CN101253304A - Bi-directional drill string telemetry for measurement and drilling control - Google Patents
Bi-directional drill string telemetry for measurement and drilling control Download PDFInfo
- Publication number
- CN101253304A CN101253304A CNA2006800291388A CN200680029138A CN101253304A CN 101253304 A CN101253304 A CN 101253304A CN A2006800291388 A CNA2006800291388 A CN A2006800291388A CN 200680029138 A CN200680029138 A CN 200680029138A CN 101253304 A CN101253304 A CN 101253304A
- Authority
- CN
- China
- Prior art keywords
- drill string
- drill
- tool assembly
- shaft bottom
- telemetry system
- 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.)
- Pending
Links
Images
Landscapes
- Earth Drilling (AREA)
- Arrangements For Transmission Of Measured Signals (AREA)
Abstract
The invention discloses a bi-directional drill string telemetry technique for measurement and drilling control. The disclosure has application for use in conjunction with an operation of drilling an earth borehole using: a drilling rig, a drill string having its generally upper end mechanically coupleable with and suspendable from the drilling rig, and a bottom hole assembly adjacent the lower end the drill string, the bottom hole assembly including a drill bit at its lower end.; A method is set forth for obtaining information about at least one parameter sensed at the bottom hole assembly, including the following steps: providing at least one measuring device in the bottom hole assembly, the at least one measuring device producing measurement data representative of a measured condition at the bottom hole assembly; providing an uphole processor system at the earth's surface; providing a drill string telemetry system coupled with the at least one measuring device and coupled with the uphole processor system; and transmitting the data from the measuring device to the uphole processor system via the drill string telemetry system.
Description
Technical field
The present invention relates to drill and the technical field of production hydrocarbon well, and relate to the measurement of shaft bottom formation properties, and relate to the measurement between shaft bottom and the ground installation and the two-way communication of control information.
Background technology
The appearance of measurement while drilling (MWD) and well logging during (LWD), and special boring method is such as the ground control development of directed drilling, the technical field in drilling well and production hydrocarbon well has obtained important progress.These methods need all communicate on both direction between ground and shaft bottom measurement and drilling equipment.At present, mud-pulse telemetry is the general commercial unique technical of using in this aspect of communicating by letter of carrying out in drilling well between bottom equipment and the ground.Unless [additionally explanation, it is to represent that drill string is in the drilling well or partly is in the drilling well that " in the time of the drilling well " that relates in full or " with boring " wait, as the part of the whole drill-well operation of comprise drilling well, end and/or make a trip (tripping), and needn't require drill bit to rotate.] in mud-pulse telemetry, data are transmitted in drilling fluid as pressure pulse.But, mud-pulse telemetry has known limitation, comprises relatively slow communication, the reliability of low data rate and difference.Current mud-pulse telemetry only can send the MWD/LWD data with the speed of about per second 12 (bit).In many cases, this speed is not enough to send all data of being collected by LWD tool string (tool string), perhaps has restriction aspect the structure of the tool string of wanting.In addition, mud pulse technology can not be worked in extending the wellhole that arrives well.Realize that such as the operation of directed drilling and drilling tool and by regulating mud pump flow the signal transmission from aboveground to the shaft bottom is also very slow in order to control operation, and have low-down information rate.In addition, under specific situation, for example adopt under the underbalance drilling well situation of gas or foam drilling fluid, current mud-pulse telemetry is inoperative.
Had various trials to develop the substitute technology of mud-pulse telemetry in recent years, these technology are faster, have higher data rate, and do not need the existence of the drilling fluid of specific type.
For example, proposed acoustic telemetry, it sends sound wave by drill string.Data rate is estimated as approximately than the high order of magnitude of mud-pulse telemetry, but still limited, and noise is a problem.The acoustic telemetry commercialization utilization of also being unrealized.Another example is the em telemetry that passes the face of land.This technology is considered to have limited scope, and the character that depends on the stratum around the drilling well is resistance coefficient especially, and also has limited data rate.
Propose in drilling rod, to be provided for transmitting the electric wire of signal for a long time.Some early stage suggestions at wired drill string are disclosed in: U.S. patent No.4126848, U.S. patent No.3957118 and U.S. patent No.3807502 and publication " four different systems that are used for MWD " (" FourDifferent Systems Used for MWD "), W.J.Mcdonald, The Oil and Gas Journal, the 115-124 page or leaf, on April 3rd, 1978.
Also proposed such as the design of using induction coupling at the union place.Following document has disclosed and used induction coupling in drill string: U.S. patent No.4605268, the patent application 2140527 that submit to the 18 days December in 1997 of russian federation published, the patent application 2040691 that submit to the 14 days February in 1992 of russian federation published, and WO publication 90/14497A2, and referring to: U.S. patent No.5052941, U.S. patent No.4806928, U.S. patent No.4901069, U.S. patent No.5531592, U.S. patent No.5278550, and U.S. patent No.5971072.
U.S. patent 6641434 has been described a kind of wired drill pipe joints, its wired (wired) drilling rod technical field for high data rate between earth station and the residing position of drilling well two-way ground, the transmission measurement data have obvious improvement reliably.' 434 Patent publish a kind of low-loss wired drill pipe joints, wherein conductive layer has reduced signal energy loss on the whole drill string length by reducing in the resistance loss at each induction coupling place and flux loss.Wired drill pipe joints is durable, also keeps under the situation in slit and can operate because it exists in conductive layer.Performance in the drill string telemetry field and these and other progressive chances that innovation is provided in the following areas: the former performance that has limited system of the existing shortcoming of range of application, speed and data rate aspect.
One of them purpose of the present invention is the coordinated of utilization and advanced bi-directional drill string telemetry, and improved measurement and stratum logging operation are provided, and the improvement of drilling parameter control and optimization, and these all can not be realized owing to a variety of causes up to now.
Summary of the invention
The present invention has such feature, and these features have especially made full use of the recent advances in the drill string telemetry.Advantageously, in embodiment, adopt real time bidirectional communication basically, improving measurement and the control in drilling well (and end and make a trip) the operation process, thereby realized improved operation and decision-making.
A kind of form of the present invention is applied to be used in combination with the operation of drilling face of land well, and this is manipulated: rig; Drill string, it roughly mechanically is combined on the rig and is suspended on the rig in the upper end; And the shaft bottom drill tool assembly of contiguous drill string lower end, this shaft bottom drill tool assembly is included in the drill bit of its lower end.A kind of method that is used to obtain about the information of at least one parameter of detecting at shaft bottom drill tool assembly place is proposed, may further comprise the steps: at least one measurement mechanism is provided in the drill tool assembly of shaft bottom, and described at least one measurement mechanism produces the survey data of representative at the measuring condition at shaft bottom drill tool assembly place; Provide the uphole processor system at the ground surface place; Provide with described at least one measurement mechanism and be coupled and the drill string telemetry system system coupled with uphole processor; And described data are transferred to the uphole processor system from measurement mechanism via the drill string telemetry system.(as used herein, the ground surface of being mentioned comprises any land, water or ice surface or near the place that is suitable for land or offshore drilling).
In embodiment, the measuring condition of shaft bottom drill tool assembly is the character on the stratum of the encirclement shaft bottom drill tool assembly that records, and provides the step of at least one measurement mechanism to be included in the drill tool assembly of shaft bottom the well logging during device is provided in the drill tool assembly of shaft bottom.In this embodiment, provide the step of well logging during device to comprise the device of selecting from the group that is made of resistivity test device, directed resistivity test device, acoustic measurement device, nuclear measurement mechanism, Nuclear Magnetic Resonance Measurement device, device for pressure measurement, seismic survey device, imaging device and formation sample device is provided.
In its another embodiment, the measuring condition at shaft bottom drill tool assembly place is the well properties that records, and provides the step of at least one measurement mechanism to be included in the drill tool assembly of shaft bottom the measurement while drilling device is provided in the drill tool assembly of shaft bottom.In this embodiment, provide the step of measurement while drilling device to comprise the device of selecting from the group that is made of the pressure of the drill (weight-on-bit) measurement mechanism, torque-measuring apparatus, vibration measurement device, shock measurement device, stick-slip measurement mechanism, orientation measurement device and inclination measurement mechanism is provided.
In its another embodiment, the shaft bottom drill tool assembly comprises the directed drilling subsystem, and comprises generation guiding control signal in the step of ground based processor place generation control signal.In this embodiment, this directed drilling subsystem comprises the rotary steering system, and comprises that in the step of ground based processor place generation control signal generation is used for the guiding control signal of rotary steering system.
In a kind of form of the present invention, in the drill tool assembly of shaft bottom, provide the step of at least one measurement mechanism to be included in a plurality of measurement mechanisms are provided in the drill tool assembly of shaft bottom, these a plurality of measurement mechanisms produce the survey data of a plurality of conditions of representing drill tool assembly place, shaft bottom.
In a kind of form of the present invention, the drill string telemetry system is two-way and is included in wired drill pipe at least a portion drill string.In this embodiment of the present invention, between drill string telemetry system and uphole processor, be provided with wireless coupling.The uphole processor system can roughly be positioned at rig near, perhaps can be in position away from described rig.This drill string telemetry system can be the mixing telemetry system that comprises the remote measurement media of number of different types.In disclosed embodiment, mix the part that the drill string telemetry system comprises wired drill pipe, and at least a portion of the remote measurement media of from the group that constitutes by cable media, optical cable media and wireless transmission medium, selecting.In this embodiment, the part of described wired drill pipe comprises the drilling rod that is connected, each drilling rod comprises the pin-end (pin end) with the induction coupling that has conducting ring, the female threaded pipe end (boxend) with the induction coupling that has conducting ring, and be connected at least one conductor between described pin-end induction coupling and the female threaded pipe end induction coupling, thereby pin thread and the induction coupling of female threaded pipe end place that adjacent drilling rod is connected at them.For propagating fartherly, can the transponder subsystem be set the joint between drilling rod.Yet, in a kind of form of the present invention, also can on the length greater than about 2000ft of the described drilling rod that is connected, provide described wired drill pipe a part and need not any transponder.
In the embodiment of the wired drill pipe of use the above-mentioned type of the present invention part, the step of transmission data is included in to be had less than the described data of transmission on the carrier of the about frequency of 500KHz.In this embodiment, data are with the speed rates of per second 100 bits at least, and carry out transmitted in both directions basically in real time.
In a kind of form of the present invention, control signal produces at the uphole processor place and is transferred to the shaft bottom drill tool assembly via the drill string telemetry system.In the embodiment of this form of the present invention, the shaft bottom drill tool assembly comprises the directed drilling subsystem, and control signal is the guiding control signal.In this embodiment, control signal produces in response to survey data.
With reference to following detailed description, it is easier to understand that other features and advantages of the present invention will become in conjunction with the drawings.
Description of drawings
Fig. 1 is according to the embodiment of the invention and can be used in the chart of the system of the embodiment that puts into practice method of the present invention, partly represents with block diagram form in schematic form and partly.
Fig. 2 A is the calcspar of the wireless transceiver subsystem electronics that can use in combination with the embodiment of the invention.
Fig. 2 B is the chart that utilizes the surface interface of wireless transceiver, partly with cross-sectional form and represent with block diagram form that partly its electronic installation and antenna are installed on the drill string.
Fig. 3 is induction coupling wired drill pipe and is disclosed in cross-sectional view in the U.S. patent No. 6641434 that it can be used as at least a portion of the drill string telemetry system that adopts in the embodiment of the invention.
Fig. 4 is the part excision phantom drawing of a pair of current loop of facing (current-loop) inductive coupler element of Fig. 3.
Fig. 5 A be shown in Figure 4 should be to the cross-sectional view of the current circuit inductive coupler element faced, they lock together the part as the running drill string, the height that comprises the closure of surrounding two cores conducts electricity the cross-sectional view of circular path of low permeability.
Fig. 5 B is the amplification cross-sectional view of the assembling of the electromagnetic component of the current circuit inductive coupler element shown in the presentation graphs 5A in more detail.
Fig. 5 C is the part excision phantom drawing of the female threaded pipe end current circuit inductive coupler shown in Fig. 5 B, at length represents coil and inside cable.
Fig. 6 is the chart of one type formation resistivity well logging apparatus among the embodiment of the inventive method and system, and described device is as the part of well logging during (LWD) device or a cover LWD device.
Fig. 7 is the chart of one type directed resistance device among the embodiment of the inventive method and system, and described device is as the part of well logging during (LWD) device or a cover LWD device.
Fig. 8 is the chart of one type acoustical well-logging devices among the embodiment of the inventive method and system, and described device is as the part of well logging during (LWD) device or a cover LWD device.
Fig. 9 A-9D is the chart of one type well-shooting device among the embodiment of the inventive method and system, and described device is as the part of well logging during (LWD) device or a cover LWD device.
Figure 10 is the chart of one type nuclear logging device among the embodiment of the inventive method and system, and described device is as the part of well logging during (LWD) device or a cover LWD device.
Figure 11 is the chart of one type nuclear magnetic resonance log device among the method and system embodiment of the present invention, and described device is as the part of well logging during (LWD) device or a cover LWD device.
Figure 12 is the chart of one type pressure measxurement well logging apparatus among the method and system embodiment of the present invention, and described device is as the part of well logging during (LWD) device or a cover LWD device.
The specific embodiment
Fig. 1 represents to adopt well system of the present invention.Can be by land or be marine in the well site.In this example system, drilling well 11 is by being formed on the known manner rotary drilling in the stratum 30 under the face of land.Embodiments of the invention also can use directed drilling, as described later.
In the present embodiment, ground system also comprises drilling fluid or the mud 26 that is stored in the pit 27 that is formed at the well location place.Pump 29 is transported to the inside of drill string 12 with drilling fluid 26 via the port in the water tap 19, makes drilling fluid be downward through drill string 12, shown in direction arrow 8.Drilling fluid flows out drill string 12 via the port of drill bit 105, passes through annular section between the drill string outside and the borehole wall then to cocycle, shown in direction arrow 9.In this known manner, the lubricated drill bit 15 of drilling fluid also turns back to pit 27 so that earth cuttings is transported on the ground during recycling at it.
As known in the art, operated in relevant well site and the data of well site condition, preferably real-time collecting to collect around sensor can be arranged on the well site.For example, this ground transaucer can be provided with and be used for measurement parameter such as standpipe pressure, suspension hook load, the degree of depth, surface torque, per minute rotating speed and other.
The shaft bottom drill tool assembly 100 of illustrated embodiment comprises interface element 110, well logging during (LWD) module 120, measurement while drilling (MWD) module 130, the rotary guidance system that is used for directed drilling and motor 150 and drill bit 105.
In the present invention, adopted the drill string telemetry system, in an illustrated embodiment, this system comprises inductive wired drill pipe 180 systems that extend to the interface element 110 the drill tool assembly of shaft bottom from terrestrial components 185.According to the factor that comprises drill string length, relay block or transponder can every a segment distance be arranged in the post of wired drill pipe, an example is expressed as 182.Relay block can be provided with sensor, in the U.S. number of patent application (document number 19.0410/11) of common pending trial further instruction is arranged, and this application and the application submitted on same, and belonged to the assignee identical with the application.
At the top of wired drill string, be terrestrial components or surface interface 185.When using the wired drill pipe system, must between uppermost wired drill pipe and ground based processor, have communication link (among other things, this communication link is usually carried out one or more following functions: receive and/or send data, recorded information and/or control is gone to and/or from the information of shaft bottom and ground installation, carry out and calculate and analyze, and reach with operating personnel communicate by letter with remote address).Advised the whole bag of tricks, wherein some are summarised in the U.S. patent 7040415, comprise the use slip-ring device, and use the rotation electric coupler based on inductance or so-called transformer action.These technology are collectively referred to as the swiveling faucet technology.Slip ring (being also referred to as brush contact susface) is the known electric connector that is designed to electric current or signal are sent to from securing electric lines whirligig.Usually, it constitutes by be bearing in the fixing graphite or the Metal Contact part (brush) that rub that (for example, are bearing in the top of drill with ferrule union) in the on-rotatably moving part on the external diameter of rotating metallic ring.Along with the metal ring rotation, electric current or signal conduct to metal ring by fixed brush, have formed connection.The known rotation electric coupler based on inductance (transformer action) as rotary transformer provides for slip ring and the optional of contact brush based on the conduction between rotation and the permanent circuit to substitute, so directly contact optional.Transformer Winding comprises fixed coil and revolving coil, and the both is concentric with axis of rotation.Any coil can both be as elementary winding and another as secondary windings.The scheme of this section described these types can be used as terrestrial components 185 shown in Figure 1.At present, wireless solution is preferred, for example the U.S. patent application serial number _ _ this type of being further specified in (file 19.0403/32), this application and the application submitted on same, and belonged to the assignee identical with the application.As mentioned patent application serial number _ _ embodiment of (file 19.0403/32) described in, the uphole interface of terrestrial components 185 forms and electronic installation 35 couplings, described electronic installation is along with kelly bar 17 rotations and comprise and the antenna of well logging and control module 4 and the transceiver and the antenna of transceiver two-way communication that well logging and control module 4 comprise the uphole processor system in the present embodiment.Communication link 175 is shown schematically between the electronic installation and antenna of uphole interface and well logging and control module 4.Therefore, the structure of this embodiment provide from well logging and control module 4 by communication link 175 to terrestrial components 185, by the wired drill pipe telemetry system to the parts of interface, shaft bottom 110 and shaft bottom drill tool assembly and in contrast be used for communicating to connect of bidirectional operation.
Fig. 2 A represents one type the wireless transceiver subsystem electronics that can be used as the electronic installation 30 of Fig. 1.Also can be with reference to U.S. patent 7040415.Connect with the WDP modem from the/signal of induction coupling of going to the top sub of uppermost wired drill pipe.WDP modem 221 connects with radio modem 231 conversely.Battery 250 and power supply 255 also are set to supply with modem electric power.Above-mentioned U.S. patent application serial number _ _ having described other in (file 19.0403/32) may preferred TRT.
WDP surface modem 202 be applicable to downhole tool in one or more modems, transponder or other interfaces communicate by letter via the wired drill pipe telemetry system.Preferably, modem provides two-way communication.Modem and another modem that is arranged in downhole tool or transponder or miscellaneous part are communicated by letter.The numeral of any kind of and analog modulation scheme can be used, such as two-phase frequency shift keying (FSK), QPSK (QPSK), quadrature amplitude modulation (QAM), discrete multitone tone (DMT) etc.These schemes can with the data multiplexing technique of any kind of such as Time Division Multiplexing, frequency division multiplexing (FDM) etc. is used in combination.Modem can comprise the function that is used for drill pipe diagnostics and downhole tool diagnostics.
Fig. 2 B be illustrated in mentioned common pending trial U.S. patent application serial numbers _ _ embodiment that (file 19.0403/32) described, wherein between kelly bar 250 and uppermost wired drill pipe 181, be provided with special protection joint 240.Protection joint 240 has the induction coupling 241 that the induction coupling with uppermost wired drill pipe is coupled at its lower end.The cable 215 that is connected to induction coupling 241 passes sealed port and draws protection joint 240, and extends to transceiver subsystem 230 in the outside of kelly bar 250, and this transceiver subsystem comprises antenna 235.The extraction location of the cable on protection joint 240 can be provided with connector 246.The cable that extends along the outside of kelly bar 250 can be sealed in the groove in the kelly bar, and for example by epoxy or PEEK material protection.Another connector can be set at the transceiver subsystem electronics place.It is right that cable 215 is provided with at least one line.Can with reference to the U.S. patent application serial number of common pending trial _ _ the more embodiment and the transceiver subsystem structure of (file 19.0403/32), and the explanation of a plurality of antennas of the redundancy that interrelates with transceiver subsystem, and the explanation of the safe power generation of using by the transceiver subsystem of rotation.
The U.S. patent application serial number of common as mentioned pending trial _ _ (file 19.0410/11) described, although only represented a surface units 4 in a well site, also can one or more surface units be set across one or more well sites.These surface units can be connected to one or more surface interface via one or more communication lines with wired or wireless connection.Communication topology between surface interface and the ground system can be point-to-point, point-to-multipoint or how point-to-point.Wired connection comprises the cable that uses any kind (using the electric wire of the agreement (serial, Ethernet, etc.) of any kind) and optical fiber.Wireless technology can be the standard wireless communication technology of any kind of, such as IEEE802.11 standard, Bluetooth, the optical communication technique of the modulation scheme of zigbee or any off-gauge RF or use any kind of, such as FM, AM, PM, FSK, QAM, DMT, OFDM etc., with the data multiplexing technique of any kind of such as TDMA, FDMA, CDMA etc. combine.As an example, the antenna that is used for wireless connections can be placed on the skin of parts.
One or more sensors 204 can be set measuring different drilling parameters in the interface, such as temperature, pressure (vertical tube, mud etc.), mudflow, noise, vibration, probing mechanics (that is, moment of torsion, weight, acceleration, pipe rotation, etc.) etc.These sensors also can be connected to AFE(analog front end) so that carry out Signal Regulation and/or be connected to processor so that handle and/or analyze data.Sensor also can be used for carrying out diagnosis.Diagnostics can be used to locate the position of the mistake in the wired drill pipe system, measures the character of noise and/or wired drill pipe telemetry system and carries out other diagnosis of drilling well.Sensors of various types can be attached in these parts.One type sensor can be a ground transaucer, is used for measuring the probing mechanics, can be with high sample rate work.Sensing data can be recorded in the storage device.
The wired drill pipe that discloses in Fig. 3-5 expression U.S. patent 6641434, this patent is merged by reference.Wired drill pipe joints 310 (Fig. 3) has the first current circuit inductive coupler element 321 and the second current circuit inductive coupler element 331, lays respectively at each end of bar.Fig. 3 represents that also wired drill pipe joints 310 comprises the elongated pipe handle 311 with axial hole 312, first inductive coupler element 321 at female threaded pipe end 322 places and second inductive coupler element 331 at pin-end 332 places.Induction coupling 320 is expressed as by second inductive coupler element 331 ' of the pin-end 332 ' in first inductive coupler element 321 and the adjacent wired drill pipe to be formed.
Fig. 3 and 4 expressions have been determined the female threaded pipe end 322 of internal thread 323 and have been had the interior contact shoulder 324 of ring-type of first groove 325.Fig. 3 and 4 also represents the pin-end 332 ' of having determined external screw thread 333 ' and the interior pipe end 334 ' that contacts of the ring-type with second groove 335 ' of adjacent wired drill pipe joints.(project of wired drill pipe joints that the back item number of following apostrophe is represented to belong to adjacent).
Fig. 5 A is the cross-sectional view of the current circuit inductive coupler element a pair of shown in Figure 3 faced mutually, and they lock together the part as the operation drill string.Provide the cross-sectional view of circular path 340 of high conductivity, the low permeability (permeability) of the closure of surrounding two cores, and the cross-sectional view of pipeline 313 has formed the passage of the inside cable 314 of two inductive coupler element that are used to be electrically connected wired drill pipe joints 310.
Fig. 5 B is the amplification cross-sectional view of the assembling of first coil 348, first high permeability core 347 and first coil windings 348.Fig. 5 B also represents to surround the pipeline 313 of inside cable 314.(in Fig. 5 B and 5C, compare with the pin thread size for clarity, first coil 328 is represented greatlyyer in a preferred embodiment than it, and the intensity of drilling rod can not be impaired in the preferred embodiment).
Fig. 5 B also shows and has determined to have concentric first annular concave surface 326 in the face of (facing) part 326a and 326b.Have the high conduction of first annular concave, low magnetic layer 327 on first annular concave surface 326.Layer 327 has been determined first ring cavity.Female threaded pipe end 322 comprise be fixedly mounted in first floor 327 with one heart in the face of first coil 328 in first ring cavity between part 327a and the 327b.
Fig. 5 B also represents to have determined to have second groove 335 ' of facing second annular concave surface 36 of part 336 ' a and 336b ' with one heart.Have the high conduction of second annular concave, low magnetic layer 337 on second annular concave surface 336 '.Layer 337 ' has been determined second ring cavity.Pin-end 332 ' comprise be fixedly mounted in the second layer 337 ' with one heart in the face of second coil 338 ' in second ring cavity between part 337a ' and the 337b '.
Fig. 5 B also represents to comprise the first current circuit inductive coupler element 321 of the first high conduction, low magnetic layer 327, and the second current circuit inductive coupler element 331 ' that comprises the second high conduction, low magnetic layer 337 '.Each layer is coated to or appends on its inner surface of groove.First coil 328 is in concentric the facing between part 327a and the 327b of first floor 327.So the shaping layer (or band) 327 of the first high conduction, low magnetic conduction partly surrounds first coil 328.Similarly, the second high conduction, low magnetic layer (or band) 337 ' partly surround second coil 338 '.
Fig. 5 C is the amplification cross-sectional view of the current circuit inductive coupler element of the female threaded pipe end shown in Fig. 5 B, represents the details of first coil 328, and this first coil comprises first high permeability core 347 and first coil windings 348.Core 347 has the cross section of axial elongation.Second coil 338 ', second core 357 ' and second coil windings 358 ' of Fig. 5 B are similar structures.
Each coil is mainly along the high conduction of the union of the inner surface that covers groove, the electric current in the low magnetic layer induction tube joint.Each of conductive material layer is connected to or is coated to around the inner surface of the groove of core.
As described in the patent of ' 434, high conduction, low magnetic layer can be made by the high conduction with the conductance that is higher than steel basically, the material of low magnetic conduction, and except other metals, example has copper and copper alloy.
Only pass the union of steel with path 340 and compare, high conduction, low magnetic layer have reduced resistance loss on whole tubing string length by the resistance that reduces circulation path 340.The magnetic flux that high conduction, low magnetic layer also penetrate into each wired union of steel by minimizing has reduced the flux loss on the whole tubing string length.Although circular path 340 is closed path ideally, path 340 must not be to be made of conductive layer all over, because any slit in the conductive layer in path 340 all can connect by the local pipe end of steel.Slit in the conductive layer of circular path may produce by wearing and tearing on the softer conductive layer of contact point near the hard steel of contact pipe end.Several this slit on the length of whole tubing string in the conductive layer of circular path can not cause the energy loss that is enough to cause appreciable impact.
As in the patent of ' 434, the two contact tube joints with first and second inductive coupler element that lay respectively at interior shoulder and inner tube place have been described by the system of Fig. 3-5D.The size of union makes distance between outer tunnel end and the interior shoulder than the big less amount of the distance between outer shoulder and the inner tube.Fig. 5 A represents the distance D between the contact shoulder 324 in outer tunnel end 341 and the ring-type
1And outer shoulder 351 ' and the interior distance D that contacts between the pipe end 334 '
2Distance D
1Compare distance D
2Big less amount.When two unions suitably fastening (promptly, being utilized as realization end 341 forces fastening with respect to the required moment of torsion of the suitable seal of tube of the shoulder 351 ' of adjacent wired bar), then this less amount allows identical moment of torsion to come the inner tube 334 ' of adjacent relatively wired union to tighten interior shoulder 324 automatically, so that form the high conduction of sealing, the circular path 340 of low magnetic conduction reliably.
In this embodiment, the part of the wired drill pipe of the type described in the patent of among Fig. 3-5C and ' 434 helps to provide length greater than about 1000ft and less than the about part of the wired drill pipe of the connection of 7000ft, and without any need for transponder.
Can be as the LWD equipment 120 of system and method for the present invention or as an example of the part of LWD equipment group 120, be that title is two resistivity LWD equipment that the U.S. patent 4899112 of " be used for the shallow and dark degree of depth well logging apparatus and the method for layer resistivity " definitely discloses, this patent is merged by reference at this.As shown in Figure 6, upper and lower transmitting antenna T
1And T
2Has upper and lower reception antenna R betwixt
1And R
2Antenna is formed on the recess in the drill collar of modification and is installed in the insulation materials.The phase shift of the electromagnetic energy between the receiver provides the indication in the formation resistivity at more shallow relatively depth of investigation place, and the decay of the electromagnetic energy between the receiver provides the indication in the formation resistivity at the main deeply place of darker relatively exploration.Can be with reference to above mentioned U.S. patent 4899112 to obtain more details.In operation, represent the signal of decay and represent the signal of phase place to be coupled to processor, its output can be coupled to telemetric circuit, and this circuit is modulated mud-pulse in the art, and in the embodiment of native system, the carrier of modulation drill string telemetry system.Different with the existing application of the two resistivity technique that combine mud-pulse telemetry, system and method for the present invention can provide more data and data are provided basically in real time.
A useful especially use of native system is to combine with controlled steering or " directed drilling ".In this embodiment, rotary guiding subsystem 150 (Fig. 1) is set, this subsystem is suitable for controlling via the drill string telemetry system.Directed drilling is intentionally to deviate from the route that drilling well can be taked naturally.In other words, directed drilling is a direction of controlling drill string like this, so that it is advanced on the direction of wanting.Directed drilling, for example, drilling well at sea is favourable, can bore a plurality of wells from single platform because it makes.Directed drilling can also be crossed reservoir by horizontal ground auger.Horizontal drilling makes that longer drilling well can stride across reservoir, and this has improved the throughput rate of well.The directed drilling system also can be used in the vertical drilling operation.Usually drill bit can leave the wellbore trace of plan, because the power that the stratum of being passed has unpredictable natural conditions or drill bit to stand to change.Depart from when occurring when this, the directed drilling system can be used to drill bit is put back in the distance of regulation.The known method of directed drilling comprises rotary steering system (" RSS ").In RSS, drill string rotates from ground, and drilling rig makes drill bit drill on the direction of wanting downwards.Make drill string rotating greatly reduce the generation of drill string hang-up in the drilling process or jam.The rotary steerable drilling system that is used for getting out on land the well that departs from usually is classified as " aligning drill bit " system or " propelling drill bit " system.In aiming at bit system, the axis of rotation of drill bit departs from the local axis of shaft bottom drill tool assembly on the basic orientation of new wellhole.Wellhole is expanded according to three point geometry of the custom of being determined by upper and lower stabilizer contact and drill bit.And the deviation angle of the drill axis that the limited distance between drill bit and the following stabilizer is coupled causes producing the needed non-colinear condition of curve.This has many methods to realize, is included near the fixed bend at a some place in the shaft bottom drill tool assembly of following stabilizer or is distributed in the bending of the bit drive shaft between the stabilizer up and down.In its idealized form, do not need the drill bit transverse cuts, because drill axis rotation continuously on the direction of the wellhole of bending.The example of aligning drill bit type rotary steering system and their mode of operation are at the open No.2002/0011359 of U.S. patent application; 2001/0052428 and U.S. patent No.6394193; 6364034; 6244361; 6158529; Have illustratedly in 6092610 and 5113953, all these files all are incorporated herein by reference.In promoting drill bit type rotary steering system, essential non-colinear condition applies eccentric force or displacement by making or descend one or two or other mechanism in the stabilizer on the direction of the propagation direction of being partial to wellhole.Equally, this also has many methods to realize, comprises the eccentric stabilizer (based on the scheme of displacement) of non-rotating (about wellhole) and apply force to eccentric actuator on the drill bit on the guide direction of wanting.Equally, realize guiding by between drill bit and two other contacts, producing non-colinear at least.Drill bit needs transverse cuts so that produce crooked hole in its ideal form.Promote the example of drill bit type rotary steering system, and their mode of operation is at U.S. patent No.5265682; 5553678; 5803185; 6089332; 5695015; 5685379; 5706905; 5553679; 5673763; 5520255; 5603385; 5582259; 5778992; Have illustratedly in 5971085, all these files are incorporated herein by reference.From ground guiding control can be at least in part based on for example using the formation resistivity measured value that obtains in conjunction with Fig. 6 and 7 described resistivity logging devices.
Point out that because conventional LWD equipment is only checked the relatively short distance in the stratum, so they slowly advanced from contact or bed boundary, were not used for the time that geographical guiding is adjusted thereby almost stay before detecting contact or bed boundary.The shallow degree of depth of exploration may cause dissatisfactory reactive geographical guiding, and wherein track only just can change when bit drills is outside the top of producing zone or bottom.Reactive geographical guiding can cause lower production discovery, the drilling well route that rises and falls and be difficult to completion.(referring to L.Chou etc., " towards the guiding control that improves output ", OilfieldReview, 2005, incorporated herein by reference.) real-time basically two-way drill string remote measurement of the present invention can improve geographical directed response time and precision.
When the equipment of the well logging during of reading deeply with orientation as the part of LWD equipment 120 shown in Figure 1 used in combination, bidirectioanl-telemetry technology of the present invention was more noticeable with the combination that geographical guiding is used.Signal from the equipment with axially aligned cylinder symmetric coil is not an orientation-sensitive.Equipment shown in Figure 7 provides inclination and horizontal coil to obtain the measurement of orientation-sensitive.(equally referring to Chou etc., Oilfield Review, 2005, supra.) sensor array comprises six emitter antennas and four receiver antennas.Five emitter antenna (T
1To T
5) axially arrange along the length of equipment.The 6th emitter antenna (T
6) the equipment axis is laterally directed relatively.The receiver antenna is positioned at each end of equipment.The receiver antenna is to (R
3And R
4) clamp transmitter, and in these receivers each is with respect to equipment axis 45 degree that tilt.Another is to receiver antenna (R
1And R
2) be positioned at the center of transmitter array, axially arrange and can obtain the propagation resistivity measured value of general type.Described layout has produced the preferential sensitivity for the electric conductivity on the side of equipment.Along with the equipment rotation, near conduction region its sensor can detect and record can record the direction of maximum conductivity.Magnetometer and accelerometer can be the direction directional data that equipment provides reference.Except its capacity of orientation, equipment provides than the darker measurement relatively of modal LWD resistivity equipment.Basically real time bidirectional drill string telemetry of the present invention in conjunction with described directed resistivity measurement equipment, has improved the performance of geographical guiding and has improved the speed and the precision of directed drilling control by the data volume that increases the place, ground.
Can be the such equipment that carries out acoustic logging in drilling well described in the U.S. patent No.6308137 as the other example of the part of the equipment of LWD equipment 120 or LWD equipment group 120, this patent be incorporated herein by reference.In disclosed embodiment, as shown in Figure 8, adopt offshore drilling equipment 810, and near the water surface, dispose sound wave emissions source or array 814.Alternatively, the aboveground or downhole source of any other adequate types or transmitter can be provided with.The igniting of uphole processor control transmitter 814.Uphole equipment also can comprise acoustic receiver and be used to catch near the recorder of the reference signal of sound source.In the prior art, uphole equipment also comprises mud-pulse telemetry equipment, is used to receive the MWD signal from downward drilling equipment.Remote-measuring equipment and recorder are coupled to processor usually so that record can utilize aboveground and downhole clock is synchronized.Down-hole LWD module 800 comprises sound receiver 831 and 832 at least, and they are coupled to signal processor so that record can synchronously be made up of the detected signal of receiver with the igniting of signal source.In the present invention, wired drill pipe or other high speed drill string telemetry, can make from the down-hole of uphole processor and aboveground timing signal high-speed synchronous, control from uphole processor when needed, and make log data and/or parameters calculated be transferred to ground at high speed, when relative lot of data can be when sound wave and/or well-shooting technology obtain, this is particularly useful.
Can be as LWD equipment 120, perhaps can be as another example of the equipment of the part of LWD equipment group, be as P.Breton etc., " seismic survey (Well PositionedSeismic Measurement) of location well ", Oilfield Review, pp.32-45, spring, the 2002 described equipment that are used to obtain seismic survey are quoted it and are incorporated into this.Down-hole LWD equipment can have single receiver (shown in Fig. 9 A and 9B), perhaps a plurality of receivers (shown in Fig. 9 C and 9D), and can be used in combination with the individually focus (shown in Fig. 9 A and 9C) or a plurality of seismic origins (shown in Fig. 9 B and 9D) at the place, ground at the place, ground.Therefore, comprise the reflection of leaving the stratigraphic boundary and be called as " zero well spacing " Fig. 9 A that vertical seismic profiling (VSP) is arranged, use single source and single receiver; Comprise the reflection of leaving the stratigraphic boundary and be called as Fig. 9 B that " becoming the well spacing " vertical seismic profiling (VSP) is arranged, use multiple source and single receiver; Comprise the refraction of passing the salt dome border and be called as Fig. 9 C of " contiguous salt petrographic province " vertical seismic profiling (VSP), use single source and a plurality of receiver; And comprise that some leave the reflection of stratigraphic boundary and be called as " inclined shaft " vertical seismic profiling (VSP), use multiple source and a plurality of receiver.As mentioned above, wired drill pipe or other high speed drill string telemetries, can make from the down-hole of uphole processor and aboveground timing signal high-speed synchronous, and can realize controlling from uphole processor when needed, and make log data and/or parameters calculated be transferred to ground at high speed, when relative lot of data can be when sound wave and/or well-shooting technology obtain, this is particularly useful.
Figure 10 represents the nuclear device of the well logging during disclosed in the U.S. patent Re.36012, this patent citation is incorporated into this, the source that it has utilized based on accelerometer is understandable that the nuclear LWD equipment of other types also can be as the part of LWD equipment 120 or LWD equipment group 120.In Figure 10, drill collar part 1040 is expressed as surrounding stainless steel equipment chassis 1054.1054 sides to its longitudinal axis (invisible in the figure) have formed the slurry channel of longitudinal extension on the chassis, are used for carrying drilling fluid downwards by drill string.Eccentric to the chassis 1054 opposite sides be neutron accelerator 1058, the detector 1062 at the nearly interval (near-spaced) of its relevant control and encapsulation 1060 of high-pressure electronic device and coaxial alignment.Nearly interval detector 1062 is mainly in response to the accelerometer output with minimum formation influence.Detector 1062 is preferably all modulated a neutron absorbing material protective cover 1064 by the combination neutron and is surrounded on all surface except contiguous accelerometer 1058.The output of contiguous detector 1062 is used for making the output needle of other detectors that source strength is fluctuateed standardization.Vertically be adjacent to nearly interval detector 1062 be a plurality of detectors or detector array, wherein 1066a and 1066d are illustrated in this view.Detector 1066a has the back protective cover, shown in 1068a.This array comprises at least one, preferably more than one, and epithermal neutron detector and at least one gamma detector, with 1084 expressions, it has protective cover 1086 in this example.Also can comprise one or more thermal neutron detectors.Above mentioned U.S. patent Re.36012 can be used to reference to further details.Except other, detector signal can be used to determine density of earth formations, porosity and lithology.In the present embodiment, the signal of representing these measurements advantageously via wired drill pipe or other two-way drill string telemetry systems with high-speed transfer to ground, and from the control signal on ground also with at a high speed and high accuracy be sent to the down-hole.
Figure 11 represents the embodiment of the kind of means described in the U.S. patent 5629623, be used to utilize the simultaneously layer assessment of pulsed nuclear magnetic resonance (NMR) in drilling well, this patent is incorporated in this paper by reference, is understandable that the NMR/LWD equipment of other types also can be as the part of LWD equipment 120 or LWD equipment group 120.Described in the patent of ' 623; the embodiment of a kind of structure of this device comprises that having of transformation is filled with the drill collar of the axial groove 1150 of ceramics insulator; and comprising RF antenna 1126, antenna 1126 is by nonmagnetic lid 1146 protections, and the RF electromagnetic energy that excites of generation and received pulse.The conductor of RF antenna at one end is grounding to drill collar.At the other end, conductor is coupled to RF transformer 1156 via pressure feedthrough 1152 and 1153.180 ° of phase differences between the electric current that transformer 1156 keeps in the diametrically opposite RF conductor.Cylindrical magnet 1122 produces static magnetic field in the stratum.The RF antenna can be arranged such that also drill collar self produces the RF magnetic field of vibration.The vibration RF magnetic field of baryon material is axially symmetrical in the stratum, with the measurement in the rotary course that helps drill string.In the present embodiment, represent the signal of these measured values advantageously to arrive ground surface with high-speed transfer, and also be sent to the down-hole with high speed and high accuracy from ground, ground control signal via wired drill pipe or other two-way drill string telemetry systems.
Figure 12 is the reduced graph of one type well logging apparatus of disclosure in the U.S. patent 6986282, this patent is incorporated herein by reference, be used for determining the down-hole pressure that comprises annular pressure, strata pressure and pore pressure during the drill-well operation, be understandable that the NMR/LWD equipment of other types also can be as the part of LWD equipment 120 or LWD equipment group 120.This device forms the stabilizer collar 1200 that having of remodeling run through the passage that is used for drilling fluid 1215 wherein.Fluid flows through this equipment and has produced interior pressure P
1The outer exposed of drill collar is in the annular pressure P of well on every side
AThe interior P that presses
1With annular pressure P
ABetween pressure reduction δ P be used for activation pressure assembly 1210.Two typical pressure measxurement component tables are shown 1210a and 1210b, are installed on the fin respectively.Pressure assembly 1210a is used for monitoring the annular pressure and/or the pressure on stratum on every side in the wellhole when being arranged to engage with the borehole wall.In Figure 12, pressure assembly 1210a is in and the borehole wall 1201 disengaged states, therefore, and measure annular pressure when needed.When moving when engaging with the borehole wall 1201, pressure assembly 1210a can be used to measure the pore pressure on stratum on every side.As shown in Figure 12, pressure assembly 1210b can utilize hydraulic control 1225 to extend from fin 1214, is used for sealed engagement with mud cake (mudcake) 1205 and/or the borehole wall 1201 so that the stratum around measuring.Above mentioned U.S. patent 6986282 can be used to reference to further details.Circuit (this not shown) is coupled to processor/controller with the signal of representative pressure, and its output can be coupled to telemetric circuit, this telemetric circuit modulate in the art mud-pulse and, in the embodiment of this system, the carrier of modulation drill string telemetry system.
In the present embodiment, represent the signal of these measured values advantageously to arrive ground surface with high-speed transfer, and also be sent to the down-hole with high speed and high accuracy from the control signal on ground via wired drill pipe or other two-way drill string telemetry systems.
Recently disclose and adopted that the equipment that is suspended on the logging cable facilitates the use locking mechanism, telescoping mechanism, motor, laterally auger spindle, positive displacement pump and drill bit are accurately laterally drilled via hole.This pump is used for making fluid to circulate with the clear drill cutter in transverse holes.Can be with reference to international open No.U.S.2006/010877 of international open No.WO2005/071208, PCT of PCT international open No.WO2004/072437, PCT and the open No.U.S.2005/0252688 of US patent application, all these files are incorporated in herein by reference.In an embodiment of the present invention, accurate laterally boring tool is used on the drill string of cooperating with the drill string telemetry system.
Claims (52)
1. method that is used to obtain about the information of at least one parameter of detecting at shaft bottom drill tool assembly place, the operation that is used for drilling face of land well, this is manipulated: rig; But it is upper end mechanical couplings rig and the drill string that hangs from rig roughly; And the shaft bottom drill tool assembly of contiguous drill string lower end, this shaft bottom drill tool assembly is included in the drill bit of its lower end; This method may further comprise the steps:
At least one measurement mechanism is provided in the drill tool assembly of shaft bottom, and described at least one measurement mechanism produces the survey data of representative at the measuring condition at shaft bottom drill tool assembly place;
Provide the uphole processor system at the ground surface place;
Provide with described at least one measurement mechanism and be coupled and the drill string telemetry system system coupled with described uphole processor; And
Described data are transferred to described uphole processor system from described measurement mechanism via described drill string telemetry system.
2. the method for claim 1, wherein the described measuring condition at shaft bottom drill tool assembly place is the character on the stratum of the encirclement shaft bottom drill tool assembly that records, and provides the described step of at least one measurement mechanism to be included in the drill tool assembly of shaft bottom the well logging during device is provided in the drill tool assembly of shaft bottom.
3. method as claimed in claim 2, wherein providing the described step of well logging during device to comprise provides the device of selecting from the group that is made of resistivity test device, directed resistivity test device, acoustic measurement device, nuclear measurement mechanism, Nuclear Magnetic Resonance Measurement device, device for pressure measurement, seismic survey device, imaging device and formation sample device.
4. the method for claim 1, wherein the described measuring condition at shaft bottom drill tool assembly place is the well properties that records, and provides the described step of at least one measurement mechanism to be included in the drill tool assembly of shaft bottom the measurement while drilling device is provided in the drill tool assembly of shaft bottom.
5. method as claimed in claim 4 wherein provides the described step of measurement while drilling device to comprise the device of selecting from the group that is made of the pressure of the drill measurement mechanism, torque-measuring apparatus, vibration measurement device, shock measurement device, stick-slip measurement mechanism, orientation measurement device and inclination measurement mechanism is provided.
6. the method for claim 1, wherein provide the described step of at least one measurement mechanism to be included in the drill tool assembly of shaft bottom a plurality of measurement mechanisms are provided in the drill tool assembly of shaft bottom, described a plurality of measurement mechanisms produce the survey data of representative in a plurality of conditions at shaft bottom drill tool assembly place.
7. the method for claim 1 wherein provides the described step of drill string telemetry system to comprise two-way drill string telemetry system is provided.
8. method as claimed in claim 3 wherein provides the described step of drill string telemetry system to comprise two-way drill string telemetry system is provided.
9. method as claimed in claim 5 wherein provides the described step of drill string telemetry system to comprise two-way drill string telemetry system is provided.
10. method as claimed in claim 7 provides wired drill pipe at least a portion that wherein provides the described step of drill string telemetry system to be included in drill string.
11. method as claimed in claim 10, wherein provide and the coupling of described at least one measurement mechanism and and the described step of the drill string telemetry system of described uphole processor coupling the wireless coupling that provides between described drill string telemetry system and the described uphole processor is provided.
12. the method for claim 1, the described step that the uphole processor system wherein is provided rig roughly near the position described uphole processor system is provided.
13. the method for claim 1 wherein provides the described step of uphole processor system to be included in position away from described rig described uphole processor system is provided.
14. the method for claim 1, wherein said drill string telemetry system are the mixing telemetry systems that comprises a plurality of dissimilar remote measurement media.
15. method as claimed in claim 14, wherein provide the described step of mixing the drill string telemetry system to comprise to provide the mixing telemetry system of at least a portion of the part that comprises wired drill pipe and remote measurement media, described remote measurement media is select from the group that is made of cable media, optical cable media and wireless transmission medium at least a.
16. the method for claim 1, wherein provide the described step of drill string telemetry system to comprise that at least a portion that drill string is provided is as the drilling rod that is connected, each drilling rod comprises the pin-end with the induction coupling that has conducting ring, the female threaded pipe end with the induction coupling that has conducting ring, and be coupling at least one conductor between described pin-end induction coupling and the female threaded pipe end induction coupling, thereby adjacent drilling rod at their pin thread that is connected to the induction coupling of female threaded pipe end place.
17. method as claimed in claim 16, the joint that wherein provides the described step of described drill string telemetry system to be included between the drilling rod provides at least one transponder subsystem.
18. method as claimed in claim 16, the wherein said step that described at least a portion of drill string is provided comprise length that the described drilling rod that is connected is provided greater than the described part of about 2000ft without any transponder.
19. method as claimed in claim 16, wherein the described step of transmitting described data via described at least a portion of drill string is included in and has less than the described data of transmission on the carrier of the about frequency of 500KHz.
20. method as claimed in claim 18, wherein the described step of transmitting described data via described at least a portion of drill string is included in and has less than the described data of transmission on the carrier of the about frequency of 500KHz.
21. method as claimed in claim 16, wherein the described step of transmitting described data via described at least a portion of drill string comprises with the described data of speed rates of per second 100 bits at least.
22. method as claimed in claim 18, wherein the described step of transmitting described data via described at least a portion of drill string comprises with the described data of speed rates of per second 100 bits at least.
23. method as claimed in claim 19, wherein the described step of transmitting described data via described at least a portion of drill string comprises with the described data of speed rates of per second 100 bits at least.
24. method as claimed in claim 7 also is included in the step that the ground based processor place produces the step of control signal and described control signal is transferred to the shaft bottom drill tool assembly via described drill string telemetry system.
25. method as claimed in claim 8 also is included in the step that the ground based processor place produces the step of control signal and described control signal is transferred to the shaft bottom drill tool assembly via described drill string telemetry system.
26. method as claimed in claim 9 also is included in the step that the ground based processor place produces the step of control signal and described control signal is transferred to the shaft bottom drill tool assembly via described drill string telemetry system.
27. method as claimed in claim 24, wherein said shaft bottom drill tool assembly comprises the directed drilling subsystem, and comprises generation guiding control signal in the described step of ground based processor generation control signal.
28. comprising in response to described survey data, method as claimed in claim 27, the described step that wherein produces control signal at the ground based processor place produce control signal.
29. method as claimed in claim 24, wherein, the described step that described control signal is transferred to described shaft bottom drill tool assembly comprises via described drill string telemetry system and in real time described control signal is transferred to described shaft bottom drill tool assembly basically.
30. method as claimed in claim 27, wherein said directed drilling subsystem comprises the rotary steering system, and the described step that produces control signal at the ground based processor place comprises and produces the guiding control signal that is used for described rotary steering system.
31. method as claimed in claim 30, the described step that wherein produces control signal comprises the signal of generation as the function that fathoms of shaft bottom drill tool assembly.
32. method as claimed in claim 27, wherein said directed drilling subsystem comprises electric power lateral wellbore instrument, and the described step that produces control signal at the ground based processor place comprises that generation is used for the guiding control signal of described electric power lateral wellbore instrument.
33. the method for claim 1, further comprising the steps of: that the surface interface between described drill string telemetry system and the described ground based processor is provided, and the ground survey of cooperating with described surface interface sensor is provided, described ground survey sensor comprises at least a sensor of selecting from the group of being made of temperature pick up, pressure sensor, mudflow sensor, noise transducer, vibrating sensor, torque sensor, acceleration transducer and turn-sensitive device.
34. method as claimed in claim 10 also is included in the step that at least one downhole sensor is provided in the wired drill pipe part of drill string, described at least one sensor is communicated by letter via wired drill pipe with uphole processor.
35. method as claimed in claim 10 also is included in the step that diverse location place in the limited drilling rod part of drill string provides a plurality of distributed downhole sensors, described sensor is communicated by letter via described wired drill pipe with described uphole processor.
36. method as claimed in claim 3, also comprise the step that the surface interface between described drill string telemetry system and the described ground based processor is provided, the drill string telemetry system that described surface interface comprises the rotation that is coupled two-wayly with and the not water tap of the signal of telecommunication between the rotary part that is coupled of described ground based processor.
37. method as claimed in claim 5, also comprise the step that the surface interface between described drill string telemetry system and the described ground based processor is provided, the drill string telemetry system that described surface interface comprises the rotation that is coupled two-wayly with and the not water tap of the signal of telecommunication between the rotary part that is coupled of described ground based processor.
38. method as claimed in claim 3, also comprise the step that the surface interface between described drill string telemetry system and the described ground based processor is provided, described surface interface comprises be coupled the drill string telemetry system of rotation and the wireless chain link of the signal of telecommunication between the described ground based processor two-wayly.
39. method as claimed in claim 5, also comprise the step that the surface interface between described drill string telemetry system and the described ground based processor is provided, described surface interface comprises be coupled the drill string telemetry system of rotation and the wireless chain link of the signal of telecommunication between the described ground based processor two-wayly.
40. a method that is used to obtain about the information of at least one parameter of detecting at shaft bottom drill tool assembly place, this method is used for the operation of drilled underbalanced face of land well, and wherein well remains under the Negative Pressure Difference with respect to the stratum of being drilled, and this is manipulated: rig; It is mechanically be coupled rig and be suspended on drill string on the rig of upper end roughly, and the shaft bottom drill tool assembly of contiguous drill string lower end, and this shaft bottom drill tool assembly is included in the drill bit of its lower end; This method may further comprise the steps:
At least one measurement mechanism is provided in the drill tool assembly of shaft bottom, and described at least one measurement mechanism produces the survey data of representative at the measuring condition at shaft bottom drill tool assembly place;
Provide the uphole processor system at the ground surface place;
Provide with described at least one measurement mechanism and be coupled and the drill string telemetry system system coupled with described uphole processor; And
Described data are transferred to described uphole processor system from described measurement mechanism via described drill string telemetry system.
41. a device that is used to obtain about the information of at least one parameter of detecting at shaft bottom drill tool assembly place, this device is used for drilling the operation of face of land well, and this is manipulated: rig; It is mechanically be coupled rig and be suspended on drill string on the rig of upper end roughly, and the shaft bottom drill tool assembly of contiguous drill string lower end, and this shaft bottom drill tool assembly is included in the drill bit of its lower end; This device comprises:
At least one measurement mechanism in the drill tool assembly of shaft bottom, described at least one measurement mechanism can be operated and produce the survey data of representative at the measuring condition at shaft bottom drill tool assembly place;
Uphole processor system at the ground surface place;
Be coupled and the drill string telemetry system system coupled with described at least one measurement mechanism with described uphole processor; And
Be used for described data are transferred to via described drill string telemetry system from described measurement mechanism the transmitter of described uphole processor system.
42. device as claimed in claim 41, wherein the described measuring condition at shaft bottom drill tool assembly place is the character on the stratum of the encirclement shaft bottom drill tool assembly that records, and described at least one measurement mechanism in the drill tool assembly of shaft bottom is included in the well logging during device in the drill tool assembly of shaft bottom.
43. device as claimed in claim 42, wherein said well logging during device comprise the device of selecting from the group that is made of resistivity test device, directed resistivity test device, acoustic measurement device, nuclear measurement mechanism, Nuclear Magnetic Resonance Measurement device, device for pressure measurement, seismic survey device, imaging device and formation sample device.
44. device as claimed in claim 41, wherein said described measuring condition at shaft bottom drill tool assembly place is the well properties that records, and described at least one measurement mechanism in the drill tool assembly of shaft bottom is included in the measurement while drilling device in the drill tool assembly of shaft bottom.
45. device as claimed in claim 44, wherein said measurement while drilling device comprises the device of selecting from the group that is made of the pressure of the drill measurement mechanism, torque-measuring apparatus, vibration measurement device, shock measurement device, stick-slip measurement mechanism, orientation measurement device and inclination measurement mechanism.
46. device as claimed in claim 41, wherein described at least one measurement mechanism in the drill tool assembly of shaft bottom is included in a plurality of measurement mechanisms in the drill tool assembly of shaft bottom, and described a plurality of measurement mechanisms can be operated and produce the survey data of representative in a plurality of conditions at shaft bottom drill tool assembly place.
47. one kind is used to obtain about the information of at least one parameter of detecting at shaft bottom drill tool assembly place and the method for control guiding motor subsystem, this method is used for drilling the operation of face of land well, and this is manipulated: rig; It is mechanically be coupled rig and be suspended on drill string on the rig of upper end roughly; And the shaft bottom drill tool assembly of contiguous drill string lower end, this shaft bottom drill tool assembly comprises the steerable drilling subsystem and at the drill bit of this assembly lower end; This method may further comprise the steps:
Directed resistivity equipment is provided in the drill tool assembly of shaft bottom, and described directed resistivity equipment produces the survey data of representing the directionally layer resistivity in the drill tool assembly zone, shaft bottom;
Provide the uphole processor system at the ground surface place;
Provide with described directed resistivity equipment and be coupled and the two-way drill string telemetry system system coupled with described uphole processor;
Described survey data is transferred to described uphole processor system from described directed resistivity equipment via described two-way drill string telemetry system; And
Control signal is transferred to the steerable drilling subsystem of described shaft bottom drill tool assembly via described two-way drill string telemetry system from described processor system.
48. method as claimed in claim 47 wherein provides the described step of drill string telemetry system to be included at least a portion drill string wired drill pipe is provided.
49. method as claimed in claim 47, wherein provide the described step of drill string telemetry system to comprise that at least a portion that drill string is provided is as the drilling rod that is connected, each drilling rod comprises the pin-end with the induction coupling that has conducting ring, the female threaded pipe end with the induction coupling that has conducting ring, and be coupling at least one conductor between described pin-end induction coupling and the female threaded pipe end induction coupling, thereby adjacent drilling rod inductively is coupled at pin thread to the female threaded pipe end place that they are connected.
50. method as claimed in claim 49, wherein the step of transmitting described data via described at least a portion of drill string is included in and has less than the described data of transmission on the carrier of the about frequency of 500KHz.
51. method as claimed in claim 49, wherein the described step of transmitting described data via described at least a portion of drill string comprises with the described data of speed rates of per second 100 bits at least.
52. method as claimed in claim 48, wherein, the described step that described control signal is transferred to described shaft bottom drill tool assembly comprises via described drill string telemetry system and in real time described control signal is transferred to described shaft bottom drill tool assembly basically.
Applications Claiming Priority (4)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US70532605P | 2005-08-04 | 2005-08-04 | |
| US60/705,326 | 2005-08-04 | ||
| US60/708,561 | 2005-08-16 | ||
| US11/498,845 | 2006-08-03 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN101253304A true CN101253304A (en) | 2008-08-27 |
Family
ID=39956028
Family Applications (3)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN2006800287414A Active CN101263276B (en) | 2005-08-04 | 2006-08-03 | interface and method for wellbore telemetry system |
| CNA2006800291388A Pending CN101253304A (en) | 2005-08-04 | 2006-08-04 | Bi-directional drill string telemetry for measurement and drilling control |
| CNA2006800289388A Pending CN101278102A (en) | 2005-08-04 | 2006-08-04 | Surface communication apparatus and method for use with string telemetry |
Family Applications Before (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN2006800287414A Active CN101263276B (en) | 2005-08-04 | 2006-08-03 | interface and method for wellbore telemetry system |
Family Applications After (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CNA2006800289388A Pending CN101278102A (en) | 2005-08-04 | 2006-08-04 | Surface communication apparatus and method for use with string telemetry |
Country Status (1)
| Country | Link |
|---|---|
| CN (3) | CN101263276B (en) |
Cited By (20)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101582724A (en) * | 2009-05-22 | 2009-11-18 | 西安石油大学 | Method for modeling seamless acoustic transmission channel of periodic drill rod |
| CN102165135A (en) * | 2008-09-30 | 2011-08-24 | 瓦姆钻杆钻具法国公司 | Instrumented drill string element |
| CN102282333A (en) * | 2008-11-26 | 2011-12-14 | 普拉德研究及开发股份有限公司 | Valve-controlled downhole motor |
| CN103883315A (en) * | 2012-12-21 | 2014-06-25 | 中国石油天然气集团公司 | Downhole and ground information transmission network system and method |
| CN104364466A (en) * | 2012-11-23 | 2015-02-18 | 特雷西德股份有限公司 | System and method of configuring control instructions for a tool assembly by means of machine readable component information |
| CN105443108A (en) * | 2015-12-25 | 2016-03-30 | 中国石油天然气股份有限公司 | Telemetering system and method for oil-gas well |
| CN105464646A (en) * | 2015-12-24 | 2016-04-06 | 中国石油天然气集团公司 | Communication device and method for downhole geological parameters |
| CN107227951A (en) * | 2012-01-05 | 2017-10-03 | 默林科技股份有限公司 | Drill column communication system, part and method |
| CN107246240A (en) * | 2017-08-07 | 2017-10-13 | 中国石油大学(华东) | Adaptive torque balances differential pressure type drill bit |
| CN107548427A (en) * | 2015-06-03 | 2018-01-05 | 哈里伯顿能源服务公司 | Drilling tool with nearly drill bit electronic installation |
| CN107567531A (en) * | 2015-03-13 | 2018-01-09 | Aps科技公司 | Monitoring system with measurement ground top contact |
| CN107965307A (en) * | 2017-11-24 | 2018-04-27 | 中国石油天然气集团公司 | Drilling Control method, apparatus, electronic equipment and storage medium |
| CN108884708A (en) * | 2016-12-09 | 2018-11-23 | 开拓工程股份有限公司 | Seal member and sacrifice mems for drill string |
| CN109312611A (en) * | 2016-05-12 | 2019-02-05 | 通用电气(Ge)贝克休斯有限责任公司 | Underground component communication and electrical management |
| CN109828317A (en) * | 2019-03-13 | 2019-05-31 | 山东大学 | One kind being coupled to receive device, TBM driving tunnel fining detection system and method |
| CN110275223A (en) * | 2019-06-26 | 2019-09-24 | 中国海洋石油集团有限公司 | The monitoring while drilling system and monitoring while drilling of a kind of deep water geological disaster and recognition methods |
| CN110799727A (en) * | 2017-06-26 | 2020-02-14 | Hrl实验室有限责任公司 | System and method for generating an output of a downhole inertial measurement unit |
| CN110847821A (en) * | 2019-10-25 | 2020-02-28 | 西安石大斯泰瑞油田技术有限公司 | High-deflecting and high-drilling-speed rotary guide system |
| CN111328363A (en) * | 2017-09-05 | 2020-06-23 | 斯伦贝谢技术有限公司 | Controlling drill string rotation |
| CN113216943A (en) * | 2021-05-24 | 2021-08-06 | 电子科技大学 | Wireless electromagnetic wave transmission receiving and transmitting system for logging-while-drilling signals |
Families Citing this family (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102168553A (en) * | 2011-04-13 | 2011-08-31 | 余慧君 | High-speed measurement-while-drilling communication system |
| CN103256038B (en) * | 2012-02-21 | 2016-01-20 | 中国石油化工股份有限公司 | The method of monitoring downhole drill bit behavior in service |
| WO2015192226A1 (en) * | 2014-06-18 | 2015-12-23 | Evolution Engineering Inc. | Measuring while drilling systems, method and apparatus |
| US20160032715A1 (en) * | 2014-07-30 | 2016-02-04 | Baker Hughes Incorporated | Rig telemetry system |
| CN112796680B (en) * | 2021-01-04 | 2022-05-03 | 中煤科工集团重庆研究院有限公司 | Suspension installation method for protecting casing pipe of pre-pumping ground well to mining well |
Family Cites Families (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US6816082B1 (en) * | 1998-11-17 | 2004-11-09 | Schlumberger Technology Corporation | Communications system having redundant channels |
| US6641434B2 (en) * | 2001-06-14 | 2003-11-04 | Schlumberger Technology Corporation | Wired pipe joint with current-loop inductive couplers |
| US7040415B2 (en) * | 2003-10-22 | 2006-05-09 | Schlumberger Technology Corporation | Downhole telemetry system and method |
-
2006
- 2006-08-03 CN CN2006800287414A patent/CN101263276B/en active Active
- 2006-08-04 CN CNA2006800291388A patent/CN101253304A/en active Pending
- 2006-08-04 CN CNA2006800289388A patent/CN101278102A/en active Pending
Cited By (33)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102165135A (en) * | 2008-09-30 | 2011-08-24 | 瓦姆钻杆钻具法国公司 | Instrumented drill string element |
| CN102282333A (en) * | 2008-11-26 | 2011-12-14 | 普拉德研究及开发股份有限公司 | Valve-controlled downhole motor |
| CN102282333B (en) * | 2008-11-26 | 2014-07-09 | 普拉德研究及开发股份有限公司 | Valve-controlled downhole motor |
| CN101582724B (en) * | 2009-05-22 | 2014-12-03 | 西安石油大学 | Method for modeling seamless acoustic transmission channel of periodic drill rod |
| CN101582724A (en) * | 2009-05-22 | 2009-11-18 | 西安石油大学 | Method for modeling seamless acoustic transmission channel of periodic drill rod |
| CN107227951B (en) * | 2012-01-05 | 2021-06-11 | 默林科技股份有限公司 | Drill string communication systems, components, and methods |
| CN107227951A (en) * | 2012-01-05 | 2017-10-03 | 默林科技股份有限公司 | Drill column communication system, part and method |
| CN104364466A (en) * | 2012-11-23 | 2015-02-18 | 特雷西德股份有限公司 | System and method of configuring control instructions for a tool assembly by means of machine readable component information |
| CN104364466B (en) * | 2012-11-23 | 2017-06-30 | 图博斯科珀挪威股份有限公司 | It is the system and method that tool assembly builds control instruction by means of machine readable component information |
| CN103883315A (en) * | 2012-12-21 | 2014-06-25 | 中国石油天然气集团公司 | Downhole and ground information transmission network system and method |
| CN107567531A (en) * | 2015-03-13 | 2018-01-09 | Aps科技公司 | Monitoring system with measurement ground top contact |
| CN107548427A (en) * | 2015-06-03 | 2018-01-05 | 哈里伯顿能源服务公司 | Drilling tool with nearly drill bit electronic installation |
| CN105464646B (en) * | 2015-12-24 | 2019-01-18 | 中国石油天然气集团公司 | A kind of communication device and method of underground geologic parameter |
| CN105464646A (en) * | 2015-12-24 | 2016-04-06 | 中国石油天然气集团公司 | Communication device and method for downhole geological parameters |
| CN105443108A (en) * | 2015-12-25 | 2016-03-30 | 中国石油天然气股份有限公司 | Telemetering system and method for oil-gas well |
| CN109312611A (en) * | 2016-05-12 | 2019-02-05 | 通用电气(Ge)贝克休斯有限责任公司 | Underground component communication and electrical management |
| CN109312611B (en) * | 2016-05-12 | 2021-11-26 | 通用电气(Ge)贝克休斯有限责任公司 | Downhole component communication and power management |
| US10934784B2 (en) | 2016-12-09 | 2021-03-02 | Evolution Engineering Inc. | Seal and sacrificial components for a drill string |
| CN108884708A (en) * | 2016-12-09 | 2018-11-23 | 开拓工程股份有限公司 | Seal member and sacrifice mems for drill string |
| CN108884708B (en) * | 2016-12-09 | 2022-04-19 | 开拓工程股份有限公司 | Seal component and sacrificial component for a drill string |
| CN110799727B (en) * | 2017-06-26 | 2023-06-27 | Hrl实验室有限责任公司 | System and method for generating output to a borehole inertia measurement unit |
| CN110799727A (en) * | 2017-06-26 | 2020-02-14 | Hrl实验室有限责任公司 | System and method for generating an output of a downhole inertial measurement unit |
| CN107246240B (en) * | 2017-08-07 | 2019-03-19 | 中国石油大学(华东) | Adaptive torque balances differential pressure type drill bit |
| CN107246240A (en) * | 2017-08-07 | 2017-10-13 | 中国石油大学(华东) | Adaptive torque balances differential pressure type drill bit |
| CN111328363A (en) * | 2017-09-05 | 2020-06-23 | 斯伦贝谢技术有限公司 | Controlling drill string rotation |
| CN107965307B (en) * | 2017-11-24 | 2021-06-01 | 中国石油天然气集团公司 | Drilling control method and device, electronic equipment and storage medium |
| CN107965307A (en) * | 2017-11-24 | 2018-04-27 | 中国石油天然气集团公司 | Drilling Control method, apparatus, electronic equipment and storage medium |
| CN109828317A (en) * | 2019-03-13 | 2019-05-31 | 山东大学 | One kind being coupled to receive device, TBM driving tunnel fining detection system and method |
| CN110275223A (en) * | 2019-06-26 | 2019-09-24 | 中国海洋石油集团有限公司 | The monitoring while drilling system and monitoring while drilling of a kind of deep water geological disaster and recognition methods |
| CN110847821B (en) * | 2019-10-25 | 2020-12-11 | 西安石大斯泰瑞油田技术有限公司 | High-deflecting and high-drilling-speed rotary guide system |
| CN110847821A (en) * | 2019-10-25 | 2020-02-28 | 西安石大斯泰瑞油田技术有限公司 | High-deflecting and high-drilling-speed rotary guide system |
| CN113216943A (en) * | 2021-05-24 | 2021-08-06 | 电子科技大学 | Wireless electromagnetic wave transmission receiving and transmitting system for logging-while-drilling signals |
| CN113216943B (en) * | 2021-05-24 | 2023-04-14 | 电子科技大学 | Wireless electromagnetic wave transmission receiving and transmitting system for logging-while-drilling signals |
Also Published As
| Publication number | Publication date |
|---|---|
| CN101278102A (en) | 2008-10-01 |
| CN101263276A (en) | 2008-09-10 |
| CN101263276B (en) | 2011-12-21 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN101253304A (en) | Bi-directional drill string telemetry for measurement and drilling control | |
| US7913773B2 (en) | Bidirectional drill string telemetry for measuring and drilling control | |
| RU2413841C2 (en) | System for double-sided telemetry of drill string for measurement and control of drilling | |
| CA2316044C (en) | Reservoir monitoring through modified casing joint | |
| US6429784B1 (en) | Casing mounted sensors, actuators and generators | |
| CA2314061C (en) | Reservoir management system and method | |
| US6766854B2 (en) | Well-bore sensor apparatus and method | |
| US20100182161A1 (en) | Wireless telemetry repeater systems and methods | |
| CN110114551A (en) | System and method for data telemetry between adjacent drilling | |
| CA2703417A1 (en) | Instrumentation of appraisal well for telemetry | |
| CN114622900A (en) | Underground information transmission device and method based on micro-current | |
| MX2007008966A (en) | Wellbore telemetry system and method. | |
| US8756018B2 (en) | Method for time lapsed reservoir monitoring using azimuthally sensitive resistivity measurements while drilling | |
| CA2390706C (en) | Reservoir management system and method | |
| AU4587602A (en) | Wellbore antennae system and method |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| C06 | Publication | ||
| PB01 | Publication | ||
| C10 | Entry into substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| C02 | Deemed withdrawal of patent application after publication (patent law 2001) | ||
| WD01 | Invention patent application deemed withdrawn after publication |
Application publication date: 20080827 |