A method of identifying parameters associated with an event comprises identifying an event at a first location, correlating the event with one or more sensor outputs, identifying at least one sensor output of the one or more sensor outputs correlated with the event at the first location; and displaying the at least one sensor output along with an indication of the event. The one or more sensor outputs are obtained from a location other than the first location.
A method of workflow selection and event detection comprises: receiving, on a user interface, a plurality of selections from a user, wherein the plurality of selections identifies a plurality of time series data elements; correlating the plurality of selections with a plurality of workflows, wherein each workflow of the plurality of workflows defines a set of associated time series data elements; identifying a first workflow of the plurality of workflows associated with the plurality of selections; retrieving a first set of time series data elements associated with the first workflow; and identifying an event using the first set of time series data elements.
Systems and methods of detecting events are disclosed. In an aspect, a method includes obtaining a first sample with a distributed temperature sensor within a first wellbore portion, and determining a baseline based on the first sample. In addition, the method includes obtaining a second sample with the temperature sensor within a second wellbore portion that is different from the first wellbore portion. Further, the method includes determining one or more temperature features from the second sample. The temperature features comprise statistical variations of temperature measurements of the second sample. Still further, the method includes calibrating at least one of the second sample, the temperature features, or one or more models using the baseline, providing, after the calibrating, the temperature features as inputs to the one or more models, and determining the identification and presence of one or more events based on an output from the one or more models.
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
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 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.
G09G 5/00 - Control arrangements or circuits for visual indicators common to cathode-ray tube indicators and other visual indicators
G09G 5/36 - Control arrangements or circuits for visual indicators common to cathode-ray tube indicators and other visual indicators characterised by the display of individual graphic patterns using a bit-mapped 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 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 comprises 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 comprises acoustic samples across a portion of a depth of 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 method includes determining a plurality of features in a data signal, correlating the plurality of features to determine similarity scores between two or more features of the plurality of features, presenting information related to at least a first feature of the plurality of features, receiving feedback on the information, and determining, using a first machine learning model, information related to at least a second feature. The determination is made using the similarity scores and the feedback in the first machine learning model.
BP EXPLORATION OPERATING COMPANY LIMITED (United Kingdom)
Inventor
Thiruvenkatanathan, Pradyumna
Abstract
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
14.
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.
A method comprises obtaining one or more first reservoir properties of a first production zone within a first wellbore, correlating the one or more first reservoir properties with a set of reservoir properties having a corresponding set of determined operating envelopes, defining an operating envelope for the first production zone based on the determined operating envelope of the set of determined operating envelopes that corresponds to the first reservoir properties, determining, using the operating envelope, a pressure within the first production zone that is less than or equal to a maximum pressure for the first production zone defined by the operating envelope, and reducing a ratio of the fluid production rate to the hydrocarbon production rate in response to producing the one or more fluids from the first production zone at a pressure within the operating envelope.
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 47/113 - Locating fluid leaks, intrusions or movements using light radiation
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
17.
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.
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.
A method of completing a wellbore includes receiving an indication of sand ingress at one or more production zones within a first wellbore, receiving an indication of a force on a production face of the one or more production zones within the first wellbore, determining one or more operating envelopes for the one or more production zones in the first wellbore, correlating one or more production zones in a second wellbore with at least one of the one or more production zones within the first wellbore, defining one or more operating envelopes for the one or more production zones in the second wellbore based on the correlation, predicting sand ingress at the one or more production zones in the second wellbore using the one or more operating envelopes for the one or more production zones in the second wellbore, and defining a completion plan for the second wellbore.
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
E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
21.
SYSTEMS AND METHODS FOR DRAW DOWN IMPROVEMENT IN WELLBORES
A method for determining an operating envelope for a wellbore includes receiving an indication of sand ingress into the wellbore from at least one production zone, sand transport along the wellbore, or both while producing one or more fluids from the wellbore from the at least one production zone, correlating a force on a production face of the at least one production zone of the wellbore with the sand ingress, the sand transport, or both, and determining an operating envelope based on the correlating. The operating envelope defines a boundary for the force on the production face of the at least one production zone of the wellbore during a production of the one or more fluids from the at least one production zone.
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
E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
22.
SYSTEMS AND METHODS FOR DRAW DOWN IMPROVEMENTS ACROSS WELLBORES
A method includes obtaining one or more first geophysical properties of a first production zone within a first wellbore, correlating the one or more first geophysical properties with a set of geophysical properties having a corresponding set of determined operating envelopes, defining an operating envelope for the first production zone based on the determined operating envelope of the set of determined operating envelopes that corresponds to the first geophysical properties, determining, using the operating envelope, a force on a production face of the first production zone in the first wellbore that is less than or equal to a maximum force on the production face of the first production zone defined by the operating envelope, and limiting sand ingress into the first wellbore to below a sand ingress threshold in response to producing the one or more fluids from the first production zone at the force on the production face.
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
E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
23.
SYSTEMS AND METHODS FOR SAND INGRESS PREDICTION FOR SUBTERRANEAN WELLBORES
In an embodiment, a method of developing a predictive model for sand production from a wellbore comprises 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 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
E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
24.
DEPTH CALIBRATION FOR DISTRIBUTED ACOUSTIC SENSORS
BP EXPLORATION OPERATING COMPANY LIMITED (United Kingdom)
LYTT LIMITED (United Kingdom)
Inventor
Cerrahoglu, Cagri
Thiruvenkatanathan, Pradyumna
Abstract
A method of calibrating a distributed acoustic sensor (DAS) system includes obtaining a backscattered optical signal from a fiber optic cable disposed within a wellbore, determining an origination point within the backscattered optical signal, determining a bottom point within the backscattered optical signal, correlating the origination point and the bottom point with physical depth information for the wellbore, and determining at least a depth calibration for the backscattered optical signal using the correlating. The backscattered optical signal is representative of an acoustic or thermal signal along the fiber optic cable. The origination point identifies a first location at an upper point of the fiber optic cable within the backscattered optical signal, and the bottom point identifies a second location at a lower point of the fiber optic cable within the wellbore. The depth calibration correlates a sensed depth within the backscattered optical signal with a physical depth within the wellbore.
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
25.
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 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
E21B 41/00 - Equipment or details not covered by groups
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
patents
