GB2438762A - Providing response signals to seismic vibrations received at a subterranean receiver - Google Patents
Providing response signals to seismic vibrations received at a subterranean receiver Download PDFInfo
- Publication number
- GB2438762A GB2438762A GB0714875A GB0714875A GB2438762A GB 2438762 A GB2438762 A GB 2438762A GB 0714875 A GB0714875 A GB 0714875A GB 0714875 A GB0714875 A GB 0714875A GB 2438762 A GB2438762 A GB 2438762A
- Authority
- GB
- United Kingdom
- Prior art keywords
- signal
- seismic
- receiver
- recited
- sending
- 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 claims abstract description 35
- 238000004891 communication Methods 0.000 claims abstract description 29
- 230000015572 biosynthetic process Effects 0.000 claims description 8
- 239000011435 rock Substances 0.000 claims description 3
- 238000012546 transfer Methods 0.000 abstract description 6
- 238000005553 drilling Methods 0.000 description 18
- 230000005540 biological transmission Effects 0.000 description 11
- 238000001514 detection method Methods 0.000 description 4
- 238000012986 modification Methods 0.000 description 3
- 230000004048 modification Effects 0.000 description 3
- 239000007787 solid Substances 0.000 description 3
- 238000013459 approach Methods 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 230000010287 polarization Effects 0.000 description 2
- 238000012545 processing Methods 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- 238000005481 NMR spectroscopy Methods 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- 238000012790 confirmation Methods 0.000 description 1
- 230000006866 deterioration Effects 0.000 description 1
- 230000001627 detrimental effect Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000010304 firing Methods 0.000 description 1
- 230000006870 function Effects 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000001208 nuclear magnetic resonance pulse sequence Methods 0.000 description 1
- 238000011045 prefiltration Methods 0.000 description 1
- 230000008672 reprogramming Effects 0.000 description 1
- 239000000523 sample Substances 0.000 description 1
- 238000012163 sequencing technique Methods 0.000 description 1
- 230000008054 signal transmission Effects 0.000 description 1
- 238000010561 standard procedure Methods 0.000 description 1
- 230000000007 visual effect Effects 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
- E21B47/14—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
-
- 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
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
-
- 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
Landscapes
- Physics & Mathematics (AREA)
- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geophysics (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- Remote Sensing (AREA)
- Geochemistry & Mineralogy (AREA)
- Acoustics & Sound (AREA)
- General Physics & Mathematics (AREA)
- Geophysics And Detection Of Objects (AREA)
Abstract
A system and method is provided for communicating with a device 54 disposed in a wellbore 66. Seismic signals 72 are sent from a vibrator 71, including a baseplate 76 in contact with the ground 24, through the earth 26 and processed by a receiver 32 disposed in the wellbore 66. The receiver 32 is in communication with the device 54 and transfers data, such as command and control signals, to the device 54. Response signals may be transmitted to the surface to acknowledge receipt of the seismic signals 72 or a modified seismic signal, having an improved signal-to-noise ratio, may be communicated to a deeper location. In an alternative arrangement, a marine vibrator sends seismic signals through the ocean into the seabed strata and onto wellbore devices.
Description
<p>SYSTEM AND METHOD FOR COMMUNICATION BETWEEN A</p>
<p>SURFACE LOCATION AND A SUBTERRANEAN LOCATION</p>
<p>BACIcGROTJND In a variety of welibore applications, downhole equipment is used for numerous operations, including drilling of the borehole, operation of a submersible pumping system, testing of the well and well servicing.</p>
<p>Current systems often have controllable components that can be operated via command and control signals sent to the system from a surface location. The signals are sent via a dedicated control line, e.g. electric or hydraulic, routed within the welibore. Such communication systems, however, add expense to the overall system and are susceptible to damage or deterioration in the often hostile weilbore environment. Other attempts have been made to communicate with downhole equipment via pressure pulses sent through the weilbore along the tubing string or through drilling mud disposed within the weilbore. 0*** * * S...</p>
<p>In general, the present invention provides a system * and method of communication between a surface location and a subterranean, e.g. downhole, location. Signals are sent through the earth using seismic vibrators, and those * *.</p>
<p>* signals are detected at a signal receiver, typically S..</p>
<p>located proximate the subterranean device to which the communication is being sent. Thus, modulated seismic waves can be used to carry data, such as command and control signals, to a wide variety of equipment utilized at subterranean locations.</p>
<p>BRIEF DESCRIPTION OF THE DRAWINGS</p>
<p>Certain embodiments of the invention will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements, and: Figure 1 is a schematic illustration of a communication system, according to an embodiment of the present invention; Figure 2 is a schematic illustration of a receiver utilized with the communication system illustrated in Figure 1; Figure 3 is a schematic illustration of a variety of subterranean devices that can be utilized with the communication system illustrated in Figure 1; : Figure 4 is a front elevation view of a seismic I...</p>
<p>communication system utilized with downhole equipment **. deployed in a welibore, according to an embodiment of the present invention; Figure 5 is a front elevation view of a seismic communication system utilized with downhole equipment deployed in a welibore, according to another embodiment of the present invention; Figure 6 is a schematic illustration of a transmitter system utilizing various techniques for sending data through the earth via seismic vibrations, according to an embodiment of the present invention Figure 7 is a schematic illustration of a technique for seismic communication utilizing spatial diversity demodulation, according to an embodiment of the present invention; Figure 8 is a schematic illustration of a system for "uplink" communication between a subsurface transmitter and a receiver/controller disposed at a surface location, according to an embodiment of the present invention; and Figure 9 is a flowchart illustrating an example of operation of a communication system, according to an embodiment of the present invention.</p>
<p>DETAILED DESCRIPTION</p>
<p>a.. In the following description, numerous details are set forth to provide an understanding of the present invention.</p>
<p>*:*::* However, it will be understood by those of ordinary skill in the art that the present invention may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.</p>
<p>The present invention generally relates to communication with subterranean equipment via the use of seismic vibrators. The use of seismic vibrations to communicate data to downhole equipment eliminates the need for control lines or control systems within the weilbore and also enables the sending of signals through a medium external to the weilbore. The present communication system facilitates transmission of data to a variety of tools, such as drilling tools, slickline tools, production systems, service tools and test equipment. For example, in drilling applications the seismic communication technique can be used for formation pressure-while-drilling sequencing, changing measurement-while-drilling telemetry rates and format, controlling rotary steerable systems and reprogramming logging-while-drilling tools. However, the devices and methods of the present invention are not limited to use in the specific applications that are described herein.</p>
<p>Referring generally to Figure 1, a system 20 is illustrated according to an embodiment of the present invention. In this embodiment, system 20 comprises a transmitter 22 disposed, for example, at a surface 24 of the earth. Transmitter 22 is a seismic vibrator that shakes the earth in a controlled manner and generates seismic waves that travel through a region 26 of the earth s.., to a subterranean system 28. Subterranean system 28 may * I. comprise a variety of components for numerous subterranean applications. To facilitate explanation, however, system 28 is illustrated as having a subterranean device 30 ** coupled to a receiver 32. Receiver 32 is designed to receive and process the signals transmitted by transmitter 22 so as to supply desired data to subterranean device 30.</p>
<p>For example, the transmission may be a command and control signal that causes device 32 undergo a desired action.</p>
<p>Seismic vibrator 22 may be coupled to a control system 34 that enables an operator to control subterranean device via seismic vibrator 22. As illustrated in Figure 1, control system 34 may comprise a processor 36. The processor 36 comprises a central processing unit ("CPU") 38 coupled to a memory 40, an input device 42 (i.e., a user interface unit), and an output device 44 (i.e., a visual interface unit). The input device 42 may be a keyboard, mouse, voice recognition unit, or any other device capable of receiving instructions. It is through the input device 42 that the operator may provide instructions to seismic vibrator 22 for the transmission of desired signals to receiver 32 and device 30. The output device 44 may be a device, e.g. a monitor that is capable of displaying or presenting data and/or diagrams to the operator. The memory 40 may be a primary memory, such as RAN, a secondary memory, such as a disk drive, a combination of those, as well as other types of memory. Note that the present invention may be implemented in a computer network, using the Internet, or other methods of interconnecting : computers. Therefore, the memory 40 may be an independent *...</p>
<p>"S memory accessed by the network, or a memory associated with one or more of the computers. Likewise, the input device * 42 and output device 44 may be associated with any one or more of the computers of the network. Similarly, the * S. system may utilize the capabilities of any one or more of the computers and a central network controller.</p>
<p>Referring to Figure 2, receiver 32 may comprise a variety of receiver components depending on the methodology selected for transmitting seismic signals through region 26 of the earth. The receiver configuration also may depend on the type of material through which the seismic signal travels, e.g. water or rock formation. In general, receiver 32 comprises a processor 46 coupled to one or more seismic signal detection devices, such as geophories 48, accelerometers 50 and hydrophones 52. By way of example, various combinations of these seismic signal detection devices, arranged to detect seismic vibrations, can be found in vertical seismic profiling (VSP) applications.</p>
<p>In the applications described herein, seismic signals are sent through the earth to provide data, such as command and control signals, to the subterranean device 30. Such signals are useful in a wide variety of applications with many types of subterranean devices, such as a weilbore device 54, as illustrated in Figure 3. Weilbore device 54 may comprise one or more devices, such as a drilling assembly 56, a slickline system 58, a service tool 60, production equipment 62, such as submersible pumping system components, and other weilbore devices 64. * *</p>
<p>Referring generally to Figure 4, one specific example of a welibore application is illustrated. In this * embodiment, welibore device 54 is disposed within a * welibore 66 on a deployment system 68, such as a tubular, a wire, a cable or other deployment system. Receiver 32 *:*::* comprises a sensor package 70 containing one or more of the seismic signal detection devices discussed above. Sensor package 70 receives and processes signals received from seismic vibrator/transmitter 22 and provides the appropriate data or control input to welibore device 54.</p>
<p>In this embodiment, region 26 is primarily a solid formation, such as a rock formation, and seismic signals 72 are transmitted through the solid formation materials from seismic vibrator 22. In this type of application, seismic vibrator 22 is a land vibrator 71 disposed such that the seismic signals 72 travel through the earth external to weilbore 66. Land vibrator 71 comprises, for example, a mass 74 that vibrates against a baseplate 76 to create the desired seismic vibrations. The seismic vibrator may be mounted on a suitable mobile vehicle, such as a truck 78, to facilitate movement from one location to another.</p>
<p>In another embodiment, seismic vibrator 22 is designed to transmit seismic signals 72 through the earth via a primarily marine environment. The signals 72 pass through an earth region 26 that is primarily liquid. For example, welibore device 54 may be disposed within weilbore 66 formed in a seabed 80. Seismic vibrator 22 comprises a marine vibrator 81 that may be mounted on a marine vehicle 82, such as a platform or ship. By way of example, marine vibrator 81 comprises two hemispherical shells of the type designed to vibrate with respect to one another to create PS,. . . . . seismic signals 72. Seismic signals 72 are transmitted through the marine environment enroute to seabed 80 and :. receiver 32.</p>
<p>I</p>
<p>*s,.., In either of the embodiments illustrated in Figure 4 or Figure 5, a variety of additional components may be included depending on the specific environment and application. For example, if wel].bore device 54 comprises a drilling assembly, a mud pump 86 may be coupled to weilbore 66 via an appropriate conduit 88 to deliver drilling mud into the weilbore. In such example, drilling device 54 may comprise a rotary, steerable drilling assembly that receives commands from seismic vibrator 22 as to direction, speed or other drilling parameters.</p>
<p>Seismic vibrator 22 may be operated according to several techniques for generating a signal that can be transmitted through the earth for receipt and processing at subterranean system 28. In general, seismic vibrator 22 is capable of generating a phase-controlled signal 90, as illustrated schematically in Figure 6. By way of specific example, seismic vibrator 22 is controllable to produce a modulated signal 92. Modulated signals can be designed to initially carry a predetermined introductory signal to begin the transmission and cause receiver 32 to recognize the specific transmission of data. Seismic vibrator 22 can transmit the modulated signal over a bandwidth using a variety of standard methods, as known to those of ordinary skill in the art. In many applications, however, it may be advantageous to restrict the top of the band so that it is :. less than approximately double the bottom of the band.</p>
<p>This helps reduce problems associated with non-linearity.</p>
<p>Additionally, a spatial diversity technique 94 can be used to facilitate transmission of the signal from seismic * S. vibrator 22 to subterranean system 28. Spatial diversity techniques may suffer fewer detrimental effects from * S. "S..' locally generated noise. These techniques also enable transmission of signals independent of any precision timing of the signals. In other words, there is no need for precision clocking components on either the transmission side or the receiving side.</p>
<p>When using the spatial diversity technique 94 for seismic communication through region 26, multiple seismic signal detection devices are utilized in accomplishing spatial diversity demodulation. This approach is similar to the approach used in certain underwater acoustic and radio communication applications and as described in certain publications, such as US Patent No. 6,195,064. As illustrated in Figure 7, spatial diversity utilizes a transmitted signal with a plurality of polarization directions 96. For example, the signals transmitted from seismic vibrator 22 can be illustrated as signals polarized along an x-axis 98, a y-axis 100 and a z-axis 102. With such a technique, there is an improved success rate in transmitting signals from seismic vibrator 22 to downhole system 28, even in adverse conditions, e.g. applications or environments with substantial locally generated noise.</p>
<p>This latter technique effectively utilizes a plurality of different field polarizations in combination with the conjugate field, i.e. pressure or vibrational pulses, to achieve the desired seismic communication.</p>
<p>In another embodiment, system 20 comprises an "uplink' which is a downhole-to-surface telemetry system 104 capable * of transmitting a signal 105 from subterranean system 28 to * a surface location, as illustrated in Figure 8. For example, uplink signal 105 can be sent to control system 34 S..</p>
<p>* which also can be used to control seismic vibrator 22, as *:*::* described above. By combining the uplink with a downlink,</p>
<p>S *.*</p>
<p>e.g. the transmission of seismic signals 72, a full duplex system can be achieved.</p>
<p>With the addition of uplink telemetry system 104, seismic signals are sent through the earth external to welibore 66 for receipt at receiver 32 of subterranean system 28, as previously described. However, an uplink transmitter 106 is communicatively coupled to receiver 32.</p>
<p>Transmitter 106 provides appropriate uplink communications related to the seismic signals transferred to receiver 32 and/or to the operation of a component of subterranean system 28, e.g. welibore device 54. For example, uplink system 104 can be used to send an acknowledgment when the initial predetermined signal of an instruction signal 72 is communicated to receiver 32. The uplink communication confirms receipt of the signals 72, however the lack of an acknowledgment to control system 34 also can be useful.</p>
<p>For example, a variety of actions can be taken ranging from ignoring the lack of acknowledgment to switching seismic vibrator 22 to a different frequency band, reducing the bit rate or bandwidth of signals 72 or making other adjustments to signals 72 until subterranean system 28 acknowledges receipt of the instruction.</p>
<p>The specific uplink system 104 used in a given application can vary. For example, uplink communication :. can be transmitted through a control line within wel].bore * S..</p>
<p>66, such as an electric or hydraulic control line.</p>
<p>Alternatively, a mud pulse telemetry system can be utilized *... to send uplink signals 105 through drilling mud, provided the application utilizes drilling mud, as illustrated in the embodiments of Figures 4 and 5. S..</p>
<p>Additionally, the two way communication via downlink signals 72 and uplink signals 105 enable subterranean system 28 to send to the surface location, e.g. control system 34, parameters that describe the transfer function from surface location to the downhole system. This enables the surface system to prefilter the signal reaching the seismic vibrator, thereby improving communication.</p>
<p>Furthermore, much of the distortion in a given signal results from near-surface impedance changes that are not significantly altered as a weilbore drilling operation progresses. Accordingly, prefiltering can be established when the downhole receiver is at a shallow depth to facilitate communication at a much greater depth. By way of example, a separate receiver system 107 can be located at a relatively shallow depth. In this embodiment, receiver system 107 comprises one or more components having transmission capability with a high-rate uplink capacity, such as found in a wireline tool. In operation, a seismic signal 108 is received at receiver 107, and an uplink signal 109 is sent to control system 34 to provide information on the seismic signal 108 being received at receiver 107. By prefiltering the signal and otherwise adjusting the vibrator parameters, the signal-to-noise ratio to the shallow receiver system 107 can be increased.</p>
<p>These same parameters can then be used to communicate via modified seismic signals 72 with a much deeper receiver, e.g. receiver 32, with which communication tends to be more difficult. Thus, the transmission of seismic signals to a shallow receiver can be used to adjust the parameters of the seismic vibrator 22 to improve the signal and thereby improve transmission to another receiver deeper in the I..</p>
<p>earth. It should be noted that the shallow receiver and the deeper receiver can be the same receiver if initial prefiltering communications are conducted when the receiver is positioned at a shallow depth prior to being run downhole to the deeper location.</p>
<p>By way of example, system 20 can be utilized for transferring many types of data in a variety of applications. In a drilling environment, for example, seismic vibrator 22 can be used to send commands such as: steering commands for a rotary steerable drilling system; instructions on the telemetry rate, modulation scheme and carrier frequency to use for the uplink telemetry; pulse sequences and parameters for nuclear magnetic resonance tools; instructions on which data is to be sent to the surface using the uplink; instructions on operation of a formation pressure probe; firing commands for a downhole bullet and numerous other commands. Many of these commands and applications can be utilized without uplink system 104 or at least without acknowledgment via uplink 105. In a well service environment, seismic signals can be used to transfer data to subterranean system 28. If uplink system 104 is included in overall system 20, the uplink can be used to acknowledge instructions and to transfer a variety of other information to the surface. Examples of command signals that can be sent via system 20 in a well service :. environment include: setting or unsetting a packer; :..::: opening, shutting or adjusting a valve; asking for certain S...</p>
<p>data to be transmitted to surface and numerous other instructions, Of course, the examples set forth in this paragraph are only provided to facilitate understanding on *:::* the part of the reader and are not meant to limit the * 12</p>
<p>applicability of system 20 to a wide variety of</p>
<p>applications, environments and data types.</p>
<p>One example of the operation of system 20 is illustrated in flowchart form in Figure 9. In this example, an initial determination is made as to a desired instruction for weilbore device 54, as illustrated by block 110. An operator can enter the instruction into control system 34 via input device 42 and that input is relayed to seismic vibrator 22 which transmits the seismic signal 72 through the earth, e.g. either a marine environment, a solid formation or a combination of those environments, as illustrated by block 112. The signal is transferred through the earth external to welibore 66 and received at the sensor package 70 of receiver 32, as illustrated by block 114. If downhole-to-surface system 104 is included as part of system 20, a confirmation is sent to the surface, e.g. to control system 34, as illustrated by block 116. Additionally, data, such as a command instruction, is transferred to weilbore device 54 from receiver 32 to, for example, control a specific activity of the welibore device, as illustrated in block 118.</p>
<p>The sequence described with reference to Figure 9 provides an example of the use of system 20 in communicating with a subterranean device. Use of the earth as a medium for transferring seismic signals 72 enables S...</p>
<p>S..... transfer of the signals externally and independently of * ** welibore 66. However, seismic vibrator 22, downhole receiver 32, the signal transfer technique, e.g. spatial *.* diversity technique, and other potential components of * S. * . . * S.</p>
<p>S *5S</p>
<p>system 20 can be utilized in additional environments and applications with other sequences of operation.</p>
<p>Accordingly, although only a few embodiments of the present invention have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this invention.</p>
<p>Accordingly, such modifications are intended to be included within the scope of this invention as defined in the claims. * * * I.. **** * * S... * .* * . S * .*</p>
<p>S SI.</p>
<p>S * I* * S S * I.</p>
<p>I</p>
<p>S</p>
Claims (1)
- <p>CLAIMS</p><p>What is claimed is: 1. A method for subterranean communication, comprising sending a modulated signal through the Earth, via a seismic vibrator, to a subsurface system located in a welibore; and providing a response signal.</p><p>2. The method of claim 1, wherein the step of providing a response signal comprises communicating the response from the subsurface system to a surface location.</p><p>3. The method of claim 1, wherein the step of providing a response signal comprises communicating the response from the subsurface system to a subsurface receiver at a deeper location than the subsurface system.</p><p>4. The method as recited in claim 1 wherein sending comprises sending the modulated signal via a land vibrator.</p><p>5. The method as recited in claim 1 wherein sending comprises sending the modulated signal via a marine vibrator.</p><p>6. The method as recited in claim 4, wherein sending comprises sending the modulated signal via the land vibrator having a base plate and a mass that can be * ** vibrated on the base plate. *** * * ** * S * S *S</p><p>S 15</p><p>7. The method as recited in claim 5, wherein sending comprises sending the modulated signal via the marine vibrator having a pair of hemispherical shells able to vibrate with respect each other.</p><p>8. The method as recited in claim 2, wherein providing comprises providing the response signal to acknowledge receipt of the modulated signal.</p><p>9. The method as recited in claim 1, further comprising sensing the modulated signal with a geophone.</p><p>10. The method as recited in claim 1, further comprising sensing the modulated signal with an accelerometer.</p><p>11. The method as recited in claim 1, further comprising sensing the modulated signal with a hydrophone.</p><p>12. A method for subterranean communication, comprising: sending a seismic signal through the Earth to a subterranean receiver; adjusting the seismic signal to obtain a modified seismic signal having an improved signal-to-noise ratio to the subterranean receiver; and transmitting the modified seismic signal to a receiver disposed at a deeper location than the subterranean receiver.</p><p>13. The method as recited in claim 12, further comprising S...</p><p>communicating between the subterranean receiver and a surface control system via a high-rate uplink * component. *** * * ** * S S * S. **</p><p>14. The method as recited in claim 12, wherein sending comprises sending the signal through a marine environment remote from a weilbore in which the welibore device is disposed.</p><p>15. The method as recited in claim 12, wherein sending comprises sending the signal through a rock formation remote from a weilbore in which the welibore device is disposed. * *** **** * .</p><p>* *..* * SI * * S * ** * ** * ** * S S S *S</p><p>S S..</p><p>S</p>
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
GB0714875A GB2438762B (en) | 2004-12-21 | 2004-12-21 | System and method for communication between a surface location and a subterranean location |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
GB0714875A GB2438762B (en) | 2004-12-21 | 2004-12-21 | System and method for communication between a surface location and a subterranean location |
GB0427908A GB2421614B (en) | 2004-12-21 | 2004-12-21 | System and method for communication between a surface location and a subterranean location |
Publications (3)
Publication Number | Publication Date |
---|---|
GB0714875D0 GB0714875D0 (en) | 2007-09-12 |
GB2438762A true GB2438762A (en) | 2007-12-05 |
GB2438762B GB2438762B (en) | 2008-08-27 |
Family
ID=38529027
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
GB0714875A Expired - Fee Related GB2438762B (en) | 2004-12-21 | 2004-12-21 | System and method for communication between a surface location and a subterranean location |
Country Status (1)
Country | Link |
---|---|
GB (1) | GB2438762B (en) |
Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3914732A (en) * | 1973-07-23 | 1975-10-21 | Us Energy | System for remote control of underground device |
WO1998015850A1 (en) * | 1996-10-09 | 1998-04-16 | Baker Hughes Incorporated | Method of obtaining improved geophysical information about earth formations |
GB2321968A (en) * | 1997-02-05 | 1998-08-12 | Inst Francais Du Petrole | Seismic data processing method |
EP0972909A2 (en) * | 1998-07-17 | 2000-01-19 | Halliburton Energy Services, Inc. | Electromagnetic telemetry system |
US20040006430A1 (en) * | 2000-06-15 | 2004-01-08 | Geo-X Systems, Ltd. | Seismic monitoring and control method |
GB2414494A (en) * | 2004-05-28 | 2005-11-30 | Schlumberger Holdings | Wireless downhole communications |
-
2004
- 2004-12-21 GB GB0714875A patent/GB2438762B/en not_active Expired - Fee Related
Patent Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3914732A (en) * | 1973-07-23 | 1975-10-21 | Us Energy | System for remote control of underground device |
WO1998015850A1 (en) * | 1996-10-09 | 1998-04-16 | Baker Hughes Incorporated | Method of obtaining improved geophysical information about earth formations |
GB2321968A (en) * | 1997-02-05 | 1998-08-12 | Inst Francais Du Petrole | Seismic data processing method |
EP0972909A2 (en) * | 1998-07-17 | 2000-01-19 | Halliburton Energy Services, Inc. | Electromagnetic telemetry system |
US20040006430A1 (en) * | 2000-06-15 | 2004-01-08 | Geo-X Systems, Ltd. | Seismic monitoring and control method |
GB2414494A (en) * | 2004-05-28 | 2005-11-30 | Schlumberger Holdings | Wireless downhole communications |
Also Published As
Publication number | Publication date |
---|---|
GB2438762B (en) | 2008-08-27 |
GB0714875D0 (en) | 2007-09-12 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
CA2591999C (en) | Downhole communication method and system | |
US4992997A (en) | Stress wave telemetry system for drillstems and tubing strings | |
US5372207A (en) | Seismic prospecting method and device using a drill bit working in a well | |
JP5352674B2 (en) | Reverse vertical borehole seismic survey by impact measurement in both directions during excavation | |
US8125848B2 (en) | Acoustic logging-while-drilling tools having a hexapole source configuration and associated logging methods | |
CA2544457C (en) | System and method for downhole telemetry | |
US6382332B1 (en) | Drill bit apparatus for receiving seismic sound signals | |
US8408330B2 (en) | Systems and methods for canceling noise and/or echoes in borehole communication | |
US20100182161A1 (en) | Wireless telemetry repeater systems and methods | |
WO2008157366A2 (en) | Imaging of formation structure ahead of the drill-bit | |
AU2001261156B2 (en) | Axially extended downhole seismic source | |
AU2001261156A1 (en) | Axially extended downhole seismic source | |
AU2007248310A1 (en) | Drill bit assembly with a logging device | |
US11513247B2 (en) | Data acquisition systems | |
GB2438762A (en) | Providing response signals to seismic vibrations received at a subterranean receiver | |
US20180223634A1 (en) | Pressure Wave Tool For Unconventional Well Recovery | |
CA2952873C (en) | Mixed-mode telemetry systems and methods | |
WO2021112843A1 (en) | Bi-directional acoustic telemetry system | |
US11992860B2 (en) | Air layer for improved performance of transducer at low frequencies | |
RU2194161C2 (en) | Telemetering system for monitoring of bottomhole parameters | |
KR100683808B1 (en) | Method and apparatus for delivering the seismic wave triggering signal to receiving station via wireless telecommunication in the seismic survey | |
RU2243377C1 (en) | Method and device for controlling face parameters in screening highly conductive beds | |
CA2064279A1 (en) | Seismic data method and apparatus |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
PCNP | Patent ceased through non-payment of renewal fee |
Effective date: 20181221 |