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公开(公告)号：US20230054654A1
公开(公告)日：2023-02-23
申请号：US17820894
申请日：2022-08-19
Applicant: Silixa Ltd.
Inventor： Peter Dawson , Veronique Mahue , Vu Nguyen , Pete Richter , Yinghui Wu
Abstract: The present disclosure provides a method of processing data obtained from distributed optical fiber sensors to detect acoustic energy generated by a poroelastic effect of fractures in a structure, such as a rock formation. The sensing fiber of an optical fiber distributed sensing system may be deployed in the vicinity of the region where fracturing is occurring, for example, along a well that is offset from a treatment well undergoing hydraulic fracturing. The DAS data obtained from along the sensing fiber is processed to measure changes in the low-frequency strain caused by the poroelastic effects in the rock as the fractures open and close. This measured strain rate data is iteratively processed at each instant time to identify fracture opening features (characterised as compression-tension-compression) that are correlated with fracture closing features (characterised as tension-compression-tension) as a function of depth, to thereby identify and locate fracture hits in the vicinity of the sensing fiber.
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公开(公告)号：US20210325238A1
公开(公告)日：2021-10-21
申请号：US17364595
申请日：2021-06-30
Applicant: Silixa Ltd.
Inventor： Mahmoud Farhadiroushan , Tom Richard Parker , Sergey Shatalin
IPC: G01H9/00 , G01D5/353 , E21B47/002 , E21B47/107 , G01M11/00 , G01F1/66 , G01V1/40
Abstract: The present invention provides novel apparatus and methods for fast quantitative measurement of perturbation of optical fields transmitted, reflected and/or scattered along a length of an optical fibre. The present invention can be used for point sensors as well as distributed sensors or the combination of both. In particular this technique can be applied to distributed sensors while extending dramatically the speed and sensitivity to allow the detection of acoustic perturbations anywhere along a length of an optical fibre while achieving fine spatial resolution. The present invention offers unique advantages in a broad range of acoustic sensing and imaging applications. Typical uses are for monitoring oil and gas wells such as for distributed flow metering and/or imaging, seismic imaging, monitoring long cables and pipelines, imaging within large vessel as well as for security applications.
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公开(公告)号：US11125909B2
公开(公告)日：2021-09-21
申请号：US15943197
申请日：2018-04-02
Applicant: Silixa Ltd. , Chevron U.S.A. Inc.
Inventor： Mahmoud Farhadiroushan , Tom Parker , Daniel Finfer
IPC: G01V11/00 , G01V1/22 , E21B47/135 , G01V1/40
Abstract: Embodiments of the present invention help in the processing and interpretation of seismic survey data, by correlating or otherwise comparing or associating seismic data obtained from a seismic survey with flow information obtained from a well or borehole in the surveyed area. In particular, embodiments of the present invention allow for flow data representing a flow profile along a well that is being monitored by a distributed acoustic sensor to be determined, such that regions of higher flow in the well can be determined. For example, in the production zone the well will be perforated to allow oil to enter the well, but it has not previously been possible to determine accurately where in the production zone the oil is entering the well. However, by determining a flow rate profile along the well using the DAS then this provides information as to where in the perforated production zone oil is entering the well, and hence the location of oil bearing sands. This location can then be combined or otherwise correlated, used, or associated with petroleum reservoir location information obtained from the seismic survey, to improve the confidence and/or accuracy in the determined petroleum reservoir location.
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公开(公告)号：US20210278255A1
公开(公告)日：2021-09-09
申请号：US17328014
申请日：2021-05-24
Applicant: Silixa Ltd. , Chevron U.S.A. Inc.
Inventor： Sergey Shatalin , Julian Dajczgewand , Mahmoud Farhadiroushan , Tom Parker
Abstract: Embodiments of the invention provide an improved optical fiber distributed acoustic sensor system that makes use of an optical fiber having reflector portions distributed along its length in at least a first portion. In particular, in order to increase the spatial resolution of the sensor system to the maximum, the reflector portions are positioned along the fiber separated by a distance that is equivalent to twice the distance an optical pulse travels along the fiber in a single sampling period of the data acquisition opto-electronics within the sensor system. As such, no oversampling of the reflections of the optical pulses from the reflector portions is undertaken, which means that it is important that the sampling points for data acquisition in the sensor system are aligned with the reflections that arrive at the sensor system from along the sensing fiber. In order to ensure such alignment, adaptive delay componentry may be used to adaptively align the reflected optical signals (or their electrical analogues) with the sampling points. Alternatively, control over the sampling points can also be undertaken to re-synchronise the sampling points with the returning reflections. In addition, in order to allow higher speed sampling to be undertaken, reflection equalisation componentry may also be used to reduce the dynamic range of the returning reflections.
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公开(公告)号：US20190323863A1
公开(公告)日：2019-10-24
申请号：US16474747
申请日：2018-01-05
Applicant: Silixa Ltd. , Chevron U.S.A. Inc.
Inventor： Sergey Shatalin , Julian Dajczgewand , Mahmoud Farhadiroushan , Tom Parker
Abstract: An improved optical fiber distributed acoustic sensor system uses an optical fiber having reflector portions distributed along its length in at least a first portion. The reflector portions are positioned along the fiber separated by a distance that is equivalent to twice the distance an optical pulse travels along the fiber in a single sampling period of the data acquisition opto-electronics within the sensor system. No oversampling of the reflections of the optical pulses from the reflector portions is undertaken. The sampling points for data acquisition in the sensor system are aligned with the reflections that arrive at the sensor system from along the sensing fiber. Adaptive delay componentry adaptively aligns the reflected optical signals (or their electrical analogues) with the sampling points. Control over the sampling points can re-synchronise the sampling points with the returning reflections. Reflection equalisation componentry may reduce the dynamic range of the returning reflections.
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Patent Agency Ranking
公开(公告)号：US10451462B2
公开(公告)日：2019-10-22
申请号：US15962196
申请日：2018-04-25
Applicant: SILIXA LTD. , CHEVRON USA INC.
Inventor： Mahmoud Farhadiroushan , Daniel Finfer , Veronique Mahue , Tom Parker , Sergey Shatalin , Dmitry Strusevich
Abstract: Embodiments of the present invention provide a cable for optical fiber sensing applications formed from fiber wound around a cable core. A protective layer is then preferably placed over the top of the wound fiber, to protect the fiber, and to help keep it in place on the cable core. The cable core is preferably of a diameter to allow bend-insensitive fiber to be wound thereon with low bending losses. The effect of winding the fiber onto the cable core means that the longitudinal sensing resolution of the resulting cable is higher than simple straight fiber, when the cable is used with an optical fiber sensing system such as a DAS or DTS system. The achieved resolution for the resulting cable is a function of the fiber winding diameter and pitch, with a larger diameter and reduced winding pitch giving a higher longitudinal sensing resolution.
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公开(公告)号：US10415373B2
公开(公告)日：2019-09-17
申请号：US15122038
申请日：2015-03-02
Applicant: Silixa Ltd.
Inventor： Andrew Clarke , Daniel Finfer , Veronique Mahue , Tom Parker , Mahmoud Farhadiroushan
Abstract: In order to address the above noted problems, embodiments of the present invention use distributed acoustic sensing to monitor the fluid level in an ESP activated well so as to monitor the condition and performance of the ESP. Embodiments of the invention use the ESP as an acoustic source in order to monitor the annulus fluid level within the well and to monitor the frequency of the ESP. Additionally, embodiments of the present invention may use distributed acoustic sensing to monitor the flow rates of the production fluid above and below the ESP to determine the pump's efficiency. In particular, some embodiments utilize one or more optical fibers to measure the acoustic waves generated by the ESP, wherein the fiber cabling has already been deployed along the length of the well. As such, the present invention is a non-invasive, in-situ method for monitoring the condition and performance of an ESP.
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公开(公告)号：US10393573B2
公开(公告)日：2019-08-27
申请号：US15368954
申请日：2016-12-05
Applicant: Silixa Ltd.
Inventor： Mahmoud Farhadiroushan , Tom Richard Parker , Sergey Shatalin
Abstract: The present invention provides novel apparatus and methods for fast quantitative measurement of perturbation of optical fields transmitted, reflected and/or scattered along a length of an optical fiber. The present invention can be used for point sensors as well as distributed sensors or the combination of both. In particular this technique can be applied to distributed sensors while extending dramatically the speed and sensitivity to allow the detection of acoustic perturbations anywhere along a length of an optical fiber while achieving fine spatial resolution. The present invention offers unique advantages in a broad range of acoustic sensing and imaging applications. Typical uses are for monitoring oil and gas wells such as for distributed flow metering and/or imaging, seismic imaging, monitoring long cables and pipelines, imaging within large vessel as well as for security applications.
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公开(公告)号：US20180224572A1
公开(公告)日：2018-08-09
申请号：US15943197
申请日：2018-04-02
Applicant: Silixa Ltd. , Chevron U.S.A. Inc.
Inventor： Mahmoud Farhadiroushan , Tom Parker , Daniel Finfer
CPC classification number: G01V11/00 , E21B47/123 , G01V1/226 , G01V1/40 , G01V2210/1429 , G01V2210/6161 , G01V2210/644
Abstract: Embodiments of the present invention help in the processing and interpretation of seismic survey data, by correlating or otherwise comparing or associating seismic data obtained from a seismic survey with flow information obtained from a well or borehole in the surveyed area. In particular, embodiments of the present invention allow for flow data representing a flow profile along a well that is being monitored by a distributed acoustic sensor to be determined, such that regions of higher flow in the well can be determined. For example, in the production zone the well will be perforated to allow oil to enter the well, but it has not previously been possible to determine accurately where in the production zone the oil is entering the well. However, by determining a flow rate profile along the well using the DAS then this provides information as to where in the perforated production zone oil is entering the well, and hence the location of oil bearing sands. This location can then be combined or otherwise correlated, used, or associated with petroleum reservoir location information obtained from the seismic survey, to improve the confidence and/or accuracy in the determined petroleum reservoir location.
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公开(公告)号：US20170082766A1
公开(公告)日：2017-03-23
申请号：US15311425
申请日：2015-05-15
Applicant: Silixa Ltd.
Inventor： Craig Milne , Brian Frankey , Tom Parker , Mahmoud Farhadiroushan
CPC classification number: G01V1/46 , E21B43/116 , E21B47/02208 , E21B47/091 , G01D5/14 , G01V1/226 , G01V1/44 , G01V11/002
Abstract: A downhole device is provided that is intended to be co-located with an optical fiber cable to be found, for example by being fixed together in the same clamp. The device has an accelerometer or other suitable orientation determining means that is able to determine its positional orientation, with respect to gravity. A vibrator or other sounder is provided, that outputs the positional orientation information as a suitable encoded and modulated acoustic signal. A fiber optic distributed acoustic sensor deployed in the vicinity of the downhole device detects the acoustic signal and transmits it back to the surface, where it is demodulated and decoded to obtain the positional orientation information. Given that the device is co-located with the optical fiber the position of the fiber can then be inferred. As explained above, detecting the fiber position is important during perforation operations, so that the fiber is not inadvertently damaged.
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