EP2972527B1 - Netzwerktelemetriesystem und verfahren - Google Patents

Netzwerktelemetriesystem und verfahren Download PDF

Info

Publication number
EP2972527B1
EP2972527B1 EP14762714.5A EP14762714A EP2972527B1 EP 2972527 B1 EP2972527 B1 EP 2972527B1 EP 14762714 A EP14762714 A EP 14762714A EP 2972527 B1 EP2972527 B1 EP 2972527B1
Authority
EP
European Patent Office
Prior art keywords
signal
node
receiver
transmitter
interference
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.)
Active
Application number
EP14762714.5A
Other languages
English (en)
French (fr)
Other versions
EP2972527A2 (de
EP2972527A4 (de
Inventor
John-Peter Van Zelm
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Baker Hughes Oilfield Operations LLC
Original Assignee
Baker Hughes Oilfield Operations LLC
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Baker Hughes Oilfield Operations LLC filed Critical Baker Hughes Oilfield Operations LLC
Publication of EP2972527A2 publication Critical patent/EP2972527A2/de
Publication of EP2972527A4 publication Critical patent/EP2972527A4/de
Application granted granted Critical
Publication of EP2972527B1 publication Critical patent/EP2972527B1/de
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

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
    • 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

Definitions

  • the present invention relates generally to telemetry apparatuses and methods, and more particularly to acoustic telemetry increased throughput network systems and methods for the well construction (drilling, completion) and production (e.g., oil and gas) industries.
  • Acoustic telemetry is a method of communication used in the well drilling, completion and production industries.
  • acoustic extensional carrier waves from an acoustic telemetry device are modulated in order to carry information via the drillpipe as the transmission medium to the surface.
  • the waves Upon arrival at the surface, the waves are detected, decoded and displayed in order that drillers, geologists and others helping steer or control the well are provided with drilling and formation data.
  • downhole information can similarly be transmitted via the well casings.
  • Drillstring acoustic telemetry systems are commonly designed with multiple transceiver nodes located at spaced intervals along the drillstring or wellbore.
  • the nodes can be configured as signal repeaters as necessary.
  • Acoustic telemetry networks can function in a synchronized fashion with the operation of the nodes and repeater nodes and other system components.
  • Data packets consisting of downhole sensor data were relayed node to node, in a daisy chain or linear fashion, typically beginning from a node located in the borehole apparatus (BHA), through the network to a destination, usually the surface receiver system.
  • BHA borehole apparatus
  • the data packets were transmitted (typically up- string) using time division multiplexing (TDM) techniques. Maximizing data packet transmission speed and throughput are objectives of drillstring telemetry systems and methods.
  • TDM time division multiplexing
  • an acoustic transmitter When exploring for oil or gas, and in other drilling applications, an acoustic transmitter can be placed near the BHA, typically near the drill bit where the transmitter can gather certain drilling, wellbore, and geological formation data, process this data, and then convert the data into a signal to be transmitted uphole to an appropriate receiving and decoding station.
  • the transmitter is designed to produce elastic extensional stress waves that propagate through the drillstring to the surface, where the waves are detected by sensors, such as accelerometers, attached to the drillstring or associated drilling rig equipment. These waves carry information of value to the drillers and others who are responsible for steering the well. Examples of such systems and their components are shown in: Drumheller U.S. Patent No.
  • a network is configured with multiple nodes using the acoustic transmission channel simultaneously, i.e., "multiplexing" the channel.
  • Network throughput is thus decoupled from the number of nodes and performance increases accordingly.
  • Internode interference can be controlled by one or more methods, including the following:
  • the reference numeral 2 generally designates a high throughput network system embodying an aspect of the present invention.
  • an exemplary application is in a drilling rig 4 ( FIG. 1 ).
  • the rig 4 can include a derrick 6 suspending a traveling block 8 mounting a kelly swivel 10, which receives drilling mud via a kelly hose 11 for pumping downhole into a drillstring 12.
  • the drillstring 12 is rotated by a kelly spinner 14 connected to a kelly pipe 16, which in turn connects to multiple drill pipe sections 18, which are interconnected by tool joints 19, thus forming a drillstring of considerable length, e.g., several kilometers, which can be guided downwardly and/or laterally using well-known techniques.
  • the drillstring 12 can terminate at or near a bottom-hole (borehole) apparatus (BHA) 20, which can be at or near an acoustic transceiver node (Primary) Station 0 (ST0).
  • BHA bottom-hole apparatus
  • ST0 acoustic transceiver node
  • FIG. 1 also shows the components of the drillstring 12 just above the BHA 20, which can include, without limitation, a repeater transceiver node 26 (ST1) and an additional repeater transceiver node 22 (ST2).
  • An upper, adjacent drillpipe section 18a is connected to the repeater 22 and the transmitter 26.
  • a downhole adjacent drillpipe section 18b is connected to the transmitter 26 and the BHA 20.
  • a surface receiver node 21 is located at the top of the drillstring 12 and is adapted for receiving the acoustic telemetry signals from the system 2 for further processing, e.g., by a processor or other output device for data analysis, recording, monitoring, displaying and other functions associated with a drilling operation.
  • FIG. 2 shows the internal construction of the drillstring 12, e.g., an inner drillpipe 30 within an outer casing 32. Interfaces 28a, 28b are provided for connecting drillpipe sections to each other and to the other drillpipe components, as described above.
  • W.1 illustrates an acoustic, electromagnetic or other energy waveform transmitted along the drillstring 12, either upwardly, downwardly, or laterally (in the case of horizontal wells).
  • the drillstring 12 can include multiple additional repeater transceiver nodes 22 at intervals determined by operating parameters such as optimizing signal transmission and reception with minimal delays and errors.
  • the drillstring 12 can also include multiple sensors along its length for producing output signals corresponding to various downhole conditions.
  • Data packets contain sensor or node status data and are transmitted from the primary node (e.g., ST0, typically the deepest node) and relayed from node-to-node in a daisy-chain (herein interchangeably referred to also as linear or serial) fashion to the surface receiver (Surface Rx) 21, which is generally located at or near the wellhead.
  • the data packets include sensor measurements from the BHA 20 and other sensors along the drillstring 12.
  • Such data packet sensor measurements can include, without limitation, wellbore conditions (e.g., annular/bore/differential pressure, fluid flow, vibration, rotation, etc.).
  • Local sensor data can be added to the data packet being relayed at each sensor node, thus providing along-string-measurements (ASMs).
  • ASMs along-string-measurements
  • a single node functions as the master node (e.g., ST0) and is typically an edge node at the top or bottom of the drillstring 12.
  • the master node monitors well conditions and sends data packets of varying type and intervals accordingly.
  • FIG. 3 shows the operation of a prior art linear telemetry network scheduling configuration where node transmissions are scheduled for separate non-overlapping time windows in order to prevent inter-node interference and the associated degradation in link performance (reliability and range).
  • TDM time division multiplexing
  • multiple nodes are configured for using the acoustic transmission channels at the same time, i.e., "multiplexing" the drillstring channel.
  • Multiplexing with multiple nodes transmitting simultaneously, decouples network throughput dependency on the number of nodes, and increases performance.
  • multiple nodes transmitting simultaneously will lead to inter-node interference and an associated degradation in link performance.
  • One or more of the following methods can be implemented to control internode interference during multi-node transmission:
  • FIG. 4 shows a 2-node gap multiplexing scheduling configuration.
  • Interfering transmissions are mitigated by physical separation (e.g., 2-node gap).
  • This configuration is applicable to electromagnetic pulse systems as well as acoustic, and is further applicable to downlink, uplink and bi-directional networks.
  • Interfering transmissions are mitigated by physical separation and associated signal propagation path loss: 3-link propagation path loss attenuation (desired) versus 1-link propagation path loss attenuation (interference). Additional interference minimization can be achieved through adjustment of the transmitter output power levels to minimize interference at one location, while providing sufficient signal power at the desired node receiver. Update interval/rate and network throughput are thus fixed regardless of the number of network nodes. Only latency increases with node number.
  • the interference between nodes can be further managed by coordinating network timing in such a manner that, while multiple node transmissions overlap in time, the desired signal precedes the anticipated interferer signal such that a sufficient portion of the desired signal experiences no interference allowing the receiving node to achieve more reliable signal detection, timing and phase recovery, and decoding once the interfering node begins transmission and signals overlap.
  • This method allows the receiver to favour the desired signal over the interferer. See, e.g., FIG. 12 , which is discussed below.
  • FIG. 5 shows a 1-node gap multiplexing scheduling configuration wherein multiple nodes are transmitting at the same time. This configuration is more aggressive than the 2-node gap configuration shown in FIG. 4 , having less interference suppression. Interfering transmissions are mitigated by physical separation and associated path loss: 1-link path loss attenuation (desired) versus 2-link path loss attenuation (interference). Update interval/rate and network throughput are thus fixed regardless of the number of network nodes. Only latency increases with node number.
  • FIG. 6 shows scheduling with an update rate which can be fixed at approximately 2t tx , for example, regardless of the number of nodes. Only latency increases with node number.
  • the receiver must be able to operate during self-transmission, without being excessively degraded by self-interference. This can be accomplished by assigning non-interfering frequency or orthogonal signal sets to the transmitter and receiver. If the transmitter and a receiver operate in the same channel (time, frequency), or further interference suppression is desired, high-power interfering self-transmission signals can be isolated from received signals through channel estimation techniques, as described below.
  • FIG. 7 shows a "receive-while-transmitting" configuration wherein an estimating function with a feedback loop is used to estimate the in-node transmitter to receiver channel.
  • a transmitter e.g., a piezo-electric stack, in the case of acoustics
  • receiver accelerometer, in the case of acoustics
  • FIG. 8 shows how the estimated intra-node channel can be used to suppress self-interference. Specifically, by applying an estimated channel filter to the known transmitted signal (as derived in FIG. 7 ), to translate the signal to how the receiver would perceive it, and subtracting it from the composite receive signal (self-interference from transmitter + desired receive signal originating from another node) to provide output corresponding to the desired receive signal only.
  • FIG. 9 shows an increased rate repeater scheduling configuration assigning orthogonal (i.e., low-interference) signal sets (indicated by ⁇ , ⁇ ) to transmitter and receiver nodes, thereby allowing multiple signals in respective channels simultaneously, increasing the update rate and the effective data rate.
  • the signal sets can be reused once interference nodes are sufficiently separated to ensure adequate interference isolation.
  • the update interval, t update is fixed at ⁇ 2 t tx , regardless of the number of repeaters and only latency increases.
  • the concept is the application of orthogonal multiple access techniques to increase channel efficiency (e.g., CDMA - Code Domain Multiple Access, FDMA - Frequency Domain Multiple Access, OFDM - Orthogonal Frequency Domain Multiplexing, etc.) as an alternative to the relatively inefficient TDM (Time Division Multiplexing) methods.
  • CDMA Code Domain Multiple Access
  • FDMA Frequency Domain Multiple Access
  • OFDM Orthogonal Frequency Domain Multiplexing
  • low-interference signal sets include: signals of non-overlapping frequencies (Frequency Division Multiplexing (FDM)), which can be contiguous frequency blocks (e.g., different passbands) or interleaved blocks (e.g., OFDM); signals of low cross-correlations, such as up/down, linear/exponential chirps, pseudorandom noise (PRN) sequences (Code Division Multiplexing (CDM)), e.g., Walsh codes, Hadamard, etc.; and signals transmitted on separate, isolated mediums (channels): acoustic, electromagnetic pulse, and mud pulse (MP); and propagation modes (e.g., axial, longitudinal and spiral).
  • FDM Frequency Division Multiplexing
  • FDM Frequency Division Multiplexing
  • OFDM Orthogonal frequency division Multiplexing
  • PRN pseudorandom noise
  • CDM Code Division Multiplexing
  • channels acoustic, electromagnetic pulse, and mud pulse (MP); and propagation modes (e.g.,
  • FIG. 10 shows orthogonal signal sets combined with simultaneous transmit and receive, to providing an update rate, t update , fixed at ⁇ t tx , regardless of the number of nodes whereby only latency increases with node number.
  • Node receivers are able to operate during transmission with minimized intra-node (self) interference due to transmitter-receiver signal orthognality, as previously discussed. If the transmitter and the receiver operate in the same channel, high-power interfering self-transmission signals can be isolated from received signals through channel estimation techniques, as described below.
  • FIG. 11 is a schematic diagram showing an example of an along-string measurement (ASM) configuration with varying/accumulating node payloads and signal propagation interference isolation.
  • ASM along-string measurement
  • FIG. 12 shows signal transmission scheduling refinement whereby a desired transmission (e.g., from M2 T x to M2 R x ) precedes an interfering transmission (e.g., from M1 T x to M2 R x ), creating a short period of interference-free reception of the desired signal.
  • This interference-free period improves signal detection, timing and phase recovery, effectively allowing the receiver (e.g., M2 R x ) to "lock" onto the desired signal, and generally improve link robustness.
  • FIG. 13 shows a system with directional transceivers for interference suppression.
  • the node receivers are tuned to receive upwardly-traveling signals and to suppress/reject downwardly-traveling signals. This can be accomplished by equipping an acoustic node with multiple transmitters and receivers, and phasing their outputs such that directional transmission or reception is achieved (e.g., transmissions propagate only uphole and receivers only detect signals originating from downhole, and vice-versa). The details of such an operation would be known to one versed in antenna beam forming techniques, and as such will not be elaborated in this text. Receive and transmit directionality can be exploited together, or individually, to suppress interference between nodes, enabling multiple nodes to transmit at the same time. Remaining interference is separated by a two-node gap.
  • the configurations described above have advantages of preserving multi-hop repeater network throughput, which is fundamentally related to channel multiplexing (reuse) efficiency.
  • EM electromagnetic

Landscapes

  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Remote Sensing (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Geophysics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Acoustics & Sound (AREA)
  • Arrangements For Transmission Of Measured Signals (AREA)
  • Radio Relay Systems (AREA)
  • Mobile Radio Communication Systems (AREA)

Claims (8)

  1. Lineares drahtloses Telemetrienetzwerksystem (2) für einen Schacht, der eine Bohrlochstruktur einschließt, die sich unterirdisch von der Oberfläche abwärts erstreckt, wobei das Telemetrienetzwerksystem einschließt: mehrere Netzwerkknoten (22, 26), die entlang des Bohrlochs verteilt sind; wobei mindestens einer der Knoten (22, 26) einen Sensor, der zum Bereitstellen einer Signaldatensatzausgabe angepasst ist, die einem lochabwärtigen Zustand entspricht; einen Übertrager zum Verbreiten des Signals zwischen Knoten (22, 26); und einen Empfänger zum Empfangen des Signals von anderen Knoten (22, 26) einschließt; wobei das System zum Übertragen von Telemetriesignalen über mehrere Netzwerkverknüpfungen gleichzeitig angepasst ist;
    dadurch gekennzeichnet, dass: ein jeweiliger Knoten (22, 26) einschließt
    einen Übertrager und einen Empfänger; wobei der jeweilige Knoten gleichzeitig überträgt und empfängt; und
    einen Filter (hch), der an eine Angleichung des Kanals zwischen dem Übertrager und dem Empfänger des jeweiligen Knotens (22, 26) angepasst ist.
  2. Telemetriesystem (2) nach Anspruch 1, einschließend:
    dass der Empfänger zum Empfangen mit abgeschwächter Selbstinterferenz während Übertragung angepasst ist.
  3. Telemetriesystem nach Anspruch 1, das eine Abschätzungsfunktion einschließt, einschließend:
    einen Übertrager-zu-Empfänger-Intraknotenkanal, der eine Ausgabe bereitstellt;
    wobei der adaptive Filter (hch) das Signal, das zur Übertragung vorgesehen ist, als eine Referenzeingabe aufweist;
    einen Summierer, der Ausgaben von dem Empfängerkanal und dem adaptiven Filter (hch) empfängt;
    wobei der Summierer ein Fehlersignal als eine Rückkopplungsausgabe an den adaptiven Filter (hch) bereitstellt; und
    der adaptive Filter (hch) derart eingestellt ist, um das Fehlersignal zu minimieren.
  4. Telemetriesystem nach Anspruch 1, das eine Empfängersignalisolierungsfunktion einschließt, einschließend:
    ein abgeschätzter Intraknoten-Übertrager-zu-Empfänger-Kanalfilter (hch), der das Signal, das zur Übertragung vorgesehen ist, als eine Eingabe vom Übertrager aufweist und eine Ausgabe bereitstellt, die das abgeschätzte Übertragersignal ist, wie es durch den Empfänger wahrgenommen wird;
    einen Summierer, der Eingaben von dem adaptiven Filter (hch) und die Empfängersignalausgabe empfängt, die zeitlich synchronisiert sind; und
    wobei der Summierer eine Ausgabe bereitstellt, die das empfangene Signal mit verringertem Übertragersignalinhalt umfasst.
  5. Telemetriesystem nach Anspruch 1, einschließend:
    dass die Steuersystemfunktion das Netzwerktiming koordiniert, wodurch ein erwünschtes Signal einem erwarteten, überlappenden Interferenzsignal zeitlich vorausläuft, das eine interferenzfreie Zeitperiode an einem Knoten zum Empfang eines Abschnitts des erwünschten Signals erzeugt, wodurch dem Knotenempfänger ermöglicht wird, sich auf dem erwünschten Signal zu arretieren.
  6. Telemetriesystem nach Anspruch 1, einschließend:
    mehrere Empfänger innerhalb eines Knotens mit Signalausgaben, die gestaffelt und derart kombiniert sind, um eine gestaffelte Anordnung zu bilden, die eine Richtungsunterscheidung von ankommenden Signalen ermöglicht, um Interferenz von einer unerwünschten Knotenübertragung zu minimieren, die aus einer anderen Richtung eintrifft.
  7. Telemetriesystem nach Anspruch 1, einschließend:
    mehrere Übertrager innerhalb eines Knotens mit Ausgabesignalen, die derart gestaffelt sind, um ausgehende Signale nur in eine Richtung zu verbreiten und Interferenz an einem anderen Knoten zu minimieren.
  8. Telemetriesystem nach Anspruch 1, einschließend:
    dass die gerichteten Empfänger dafür angepasst sind, unerwünschte Interferenzsignale, die am Empfänger aus einer Richtung eintreffen, zu unterdrücken, während sie erwünschte Signale aus einer anderen Richtung empfangen.
EP14762714.5A 2013-03-15 2014-03-17 Netzwerktelemetriesystem und verfahren Active EP2972527B1 (de)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201361800063P 2013-03-15 2013-03-15
PCT/US2014/030682 WO2014145848A2 (en) 2013-03-15 2014-03-17 Network telemetry system and method

Publications (3)

Publication Number Publication Date
EP2972527A2 EP2972527A2 (de) 2016-01-20
EP2972527A4 EP2972527A4 (de) 2016-11-16
EP2972527B1 true EP2972527B1 (de) 2019-10-23

Family

ID=51525115

Family Applications (1)

Application Number Title Priority Date Filing Date
EP14762714.5A Active EP2972527B1 (de) 2013-03-15 2014-03-17 Netzwerktelemetriesystem und verfahren

Country Status (5)

Country Link
US (1) US20140266769A1 (de)
EP (1) EP2972527B1 (de)
BR (1) BR112015023566A2 (de)
CA (1) CA2906905C (de)
WO (1) WO2014145848A2 (de)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11095399B2 (en) 2013-03-15 2021-08-17 Baker Hughes Oilfield Operations Llc Robust telemetry repeater network system and method
EP3114317B1 (de) * 2014-03-06 2023-04-26 Baker Hughes Oilfield Operations LLC System und verfahren zur relaisnetzwerktaktung eines linearen bohrlochrepeaters mit niedriger rate

Families Citing this family (46)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9458711B2 (en) 2012-11-30 2016-10-04 XACT Downhole Telemerty, Inc. Downhole low rate linear repeater relay network timing system and method
WO2014100262A1 (en) 2012-12-19 2014-06-26 Exxonmobil Upstream Research Company Telemetry for wireless electro-acoustical transmission of data along a wellbore
WO2014100275A1 (en) 2012-12-19 2014-06-26 Exxonmobil Upstream Research Company Wired and wireless downhole telemetry using a logging tool
US20150300159A1 (en) 2012-12-19 2015-10-22 David A. Stiles Apparatus and Method for Evaluating Cement Integrity in a Wellbore Using Acoustic Telemetry
US10480308B2 (en) 2012-12-19 2019-11-19 Exxonmobil Upstream Research Company Apparatus and method for monitoring fluid flow in a wellbore using acoustic signals
CA2920912C (en) 2013-08-28 2020-07-28 Evolution Engineering Inc. Optimizing electromagnetic telemetry transmissions
WO2015080754A1 (en) 2013-11-26 2015-06-04 Exxonmobil Upstream Research Company Remotely actuated screenout relief valves and systems and methods including the same
CA2955381C (en) 2014-09-12 2022-03-22 Exxonmobil Upstream Research Company Discrete wellbore devices, hydrocarbon wells including a downhole communication network and the discrete wellbore devices and systems and methods including the same
US9879525B2 (en) 2014-09-26 2018-01-30 Exxonmobil Upstream Research Company Systems and methods for monitoring a condition of a tubular configured to convey a hydrocarbon fluid
US9863222B2 (en) 2015-01-19 2018-01-09 Exxonmobil Upstream Research Company System and method for monitoring fluid flow in a wellbore using acoustic telemetry
US10408047B2 (en) 2015-01-26 2019-09-10 Exxonmobil Upstream Research Company Real-time well surveillance using a wireless network and an in-wellbore tool
WO2016153466A1 (en) * 2015-03-20 2016-09-29 Halliburton Energy Services, Inc. Repeater for a wellbore
US11441418B2 (en) 2016-06-30 2022-09-13 Schlumberger Technology Corporation Downhole electromagnetic network
US10364669B2 (en) 2016-08-30 2019-07-30 Exxonmobil Upstream Research Company Methods of acoustically communicating and wells that utilize the methods
US10590759B2 (en) 2016-08-30 2020-03-17 Exxonmobil Upstream Research Company Zonal isolation devices including sensing and wireless telemetry and methods of utilizing the same
US10167716B2 (en) 2016-08-30 2019-01-01 Exxonmobil Upstream Research Company Methods of acoustically communicating and wells that utilize the methods
US10697287B2 (en) 2016-08-30 2020-06-30 Exxonmobil Upstream Research Company Plunger lift monitoring via a downhole wireless network field
US10190410B2 (en) 2016-08-30 2019-01-29 Exxonmobil Upstream Research Company Methods of acoustically communicating and wells that utilize the methods
US10415376B2 (en) 2016-08-30 2019-09-17 Exxonmobil Upstream Research Company Dual transducer communications node for downhole acoustic wireless networks and method employing same
US11828172B2 (en) 2016-08-30 2023-11-28 ExxonMobil Technology and Engineering Company Communication networks, relay nodes for communication networks, and methods of transmitting data among a plurality of relay nodes
US10344583B2 (en) 2016-08-30 2019-07-09 Exxonmobil Upstream Research Company Acoustic housing for tubulars
US10465505B2 (en) 2016-08-30 2019-11-05 Exxonmobil Upstream Research Company Reservoir formation characterization using a downhole wireless network
AU2017321138B2 (en) * 2016-08-30 2020-05-21 Exxonmobil Upstream Research Company Reservoir formation characterization using a downhole wireless network
US10526888B2 (en) 2016-08-30 2020-01-07 Exxonmobil Upstream Research Company Downhole multiphase flow sensing methods
NO20180940A1 (en) * 2017-07-03 2019-01-04 Schlumberger Technology Bv Downhole adaptive multiband communication system
US10697288B2 (en) 2017-10-13 2020-06-30 Exxonmobil Upstream Research Company Dual transducer communications node including piezo pre-tensioning for acoustic wireless networks and method employing same
US10837276B2 (en) 2017-10-13 2020-11-17 Exxonmobil Upstream Research Company Method and system for performing wireless ultrasonic communications along a drilling string
CA3079020C (en) 2017-10-13 2022-10-25 Exxonmobil Upstream Research Company Method and system for performing communications using aliasing
WO2019074657A1 (en) 2017-10-13 2019-04-18 Exxonmobil Upstream Research Company METHOD AND SYSTEM FOR REALIZING OPERATIONS USING COMMUNICATIONS
CN111201454B (zh) 2017-10-13 2022-09-09 埃克森美孚上游研究公司 用于利用通信执行操作的方法和系统
AU2018347876B2 (en) * 2017-10-13 2021-10-07 Exxonmobil Upstream Research Company Method and system for performing hydrocarbon operations with mixed communication networks
US10715620B2 (en) * 2017-11-08 2020-07-14 Google Llc Streaming network monitoring caching infrastructure
US12000273B2 (en) 2017-11-17 2024-06-04 ExxonMobil Technology and Engineering Company Method and system for performing hydrocarbon operations using communications associated with completions
WO2019099188A1 (en) 2017-11-17 2019-05-23 Exxonmobil Upstream Research Company Method and system for performing wireless ultrasonic communications along tubular members
US10690794B2 (en) 2017-11-17 2020-06-23 Exxonmobil Upstream Research Company Method and system for performing operations using communications for a hydrocarbon system
WO2019113694A1 (en) 2017-12-13 2019-06-20 Mwdplanet And Lumen Corporation Electromagnetic telemetry transmitter apparatus and mud pulse-electromagnetic telemetry assembly
US10337321B1 (en) 2017-12-15 2019-07-02 Schlumberger Technology Corporation System and method to automate data acquisition in a wireless telemetry system
US10844708B2 (en) 2017-12-20 2020-11-24 Exxonmobil Upstream Research Company Energy efficient method of retrieving wireless networked sensor data
US11156081B2 (en) 2017-12-29 2021-10-26 Exxonmobil Upstream Research Company Methods and systems for operating and maintaining a downhole wireless network
AU2018397574A1 (en) 2017-12-29 2020-06-11 Exxonmobil Upstream Research Company (Emhc-N1-4A-607) Methods and systems for monitoring and optimizing reservoir stimulation operations
WO2019156966A1 (en) 2018-02-08 2019-08-15 Exxonmobil Upstream Research Company Methods of network peer identification and self-organization using unique tonal signatures and wells that use the methods
US11268378B2 (en) 2018-02-09 2022-03-08 Exxonmobil Upstream Research Company Downhole wireless communication node and sensor/tools interface
US11952886B2 (en) 2018-12-19 2024-04-09 ExxonMobil Technology and Engineering Company Method and system for monitoring sand production through acoustic wireless sensor network
US11293280B2 (en) 2018-12-19 2022-04-05 Exxonmobil Upstream Research Company Method and system for monitoring post-stimulation operations through acoustic wireless sensor network
WO2020201762A1 (en) 2019-04-03 2020-10-08 Raptor Oil Ltd Determining frequency band suitability for communication
EP4006299A1 (de) 2020-11-30 2022-06-01 Services Pétroliers Schlumberger Verfahren und system zur automatischen mehrzonenbohrlochprüfung mit geschlossener schleife eines reservoirs

Family Cites Families (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5128901A (en) 1988-04-21 1992-07-07 Teleco Oilfield Services Inc. Acoustic data transmission through a drillstring
US5838727A (en) * 1991-02-15 1998-11-17 Schlumberger Technology Corporation Method and apparatus for transmitting and receiving digital data over a bandpass channel
US6144316A (en) * 1997-12-01 2000-11-07 Halliburton Energy Services, Inc. Electromagnetic and acoustic repeater and method for use of same
US6791470B1 (en) 2001-06-01 2004-09-14 Sandia Corporation Reducing injection loss in drill strings
US20060114746A1 (en) * 2004-11-29 2006-06-01 Halliburton Energy Services, Inc. Acoustic telemetry system using passband equalization
US7928861B2 (en) 2006-04-19 2011-04-19 Xact Downhole Telemetry Inc. Telemetry wave detection apparatus and method
US8115651B2 (en) 2007-04-13 2012-02-14 Xact Downhole Telemetry Inc. Drill string telemetry methods and apparatus
US9234981B2 (en) * 2009-07-31 2016-01-12 Halliburton Energy Services, Inc. Exploitation of sea floor rig structures to enhance measurement while drilling telemetry data
DE102010047568A1 (de) 2010-04-12 2011-12-15 Peter Jantz Einrichtung zur Übertragung von Informationen über Bohrgestänge
US8944183B2 (en) * 2010-08-11 2015-02-03 Baker Hughes Incorporated Low frequency formation shear slowness from drilling noise derived quadrupole array data
US9458711B2 (en) 2012-11-30 2016-10-04 XACT Downhole Telemerty, Inc. Downhole low rate linear repeater relay network timing system and method

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
None *

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11095399B2 (en) 2013-03-15 2021-08-17 Baker Hughes Oilfield Operations Llc Robust telemetry repeater network system and method
EP3114317B1 (de) * 2014-03-06 2023-04-26 Baker Hughes Oilfield Operations LLC System und verfahren zur relaisnetzwerktaktung eines linearen bohrlochrepeaters mit niedriger rate

Also Published As

Publication number Publication date
WO2014145848A2 (en) 2014-09-18
EP2972527A2 (de) 2016-01-20
WO2014145848A3 (en) 2014-11-13
CA2906905C (en) 2023-03-28
BR112015023566A2 (pt) 2017-08-22
CA2906905A1 (en) 2014-09-18
US20140266769A1 (en) 2014-09-18
WO2014145848A4 (en) 2014-12-31
EP2972527A4 (de) 2016-11-16

Similar Documents

Publication Publication Date Title
EP2972527B1 (de) Netzwerktelemetriesystem und verfahren
US10677049B2 (en) Downhole low rate linear repeater relay network timing system and method
US10673571B2 (en) Robust telemetry repeater network system and method
EP2692075B1 (de) Algorithmus zur entdeckung drahtloser netzwerke und wegoptimierung sowie system
EP2983313B1 (de) Netzwerk zur akustischen Kommunikation mit Frequenzdiversifizierung
US10637529B2 (en) Signal equalisation
US20130146279A1 (en) System and method for borehole communication
US11542814B2 (en) Telemetry system combining two telemetry methods
EP3114317B1 (de) System und verfahren zur relaisnetzwerktaktung eines linearen bohrlochrepeaters mit niedriger rate
WO2021108322A1 (en) Telemetry system combining two telemetry methods

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

17P Request for examination filed

Effective date: 20150930

AK Designated contracting states

Kind code of ref document: A2

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

AX Request for extension of the european patent

Extension state: BA ME

DAX Request for extension of the european patent (deleted)
REG Reference to a national code

Ref country code: DE

Ref legal event code: R079

Ref document number: 602014055601

Country of ref document: DE

Free format text: PREVIOUS MAIN CLASS: G02B0006020000

Ipc: E21B0047120000

A4 Supplementary search report drawn up and despatched

Effective date: 20161014

RIC1 Information provided on ipc code assigned before grant

Ipc: E21B 47/14 20060101ALI20161010BHEP

Ipc: E21B 47/12 20120101AFI20161010BHEP

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: EXAMINATION IS IN PROGRESS

17Q First examination report despatched

Effective date: 20180822

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: GRANT OF PATENT IS INTENDED

INTG Intention to grant announced

Effective date: 20190306

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE PATENT HAS BEEN GRANTED

RAP1 Party data changed (applicant data changed or rights of an application transferred)

Owner name: BAKER HUGHES OILFIELD OPERATIONS LLC

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

REG Reference to a national code

Ref country code: GB

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: CH

Ref legal event code: EP

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: DE

Ref legal event code: R096

Ref document number: 602014055601

Country of ref document: DE

REG Reference to a national code

Ref country code: AT

Ref legal event code: REF

Ref document number: 1193841

Country of ref document: AT

Kind code of ref document: T

Effective date: 20191115

REG Reference to a national code

Ref country code: NL

Ref legal event code: MP

Effective date: 20191023

REG Reference to a national code

Ref country code: NO

Ref legal event code: T2

Effective date: 20191023

REG Reference to a national code

Ref country code: LT

Ref legal event code: MG4D

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: ES

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: NL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: LT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: GR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20200124

Ref country code: PL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: FI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: PT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20200224

Ref country code: LV

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: SE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: BG

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20200123

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20200224

Ref country code: RS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: HR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: AL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

REG Reference to a national code

Ref country code: DE

Ref legal event code: R097

Ref document number: 602014055601

Country of ref document: DE

PG2D Information on lapse in contracting state deleted

Ref country code: IS

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: EE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: DK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: CZ

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: RO

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: IS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20200223

REG Reference to a national code

Ref country code: AT

Ref legal event code: MK05

Ref document number: 1193841

Country of ref document: AT

Kind code of ref document: T

Effective date: 20191023

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SM

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: SK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: IT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

26N No opposition filed

Effective date: 20200724

REG Reference to a national code

Ref country code: DE

Ref legal event code: R119

Ref document number: 602014055601

Country of ref document: DE

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MC

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

REG Reference to a national code

Ref country code: CH

Ref legal event code: PL

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: AT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

REG Reference to a national code

Ref country code: BE

Ref legal event code: MM

Effective date: 20200331

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LU

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20200317

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LI

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20200331

Ref country code: CH

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20200331

Ref country code: FR

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20200331

Ref country code: DE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20201001

Ref country code: IE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20200317

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: BE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20200331

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: TR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: MT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

Ref country code: CY

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20191023

P01 Opt-out of the competence of the unified patent court (upc) registered

Effective date: 20230526

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: GB

Payment date: 20240220

Year of fee payment: 11

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: NO

Payment date: 20240222

Year of fee payment: 11