US20150022371A1 - Data communications system - Google Patents

Data communications system Download PDF

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Publication number
US20150022371A1
US20150022371A1 US14/383,719 US201314383719A US2015022371A1 US 20150022371 A1 US20150022371 A1 US 20150022371A1 US 201314383719 A US201314383719 A US 201314383719A US 2015022371 A1 US2015022371 A1 US 2015022371A1
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US
United States
Prior art keywords
data
frequency
high frequency
transmission according
data transmission
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.)
Abandoned
Application number
US14/383,719
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English (en)
Inventor
David Sirda Shanks
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.)
Zenith Oilfield Technology Ltd
Original Assignee
Zenith Oilfield Technology Ltd
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
Priority claimed from GB1204126.5A external-priority patent/GB2500047B/en
Priority claimed from GBGB1209141.9A external-priority patent/GB201209141D0/en
Priority claimed from GBGB1211806.3A external-priority patent/GB201211806D0/en
Priority claimed from GBGB1215281.5A external-priority patent/GB201215281D0/en
Application filed by Zenith Oilfield Technology Ltd filed Critical Zenith Oilfield Technology Ltd
Publication of US20150022371A1 publication Critical patent/US20150022371A1/en
Abandoned legal-status Critical Current

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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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/128—Adaptation of pump systems with down-hole electric drives
    • H—ELECTRICITY
    • H04—ELECTRIC COMMUNICATION TECHNIQUE
    • H04B—TRANSMISSION
    • H04B3/00—Line transmission systems
    • H04B3/54—Systems for transmission via power distribution lines
    • H—ELECTRICITY
    • H04—ELECTRIC COMMUNICATION TECHNIQUE
    • H04B—TRANSMISSION
    • H04B2203/00—Indexing scheme relating to line transmission systems
    • H04B2203/54—Aspects of powerline communications not already covered by H04B3/54 and its subgroups
    • H04B2203/5462—Systems for power line communications
    • H04B2203/5466—Systems for power line communications using three phases conductors
    • H—ELECTRICITY
    • H04—ELECTRIC COMMUNICATION TECHNIQUE
    • H04B—TRANSMISSION
    • H04B2203/00—Indexing scheme relating to line transmission systems
    • H04B2203/54—Aspects of powerline communications not already covered by H04B3/54 and its subgroups
    • H04B2203/5462—Systems for power line communications
    • H04B2203/5475—Systems for power line communications adapted for drill or well combined with data transmission

Definitions

  • the present invention relates to data transmission to and from down hole equipment and in particular, though not exclusively, to an improved method of data transmission through a three phase power system between the sub surface and a surface location.
  • Down hole equipment is understood to refer to any tool, equipment or instrument that is used in a wellbore.
  • DC current based devices which are coupled to the power system using inductive couplings have been developed and are extensively used. Examples of digital and processor based devices are disclosed in U.S. Pat. No. 5,515,038, GB 2283889 and U.S. Pat. No. 6,396,415. These systems utilise DC current injected onto the power signal and extracted through inductive Y-point couplings. These are all susceptible to failure when insulation on the power cable is lost or damaged. They are also typically either analogue in nature introducing noise into the measurements or where digital data is transmitted, it is at a very slow data rate.
  • AC based systems which make use of AC power and/or signal transmission have been developed to overcome these problems.
  • these AC based systems introduce disadvantages of their own as frequency at which the signal is transmitted becomes critical.
  • Significant issues arise with attenuation of the signal in the motor cable system and also interference with the signal from both the instrument system power source and the motor power system which often is a variable speed drive generating switching noise with harmonics at very high frequencies.
  • the combination of the attenuation of the signal and interference from the other power sources in the system mean that AC based systems are not in widespread use today because of the practical problems of signal recovery, and power delivery in the presence of cable faults.
  • GB 2416097 suggests altering the frequency of the surface power frequency to reduce noise. Unfortunately, this only reduces noise from the instrument AC power and has no effect on noise from the main motor supply which is not within the control of the instrument system.
  • GB 2352150 suggests synchronising the data transmit with the power frequency and/or the motor power frequency. While this appears to be an effective technique, in practice it is extremely difficult to fully implement because of the nature of the motor supply waveforms which are difficult to measure, and also because the motor supply can change relatively rapidly and quite often.
  • US 2012/0026003 to Layton describes systems and methods for reliably communicating data between surface and down hole equipment over a power cable, regardless of the length of the power cable, wherein a transmitter modulates a common data stream onto multiple high frequency carrier signals, each of which has a different frequency. Each of the different frequencies is best suited to communication over a different length of cable.
  • the resulting modulated high frequency data signals are impressed on the power cable and are recovered from the cable by a receiver.
  • the receiver is configured to recover signals at each of the different carrier frequencies, at least one of which should be transmitted with little enough attenuation and interference that the data stream can be accurately recovered from the corresponding modulated high frequency data signal.
  • This technique describes using a plurality of high frequency signals which are transmitted both as square waves so that they contain harmonics, and also superimposed simultaneously on the power cable.
  • This provides disadvantages in that: the square wave transmission is phase shifted and distorted when it is received at surface making it harder to detect; the harmonics from the transmissions will mean that some portion of each carrier will be detected in each of the other carrier based data streams, causing interference and degradation of the signal; and even if they were not square waves any impurity in the signal transmission will mean you get some portion of each carrier in each other carrier, causing corruption of the data, because they are transmitted at the same time.
  • the term data transmit frequency will also include the data carrier frequency in FM transmission.
  • a method of high frequency data transmission for transmitting data over a three phase power system between a surface and a subsurface location, the method using a first data transmit frequency and a second data transmit frequency, the data transmit frequencies being numerically distinct to each other and the data is transmitted on at least the second transmit frequency with a time delay between transmissions at each of the transmit frequencies.
  • the second transmit frequency can be selected to not be numerically related to or be transmitted at the same time as the first data transmit frequency so that any noise present at the first data transmit frequency will not interfere with the data transmitted at the second frequency. In this way, an uncorrupted data signal without interference is transmitted. By introducing a time delay, any harmonics from the data transmit frequencies will not interfere with the other data channels and the data recovery is simplified.
  • each data transmit frequency is not a harmonic multiple of any other data transmit frequency.
  • the data transmit frequencies may be in different frequency bands.
  • the second data transmit frequency may be pre-programmed at the subsurface.
  • the second data transmit frequency may be pre-programmed at the surface. In this way, all data transmitted between the surface and subsurface is transmitted at a first and at least a second transmit frequency.
  • the second data transmit frequency is selected at the surface and communicated to the subsurface for use in transmitting data.
  • a signal can be sent to the subsurface to transmit the data at the second frequency to avoid interference. This may be considered as channel hopping.
  • first and second data transmit frequencies at 70 and 106 KHz. In an alternative embodiment of the present invention there are first and second data transmit frequencies at 90 and 123 KHz.
  • data at each transmit frequency is transmitted sequentially. This reduces the time to obtain a recoverable signal.
  • the three phase power system includes down hole equipment and the data is transmitted between the down hole equipment and a surface.
  • the down hole equipment comprises a component of an artificial lift system.
  • the down hole equipment includes an electrical submersible pump (ESP).
  • ESP electrical submersible pump
  • the data may be analogue or digital.
  • the transmitted data may be frequency modulated. In such an arrangement the data transmit frequency will be the carrier frequency.
  • FIG. 1 shows the typical set up of a down hole equipment in a well, showing the positions of the equipment, the motor and the control interfaces at the surface;
  • FIG. 2 is a functional block diagram of a data transmission system according to an embodiment of the present invention.
  • FIGS. 3A , 3 B, and 3 C are spectral plots illustrating ( 3 A) a data signal at a single transmission frequency, ( 3 B) an illustrative noise signal with noise at the transmission frequency, and ( 3 C) the recovered signal; and
  • FIGS. 4A and 4B are spectral plots illustrating ( 4 A) a data signal and ( 4 B) a recovered signal according to an embodiment of the present invention.
  • One category of down hole equipment is artificial lift systems, for use in wells where there is insufficient pressure in the reservoir to lift the well's fluid (e.g. oil, water or gas) to the surface.
  • types of artificial lift systems include hydraulic pumps, Rod pumps, Electric Submersible Pumps (ESPs), Jet Pumps, Progressing-Cavity pumps (PCPs) and gas lift.
  • FIG. 1 of the drawings illustrates a typical ESP completion in a wellbore.
  • An ESP motor 10 is coupled through a seal 12 to a centrifugal pump 14 and used to lift the fluids through a tubing 16 to a surface 18 of the well 20 in a manner known to those skilled in the art.
  • sensors or gauges 22 are located below the ESP 10 .
  • the motor 10 is a three phase Y configuration.
  • the motor is driven by a variable speed drive system 24 and is connected via a three phase power cable 26 .
  • the system can be considered to comprise two distinct parts, a surface system, generally indicated by reference numeral 28 , and a down hole system, generally indicated by reference numeral 30 . These two parts 28 , 30 communicate using the ESP power cable 26 .
  • FIG. 1 Surface equipment relating to the gauge system is shown in FIG. 1 where there is a HV unit 13 connected directly to the 3 phase power supply to the down hole motor and there is a further LV or low voltage unit 8 which is safely isolated from the high voltage system.
  • the LV system is primarily for data recovery and processing and data display etc.
  • the HV unit is used to inject AC power and also make recovery of raw data from the 3-phase power system, in separate couplings as will be described.
  • FIG. 2 of the drawings there is illustrated a functional block diagram of a data transmission system, generally indicated by reference numeral 40 , according to an embodiment of the present invention.
  • data can be transmitted onto the three phase power cable 26 in either direction between the surface equipment 28 and subsurface or down hole equipment 30 .
  • the equipment is divided into a high voltage side 32 and a low voltage side 34 .
  • the high voltage side 32 provides the power to the down hole system 30 .
  • Tuned high-voltage AC coupling 36 is used to connect to each of the phases in the power cable 26 .
  • a microprocessor 38 controls the power distribution on to the three-phase cable 26 and is linked to a corresponding microprocessor 40 on the low voltage side 34 .
  • the high-voltage side 32 uses tuned high-voltage AC coupling 36 , in parallel to pick off the data signals on the three-phase cable 26 . These signals are then filtered 42 and de-modulated 44 by known methods.
  • Data signals then pass via the microprocessor 40 for display 46 or transport to a data logger or SCADA system. Additionally, the process can work in reverse where microprocessor 40 provides data on to the power lines 26 via the tuned high-voltage AC coupling 36 on the high-voltage side 32 as is known in the art.
  • Down hole an ESP system 48 is provided as described herein with reference to FIG. 1 . Like parts have the same reference numerals to aid clarity.
  • Below the motor 10 is a standard Y-point connector 50 .
  • a down hole system 52 provides monitoring in the form of measurement devices sensors or gauges 54 , hooked up via a microprocessor 56 .
  • Power to drive the gauges 54 is provided via tuned HV AC coupling circuits 36 to a power regulator 58 .
  • data from the measurement devices 54 is processed in the microprocessor 56 .
  • the data is transmitted on to the power line 62 for transmission to the Y-point 50 and onward transmission up the three-phase power cable 26 to the surface units 28 .
  • two distinct transmission frequencies are selected. These frequencies are numerically distinct and are specifically not harmonics of each other or any other known frequencies in the system 40 .
  • Each frequency is pre-programmed into the microprocessor 56 on the down hole side 30 , and the data is frequency modulated at these carrier frequencies on to the power line 62 and cable 26 in a known manner.
  • the data is sent at each of the transmission frequencies with a time delay there between.
  • the data can be sent sequentially at each transmission frequency. This improves the signal processing and simplifies the demodulation 44 stage on the surface equipment 28 .
  • the microprocessor 40 at the surface 28 analyses the received signals and if one is corrupted then this is discarded and the data recovered from the other signal. It will be apparent that multiple data transmit frequencies can be used to send the same data at different carrier frequencies or at different data rates to ensure the data is received without interference.
  • a data transmit frequency is pre-programmed into the microprocessor 56 of the down hole equipment 30 .
  • a data test signal is sent from the surface 28 to the microprocessor 56 down hole. This signal is sent back across the cable 26 .
  • Microprocessor 40 at surface analyses the received signal for any signs of interference of corruption of the data. If the received test signal does not match the sent signal then interference is determined and the microprocessor 40 sends a command signal to the microprocessor 56 down hole, to select a second data transmit frequency. This second frequency is numerically distinct from the first, being neither a multiple or harmonic of the first data transmit frequency. Data is then transmitted at the second data transmit frequency to surface.
  • test signals may be sent to ensure that interference has not been introduced at the second data transmit frequency. If the signal is corrupted by interference, then a command signal can be sent to switch to a third data transmit frequency, selected to be distinct from the first and second data transmit frequencies. This process of testing and channel hopping can be repeated to ensure clean uninterrupted data transmission.
  • FIG. 3A This plot gives voltage 66 versus frequency 68 and shows the amplitude of a data signal at a frequency F2 70 .
  • the signal 64 has smaller side band harmonic components.
  • FIG. 3B there is illustrated a plot of frequency versus voltage for noise generated by the motor power supply.
  • This noise signal 74 is at a much lower frequency 76 than our data signal 64 , but it has a harmonic side band at a lower amplitude which is at a frequency F2 78 that matches the frequency F2 70 of our data signal 64 ( FIG. 3A ).
  • the recovered signal 80 illustrated in FIG. 3C , again as a plot of voltage versus frequency, it is apparent that in the combination 80 of the data signal 64 and the noise signal 78 , only the noise harmonic is recovered at F2 82 . Accordingly if the data signal 64 and the noise signal 74 both exist in the same system, the data signal 64 while still present cannot be recovered regardless of how much filtering is applied because of the larger amplitude harmonic data from the motor supply.
  • FIG. 4A illustrates a voltage 66 versus frequency 68 plot of the data 64 with several different signal transmit frequencies F1, F2 and so on potentially to Fn.
  • the noise signal is that illustrated in FIG. 3B
  • FIG. 4B our combination and recovered signal is shown in FIG. 4B .
  • FIG. 4B In this plot of voltage versus frequency, it is seen at that the noise at F2 84 is larger than the signal so the data transmitted at F2 cannot be decoded.
  • the signal at F1 86 is not affected and so the data transmitted at the frequency F1 can be recovered.
  • the data transmit frequencies are best selected from different frequency bands. Suggested frequencies could be 70 and 106 KHz or 90 and 123 KHz and so on.
  • the principle advantage of the present invention is that it provides a method of data transmission over a three phase power system where the data transmit frequency or the data carrier frequency in the case of FM transmission, is not lost or corrupted by the presence of noise at the exact data or carrier frequency.
  • a further advantage of the present invention is that it provides a method of data transmission over a three phase power system which can be implemented in signal processing and does not require additional equipment in the well.
  • the principle can be applied to analogue or digital signals, signalling in either direction between the surface and the subsurface, and the transmission of control signals.
  • this data transmission system can be applied across any system where there is a remote ac powered motor present and there is a need to transfer data across a system in proximity to the motor with a single star-point connection without the addition of dedicated wires.
  • Other applications where this transmission system could be applied include: Sub-sea control valves; Chokes—Sub-sea power transformer monitoring; ESPCP systems; Remote surface motor/transformer systems; and general telemetry.
  • the motor can also be in any phase configuration. It is also to be appreciated that for more powerful or more complex systems, the transmission system can be used across a number of similar motors arranged in a stacked manner.

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  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Geophysics (AREA)
  • Remote Sensing (AREA)
  • Power Engineering (AREA)
  • Computer Networks & Wireless Communication (AREA)
  • Signal Processing (AREA)
  • Cable Transmission Systems, Equalization Of Radio And Reduction Of Echo (AREA)
  • Arrangements For Transmission Of Measured Signals (AREA)
  • Remote Monitoring And Control Of Power-Distribution Networks (AREA)
  • Control Of Ac Motors In General (AREA)
  • Testing Of Short-Circuits, Discontinuities, Leakage, Or Incorrect Line Connections (AREA)
US14/383,719 2012-03-08 2013-02-28 Data communications system Abandoned US20150022371A1 (en)

Applications Claiming Priority (9)

Application Number Priority Date Filing Date Title
GB1204126.5 2012-03-08
GB1204126.5A GB2500047B (en) 2012-03-08 2012-03-08 Data communications system
GBGB1209141.9A GB201209141D0 (en) 2012-05-24 2012-05-24 Data communications system
GB1209141.9 2012-05-24
GBGB1211806.3A GB201211806D0 (en) 2012-07-04 2012-07-04 Data communications system
GB1211806.3 2012-07-04
GB1215281.5 2012-08-28
GBGB1215281.5A GB201215281D0 (en) 2012-08-28 2012-08-28 Data communications system
PCT/GB2013/050508 WO2013132231A1 (fr) 2012-03-08 2013-02-28 Système de communication de données

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US20150022371A1 true US20150022371A1 (en) 2015-01-22

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US14/383,790 Active 2033-05-11 US9840907B2 (en) 2012-03-08 2013-02-28 Data communications system
US14/383,745 Active 2033-11-08 US9951609B2 (en) 2012-03-08 2013-02-28 Data communications system
US14/383,719 Abandoned US20150022371A1 (en) 2012-03-08 2013-02-28 Data communications system
US14/383,769 Active 2034-01-29 US9976412B2 (en) 2012-03-08 2013-02-28 Data communications system

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US14/383,790 Active 2033-05-11 US9840907B2 (en) 2012-03-08 2013-02-28 Data communications system
US14/383,745 Active 2033-11-08 US9951609B2 (en) 2012-03-08 2013-02-28 Data communications system

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US14/383,769 Active 2034-01-29 US9976412B2 (en) 2012-03-08 2013-02-28 Data communications system

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US (4) US9840907B2 (fr)
EP (4) EP2823573B1 (fr)
CN (4) CN104303426A (fr)
CA (4) CA2865829C (fr)
WO (4) WO2013132233A1 (fr)

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US20150109139A1 (en) 2015-04-23
CA2865831A1 (fr) 2013-09-12
CA2865833C (fr) 2021-06-22
CN104303426A (zh) 2015-01-21
CA2865831C (fr) 2020-03-24
EP2823574B1 (fr) 2019-01-23
EP2823574A1 (fr) 2015-01-14
EP2823572A1 (fr) 2015-01-14
WO2013132232A1 (fr) 2013-09-12
CN104321974A (zh) 2015-01-28
WO2013132233A1 (fr) 2013-09-12
WO2013132231A1 (fr) 2013-09-12
US20150109138A1 (en) 2015-04-23
CA2865833A1 (fr) 2013-09-12
CN104303424A (zh) 2015-01-21
CA2865844A1 (fr) 2013-09-12
US9840907B2 (en) 2017-12-12
EP2823572B1 (fr) 2020-01-01
CN104303424B (zh) 2017-03-08
CA2865829A1 (fr) 2013-09-12
EP2823573A1 (fr) 2015-01-14
US20150176397A1 (en) 2015-06-25
US9951609B2 (en) 2018-04-24
CN104321974B (zh) 2017-01-18
EP2823571A1 (fr) 2015-01-14
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CN104303425A (zh) 2015-01-21
US9976412B2 (en) 2018-05-22

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