SYSTEMS, METHODS, AND COMPUTER MEDIUM TO PROVIDE ENTROPY BASED CHARACTERIZATION OF MULTIPHASE FLOW

• US 20160369624A1
• Filed: 06/22/2016
• Published: 12/22/2016
• Est. Priority Date: 06/22/2015
• Status: Active Grant

• Current Assignee: Saudi Arabian Oil Company (Government of Saudi Arabia)
• Original Assignee: Saudi Arabian Oil Company (Government of Saudi Arabia)
• Inventors: Ahmad, Talha Jamal, Black, Michael John, Arsalan, Muhammad, Noui-Mehidi, Mohamed Nabil
• Granted Patent: US 10,030,511 B2
• Time in Patent Office: Days
• US Class Current: 1/1
• CPC Class Codes: E21B 47/13 by electromagnetic energy, e.g. radio frequency
• CPC Class Codes: E21B 47/18 through the well fluid , e.g. mud pressure pulse telemetry
• CPC Class Codes: G01F 1/666 by detecting noise and sounds generated by the flowing fluid
• CPC Class Codes: G01F 1/74 Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
• CPC Class Codes: G01N 2291/02416 Solids in liquids
• CPC Class Codes: G01N 2291/02433 Gases in liquids, e.g. bubbles, foams
• CPC Class Codes: G01N 29/02 Analysing fluids using acoustic emission techniques G01N29/14 ; constructional or flow details for analysing fluids G01N29/222; optoacoustic fluid cells G01N29/2425
• CPC Class Codes: G01N 29/14 using acoustic emission techniques echo of particles G01N29/046; measuring mechanical vibrations or acoustic waves in solids in general G01H1/00
• CPC Class Codes: G01N 29/46 by spectral analysis, e.g. Fourier analysis or wavelet analysis spectral signal processing per se G06F17/14

Abstract

Systems, computer-implemented methods, and non-transitory computer-readable medium having a stored computer program provide characterization of multiphase fluid flow (MPF) using approximate entropy calculation techniques to enhance measuring and monitoring of a flow regime in a segment of pipe for hydrocarbon-production operations. The systems and methods can be optimized using principal component analysis.

Claims

1. A multiphase fluid flow (MPF) characterization system to enhance measuring and monitoring of a flow regime in a segment of pipe for hydrocarbon-production operations, the system comprising:

an acoustic receiver disposed proximate to the segment of pipe and operable to receive an acoustic signal transmitted through a MPF, the segment of pipe operable to support the MPF in hydrocarbon-production operations including at least two physical phases, and the acoustic receiver operable to convert the received acoustic signal to an electrical signal;

an acoustic transmitter disposed proximate to the segment of pipe and operable to convey an acoustic signal through the MPF in hydrocarbon-production operations, further operable to convey the acoustic signal such that the acoustic signal is receivable by the acoustic receiver;

a processing unit, including a processor, operable to receive the electrical signal and transform the electrical signal to characterize the MPF, the processing unit in communication with and comprising;

non-transitory, tangible memory medium in communication with the processor having a set of stored instructions, the set of stored instructions being executable by the processor and including the steps of;

segmenting the electrical signal into short term, medium term, and long term time series;

assigning positive real numbers to the time series, the positive real numbers including larger values and smaller values, the larger values corresponding to process randomness, and the smaller values corresponding to instances of recognizable patterns in the electrical signal;

categorizing certain positive real numbers as outlier values;

calculating short term, medium term, and long term approximate entropy values for the MPF based upon the short term, medium term, and long term time series from the electrical signal;

comparing the short term, medium term, and long term approximate entropy values for the MPF to pre-determined short term, medium term, and long term approximate entropy values; and

determining characteristics of the MPF responsive to similarities between the short term, medium term, and long term approximate entropy values for the MPF and the pre-determined short term, medium term, and long term approximate entropy values; and

a user interface coupled to the processing unit, the user interface operable to accept user inputs to control the processing unit, and operable to display the characteristics of the MPF to a user.

2. The system of claim 1 further comprising a database with pre-determined short term, medium term, and long term approximate entropy values for a variety of MPF flow regimes.

3. The system of claim 1 further comprising a preamplifier coupled to the acoustic receiver, and operable to receive and amplify the electrical signal from the acoustic receiver.

4. The system of claim 3 further comprising a band-pass signal filter coupled to the preamplifier,

the band-pass signal filter operable to receive an amplified electrical signal from the preamplifier, and

further operable to remove acoustic background noise from useful MPF acoustic information contained within the amplified electrical signal, responsive to programmed cutoff frequencies in the band-pass signal filter derived from an operating frequency and bandwidth of the acoustic receiver.

5. The system of claim 4 further comprising an analog-to-digital converter coupled to the band-pass signal filter, the analog-to-digital converter operable to receive from the band-pass signal filter the useful MPF acoustic information, and operable to convert the useful MPF acoustic information to a digital signal.

6. The system of claim 1 further comprising an amplifier disposed proximate the acoustic transmitter and operable to receive and amplify a drive signal to provide an amplified signal to the acoustic transmitter, where the amplifier is a high-voltage amplifier operable from about 50 volts (V) to about 100 V.

7. The system of claim 1,

where the acoustic receiver comprises a first acoustic receiver, and where the system further comprises a second acoustic receiver disposed proximate to the segment of pipe and operable to receive an acoustic signal transmitted through the MPF, the second acoustic receiver further operable to convert the received acoustic signal to an electrical signal, and

a second acoustic transmitter disposed proximate to the segment of pipe and operable to convey an acoustic signal through the MPF in hydrocarbon-production operations, further operable to convey the acoustic signal such that the acoustic signal is receivable by the second acoustic receiver.

8. The system of claim 7, where the second acoustic receiver is disposed at a distance D from the first acoustic receiver,

where the distance D is operable to allow coherent measurements of the MPF in a substantially similar state at both the first acoustic receiver and the second acoustic receiver, and

where an accurate measurement of flow velocity of the MPF is obtained by dividing the distance D by a difference in time between a first time at which the MPF passes the first acoustic receiver and a second time at which the MPF passes the second acoustic receiver.

9. The system of claim 1, where the processing unit further is operable to execute a set of instructions to conduct a principal component analysis on the system including the steps of:

gathering acoustic signal data under a variety of flow parameters in situations in which an appropriate Reynolds number is known for the MPF for which data is being gathered;

forming time series of acoustic waveforms;

performing a Fourier Transformation on the data, the data being converted into measurements of acoustic power as a function of frequency;

executing a suite of measurements using a test matrix including different conditions of the MPF including at least one variable selected from the group consisting of;

stepped values of watercut;

stepped values of total liquid flow; and

MPF regimes; and

post-processing the data by applying principal component analysis to the data to determine measurable frequencies relevant to determining the characteristics of the MPF.

10. The system of claim 9 further comprising an optimized acoustic receiver, where the optimized acoustic receiver is operable to receive the frequencies determined by the principal component analysis to be relevant to determining the characteristics of the MPF.

11. The system of claim 7, where the processing unit further is operable to execute a set of instructions to conduct a principal component analysis on the system including the steps of:

gathering acoustic signal data under a variety of flow parameters in situations in which an appropriate Reynolds number is known for the MPF for which data is being gathered;

forming time series of acoustic waveforms;

performing a Fourier Transformation on the data, the data being converted into measurements of acoustic power as a function of frequency;

executing a suite of measurements using a test matrix including different conditions of the MPF including at least one variable selected from the group consisting of;

stepped values of watercut, stepped values of total liquid flow, and MPF regimes; and

post-processing the data by applying principal component analysis to the data to determine measurable frequencies relevant to determining the characteristics of the MPF.

12. The system of claim 11 further comprising an optimized acoustic receiver, where the optimized acoustic receiver is operable to receive the frequencies determined by the principal component analysis to be relevant to determining the characteristics of the MPF.

13. A method for characterizing multiphase fluid flow (MPF) to enhance measuring and monitoring of a flow regime in a segment of pipe for hydrocarbon-production operations, the method comprising the steps of:

transmitting an acoustic signal through a MPF;

receiving an acoustic signal transmitted through the MPF, the segment of pipe operable to support the MPF in hydrocarbon-production operations including at least two physical phases;

converting the acoustic signal to an electrical signal;

segmenting the electrical signal into short term, medium term, and long term time series;

assigning positive real numbers to the time series, the positive real numbers including larger values and smaller values, the larger values corresponding to process randomness, and the smaller values corresponding to instances of recognizable patterns in the electrical signal;

categorizing certain positive real numbers as outlier values;

calculating short term, medium term, and long term approximate entropy values for the MPF responsive to the short term, medium term, and long term time series from the electrical signal;

comparing the short term, medium term, and long term approximate entropy values for the MPF to pre-determined short term, medium term, and long term approximate entropy values; and

determining characteristics of the MPF responsive to similarities between the short term, medium term, and long term approximate entropy values for the MPF and the pre-determined short term, medium term, and long term approximate entropy values.

14. The method of claim 13, further comprising the step of displaying the characteristics of the MPF on a user interface, where the user interface is operable to graphically represent at least one flow regime.

15. The method of claim 13, further comprising the step of preamplifying the electrical signal before the step of segmenting the electrical signal.

16. The method of claim 15 further comprising the step of filtering the electrical signal, before segmenting the electrical signal, responsive to programmed cutoff frequencies in a band-pass signal filter derived from an operating frequency and bandwidth of an acoustic receiver.

17. The method of claim 16 further comprising the step of converting the electrical signal to a digital signal, before segmenting the electrical signal.

18. The method of claim 13, where the step of receiving an acoustic signal comprises the step of receiving a first acoustic signal, and further comprises the step of receiving a second acoustic signal transmitted through the MPF, the second acoustic signal being received simultaneously with and at a distance D from the first acoustic signal, and where the step of transmitting an acoustic signal comprises the step of transmitting a first acoustic signal, and further comprises the step of transmitting a second acoustic signal through the MPF, the second acoustic signal being conveyed simultaneously with and at a distance D from the first acoustic signal.

19. The method of claim 18, further comprising the step of calculating an accurate measurement of flow velocity of the MPF in response to the distance D and receiving the first acoustic signal and receiving the second acoustic signal.

20. The method of claim 13, further comprising the step of conducting a principal component analysis, where the principal component analysis comprises the steps of:

gathering acoustic signal data under a variety of flow parameters in situations in which an appropriate Reynolds number is known for the MPF for which data is being gathered;

forming time series of acoustic waveforms;

performing a Fourier Transformation on the data, the data being converted into measurements of acoustic power as a function of frequency;

executing a suite of measurements using a test matrix including different conditions of the MPF including at least one variable selected from the group consisting of;

stepped values of watercut, stepped values of total liquid flow, and multiphase flow patterns; and

post-processing the data by applying principal component analysis to the data to determine measurable frequencies relevant to determining the characteristics of the MPF.

21. The method of claim 20 further comprising the step of optimizing the step of receiving an acoustic signal from the MPF to receive the frequencies determined by the principal component analysis to be relevant to determining the characteristics of the MPF.

22. The method of claim 18, further comprising the step of conducting a principal component analysis, where the principal component analysis comprises the steps of:

gathering acoustic signal data under a variety of flow parameters in situations in which an appropriate Reynolds number is known for the MPF for which data is being gathered;

forming time series of acoustic waveforms;

performing a Fourier Transformation on the data, the data being converted into measurements of acoustic power as a function of frequency;

executing a suite of measurements using a test matrix including different conditions of the MPF including at least one variable selected from the group consisting of;

stepped values of watercut, stepped values of total liquid flow, and multiphase flow patterns; and

post-processing the data by applying principal component analysis to the data to determine measurable frequencies relevant to determining the characteristics of the MPF.

23. The method of claim 22 further comprising the step of optimizing the step of receiving an acoustic signal from the MPF to receive the frequencies determined by the principal component analysis to be relevant to determining the characteristics of the MPF.