CA2941558C - Downhole low rate linear repeater relay network timing system and method - Google Patents
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- 238000000034 method Methods 0.000 title claims abstract description 22
- 238000005553 drilling Methods 0.000 claims abstract description 19
- 238000005259 measurement Methods 0.000 claims description 46
- 230000005540 biological transmission Effects 0.000 claims description 31
- 230000001360 synchronised effect Effects 0.000 claims description 9
- 238000004519 manufacturing process Methods 0.000 claims description 7
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- 238000002592 echocardiography Methods 0.000 claims description 3
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- 230000015572 biosynthetic process Effects 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 101150006257 rig-4 gene Proteins 0.000 description 2
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- 239000003245 coal Substances 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
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- 239000006185 dispersion Substances 0.000 description 1
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- 230000008054 signal transmission Effects 0.000 description 1
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- 238000001228 spectrum Methods 0.000 description 1
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- 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
- E21B47/18—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 through the well fluid, e.g. mud pressure pulse telemetry
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- 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
- E21B47/13—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 by electromagnetic energy, e.g. radio frequency
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- 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
- E21B47/16—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 through the drill string or casing, e.g. by torsional acoustic waves
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Abstract
A downhole repeater network timing system for a drilling rig including a drillstring extending subsurface downwardly from a surface wellhead. The system includes a node located at the drillstring lower end and including a sensor adapted for providing a signal data set output corresponding to downhole drilling conditions. Multiple nodes are located downhole between the Bottom Hole Assembly (BHA) and the wellhead and are associated with the drillstring. The nodes are adapted for receiving and transmitting the signals. The timing control system is adapted for controlling all times within a timeframe according to pre-configured constants known to all nodes. A downhole low rate linear repeater network timing method uses the system.
Description
DOVVNHOLE LOW RATE LINEAR REPEATER RELAY NETWORK TIMING
SYSTEM AND METHOD
[0001] BACKGROUND OF THE INVENTION
1. Field of the Invention
SYSTEM AND METHOD
[0001] BACKGROUND OF THE INVENTION
1. Field of the Invention
[0002] The present invention relates generally to telemetry apparatuses and methods, and more particularly to acoustic telemetry relay network timing for exploration, completion and production wells for hydrocarbons and other resources, and for other telemetry applications.
2. Description of the Related Art
2. Description of the Related Art
[0003] Acoustic telemetry is a method of communication used in the well drilling, completion and production industries. In a typical drilling environment, 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. 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. In production wells, downhole information can similarly be transmitted via the well casings.
Acoustic telemetry .. transmits data to the surface in real-time and is independent of fluid flow, depth, well trajectory and other drilling parameters.
Acoustic telemetry .. transmits data to the surface in real-time and is independent of fluid flow, depth, well trajectory and other drilling parameters.
[0004] The theory of acoustic telemetry as applied to communication along drillstrings and well casings has a long history, and a comprehensive theoretical understanding has generally been backed up by accurate measurements. It is now generally .. recognized that the nearly regular periodic structure of drillpipe and well casings imposes a passband/stopband structure on the frequency response, similar to that of a comb filter.
Dispersion, phase non-linearity and frequency-dependent attenuation make drillpipe a challenging medium for telemetry, the situation being made even more challenging by the significant surface and downhole noise generally experienced.
100051 When exploring for oil or gas, in coal mine drilling and in other drilling applications, an acoustic transmitter is preferentially placed near the BHA, typically near the drill bit where the transmitter can gather certain drilling and geological formation data, process this data, and then convert the data into a signal to be transmitted up-hole to an appropriate receiving and decoding node. In some systems, 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 drill string 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. 5,128,901 for Acoustic Data Transmission through a Drillstring; Drumheller U.S. Patent No. 6,791,470 for Reducing Injection Loss in Drill Strings; Camwell et al. U.S. Patent No. 7,928,861 for Telemetry Wave Detection Apparatus and Method; and Camwell et al. U.S. Patent No. 8,115,651 for Drill String Telemetry Methods and Apparatus.
[0006] Acoustic communication through drilling and production strings (collectively "drillstrings") is generally limited by available frequency spectra and signal attenuation.
Consequently, transmission data rates tend to be relatively low, e.g., in the range of tens of bits per second, and multiple repeater nodes have previously been used to boost the telemetry signals and overcome the problem of acoustic signal attenuation and associated range limitations. The inclusion of multiple acoustic transceiver nodes within a drillstring forms a low rate linear repeater dam network. As used herein "nodes" are defined as receivers (Rx), transmitters or transceivers (Tx) for telemetry signals traveling between adjacent pairs of nodes. Alternatively, the nodes could be associated with and referred to as "stations" (e.g., STO, ST1. STn) located along the drillstring. The low data rate linear repeater networks suffer from high latency (time for data to propagate through the network) due to the time it takes for each node to receive data packets and relay data onward. An objective of repeater networks is to relay data as quickly as possible after initial receipt, in order to minimize latency of data delivered to the surface (or other destination) and to maximize data throughput.
100071 The latency of delivered measurement data translates into a potentially large time difference between the time at which a downhole sensor measurement is made and when that value is delivered to the surface, obscuring potentially valuable correlation between downhole and upholc events. Additionally, as sensor acquisition at each node within the network occurs at different points in time, the accuracy of inter-node differential measurements is limited, impairing the ability to discern transient events traversing the string.
[00081 A possible solution to drillstring acoustic communication latency-associated problems is to include time-of-measurement information with transmitted information from each node. However, bandwidth limitations make the inclusion of time-of-measurement (e.g., sensor acquisition time) information overhead in the acoustic packets undesirable, and require all downhole clocks to be very accurately aligned, which can be problematic given the significant temperature differentials across the networks (e.g., 150 C or more) and the .. long periods of continuous network operation.
SUMMARY OF THE INVENTION
100091 In the practice of the present invention, a repeater network is provided with highly controlled and predictable timing. This is achieved by reconfiguring the network with constants, which are known to all nodes: guard time, allocated time between receipt and transmission (relay), thus allowing for processing time, acquisition of sensor data and subsiding of channel delay spread (echoes, e.g., 0.5-5 seconds); and data packet transmission time, a function of the internodc data rate and the packet bit length (for example, a 100-bit packet transmitted at a 20 bits-per-second (bps) link rate would have a data packet transmission time of 5 seconds). The sensor acquisition time is typically negligible, and is .. determined by the time between the acquisition of a measurement from a sensor to transmission of the corresponding data through the telemetry network. Based on the network time constants, a surface time-of-measurement for the relative timing offsets of all relay transmissions within the network can be computed from variables including: the packet received times, packet types, and guard and sensor acquisition times.
Propagation delays can either be neglected or included in the time-of-measurement computation based on node separations and depth from surface, i.e., node depths. The advantages of the repeater network timing control include, without limitation:
= No costly overhead associated with time-of-measurement within acoustic packets.
= No network synchronization signal is required.
= Variable inter-node propagation delays do not impact.
= Agility, timing can change from frame-to-frame (packet type-to-packet type).
1009a] In a broad aspect, moreover, the present invention relates to a downhole linear repeater relay network timing control system for a drilling rig including a drillstring extending subsurface downwardly from a surface and terminating at a drillstring end, the linear repeater relay network timing control system comprising: a primary node located near said drillstring end and including a sensor configured to output signal data corresponding to downhole conditions; a surface node; and multiple nodes located between the primary node and the surface node and associated with the drillstring, the multiple nodes configured to receive and retransmit the signal data to form a telemetry relay network, wherein linear repeater relay network timing control system is configured to control one or more variables within a relay frame according to a plurality of preconfigured network constants that are known to all of the nodes, wherein the preconfigured network constants include at least guard times allocated between receipt and re-transmission of the signal data and packet transmission duration;
wherein said multiple nodes are configured to individually derive transmission timing offsets relative to each other based on point in time of receipt of the signal data and the network constants known to all of the nodes, wherein the multiple nodes are configured to select measurement data for transmission with the signal data, and wherein selection of the measurement data at the multiple nodes is time-synchronized; and a signal receiver configured to calculate an originating node sensor data acquisition point in time from the point in time of receipt of the signal data for use as an accurate time-of-measurement.
1009b] In another broad aspect, the present invention relates to a downhole linear repeater relay network timing control system for a drilling rig including a drillstring extending subsurface downwardly from a surface and terminating at a drillshing end, the downhole linear repeater relay network timing control system comprising: multiple nodes located downhole between said drillstring end and said surface and associated with said drillstring, at least one node located at the surface, two or more of said nodes including a sensor adapted for providing signal data output corresponding to downhole conditions, and said nodes receiving and re-transmitting said signal data output to form a telemetry relay network;
said relay network system being adapted for controlling one or more variables within a relay frame according to a plurality of preconfigured constants that are known to all nodes, wherein the Date Recue/Date Received 2022-10-07 4a preconfigured network constants include at least guard times allocated between receipt and re-transmission of the signal data and packet transmission duration; said nodes being individually adapted to derive timing offsets relative to each other based on said network constants and signal reception points in time; two or more of said nodes selecting current or buffered past sensor data, such that sensor data acquisitions at said nodes are time-synchronized with each other; and said nodes sending said selected sensor data to a destination node located downhole or at surface, directly or via said telemetry relay network.
[0009c] In another broad aspect, the present invention relates to a downhole linear repeater relay network timing method for acoustic telemetry, the method comprises the steps of:
providing an originating node near a downhole end of a drillstring and having a sensor configured to transmit signal data corresponding to downhole conditions;
providing intennediate nodes along the drillstring configured to receive and retransmit the signal data to form a telemetry relay network, wherein each intermediate node has a sensor configured to acquire measurement data, and wherein the signal data is relayed between the nodes as data packets; determining with said relay timing system, transmission times based on signal data received times from said intermediate nodes according to a plurality of preconfigured network constants that are known to all nodes, wherein the preconfigured network constants include at least guard times allocated between receipt and re-transmission of the signal data and packet transmission duration; synchronizing sensor acquisition within the linear repeater relay network; configuring data packets received at a surface node with network synchronized payload data; adjusting timestamps of said synchronized payload data according to that of the originating node; providing all nodes with the same acquisition timestamp; and acquiring sensor measurement data at all intermediate nodes at the same point in time as the originating node.
[0010] Other objects and advantages of the present invention will be apparent from the following description. Detailed descriptions of exemplary embodiments are provided in the following sections. However, the invention is not limited to such embodiments.
Date Recue/Date Received 2022-10-07 4b BRIEF DESCRIPTION OF THE DRAWINGS
[0011] FIG. I is a diagram of a typical drilling rig, including an acoustic telemetry system, which can be provided with a downhole linear repeater relay network timing system embodying an aspect of the present invention.
[0012] FIG. 2 is a fragmentary, side-elevational and cross-sectional view of a typical drillstring, which can provide the medium for acoustic telemetry transmissions for relaying, repeating and timing with the present invention.
[0013] FIG. 3 is a schematic diagram of the repeater relay network timing system of the present invention, particularly showing accurate surface time-of-measurement.
[0014] FIG. 4 is another schematic diagram of the repeater relay network timing system, particularly showing how a surface decode time-of-receipt of telemetry signal can be related back to the sensor acquisition time of any network node.
[0015] FIG. 5 is another schematic diagram of the repeater relay network timing system, particularly showing how a surface decode time-of-receipt of telemetry signal of a Date Recue/Date Received 2022-10-07 packet containing synchronized data is related to synchronized sensor acquisition across the network.
DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS
100161 In the following description, reference is made to -up" and "down" waves, but
Dispersion, phase non-linearity and frequency-dependent attenuation make drillpipe a challenging medium for telemetry, the situation being made even more challenging by the significant surface and downhole noise generally experienced.
100051 When exploring for oil or gas, in coal mine drilling and in other drilling applications, an acoustic transmitter is preferentially placed near the BHA, typically near the drill bit where the transmitter can gather certain drilling and geological formation data, process this data, and then convert the data into a signal to be transmitted up-hole to an appropriate receiving and decoding node. In some systems, 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 drill string 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. 5,128,901 for Acoustic Data Transmission through a Drillstring; Drumheller U.S. Patent No. 6,791,470 for Reducing Injection Loss in Drill Strings; Camwell et al. U.S. Patent No. 7,928,861 for Telemetry Wave Detection Apparatus and Method; and Camwell et al. U.S. Patent No. 8,115,651 for Drill String Telemetry Methods and Apparatus.
[0006] Acoustic communication through drilling and production strings (collectively "drillstrings") is generally limited by available frequency spectra and signal attenuation.
Consequently, transmission data rates tend to be relatively low, e.g., in the range of tens of bits per second, and multiple repeater nodes have previously been used to boost the telemetry signals and overcome the problem of acoustic signal attenuation and associated range limitations. The inclusion of multiple acoustic transceiver nodes within a drillstring forms a low rate linear repeater dam network. As used herein "nodes" are defined as receivers (Rx), transmitters or transceivers (Tx) for telemetry signals traveling between adjacent pairs of nodes. Alternatively, the nodes could be associated with and referred to as "stations" (e.g., STO, ST1. STn) located along the drillstring. The low data rate linear repeater networks suffer from high latency (time for data to propagate through the network) due to the time it takes for each node to receive data packets and relay data onward. An objective of repeater networks is to relay data as quickly as possible after initial receipt, in order to minimize latency of data delivered to the surface (or other destination) and to maximize data throughput.
100071 The latency of delivered measurement data translates into a potentially large time difference between the time at which a downhole sensor measurement is made and when that value is delivered to the surface, obscuring potentially valuable correlation between downhole and upholc events. Additionally, as sensor acquisition at each node within the network occurs at different points in time, the accuracy of inter-node differential measurements is limited, impairing the ability to discern transient events traversing the string.
[00081 A possible solution to drillstring acoustic communication latency-associated problems is to include time-of-measurement information with transmitted information from each node. However, bandwidth limitations make the inclusion of time-of-measurement (e.g., sensor acquisition time) information overhead in the acoustic packets undesirable, and require all downhole clocks to be very accurately aligned, which can be problematic given the significant temperature differentials across the networks (e.g., 150 C or more) and the .. long periods of continuous network operation.
SUMMARY OF THE INVENTION
100091 In the practice of the present invention, a repeater network is provided with highly controlled and predictable timing. This is achieved by reconfiguring the network with constants, which are known to all nodes: guard time, allocated time between receipt and transmission (relay), thus allowing for processing time, acquisition of sensor data and subsiding of channel delay spread (echoes, e.g., 0.5-5 seconds); and data packet transmission time, a function of the internodc data rate and the packet bit length (for example, a 100-bit packet transmitted at a 20 bits-per-second (bps) link rate would have a data packet transmission time of 5 seconds). The sensor acquisition time is typically negligible, and is .. determined by the time between the acquisition of a measurement from a sensor to transmission of the corresponding data through the telemetry network. Based on the network time constants, a surface time-of-measurement for the relative timing offsets of all relay transmissions within the network can be computed from variables including: the packet received times, packet types, and guard and sensor acquisition times.
Propagation delays can either be neglected or included in the time-of-measurement computation based on node separations and depth from surface, i.e., node depths. The advantages of the repeater network timing control include, without limitation:
= No costly overhead associated with time-of-measurement within acoustic packets.
= No network synchronization signal is required.
= Variable inter-node propagation delays do not impact.
= Agility, timing can change from frame-to-frame (packet type-to-packet type).
1009a] In a broad aspect, moreover, the present invention relates to a downhole linear repeater relay network timing control system for a drilling rig including a drillstring extending subsurface downwardly from a surface and terminating at a drillstring end, the linear repeater relay network timing control system comprising: a primary node located near said drillstring end and including a sensor configured to output signal data corresponding to downhole conditions; a surface node; and multiple nodes located between the primary node and the surface node and associated with the drillstring, the multiple nodes configured to receive and retransmit the signal data to form a telemetry relay network, wherein linear repeater relay network timing control system is configured to control one or more variables within a relay frame according to a plurality of preconfigured network constants that are known to all of the nodes, wherein the preconfigured network constants include at least guard times allocated between receipt and re-transmission of the signal data and packet transmission duration;
wherein said multiple nodes are configured to individually derive transmission timing offsets relative to each other based on point in time of receipt of the signal data and the network constants known to all of the nodes, wherein the multiple nodes are configured to select measurement data for transmission with the signal data, and wherein selection of the measurement data at the multiple nodes is time-synchronized; and a signal receiver configured to calculate an originating node sensor data acquisition point in time from the point in time of receipt of the signal data for use as an accurate time-of-measurement.
1009b] In another broad aspect, the present invention relates to a downhole linear repeater relay network timing control system for a drilling rig including a drillstring extending subsurface downwardly from a surface and terminating at a drillshing end, the downhole linear repeater relay network timing control system comprising: multiple nodes located downhole between said drillstring end and said surface and associated with said drillstring, at least one node located at the surface, two or more of said nodes including a sensor adapted for providing signal data output corresponding to downhole conditions, and said nodes receiving and re-transmitting said signal data output to form a telemetry relay network;
said relay network system being adapted for controlling one or more variables within a relay frame according to a plurality of preconfigured constants that are known to all nodes, wherein the Date Recue/Date Received 2022-10-07 4a preconfigured network constants include at least guard times allocated between receipt and re-transmission of the signal data and packet transmission duration; said nodes being individually adapted to derive timing offsets relative to each other based on said network constants and signal reception points in time; two or more of said nodes selecting current or buffered past sensor data, such that sensor data acquisitions at said nodes are time-synchronized with each other; and said nodes sending said selected sensor data to a destination node located downhole or at surface, directly or via said telemetry relay network.
[0009c] In another broad aspect, the present invention relates to a downhole linear repeater relay network timing method for acoustic telemetry, the method comprises the steps of:
providing an originating node near a downhole end of a drillstring and having a sensor configured to transmit signal data corresponding to downhole conditions;
providing intennediate nodes along the drillstring configured to receive and retransmit the signal data to form a telemetry relay network, wherein each intermediate node has a sensor configured to acquire measurement data, and wherein the signal data is relayed between the nodes as data packets; determining with said relay timing system, transmission times based on signal data received times from said intermediate nodes according to a plurality of preconfigured network constants that are known to all nodes, wherein the preconfigured network constants include at least guard times allocated between receipt and re-transmission of the signal data and packet transmission duration; synchronizing sensor acquisition within the linear repeater relay network; configuring data packets received at a surface node with network synchronized payload data; adjusting timestamps of said synchronized payload data according to that of the originating node; providing all nodes with the same acquisition timestamp; and acquiring sensor measurement data at all intermediate nodes at the same point in time as the originating node.
[0010] Other objects and advantages of the present invention will be apparent from the following description. Detailed descriptions of exemplary embodiments are provided in the following sections. However, the invention is not limited to such embodiments.
Date Recue/Date Received 2022-10-07 4b BRIEF DESCRIPTION OF THE DRAWINGS
[0011] FIG. I is a diagram of a typical drilling rig, including an acoustic telemetry system, which can be provided with a downhole linear repeater relay network timing system embodying an aspect of the present invention.
[0012] FIG. 2 is a fragmentary, side-elevational and cross-sectional view of a typical drillstring, which can provide the medium for acoustic telemetry transmissions for relaying, repeating and timing with the present invention.
[0013] FIG. 3 is a schematic diagram of the repeater relay network timing system of the present invention, particularly showing accurate surface time-of-measurement.
[0014] FIG. 4 is another schematic diagram of the repeater relay network timing system, particularly showing how a surface decode time-of-receipt of telemetry signal can be related back to the sensor acquisition time of any network node.
[0015] FIG. 5 is another schematic diagram of the repeater relay network timing system, particularly showing how a surface decode time-of-receipt of telemetry signal of a Date Recue/Date Received 2022-10-07 packet containing synchronized data is related to synchronized sensor acquisition across the network.
DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS
100161 In the following description, reference is made to -up" and "down" waves, but
5 this is merely for convenience and clarity. It is to be understood that the present invention is not to be limited in this manner to conceptually simple applications in acoustic communication from the downhole end of the drillstring to the surface. It will be readily apparent to one skilled in the art that the present invention applies equally, for example, to subsurface nodes, such as would be found in telemetry repeaters.
I. Drilling Rig, Drillstring and Well Environment 100171 Referring to the drawings in more detail, the reference numeral 2 generally designates a downhole low rate linear repeater relay network timing or control system embodying an aspect of the present invention. Without limitation on the generality of useful applications of the system 2, an exemplary application is in a drilling rig 4 (FIG. 1). For example, 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.
100181 The drillstring 12 terminates at a bottom-hole assembly (BHA) 20 at acoustic transceiver node (STO). Other rig configurations can likewise employ the present invention, including top-drive, coiled tubing, etc. Moreover, additional applications include completion rigs, completion strings, casing strings, gravel packs, frac packs and other applications.
Without limitation on the generality of useful applications of the present invention, acoustic telemetry systems in general can utilize the repeater network timing control system and method of the present invention. FIG. I 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 I 8a is connected to the repeater 22 and the transmitter 26. A downhole adjacent drillpipe section
I. Drilling Rig, Drillstring and Well Environment 100171 Referring to the drawings in more detail, the reference numeral 2 generally designates a downhole low rate linear repeater relay network timing or control system embodying an aspect of the present invention. Without limitation on the generality of useful applications of the system 2, an exemplary application is in a drilling rig 4 (FIG. 1). For example, 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.
100181 The drillstring 12 terminates at a bottom-hole assembly (BHA) 20 at acoustic transceiver node (STO). Other rig configurations can likewise employ the present invention, including top-drive, coiled tubing, etc. Moreover, additional applications include completion rigs, completion strings, casing strings, gravel packs, frac packs and other applications.
Without limitation on the generality of useful applications of the present invention, acoustic telemetry systems in general can utilize the repeater network timing control system and method of the present invention. FIG. I 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 I 8a is connected to the repeater 22 and the transmitter 26. A downhole adjacent drillpipe section
6 I fib is connected to the transmitter 26 and the BHA 20. A surface receiver (node) 2] can be provided at or near the upper end of the drillstring 12.
[0019] 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 or downwardly. The drillstring 12 can include multiple additional repeaters 22 at intervals determined by operating parameters such as optimizing signal transmissions 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.
II. Acoustic Network: Operation [0020] FIG. 3 shows the operation of a downhole low rate linear repeater acoustic network timing control system. Other applications of the present invention include electromagnetic signal telemetry systems and systems transmitting signaLs through other media, such as drilling mud, ground, water, air, etc.
100211 Telemetry data packets contain sensor or tool status data and are transmitted fi U111 the ptioraty itodc(STO, typically the deepest node) and relayed from node-to-node to the surface receiver 21 (Surface Rx), which is generally located at or near the wellhead. The telemetry 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).
100221 A single node functions as the master node (e.g., STO) and is typically an edge node at the top or bottom of the drillstring l2. The master node monitors well conditions and sends data packets of varying types and intervals accordingly. In addition to the long transmission/reception times associated with low data rate links, the asynchronous nature of wellbore variation tends to cause latency in an ASM operating mode because data-receiving nodes must await incoming packets before determining what sensor measurements must be
[0019] 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 or downwardly. The drillstring 12 can include multiple additional repeaters 22 at intervals determined by operating parameters such as optimizing signal transmissions 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.
II. Acoustic Network: Operation [0020] FIG. 3 shows the operation of a downhole low rate linear repeater acoustic network timing control system. Other applications of the present invention include electromagnetic signal telemetry systems and systems transmitting signaLs through other media, such as drilling mud, ground, water, air, etc.
100211 Telemetry data packets contain sensor or tool status data and are transmitted fi U111 the ptioraty itodc(STO, typically the deepest node) and relayed from node-to-node to the surface receiver 21 (Surface Rx), which is generally located at or near the wellhead. The telemetry 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).
100221 A single node functions as the master node (e.g., STO) and is typically an edge node at the top or bottom of the drillstring l2. The master node monitors well conditions and sends data packets of varying types and intervals accordingly. In addition to the long transmission/reception times associated with low data rate links, the asynchronous nature of wellbore variation tends to cause latency in an ASM operating mode because data-receiving nodes must await incoming packets before determining what sensor measurements must be
7 acquired for inclusion in the packets being relayed. Such latency in a low-throughput repeater network translates into a potentially large time difference between the point when a downhole sensor measurement is made and when that value is delivered to the surface.
Although including time-of-measurement (i.e., telemetry signal receive time) information within each acoustic packet with measurement data delivered to the surface can partly address this problem, additional problems can arise based on prohibitively large bandwidth requirements necessitated by the network low data rates, and the necessity of highly accurate alignment (synchronization) of downhole and surface clocks, which can be problematic due to relatively wide temperature differentials across the network (e.g., 150 C
+), and long periods of network operation.
Ill. Acoustic Network: Relay Timing and Control 100231 According to the system and method of the present invention, all time constraints are controlled based on pre-configured constants, which are input to all nodes.
The pre-configured constants can include:
= Civard Times: time allocated between receipt and transmission (relay) to allow for processing time, acquisition of sensor data and channel delay spread (echoes) subsiding. Typically about 0.5 to 5.0 seconds.
= Packet Transmission Time: a function of the internode data rate and packet bit length.
For example, transmitting 100 bits (c4 20 bps link rate = 5 seconds.
= Sensor Acquisition Time: time between the acquisition and measurement from a sensor to transmission of data through the telemetry network. Typically negligible, e.g. about 5-100 ms.
100241 With all time controlled within such a frame, the surface receiver can calculate the relative timing offsets of all relay transmissions within the network based on the telemetry signal received time (e.g., time-of-measurement) of any packet and its type.
With the additional information of sensor acquisition time, an exact time of sensor measurement can be calculated from the received time and used as an accurate time-of-measurement as follows:
Although including time-of-measurement (i.e., telemetry signal receive time) information within each acoustic packet with measurement data delivered to the surface can partly address this problem, additional problems can arise based on prohibitively large bandwidth requirements necessitated by the network low data rates, and the necessity of highly accurate alignment (synchronization) of downhole and surface clocks, which can be problematic due to relatively wide temperature differentials across the network (e.g., 150 C
+), and long periods of network operation.
Ill. Acoustic Network: Relay Timing and Control 100231 According to the system and method of the present invention, all time constraints are controlled based on pre-configured constants, which are input to all nodes.
The pre-configured constants can include:
= Civard Times: time allocated between receipt and transmission (relay) to allow for processing time, acquisition of sensor data and channel delay spread (echoes) subsiding. Typically about 0.5 to 5.0 seconds.
= Packet Transmission Time: a function of the internode data rate and packet bit length.
For example, transmitting 100 bits (c4 20 bps link rate = 5 seconds.
= Sensor Acquisition Time: time between the acquisition and measurement from a sensor to transmission of data through the telemetry network. Typically negligible, e.g. about 5-100 ms.
100241 With all time controlled within such a frame, the surface receiver can calculate the relative timing offsets of all relay transmissions within the network based on the telemetry signal received time (e.g., time-of-measurement) of any packet and its type.
With the additional information of sensor acquisition time, an exact time of sensor measurement can be calculated from the received time and used as an accurate time-of-measurement as follows:
8 N : Decoded Packet STID
o :Originating Station ID
Packet Time :# payload bits (link bit rate) Time of measurement =
Surface DecodeTime[N] - E Packet Time[n]- Guard Timex (N - o) - Ac Time[o]
n-o 100251 Wave propagation delays tend to minor relative to the above delays, and can be neglected, or can be easily accounted for with an additional subtraction based on originating node separation from the surface and group velocity of the packet signal (i.e.
propagation delay = node depth x group velocity). In this way, a surface decode time-of-measurement can be related back to the signal receive time of any network node, as shown in FIGS. 4 and 5.
100261 In eases requiring quality differential measurements between nodes, all nodes must acquire sensor measurement data at the same point in time, and add the data to the appropriate relay packet such that the packet delivered to the surface contains time-synchronized sensor data acquisition. This can be accomplished with controlled network timing, if, based upon receipt time and type of a packet, all nodes can calculate the relative point in time at which the primary node (e.g. STO, deepest node) acquired its measurement data, and acquire sensor data at that same point in time.
[00271 From the perspective of the receiver node(s), the primary node sensor acquisition point occurred in the past. Sensor acquisition must therefore occur regularly and be buffered such that past measurement values are accessible. Buffer capacity and sampling rate are determined by the greatest possible frame length of all configurable modes, and the required alignment accuracy in the data of the network synchronized measurement. At the surface, the packets that arc configured with network synchronized payload data will have their times-of-measurement adjusted according to that of the primary node.
[00281 In the practice of the method of the present invention, all nodes acquire sensor measurement value at the same point in time as the primary node. All nodes have the same
o :Originating Station ID
Packet Time :# payload bits (link bit rate) Time of measurement =
Surface DecodeTime[N] - E Packet Time[n]- Guard Timex (N - o) - Ac Time[o]
n-o 100251 Wave propagation delays tend to minor relative to the above delays, and can be neglected, or can be easily accounted for with an additional subtraction based on originating node separation from the surface and group velocity of the packet signal (i.e.
propagation delay = node depth x group velocity). In this way, a surface decode time-of-measurement can be related back to the signal receive time of any network node, as shown in FIGS. 4 and 5.
100261 In eases requiring quality differential measurements between nodes, all nodes must acquire sensor measurement data at the same point in time, and add the data to the appropriate relay packet such that the packet delivered to the surface contains time-synchronized sensor data acquisition. This can be accomplished with controlled network timing, if, based upon receipt time and type of a packet, all nodes can calculate the relative point in time at which the primary node (e.g. STO, deepest node) acquired its measurement data, and acquire sensor data at that same point in time.
[00271 From the perspective of the receiver node(s), the primary node sensor acquisition point occurred in the past. Sensor acquisition must therefore occur regularly and be buffered such that past measurement values are accessible. Buffer capacity and sampling rate are determined by the greatest possible frame length of all configurable modes, and the required alignment accuracy in the data of the network synchronized measurement. At the surface, the packets that arc configured with network synchronized payload data will have their times-of-measurement adjusted according to that of the primary node.
[00281 In the practice of the method of the present invention, all nodes acquire sensor measurement value at the same point in time as the primary node. All nodes have the same
9 acquisition time. A surface decode time-of-receipt of telemetry signal can be related back to the sensor acquisition time of STO, as shown in FIG. 5.
IV. Extensions and Additional Applications 100291 Without limitation on the generality of useful applications of the present invention, the network timing control system and method described above can bc extended and applied to a wide range of additional applications, including:
= Applicable to electromagnetic pulse systems as well as acoustic.
= Applicable to downlink, uplink and bi-directional networks.
= The network synchronized sensor acquisition could be aligned with any node within the network, or any point in time within a frame.
[0030] It is to be understood that the invention can be embodied in various forms, and is not to be limited to the examples discussed above. The range of components and configurations which can be utilized in the practice of the present invention is virtually unlimited.
IV. Extensions and Additional Applications 100291 Without limitation on the generality of useful applications of the present invention, the network timing control system and method described above can bc extended and applied to a wide range of additional applications, including:
= Applicable to electromagnetic pulse systems as well as acoustic.
= Applicable to downlink, uplink and bi-directional networks.
= The network synchronized sensor acquisition could be aligned with any node within the network, or any point in time within a frame.
[0030] It is to be understood that the invention can be embodied in various forms, and is not to be limited to the examples discussed above. The range of components and configurations which can be utilized in the practice of the present invention is virtually unlimited.
Claims (20)
1. A downhole linear repeater relay network timing control system for a drilling rig including a drillstring extending subsurface downwardly from a surface and terminating at a drillstring end, the linear repeater relay network timing control system comprising:
a primary node located near said drillstring end and including a sensor configured to output signal data corresponding to downhole conditions;
a surface node;
multiple nodes located between the primary node and the surface node and associated with the drillstring, the multiple nodes configured to receive and retransmit the signal data to form a telemetry relay network, wherein linear repeater relay network timing control system is configured to control one or more variables within a relay frame according to a plurality of preconfigured network constants that are known to all of the nodes, wherein the preconfigured network constants include at least guard times allocated between receipt and re-transmission of the signal data and packet transmission duration;
wherein said multiple nodes are configured to individually derive transmission timing offsets relative to each other based on point in time of receipt of the signal data and the network constants known to all of the nodes, wherein the multiple nodes are configured to select measurement data for transmission with the signal data, and wherein selection of the measurement data at the multiple nodes is time-synchronized; and a signal receiver configured to calculate an originating node sensor data acquisition point in time from the point in time of receipt of the signal data for use as an accurate time-of-measurement.
a primary node located near said drillstring end and including a sensor configured to output signal data corresponding to downhole conditions;
a surface node;
multiple nodes located between the primary node and the surface node and associated with the drillstring, the multiple nodes configured to receive and retransmit the signal data to form a telemetry relay network, wherein linear repeater relay network timing control system is configured to control one or more variables within a relay frame according to a plurality of preconfigured network constants that are known to all of the nodes, wherein the preconfigured network constants include at least guard times allocated between receipt and re-transmission of the signal data and packet transmission duration;
wherein said multiple nodes are configured to individually derive transmission timing offsets relative to each other based on point in time of receipt of the signal data and the network constants known to all of the nodes, wherein the multiple nodes are configured to select measurement data for transmission with the signal data, and wherein selection of the measurement data at the multiple nodes is time-synchronized; and a signal receiver configured to calculate an originating node sensor data acquisition point in time from the point in time of receipt of the signal data for use as an accurate time-of-measurement.
2. The downhole linear repeater relay network timing control system according to claim 1, wherein said signal data comprises data sets from said primary node and wherein said data sets are relayed between the nodes as telemetry data packets.
3. The downhole linear repeater relay network timing control system according to claim 2, wherein each of the multiple nodes comprises a sensor configured to acquire the measurement data.
Date Reçue/Date Received 2022-10-07
Date Reçue/Date Received 2022-10-07
4. The downhole linear repeater relay network timing control system according to claim 3, wherein the net-work constants known to all of the nodes further comprise:
acquisition of sensor data and subsiding of channel delay spread echoes; and sensor acquisition time between acquisition of measurement data from the sensor to transmission of data through the telemetry relay network.
acquisition of sensor data and subsiding of channel delay spread echoes; and sensor acquisition time between acquisition of measurement data from the sensor to transmission of data through the telemetry relay network.
5. The downhole linear repeater relay network timing control system according to any one of claims 1 to 3, wherein the multiple nodes derive the transmission time offsets relative to each other further based on signal propagation time between multiple nodes as a function of physical node distance separation.
6. The downhole linear repeater relay network timing control system according to any one of claims 1 to 3, wherein the transmission timing offsets specify one or more of:
future transmission points of time, expected reception points of time, and transmission guard times.
future transmission points of time, expected reception points of time, and transmission guard times.
7. The downhole linear repeater relay network timing control system according to any one of claims 1 to 6, wherein the primary and multiple nodes are connected to the drillstring.
8. The downhole linear repeater relay network timing control system according to claim 3, wherein the multiple nodes comprise means for buffering said signal data and said measurement data.
9. The downhole linear repeater relay network timing control system according to claim 8, wherein the multiple nodes are configured to select buffered measurement data.
10. The downhole linear repeater relay network timing control system according to any one of claims 1 to 9, wherein the signal data relates to one or more of the group comprising: exploration wells, production wells, completion rigs, completion strings, casing strings, coiled tubing, gravel pack, and frac pack operations.
Date Reçue/Date Received 2022-10-07
Date Reçue/Date Received 2022-10-07
11. A downhole linear repeater relay network timing control system for a drilling rig including a drillstring extending subsurface downwardly from a surface and terminating at a drillstring end, the downhole linear repeater relay network timing control system comprising:
multiple nodes located downhole between said drillstring end and said surface and associated with said drillstring, at least one node located at the surface, two or more of said nodes including a sensor adapted for providing signal data output corresponding to downhole conditions, and said nodes receiving and re-transmitting said signal data output to form a telemetry relay network;
said relay network system being adapted for controlling one or more variables within a relay frame according to a plurality of preconfigured constants that are known to all nodes, wherein the preconfigured network constants include at least guard times allocated between receipt and re-transmission of the signal data and packet transmission duration;
said nodes being individually adapted to derive timing offsets relative to each other based on said network constants and signal reception points in time;
two or more of said nodes selecting current or buffered past sensor data, such that sensor data acquisitions at said nodes are time-synchronized with each other; and said nodes sending said selected sensor data to a destination node located downhole or at surface, directly or via said telemetry relay network
multiple nodes located downhole between said drillstring end and said surface and associated with said drillstring, at least one node located at the surface, two or more of said nodes including a sensor adapted for providing signal data output corresponding to downhole conditions, and said nodes receiving and re-transmitting said signal data output to form a telemetry relay network;
said relay network system being adapted for controlling one or more variables within a relay frame according to a plurality of preconfigured constants that are known to all nodes, wherein the preconfigured network constants include at least guard times allocated between receipt and re-transmission of the signal data and packet transmission duration;
said nodes being individually adapted to derive timing offsets relative to each other based on said network constants and signal reception points in time;
two or more of said nodes selecting current or buffered past sensor data, such that sensor data acquisitions at said nodes are time-synchronized with each other; and said nodes sending said selected sensor data to a destination node located downhole or at surface, directly or via said telemetry relay network
12. The downhole linear repeater relay network timing system according to claim 11, wherein said telemetry relay network utilizes either acoustic signals or electromagnetic signals.
13. The downhole linear repeater relay network timing system according to claim 11 or 12, wherein said signal data relates to one or more of the group comprising:
exploration wells, production wells, completion rigs, completion strings, casing strings, coiled tubing, gravel pack, and frac pack operations.
exploration wells, production wells, completion rigs, completion strings, casing strings, coiled tubing, gravel pack, and frac pack operations.
14. The downhole linear repeater relay network timing system according to any one of claims 11 to 13, wherein said network constants include sensor time-to-acquire measurement data.
Date Reçue/Date Received 2022-10-07
Date Reçue/Date Received 2022-10-07
15. A downhole linear repeater relay network timing method for acoustic telemetry, the method comprises the steps of:
providMg an originating node near a downhole end of a drillstring and having a sensor configured to transmit signal data corresponding to downhole conditions;
providing intermediate nodes along the drillstring configured to receive and retransmit the signal data to form a telemetry relay network, wherein each intermediate node has a sensor configured to acquire measurement data, and wherein the signal data is relayed between the nodes as data packets;
determining with said relay timing system, transmission times based on signal data received times from said intermediate nodes according to a plurality of preconfigured network constants that are known to all nodes, wherein the preconfigured network constants include at least guard times allocated between receipt and re-transmission of the signal data and packet transmission duration;
synchronizing sensor acquisition within the linear repeater relay network;
configuring data packets received at a surface node with network synchronized payload data;
adjusting timestamps of said synchronized payload data according to that of the originating node;
providing all nodes with the same acquisition timestamp; and acquiring sensor measurement data at all intermediate nodes at the same point in time as the originating node.
providMg an originating node near a downhole end of a drillstring and having a sensor configured to transmit signal data corresponding to downhole conditions;
providing intermediate nodes along the drillstring configured to receive and retransmit the signal data to form a telemetry relay network, wherein each intermediate node has a sensor configured to acquire measurement data, and wherein the signal data is relayed between the nodes as data packets;
determining with said relay timing system, transmission times based on signal data received times from said intermediate nodes according to a plurality of preconfigured network constants that are known to all nodes, wherein the preconfigured network constants include at least guard times allocated between receipt and re-transmission of the signal data and packet transmission duration;
synchronizing sensor acquisition within the linear repeater relay network;
configuring data packets received at a surface node with network synchronized payload data;
adjusting timestamps of said synchronized payload data according to that of the originating node;
providing all nodes with the same acquisition timestamp; and acquiring sensor measurement data at all intermediate nodes at the same point in time as the originating node.
16. The linear repeater relay network timing method according to claim 15, further comprising the steps of:
synchronizing data payload acquisition without a network synchronization signal;
accommodating variable inter-node propagation delays without impact on said network; and accommodating timing changes from frame-to-frame and packet-to-packet tYPe=
synchronizing data payload acquisition without a network synchronization signal;
accommodating variable inter-node propagation delays without impact on said network; and accommodating timing changes from frame-to-frame and packet-to-packet tYPe=
17. The linear repeater relay network timing method according to claim 15 or 16, wherein said relay timing system utilizes either acoustic signals or electromagnetic pulse signals.
Date Reçue/Date Received 2022-10-07
Date Reçue/Date Received 2022-10-07
18. The linear repeater relay network timing method according to any one of claims 15 to 17, wherein said network utilizes downlink, uplink or bi-directional data relay operations.
19. The linear repeater relay network timing method according to any one of claims 15 to 18, further comprising buffering the signal data.
20. The linear repeater relay network timing method according to any one of claims 15 to 19, wherein the signal data relates to one or more of the group comprising:
exploration wells, production wells, completion rigs, completion strings, casing strings, coiled tubing, gravel pack, and frac pack operations.
Date Recue/Date Received 2022-10-07
exploration wells, production wells, completion rigs, completion strings, casing strings, coiled tubing, gravel pack, and frac pack operations.
Date Recue/Date Received 2022-10-07
Applications Claiming Priority (1)
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|---|---|---|---|
| PCT/US2014/021356 WO2015134030A1 (en) | 2014-03-06 | 2014-03-06 | Downhole low rate linear repeater relay network timing system and method |
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|---|---|
| CA2941558A1 CA2941558A1 (en) | 2015-09-11 |
| CA2941558C true CA2941558C (en) | 2023-10-10 |
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| CA2941558A Active CA2941558C (en) | 2014-03-06 | 2014-03-06 | Downhole low rate linear repeater relay network timing system and method |
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| EP (1) | EP3114317B1 (en) |
| BR (1) | BR112016020523A2 (en) |
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| US7765422B2 (en) * | 2001-01-19 | 2010-07-27 | Alcatel-Lucent Usa Inc. | Method of determining a time offset estimate between a central node and a secondary node |
| US7139218B2 (en) * | 2003-08-13 | 2006-11-21 | Intelliserv, Inc. | Distributed downhole drilling network |
| JP4714025B2 (en) * | 2006-01-06 | 2011-06-29 | 株式会社日立製作所 | Sensor node, base station, sensor network, and sensing data transmission method |
| WO2009143409A2 (en) * | 2008-05-23 | 2009-11-26 | Martin Scientific, Llc | Reliable downhole data transmission system |
| US8164980B2 (en) | 2008-10-20 | 2012-04-24 | Baker Hughes Incorporated | Methods and apparatuses for data collection and communication in drill string components |
| US8731837B2 (en) * | 2009-06-11 | 2014-05-20 | Schlumberger Technology Corporation | System and method for associating time stamped measurement data with a corresponding wellbore depth |
| WO2014145848A2 (en) * | 2013-03-15 | 2014-09-18 | Xact Downhole Telemetry, Inc. | Network telemetry system and method |
-
2014
- 2014-03-06 BR BR112016020523A patent/BR112016020523A2/en not_active IP Right Cessation
- 2014-03-06 EP EP14884471.5A patent/EP3114317B1/en active Active
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| CA2941558A1 (en) | 2015-09-11 |
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| EP3114317A1 (en) | 2017-01-11 |
| EP3114317B1 (en) | 2023-04-26 |
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