts 17 to form a first sub.
6 The side wall 18 of the port sub 15 forms an internal perforating charge 7 chamber 19. A charge carrier 20 is positioned in the chamber 19. This charge carrier 8 20 has a locator sub 21 at its base which includes a pin 22, which seats in a pin hole 9 23 formed in the bottom wall 24 of the port sub 15 to orient the carrier 20.
One or more shaped explosive perforating charges 25 are carried by the carrier 20. A
11 conductor 26 from the cable 9 connects to a firing boot 27, for activating or 12 detonating the detonator of the charge 25. The carrier 20 is suspended at its upper 13 end from a connector insulator block 28 which closes the top end of the charge 14 chamber 19. The connector insulator block 28 is sealed by 0-rings 29 with the interior surface 30 of the port sub 15. The connector insulator block 28 forms an axial 16 bore 32. A top connector block 33, having an axial bore 34, is threaded into the upper 17 end of the bore 32. The conductor 26 extends through the axial bores 32, 34 and 18 continues through the cable 9 to ground surface 10.
19 The side wall 18 of the port sub 15 also forms a pressure port or passage having horizontal and vertical sections 36, 37. The pressure passage radial section 36 21 terminates in an opening at the outer surface 39 of the port sub 15. A
connector 40 is 22 screwed into the upper end 41 of the port vertical section 37. The connector 40 23 connects with a conduit 42 extending up through a top aperture 43 formed through the 24 top nose sub 16.
{E5160467.DOC;5}
1 The sensor assembly 1 further comprises a sensor housing 50 formed by a 2 bottom sub 51, sensor sub 52 and top sub 53, connected together by socket bolts 54 to 3 form a second sub.
4 The sensor sub 52 forms a chamber 55 in which is positioned a pressure sensor 11.
6 The sensor 11 is connected at its upper end by wiring 57 through a bulkhead 7 60 to the cable clamp 58 of the cable 9. Suitable wiring (not shown) forming part of 8 the cable 9 provides connection between the sensor wiring 57 and recording means 12 9 at ground surface.
At its lower end, the sensor 11 is connectrd through a bulkhead 70 with the 11 conduit 42 extending from the pressure passage 35.
12 Thus, formation pressure, transmitted through the pressure passage 35 and 13 conduit 42 and their contained grease and silicon oil medium , collectively forming a 14 pressure transmission passageway, reaches the sensor 11 under normal operation.
Otherwise stated, the sensor 11 is hydraulically coupled with the formation.
16 However, in the event the formation pressure is not being transmitted through the 17 pressure passageway, a perforating charge 25 can be detonated to form a perforation 18 intersecting passage 35 and penetrating through the cement layer 8 into the formation 19 7.
It will be appreciated by those skilled in the art that downhole perforating 21 charge assemblies and pressure-measuring sensor assemblies are conventional and 22 require no detailed description. It is their combination and the orientation of the 23 charge and pressure passage that come together to yield the desired objective.
{E5160467.DOC;5}
Figure 1 is a schematic side view showing a wellbore, cemented casing string, 16 and casing-conveyed downhole pressure sensor assembly positioned opposite a 17 subterranean formation;
18 Figure 2 is a partly sectional side elevation showing a perforating charge in a 19 separate lower housing; and Figure 3 is a partly sectional side elevation showing a pressure sensor in a 21 separate upper housing, for use with the assembly of Figure 2.
{85160467.DOC;5}
2 The invention involves the concept of 3 = providing perforation-forming means, such as a shaped explosive perforating 4 charge, in association with a downhole sensor assembly having housing means containing a sensor, such as a pressure sensor, in a sensor chamber, the sensor 6 assembly being mounted to the exterior surface of a casing string, often 7 cemented, in a wellbore penetrating a subterranean formation, said housing 8 means having a passageway connecting the sensor with the outside surface of the 9 housing means; and = activating the perforation-forming means from ground surface, when required, to 11 form a perforation intersecting the passageway and extending into the formation, 12 the perforation therefore being in conimunication with the sensor to enable 13 pressure transmission between the formation and the sensor.
14 Figures 1- 3 show a preferred embodiment for implementing the invention.
However, it will be apparent to those skilled in the art that various alternatives can be 16 used to implement the steps just described.
17 In this embodiment, a downhole pressure sensor assembly 1 is provided. The 18 sensor assembly 1 will have been secured to the exterior surface 2 of a casing joint 4 19 forming part of a casing string 5, prior to running the string into a wellbore 6. The casing string 5 is cemented in place in the wellbore 6. The sensor assembly 1 is 21 positioned opposite a subterranean formation 7, whose pressure is to be monitored. A
22 layer 8 of cement surrounds the casing joint 4 and sensor assembly 1. A
cable 9 23 extends from ground surface 10 along the outer surface of the casing string 5. The 24 cable 9 is operatively connected with the sensor assembly 1 to power the electronics {E5160467.DOC;5 }
1 (not shown) of a conventional pressure sensor 11 and convey pressure measurement 2 signals back to a data recorder 12 at ground surface 10.
3 The sensor assembly 1 comprises a charge housing 13 formed by a bottom 4 protector nose sub 14, a standoff pressure port sub 15 and a top protector nose sub 16.
The subs 14, 15, 16 are connected together by socket bolts 17 to form a first sub.
6 The side wall 18 of the port sub 15 forms an internal perforating charge 7 chamber 19. A charge carrier 20 is positioned in the chamber 19. This charge carrier 8 20 has a locator sub 21 at its base which includes a pin 22, which seats in a pin hole 9 23 formed in the bottom wall 24 of the port sub 15 to orient the carrier 20.
One or more shaped explosive perforating charges 25 are carried by the carrier 20. A
11 conductor 26 from the cable 9 connects to a firing boot 27, for activating or 12 detonating the detonator of the charge 25. The carrier 20 is suspended at its upper 13 end from a connector insulator block 28 which closes the top end of the charge 14 chamber 19. The connector insulator block 28 is sealed by 0-rings 29 with the interior surface 30 of the port sub 15. The connector insulator block 28 forms an axial 16 bore 32. A top connector block 33, having an axial bore 34, is threaded into the upper 17 end of the bore 32. The conductor 26 extends through the axial bores 32, 34 and 18 continues through the cable 9 to ground surface 10.
19 The side wall 18 of the port sub 15 also forms a pressure port or passage having horizontal and vertical sections 36, 37. The pressure passage radial section 36 21 terminates in an opening at the outer surface 39 of the port sub 15. A
connector 40 is 22 screwed into the upper end 41 of the port vertical section 37. The connector 40 23 connects with a conduit 42 extending up through a top aperture 43 formed through the 24 top nose sub 16.
{E5160467.DOC;5}
1 The sensor assembly 1 further comprises a sensor housing 50 formed by a 2 bottom sub 51, sensor sub 52 and top sub 53, connected together by socket bolts 54 to 3 form a second sub.
4 The sensor sub 52 forms a chamber 55 in which is positioned a pressure sensor 11.
6 The sensor 11 is connected at its upper end by wiring 57 through a bulkhead 7 60 to the cable clamp 58 of the cable 9. Suitable wiring (not shown) forming part of 8 the cable 9 provides connection between the sensor wiring 57 and recording means 12 9 at ground surface.
At its lower end, the sensor 11 is connectrd through a bulkhead 70 with the 11 conduit 42 extending from the pressure passage 35.
12 Thus, formation pressure, transmitted through the pressure passage 35 and 13 conduit 42 and their contained grease and silicon oil medium , collectively forming a 14 pressure transmission passageway, reaches the sensor 11 under normal operation.
Otherwise stated, the sensor 11 is hydraulically coupled with the formation.
16 However, in the event the formation pressure is not being transmitted through the 17 pressure passageway, a perforating charge 25 can be detonated to form a perforation 18 intersecting passage 35 and penetrating through the cement layer 8 into the formation 19 7.
It will be appreciated by those skilled in the art that downhole perforating 21 charge assemblies and pressure-measuring sensor assemblies are conventional and 22 require no detailed description. It is their combination and the orientation of the 23 charge and pressure passage that come together to yield the desired objective.
{E5160467.DOC;5}
Claims (16)
1. An apparatus for measuring a condition of a subterranean formation, comprising:
(a) a first sub having a passage in fluid communication with the formation fluid outside of the first sub, the first sub adapted to be fixed on a casing for positioning in a wellbore;
(b) a second sub for positioning adjacent to the first sub, the second sub including a sensor for measuring a condition of the formation and a conduit hydraulically coupled to the first sub passage, the sensor communicating with the formation fluid via the conduit and the passage; and (c) a charge carrier disposed adjacent the first sub passage, the charge carrier including at least one selectively activatable means for forming a perforation that intersects the passage and extends into a cement surrounding the first sub upon detonation, the at least one selectively activatable means being activated to increase the fluid communication between the sensor and the formation fluid.
(a) a first sub having a passage in fluid communication with the formation fluid outside of the first sub, the first sub adapted to be fixed on a casing for positioning in a wellbore;
(b) a second sub for positioning adjacent to the first sub, the second sub including a sensor for measuring a condition of the formation and a conduit hydraulically coupled to the first sub passage, the sensor communicating with the formation fluid via the conduit and the passage; and (c) a charge carrier disposed adjacent the first sub passage, the charge carrier including at least one selectively activatable means for forming a perforation that intersects the passage and extends into a cement surrounding the first sub upon detonation, the at least one selectively activatable means being activated to increase the fluid communication between the sensor and the formation fluid.
2. The apparatus according to claim 1 wherein the passage is at least partially filled with a pressure transmission medium.
3. The apparatus according to claim 2 wherein the pressure transmission medium includes one of (i) grease, and (ii) silicon oil.
4. The apparatus according to claims 1, 2, or 3 further comprising an orienting means to orient the charge carrier.
5. The apparatus according to claims 1, 2, 3, or 4 further comprising:
(a) a surface recorder; and (b) a cable for conducting electronic signals from the sensor to the surface recorder.
(a) a surface recorder; and (b) a cable for conducting electronic signals from the sensor to the surface recorder.
6. The apparatus according to any one of claims 1 to 5 wherein the sensor measures pressure.
7. The apparatus according to claim 1 wherein the first sub and the second sub are positioned in a single housing.
8. The apparatus according to any one of claims 1 to 7 wherein the selectively activatable means includes a shaped charge.
9. An apparatus adapted to measure a condition of a subterranean formation intersected by a wellbore having a cemented casing, comprising:
(a) a sensor measuring the condition via a fluid passage terminating at an opening on a sub fixed to an exterior of the casing, the fluid passage thereby providing fluid communication between the sensor and the exterior of the casing; and (b) at least one selectively activatable means positioned adjacent the passage for forming a perforation that intersects the passage, the activatable means being activated to increase the fluid communication between the sensor and the formation fluid if the fluid passage does not provide sufficient fluid communication.
(a) a sensor measuring the condition via a fluid passage terminating at an opening on a sub fixed to an exterior of the casing, the fluid passage thereby providing fluid communication between the sensor and the exterior of the casing; and (b) at least one selectively activatable means positioned adjacent the passage for forming a perforation that intersects the passage, the activatable means being activated to increase the fluid communication between the sensor and the formation fluid if the fluid passage does not provide sufficient fluid communication.
10. The apparatus according to claim 9 wherein the passage is at least partially filled with a pressure transmission medium.
11. The apparatus according to claim 10 wherein the pressure transmission medium is selected from the group consisting of grease, and silicon oil.
12. The apparatus according to claims 9, 10, or 11 further comprising an orienting means positioned in the chamber to orient the charge carrier.
13. The apparatus according to any one of claims 9 to 12 further comprising:
(a) a surface recorder; and (b) a cable conducting electronic signals from the sensor to the surface recorder.
(a) a surface recorder; and (b) a cable conducting electronic signals from the sensor to the surface recorder.
14. The apparatus according to any one of claims 9 to 13 wherein the sensor measures pressure.
15. The apparatus according to any one of claims 9 to 14 wherein the selectively activatable means can be activated from the surface.
16. The apparatus according to claim 15 wherein the selectively activatable means includes a shaped charge.
Priority Applications (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002373498A CA2373498C (en) | 2002-02-27 | 2002-02-27 | Pressure sensor assembly for wellbore |
| US10/085,030 US20030164037A1 (en) | 2002-02-27 | 2002-03-01 | Pressure sensor assembly for wellbore |
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002373498A CA2373498C (en) | 2002-02-27 | 2002-02-27 | Pressure sensor assembly for wellbore |
| US10/085,030 US20030164037A1 (en) | 2002-02-27 | 2002-03-01 | Pressure sensor assembly for wellbore |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2373498A1 CA2373498A1 (en) | 2003-08-27 |
| CA2373498C true CA2373498C (en) | 2009-05-19 |
Family
ID=29713003
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002373498A Expired - Lifetime CA2373498C (en) | 2002-02-27 | 2002-02-27 | Pressure sensor assembly for wellbore |
Country Status (2)
| Country | Link |
|---|---|
| US (1) | US20030164037A1 (en) |
| CA (1) | CA2373498C (en) |
Families Citing this family (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7343970B2 (en) * | 2003-12-04 | 2008-03-18 | Schlumberger Technology Corporation | Real time optimization of well production without creating undue risk of formation instability |
| US7637318B2 (en) * | 2006-03-30 | 2009-12-29 | Halliburton Energy Services, Inc. | Pressure communication assembly external to casing with connectivity to pressure source |
| US8127832B1 (en) * | 2006-09-20 | 2012-03-06 | Bond Lesley O | Well stimulation using reaction agents outside the casing |
| US20120048539A1 (en) * | 2010-08-24 | 2012-03-01 | Baker Hughes Incorporated | Reservoir Pressure Monitoring |
| US9488034B2 (en) * | 2011-04-12 | 2016-11-08 | Halliburton Energy Services, Inc. | Opening a conduit cemented in a well |
| CN102536202B (en) * | 2012-03-12 | 2012-12-05 | 中国石油大学(华东) | Method for manufacturing test piece for testing gas storage well completion sleeve-cement ring bonding strength |
| US9631462B2 (en) * | 2013-04-24 | 2017-04-25 | Baker Hughes Incorporated | One trip perforation and flow control method |
| US9970286B2 (en) * | 2015-01-08 | 2018-05-15 | Sensor Developments As | Method and apparatus for permanent measurement of wellbore formation pressure from an in-situ cemented location |
| CN113216933B (en) * | 2021-05-12 | 2023-12-22 | 中煤科工集团西安研究院有限公司 | Pressure release cabin, device and method for testing hydraulic conveying sieve tube in drill rod |
-
2002
- 2002-02-27 CA CA002373498A patent/CA2373498C/en not_active Expired - Lifetime
- 2002-03-01 US US10/085,030 patent/US20030164037A1/en not_active Abandoned
Also Published As
| Publication number | Publication date |
|---|---|
| US20030164037A1 (en) | 2003-09-04 |
| CA2373498A1 (en) | 2003-08-27 |
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