GB2356209A - Method and apparatus for deployment mounting and coupling of downhole geophones - Google Patents
Method and apparatus for deployment mounting and coupling of downhole geophones Download PDFInfo
- Publication number
- GB2356209A GB2356209A GB0027658A GB0027658A GB2356209A GB 2356209 A GB2356209 A GB 2356209A GB 0027658 A GB0027658 A GB 0027658A GB 0027658 A GB0027658 A GB 0027658A GB 2356209 A GB2356209 A GB 2356209A
- Authority
- GB
- United Kingdom
- Prior art keywords
- wellbore
- tubing
- acoustic
- acoustic device
- packer
- 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.)
- Granted
Links
- 238000000034 method Methods 0.000 title claims abstract description 23
- 238000010168 coupling process Methods 0.000 title claims description 22
- 230000008878 coupling Effects 0.000 title claims description 20
- 238000005859 coupling reaction Methods 0.000 title claims description 20
- 238000004873 anchoring Methods 0.000 claims abstract description 35
- 238000004519 manufacturing process Methods 0.000 description 11
- 230000015572 biosynthetic process Effects 0.000 description 6
- 238000012544 monitoring process Methods 0.000 description 5
- 238000004891 communication Methods 0.000 description 3
- 239000012530 fluid Substances 0.000 description 3
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 230000003287 optical effect Effects 0.000 description 3
- 239000004568 cement Substances 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000003325 tomography Methods 0.000 description 2
- 238000003491 array Methods 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 239000004020 conductor Substances 0.000 description 1
- 230000002950 deficient Effects 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 239000000835 fiber Substances 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 230000002452 interceptive effect Effects 0.000 description 1
- 238000002955 isolation Methods 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/40—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
- G01V1/52—Structural details
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/01—Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V11/00—Prospecting or detecting by methods combining techniques covered by two or more of main groups G01V1/00 - G01V9/00
- G01V11/002—Details, e.g. power supply systems for logging instruments, transmitting or recording data, specially adapted for well logging, also if the prospecting method is irrelevant
- G01V11/005—Devices for positioning logging sondes with respect to the borehole wall
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Physics & Mathematics (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Geophysics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- General Physics & Mathematics (AREA)
- Acoustics & Sound (AREA)
- Remote Sensing (AREA)
- Geophysics And Detection Of Objects (AREA)
- Earth Drilling (AREA)
- Investigating Or Analyzing Materials By The Use Of Ultrasonic Waves (AREA)
Abstract
A method of and system for anchoring at least one acoustic device 40 against a borehole or wellbore wall 14 where the acoustic device 40 is attached to an anchoring device 20; a tubing 18, provided with the anchoring and acoustic devices, is then placed within a borehole and the anchoring device 20 is extended to the borehole wall 14 in order to couple the acoustic device to the borehole wall 14. The acoustic device may include at least one of a plurality of seismic motion sensors; at least one source and a combination including at least one acoustic source and at least one acoustic detector. The acoustic device may be attached to the anchoring device so that the acoustic device is located in the annulus between the tubing and the borehole wall when the tubing is placed in the borehole.
Description
2356209 QROSS REFERENCES TO RELATr;D APPLIC A-1-IONS This application
claims pdorlity from United States Provisional. Application Serial Number 60/165,272 filed on November 12, 1999.
BMKGLZOUND OF THE INVENIM I Field of JbgI l"y Mlon
This invention relates to downhole seismic services and more particularly to a method for deployment, mounting and coupling of motion sensors and sources downhole.
2. Description of the Related Art
Seismic sources and sensors are often deployed in wellbores for a variety of oilfield operations, including monitoring of lhjectlon well operations, fractuflng operations, performing "Seismic-profiling" surveys to obtain enhanced subsurface seismic maps and monitoring downhole vibrations. Such operations include slim-to large-diameter boreholes, vertical to horizontal wells, open and cased holes, and high pressure and high temperature wells. Downhole sensors are sometimes utilized in combination with other logging services, either wireline, coiled tubingconveyed, or with pipe to pruvide addifional reservoir information,
Seismic sensors deployed in wellbores are particularly useful to monitor fracturing and injection well operations, to generate cross-well infonnation and to obtain seismic; measurements overtime, to obtain enhanced subsurface maps and 2. to improve reservoir modeling. However, the majority of seismic data gathering is accomplished by wireline methods or by deploying seismic sensors such as gsophones on coiled tubing or production pipe. Multi- component geophones; are usually preferred for such applications, Multil- component geophones sense motion in one or more directions. An example Is the classical three (3) component geophone which detects particle motion in three mutually orthogonal directions (x, y and z directions).
An inherent problem with commonly utilized deployment methods for motion sensors in weilbores is the presence of high amplitude vibrations. The high amplitude vibrations may be due to the motion of the wirellne or tubing used to cany these sensors in the wellbore. Even when these motion sensors are attached to the tubing, the sensors are subjected to substantial undesired motion due to the movement of the tubing in the wellbore or other operating factors, Ideally, a sensor deployment system should be free of all motion, thus enabling the sensors to accurately detect motion due to Induced acoustic signals. Presence of spurious motion associated with movement of the tubing in the wellbore can significantly reduce the signal to noise ratlo and mask the desired seismic signal in a high amplitude noise field.
Thus there is a need for a method and apparatus that reduces motion and noise associated with movement of tubing in the wellbore, 3 SUMMARY-OE-T-HE INVENTION
Geophones which are rigidly coupled to the wellbore, particularly in production wells, can provide high fidelity signals, i.e., with high signal to noise ratio. Such sensors are less likely to resonate. Distributed sensors can provide measurements useful for a number af applications, including monitoring of fracturing, seismic-profiling surveys, cross-well tomography and monitoring of injection operations.
Directly coupling of the seismic receVers to the borehole, wherein the coupling force is substantally greater then the radial and axial force on the sensor due to operating conditions, provides signals with the desired high fidelity.
Inadequate or defective coupling, however, induces distortion of seismic wavelets, including date amplitude loss, phase change and bandwidth reduction. Downhole ambient noise can swamp recorded.data. It is also well known that the quality of the data detected by the motion sensors improves with the use of receiver arrays (distributed sensors) and with the acquieftion of redundant date.
Seismic sources are also placed in wellbores to Induce acoustic waves in the formation for the kinds of operations described above with respect to receivers. Vibratory sources are often used as the acoustic sources. Directly coupling of the acoustic source in the wellbore greatly impacts the amount of energy transmitted Into the fonnation. Smaller sources can be utilized with direot coupling because the energy loss between the source location and the receiver(s) is reduced.
1-1, In one aspect, the present invention provides a method of placing acoustic devices in wellbores. The method Includes providing a tubing with at least one anchoring device in the wellbore, the anchoring device being extendable to the wellbore to exert a predetermined force on the wellbore, and attaching at least one acoustic device to at least one anchoring device; placing the tubing in the at least one acoustic device attached to at least one anchoring device in the wellbore; and setting the anchoring device to extend to the wellbore to exert a predetermined force on the wellbore, thereby coupling the acoustic device to the wellbore. The acoustic device is attached to the anchoring device so that the acoustic device would be located in an annulus between the tubing and the wellbore when the tubing is placed in the wellbore. Multiple spaced- apart acoustic devices may also be used. For example, spaced-apart acoustic detectors may be used in the wellbore, forming an array of detectors for detecting seismic wavelets.
The acoustic device used may be any one of a plurality of geophones, at least one source; or a combination including at least one acoustic source and at least one acoustic detector. The anchoring device may be any one of a hook-wall packer, an Inflatable packer, a tubing anchor, a tubing hanger, a whipstock packer, a sump packer, a tubing centralizer, or a mechanically expandable elastomeric packer.
Thus, the present invention provides a wellbore for offield operations wherein the wellbore fricludes a tubing with an annular space between the tubing and the wellbore; and at least one anchoring device disposed on an outer surface of the tubing. The anchoring device extends to and exerts a predetermined force on the wellbore. An acoustic device is attached to the anchoring device prior to the placement of the tubing in the wellbore. When the anchoring device is set in the wellbore, it couples the acoustic sensor with the wellbore, A line attached to the acoustic device provides power (electrical, optical, hydraulic, etc.) to the acoustic device. This line also provides data communication and control between the acoustic device and surface control units, such as a processor, which may be a computer or another data processing and control unit such as a microprocessorbased unit.
Examples of the more important features of the invention have been summarized rather broadly in order that the detailed descriptlion that follows may be better understood, and in order that the contdbutions to the art may be appreciated, There are, of course, additional features of the invention that will be described hereinafter and which will form the subject of the claims appended hereto.
BRIEF DIESCRIPTIONJOE -IJHlE DRAW INGS For detailed understanding of the present invention, references should be made to the followin g'detalled description of the preferred embodiment, taken in conjunction with the accompanying drawings, in which like elements have been given like numerals and wherein:
6 Figure I shows a schematic diagram of mechanically coupling a multicomponent motion sensor to a well casing or liner, according to one method of the present invention; and, Figure 2 shows the deployment of a distributed sensors in a wellbore according to one method of the present invention.
DESCRIPTION OF THE PREFERRED EMBODIMEN-T
The present invention provides a method for directly coupling acoustic sources and motion sensors to a wellbore with a coupling force substantially greater than the radial or vertical force received by such devices during norrnal wellbore operations. In one method, the device is positioned contiguous to or as an integral part of a tubing-to-casing (or tubing-to-open hole) anchoring device utilized for anchoring to the production wellbore, thereby providing direct coupling of the device to the wellbore, Multkomponent geophones are preferred acoustic detectors.
Such a coupling method minimizes coupling losses associated with commonly utifized methods of deploying such devices in wellbores. Each anchored location of the device provides an acoustic node, either an acoustic source node or a seismic detection node.
Figure 1 shows a schematic for the placement of an acoustic device in a production well 10. The well 10 shown is a cased well wherein a casing or liner 14 is set in the well with cement 16 between the well 10 and the casing 14. Typical producton wells, Le. wells that have been completed for producing oillgas (formation I fluid), include pmduction tubing such as tubing IS. Often such tubing has a plurality of spaced-apart anchoring devices such as an anchor 20 which mechanically couples the tubing 18 to the well casing 14 and thus the wellbore 10. Such anchodng devices are mechanical devices and are disposed radially around the tubing 18, Such anchoring devices are commercially available and are thus not described in detail herein. For the purpose of illustrabon of the present invention and not as a limitation, Figure 1 shows the preferred type of mechanical anchor 20 that has an upper slip cone 24 and a lower slip cone 26. A plurality of slips psually three to four, 30a-30m are provided in the anchor between the upper slip 24 and the lower slip 26. Each of the slips 30a-30m is designed to retractibly extend from the anchor 20 to make contact With the casing 14, Each slip further includes a set of teeth which are designed to firmly set into the casing 14 when the corresponding slip is extended. Figure I shows teeth 3la-31m respectively on slips 30a-30m. The slips 30a,30m may be set (extended to contact the casing 14) hydraulically via tubing pressure or via a separate capillary tubing (not shown). preferably affixed externally to the casing 14.
The anchor 20 also includes a top sub 34 above the upper slip cone 24 and a bottom sub 36 below the lower slip cone 26. The top sub 34 and the bottom sub 36 are threaded into the anchor body 21. In a production well, the casing 14 is set in the well 10 with cement 16 in the annulus 11 between the casing 14 and the inside wall 13 of the wellbore 10. After the casing 14 has been set, a production tubing 18 with a plurality of spaced apart anchoring devices (also referred to herein as anchor or anchors) along with other production equipment and devices (not 19 shown, as such devices are well known in the art) Is placed inside the casing 14. The production tubing usually extends to the lowest producing zone. There is usually an annulus space, such as space IS between the production tubing 18 and the casing 14, Figure I shows a pair of orthogonally-orlented three-component geophones 40 and 41. Elements 40x, 40y and 40z represent the three x, y, and z components of the sensor 40.
The use of the annular space 15 enables the orthogonal orientation of the indiAdual geophone sets. Annular positioning also allows for redundant positioning of more than one set of geophones fbr differential operations. Direct coupling of the devices to the casing or wellbore - as part of the anchoring system - minimizes typical coupling efficiency losses. The annular mounting can also utilize acoustic isolation systerns, thus preferentially decoupling the geophones from the tubing string and hence reducing the tubing-conducted noise while maintaining the preferred direct coupling of the device to the casing or the wellbore. Annular mounting enables geophysical surveying and data gathering without interfering with the production operations. The formation fluid may be produced through tubing IS during any operation of the devices coupled to the wellbore according to the present invention, The devices may also be coupled to open holes, i.e., wellbores without the casing. In such wellbores, the anchor device is directly coupled to the Vellbore interior. The coupling system described above is equally applicable to such open hole completions.
In the present invention, the force exerted on the wellbore by the anchor is substantially greater than any lateral (also refenred to herein as radial) force or longitudinal or axial force received by the device during normal wellbore operations. Although mechanical anchors.are preferred as the anchoring devices, any number of different devices may be utilized. Such devices may include, hook-wall packers, inflatable packers, tubing anchors, tubing hangers, whipstock packers, sump packers, tubing centralizers, and mechanically expandable elastorneric packers.
A power, control and data communication line or rink 50 runs from the surface to the device 20. The line 50 is preferably run along the outside of the tubing 18 so that line 50 Will be positioned in the annular space 15 and will not Interfere with any wellbore production or maintenance operations. Any suitable conductors or combinations of Merent types of lines may be used, Fiber optic lines may be used If the devices used require optical energy or optical data transfer to the surface equipment. Other sensors that measure such parameters as acoustic pressure, temperature, reservoir pressure, and compass orientation can be included along with the motion senson(s) on a common physical installation.
Figure 2 shows a plurality of deVices 120a-120m disposed around a tubing 118 suitably coupled to a wellbore 110 formed from a surface location 101 and penetrating a producing formation 117. Formation fluid (oil and gas) 119 from the producing formation 117 flows into the tubing via the perforations 123 and then to the surface 101. The location of each of the devices 120a-120m provides an acoustic node along wellbore 110. Acoustic devicbs 140a-140m respectively are attached or coupled to devices 120a-120m respectively. One or more lines, such as line 160, extending from the surface, provide power to the devices 140a-1 40m and data communication, and control between the devices and surface equipment Particularly, energy to the devices 140 is provided by a source 152. A processor or control unit that may be a computer or a micro-processor-based unit receives sensor signals from the sensors 140 and provides and processes such data according to programs and models provided thereto. The control unit 154 also controls the operation of any acoustic sources deployed at any of the acoustic nodes N, -N,,. The wellbore depleted in Figure 2 is a vertical well. The devices are equally applicable to horizontal and multi-lateral well configurations.
The above-described system and method provide direct coupling of acoustic devices to the wellbore. The direct coupling force is substantially greater than any motion force observed by the device in the wellbore, This provides a more stable platform for those devices sensitive to the motion than do current methods, The response of the acoustic sensors, such as multiple-component geophones, provide better signals compared to conventional coupling methods. The acoustic devilces coupled to the wellbores according to the methods of the present invention may be used for any application that requires deployment of acoustic sources and/or detectors in the wellbore. Such uses may include, but are not limited to cross-well tomography, vertical seismic and reverse vertical seismic profiling surveys, monitoring and control of injection well and fracturing operations.
The foregoing description is directed to particular embodiments of the present invention 1br the purpose of illustration and explanation. It will be apparent, however, to one skilled in the art that many modifications and changes to the embodiment set forth above are possible without departing from the scope and the spirit of the invention. It is intended that the following claims be interpreted to embrace all such modifications and changes.
Claims (10)
1. A method of placing at least one acoustic device in a wellbore, comprising:
(a) providing a tubing with at least one anchoring device in said wellbore. said anchoring device being extendable to the wellbore to exert a force on the wellbore; and (b) attaching the at least one acoustic device to the at least one anchoring device; (a) placing sold tubing with the at least one acoustic device attached to said at least one anchoring device in the wellbore: and (d) extending the anchoring device to the wellbore to exert force on the wellbore, thereby coupling the acoustic device to the wellbore,
2. The method of claim 1, wherein said at least one acoustic device includes at least one of (1) a plurality of seismic motion sensors, (11) at least one source; and (Iii) a combination including at least one.1coustic source and at least one acoustic detector.
3. The method of claim 1. wherein the step of attaching said at least one acoustic device includes attaching said at least one acoustic device to an exterior section of the tubing,
4. The method of claim 3, wherein the at least one acoustic device is attached to ft anchoring device so that the acoustic device is located in an annulus between the tubing and the wellbore when the tubing is placed in the wellbore.
1-3
5. The method of claim 1, wherein the at least one anchoring device is selected from a group consisting of (i) a hook-wall packer, (11) an inflatable packer, (iii)a tubing anchor, (jv) a tubing hanger, (v) a whipstock packer, (vi) a sump packer, (vii) a tubing centralizer, and (viii) a mechanically expandable elastomeric packer.
6. The method of claim 1, wherein attaching the at least one acoustic device includes at least partially embedding the at least one acoustic device in a section of the anchoring device.
7. A wellbore system for placing at least one acoustic deVice In a wellbore for ollfield operations, comprising:
(a) a tubing placed in said wellbore with an annular space between the tubing and the wellbore; (b) at least one anchoring device ort an outer periphery of said tubing, said at least one anchoring device extending to and exerting a fbirce on said wellbore; and (c) at least one acoustic device attached to said at least one anchoring device prior to the placement of said tubing in said wellbore.
8. the wellbore system of claim 7, wherein the acoustic device is deployed in the annular space.
i Li-
9. The wellbore system af claim 7, wherein the at least one acoustic device includes one of (i) a plurality of seismic motion sensors, (R) at least one source; and (iii) a combination including at least one acoustic source and at least one acoustic detector,
10. The wellbore system of claim 7, wherein the at least one anchoring device is selected from a group consisting of (i) a hook-wall packer, (ii) an inflatable packer, (iii)a tubing anchor, (iv) a tubing hanger, (v) a whipstock packer, (A) a sump packer, (0) a tubing centralizer, and (vill) a mechanically expandable elastomeric packer,
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US16527299P | 1999-11-12 | 1999-11-12 |
Publications (3)
| Publication Number | Publication Date |
|---|---|
| GB0027658D0 GB0027658D0 (en) | 2000-12-27 |
| GB2356209A true GB2356209A (en) | 2001-05-16 |
| GB2356209B GB2356209B (en) | 2004-03-24 |
Family
ID=22598206
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| GB0027658A Expired - Fee Related GB2356209B (en) | 1999-11-12 | 2000-11-13 | Method and apparatus for deployment mounting and coupling of downhole geophones |
Country Status (4)
| Country | Link |
|---|---|
| AU (1) | AU779196B2 (en) |
| CA (1) | CA2325917C (en) |
| GB (1) | GB2356209B (en) |
| NO (1) | NO333419B1 (en) |
Cited By (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB2382650A (en) * | 2001-10-17 | 2003-06-04 | Read Asa | Borehole seismic acquisition system for production well with sensors placed between production tubing and well casing |
| WO2003065076A2 (en) * | 2002-01-29 | 2003-08-07 | Baker Hughes Incorporated | Deployment of downhole seismic sensors for microfracture detection |
| WO2003091540A1 (en) * | 2002-04-25 | 2003-11-06 | Quantx Wellbore Instrumentation, Llc | System and method for acquiring seismic and micro-seismic data in deviated wellbores |
| GB2394287A (en) * | 2002-10-06 | 2004-04-21 | Weatherford Lamb | Seismic sensor housing which naturally couples with well casing when deployed in a deviated production well |
| FR2854467A1 (en) * | 2003-05-02 | 2004-11-05 | Weatherford Lamb | ADJUSTABLE DEPLOYMENT DEVICE FOR A SEISMIC STATION ACTIVE FIXED AND CONVEYED BY TUBING IN A WELL |
| WO2007142949A2 (en) * | 2006-05-31 | 2007-12-13 | Baker Hughes Incorporated | Active noise cancellation through the use of magnetic coupling |
| WO2009118625A1 (en) * | 2008-03-26 | 2009-10-01 | Schlumberger Technology B.V. | Method and apparatus for detecting acoustic activity in a subsurface formation |
| CN106907124A (en) * | 2015-12-22 | 2017-06-30 | 中国石油天然气股份有限公司 | Packer central tube and packer |
Families Citing this family (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7219729B2 (en) | 2002-11-05 | 2007-05-22 | Weatherford/Lamb, Inc. | Permanent downhole deployment of optical sensors |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5111903A (en) * | 1988-09-21 | 1992-05-12 | Institut Francais Du Petrole | Signal receiving system able to be coupled with the wall of a well or drilling |
| GB2253699A (en) * | 1991-03-11 | 1992-09-16 | Inst Francais Du Petrole | Method and apparatus for acoustic wave prospecting in producing wells |
| US5829520A (en) * | 1995-02-14 | 1998-11-03 | Baker Hughes Incorporated | Method and apparatus for testing, completion and/or maintaining wellbores using a sensor device |
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| FR2656034B1 (en) * | 1989-12-20 | 1992-04-24 | Inst Francais Du Petrole | WELL PROBE THAT CAN BE DECOUPLED WITH A RIGID CONNECTION THAT CONNECTS TO THE SURFACE. |
| FR2787503B1 (en) * | 1998-12-18 | 2001-03-30 | Inst Francais Du Petrole | SYSTEM FOR THE PERMANENT INSTALLATION OF MEASUREMENT PROBES WITHIN A FLUID PRESSURE REMOVABLE LOCK |
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2000
- 2000-11-13 GB GB0027658A patent/GB2356209B/en not_active Expired - Fee Related
- 2000-11-13 AU AU71579/00A patent/AU779196B2/en not_active Ceased
- 2000-11-13 NO NO20005740A patent/NO333419B1/en not_active IP Right Cessation
- 2000-11-14 CA CA002325917A patent/CA2325917C/en not_active Expired - Fee Related
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| US5111903A (en) * | 1988-09-21 | 1992-05-12 | Institut Francais Du Petrole | Signal receiving system able to be coupled with the wall of a well or drilling |
| GB2253699A (en) * | 1991-03-11 | 1992-09-16 | Inst Francais Du Petrole | Method and apparatus for acoustic wave prospecting in producing wells |
| US5829520A (en) * | 1995-02-14 | 1998-11-03 | Baker Hughes Incorporated | Method and apparatus for testing, completion and/or maintaining wellbores using a sensor device |
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| Leary & Ziolkowski, Borehole Seismics for IOR: the Uniwell Concept,PESGB PETEX Conference 1-3/12/98 * |
Cited By (21)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB2382650B (en) * | 2001-10-17 | 2004-05-19 | Read Asa | Block and module for seismic sources and sensors |
| GB2382650A (en) * | 2001-10-17 | 2003-06-04 | Read Asa | Borehole seismic acquisition system for production well with sensors placed between production tubing and well casing |
| US7020045B2 (en) | 2001-10-17 | 2006-03-28 | Read Asa | Block and module for seismic sources and sensors |
| WO2003065076A2 (en) * | 2002-01-29 | 2003-08-07 | Baker Hughes Incorporated | Deployment of downhole seismic sensors for microfracture detection |
| WO2003065076A3 (en) * | 2002-01-29 | 2003-11-13 | Baker Hughes Inc | Deployment of downhole seismic sensors for microfracture detection |
| GB2405930B (en) * | 2002-04-25 | 2006-11-22 | Quantx Wellbore Instrumentatio | System and method for acquiring seismic and micro-seismic data in deviated wellbores |
| GB2405930A (en) * | 2002-04-25 | 2005-03-16 | Quantx Wellbore Instrumentatio | System and method for acquiring seismic and micro-seismic data in deviated wellbores |
| WO2003091540A1 (en) * | 2002-04-25 | 2003-11-06 | Quantx Wellbore Instrumentation, Llc | System and method for acquiring seismic and micro-seismic data in deviated wellbores |
| US7263029B2 (en) | 2002-04-25 | 2007-08-28 | Baker Hughes Incorporated | System and method for acquiring seismic and micro-seismic data in deviated wellbores |
| NO338082B1 (en) * | 2002-04-25 | 2016-07-25 | Baker Hughes Inc | System and method for collecting seismic and microseismic data in different boreholes |
| GB2394287B (en) * | 2002-10-06 | 2006-03-08 | Weatherford Lamb | In-well seismic sensor casing coupling using natural forces in wells |
| GB2394287A (en) * | 2002-10-06 | 2004-04-21 | Weatherford Lamb | Seismic sensor housing which naturally couples with well casing when deployed in a deviated production well |
| NO335755B1 (en) * | 2003-05-02 | 2015-02-09 | Weatherford Technology Holdings Llc | Adjustable acoustic coupling for a seismic sensor actively clamped in a well |
| FR2854467A1 (en) * | 2003-05-02 | 2004-11-05 | Weatherford Lamb | ADJUSTABLE DEPLOYMENT DEVICE FOR A SEISMIC STATION ACTIVE FIXED AND CONVEYED BY TUBING IN A WELL |
| WO2007142949A2 (en) * | 2006-05-31 | 2007-12-13 | Baker Hughes Incorporated | Active noise cancellation through the use of magnetic coupling |
| US7639562B2 (en) | 2006-05-31 | 2009-12-29 | Baker Hughes Incorporated | Active noise cancellation through the use of magnetic coupling |
| US7911877B2 (en) | 2006-05-31 | 2011-03-22 | Baker Hughes Incorporated | Active noise cancellation through the use of magnetic coupling |
| WO2007142949A3 (en) * | 2006-05-31 | 2009-04-30 | Baker Hughes Inc | Active noise cancellation through the use of magnetic coupling |
| US8069913B2 (en) | 2008-03-26 | 2011-12-06 | Schlumberger Technology Corporation | Method and apparatus for detecting acoustic activity in a subsurface formation |
| WO2009118625A1 (en) * | 2008-03-26 | 2009-10-01 | Schlumberger Technology B.V. | Method and apparatus for detecting acoustic activity in a subsurface formation |
| CN106907124A (en) * | 2015-12-22 | 2017-06-30 | 中国石油天然气股份有限公司 | Packer central tube and packer |
Also Published As
| Publication number | Publication date |
|---|---|
| NO333419B1 (en) | 2013-06-03 |
| GB0027658D0 (en) | 2000-12-27 |
| NO20005740D0 (en) | 2000-11-13 |
| AU7157900A (en) | 2001-08-02 |
| AU779196B2 (en) | 2005-01-13 |
| NO20005740L (en) | 2001-05-14 |
| CA2325917C (en) | 2005-10-04 |
| CA2325917A1 (en) | 2001-05-12 |
| GB2356209B (en) | 2004-03-24 |
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