A method of presenting sensor data can include receiving a request for data to be displayed on a display area of a display device, determining a data distribution per pixel within the display area for both the first axis and the second axis based on the pixel resolution, the first output range, and the second output range, fitting the data distribution per pixel for data associated with the first axis to provide first axis fitted data, fitting the data distribution per pixel for data associated with the second axis to provide second axis fitted data, and sending the first axis fitted data and the second axis fitted data. The request comprises a pixel resolution of the display area, a first output range of the data along a first axis, and a second output range of the data along a second axis.
A method of reducing data storage volumes for event by identifying an anomaly in a first portion of a sensor data set using one or more features derived from the sensor data, wherein the sensor data set is obtained from a sensor, and wherein the sensor data set comprises a plurality of individual sensor readings through time, determining one or more signal characteristics of the first portion of the sensor data set; and storing, in a memory, the one or more signal characteristics of the first portion of the sensor data set, wherein a second portion of the sensor data does not contain the anomaly, and wherein the second portion of the sensor data is not stored in the memory.
A method of identifying anomalies comprises determining, using a first data set, a baseline for one or more time series data components or features, determining, using a second data set, that one or more of the time series data components or features in the second data set exceed the baseline, providing, on a user interface, an indication of the one or more time series data components or features that exceed the baseline, receiving, using the user interface, feedback on the indication, and updating the baseline based on the feedback.
A method of identifying events comprises obtaining a first set of measurements comprising a first signal of field data at a location; identifying one or more events at the location using the first set of measurements; obtaining a second set of measurements comprising a second signal at the location, wherein the first signal and the second signal represent at least one different physical measurements; training one or more event models using the second set of measurements and the identification of the one or more events as inputs; and using the one or more event models to identify at least one additional event at one or more locations.
A method of identifying events within a wellbore comprises obtaining a first set of measurements of a first signal within a wellbore, identifying one or more events within the wellbore using the first set of measurements, obtaining a second set of measurements of a second signal within the wellbore, wherein the first signal and the second signal represent different physical measurements, training one or more event models using the second set of measurements and the identification of the one or more events as inputs, and using the one or more event models to identify at least one additional event within the wellbore.
A method for capturing user workflows can include tracking user queries for a plurality of users, correlating the user queries between two or more users of the plurality of users, determining that the user queries of the two or more users of the plurality of users are correlated, and classifying the user queries of the at least two users as a workflow neighbor. The workflow neighbor defines a set of time series data or features.
A monitoring system includes a flow line, an optical fiber coupled to the flow line, and a receiver coupled to an end of the optical fiber. The receiver is configured to detect at least one acoustic signal from the optical fiber. In addition, the monitoring system includes processor unit to detect a flow obstruction within the flow line based on the acoustic signal.
E21B 47/095 - Locating or determining the position of objects in boreholes or wells; Identifying the free or blocked portions of pipes by detecting acoustic anomalies, e.g. using mud-pressure pulses
E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
8.
Event Detection Using DAS Features with Machine Learning
BP Exploration Operating Company Limited (United Kingdom)
Lytt Limited (United Kingdom)
Inventor
Thiruvenkatanathan, Pradyumna
Abstract
A method of identifying events includes obtaining an acoustic signal from a sensor, determining one or more frequency domain features from the acoustic signal, providing the one or more frequency domain features as inputs to a plurality of event detection models, and determining the presence of one or more events using the plurality of event detection models. The one or more frequency domain features are obtained across a frequency range of the acoustic signal, and at least two of the plurality of event detection models are different.
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
G01V 99/00 - Subject matter not provided for in other groups of this subclass
9.
SYSTEMS AND METHODS FOR SUBTERRANEAN FLUID FLOW CHARACTERIZATION
A method of monitoring fluid outflow along a wellbore includes obtaining an acoustic signal from a sensor within the wellbore. The acoustic signal includes acoustic samples across a portion of a depth of the wellbore. In addition, the method includes determining one or more frequency domain features from the acoustic signal. Further, the method includes identifying one or more fluid outflow locations along the portion of the depth of the wellbore using the one or more frequency domain features.
G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
G01K 11/32 - Measuring temperature based on physical or chemical changes not covered by group , , , or using changes in transmittance, scattering or luminescence in optical fibres
10.
EVENT CHARACTERIZATION USING HYBRID DAS/DTS MEASUREMENTS
A method of determining the presence and/or extent of an event comprises determining a plurality of temperature features from a temperature sensing signal, determining one or more frequency domain features from an acoustic signal, and using at least one temperature feature of the plurality of temperature features and at least one frequency domain feature of the one or more frequency domain features to determine the presence and/or extent of the event at one or more locations.
A method of detecting one or more events comprises determining a plurality of temperature features from a temperature sensing signal, using the plurality of temperature features in an event detection model, and determining the presence or absence of the one or more events at one or more locations based on an output from the event detection model.
E21B 47/135 - 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. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
E21B 47/103 - Locating fluid leaks, intrusions or movements using thermal measurements
E21B 47/113 - Locating fluid leaks, intrusions or movements using light radiation
G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
G01K 11/32 - Measuring temperature based on physical or chemical changes not covered by group , , , or using changes in transmittance, scattering or luminescence in optical fibres
E21B 47/08 - Measuring diameters or related dimensions at the borehole
E21B 47/14 - 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
12.
SYSTEMS AND METHODS FOR SAND INGRESS PREDICTION FOR SUBTERRANEAN WELLBORES
A method of developing a predictive model for sand production from a wellbore includes receiving an indication of sand ingress at one or more production zones within a first wellbore using a sand monitoring system disposed within the first wellbore, detecting, using a pressure monitoring system, a pressure within the first wellbore while producing the one or more fluids and detecting the sand ingress, determining one or more geophysical properties of the one or more production zones of the first wellbore, and determining a model that correlates sand ingress at each of the one or more production zones with a plurality of variables. The sand ingress occurs while producing one or more fluids from the first wellbore.
E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
E21B 47/14 - 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
E21B 47/135 - 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. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A method of identifying events within a wellbore comprises obtaining a first set of measurements of a first signal within a wellbore, identifying one or more events within the wellbore using the first set of measurements, obtaining a second set of measurements of a second signal within the wellbore, wherein the first signal and the second signal represent different physical measurements, training one or more event models using the second set of measurements and the identification of the one or more events as inputs, and using the one or more event models to identify at least one additional event within the wellbore.
A method of monitoring fluid outflow along a wellbore includes obtaining an acoustic signal from a sensor within the wellbore, determining one or more frequency domain features from the acoustic signal, and identifying one or more fluid outflow locations along the portion of the depth of the wellbore using the one or more frequency domain features. The acoustic signal includes acoustic samples across a portion of a depth of the wellbore.
G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
G01K 11/32 - Measuring temperature based on physical or chemical changes not covered by group , , , or using changes in transmittance, scattering or luminescence in optical fibres
15.
Systems and methods for draw down improvements across wellbores
A method for determining an operating envelope for a wellbore can include receiving an indication of a hydrocarbon production rate of a hydrocarbon fluid into the wellbore from at least one production zone, receiving an indication of a fluid production rate of a fluid into the wellbore from the at least one production zone, receiving an indication of a pressure within the wellbore while producing the one or more fluids from the wellbore from the at least one production zone, correlating the indication of the pressure with the hydrocarbon production rate and the fluid production rate, and determining an operating envelope based on the correlating. The fluid production rate comprises at least one of: an aqueous fluid production rate or a gas production rate. The operating envelope defines a boundary for the indication of the pressure, the fluid production rate, and the hydrocarbon production rate.
E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
E21B 47/135 - 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. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 47/10 - Locating fluid leaks, intrusions or movements
16.
Fluid inflow characterization using hybrid DAS/DTS measurements
A method of determining fluid inflow rates within a wellbore comprises determining a plurality of temperature features from a distributed temperature sensing signal originating in a wellbore, determining one or more frequency domain features from an acoustic signal originating the wellbore, and using at least one temperature feature of the plurality of temperature features and at least one frequency domain feature of the one or more frequency domain features to determine a fluid inflow rate at one or more locations along the wellbore.
E21B 47/135 - 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. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
E21B 47/14 - 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
A method of determining fluid inflow locations comprises determining a plurality of temperature features from a distributed temperature sensing signal originating in a wellbore, using the plurality of temperature features in a fluid inflow identification model, and determining the presence of fluid inflow at one or more locations along the wellbore based on an output from the fluid inflow identification model.
E21B 47/103 - Locating fluid leaks, intrusions or movements using thermal measurements
E21B 47/135 - 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. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
E21B 47/113 - Locating fluid leaks, intrusions or movements using light radiation
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 47/12 - 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
E21B 47/14 - 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
E21B 47/08 - Measuring diameters or related dimensions at the borehole
G01K 11/32 - Measuring temperature based on physical or chemical changes not covered by group , , , or using changes in transmittance, scattering or luminescence in optical fibres
G01F 23/00 - Indicating or measuring liquid level or level of fluent solid material, e.g. indicating in terms of volume or indicating by means of an alarm
18.
Event Detection Using DAS Features with Machine Learning
BP Exploration Operating Company Limited (United Kingdom)
Lytt Limited (United Kingdom)
Inventor
Thiruvenkatanathan, Pradyumna
Abstract
A method of identifying events includes obtaining an acoustic signal from a sensor, determining one or more frequency domain features from the acoustic signal, providing the one or more frequency domain features as inputs to a plurality of event detection models, and determining the presence of one or more events using the plurality of event detection models. The one or more frequency domain features are obtained across a frequency range of the acoustic signal, and at least two of the plurality of event detection models are different.
E21B 47/14 - 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
G06N 7/00 - Computing arrangements based on specific mathematical models
patents
