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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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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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Patent Agency Ranking
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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公开(公告)号：US20230314189A1
公开(公告)日：2023-10-05
申请号：US18209569
申请日：2023-06-14
Applicant: Silixa Ltd.
Inventor： Mahmoud Farhadiroushan , Tom Parker , Sergey Shatalin
CPC classification number: G01D5/3537 , G01H9/004 , G01D5/35306 , G01D5/35374 , E21B47/135
Abstract: An optical fiber distributed acoustic sensor system makes use of a specially designed optical fiber to improve overall sensitivity of the system by a factor in excess of 10. This is achieved by inserting into the fiber weak broadband reflectors periodically along the fiber. The reflectors reflect a small proportion of the light from the DAS incident thereon back along the fiber, typically in the region of 0.001% to 0.1%. To allow for temperate compensation to ensure that the same reflectivity is obtained if the temperature changes, the reflection bandwidth is relatively broadband. The reflectors are formed from a series of fiber Bragg gratings, each with a different center reflecting frequency, the reflecting frequencies and bandwidths of the gratings being selected to provide the broadband reflection. The reflectors are spaced at the desired spatial resolution of the optical fiber DAS.
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公开(公告)号：US11719560B2
公开(公告)日：2023-08-08
申请号：US16934189
申请日：2020-07-21
Applicant: Silixa Ltd.
Inventor： Mahmoud Farhadiroushan , Tom Parker , Sergey Shatalin
IPC: G01D5/353 , G01H9/00 , E21B47/135 , G01V8/16
CPC classification number: G01D5/3537 , G01D5/35306 , G01D5/35374 , G01H9/004 , E21B47/135 , G01V8/16
Abstract: An optical fiber distributed acoustic sensor system makes use of a specially designed optical fiber to improve overall sensitivity of the system by a factor in excess of 10. This is achieved by inserting into the fiber weak broadband reflectors periodically along the fiber. The reflectors reflect a small proportion of the light from the DAS incident thereon back along the fiber, typically in the region of 0.001% to 0.1%. To allow for temperate compensation to ensure that the same reflectivity is obtained if the temperature changes, the reflection bandwidth is relatively broadband. The reflectors are formed from a series of fiber Bragg gratings, each with a different center reflecting frequency, the reflecting frequencies and bandwidths of the gratings being selected to provide the broadband reflection. The reflectors are spaced at the desired spatial resolution of the optical fiber DAS.
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公开(公告)号：US20210072190A1
公开(公告)日：2021-03-11
申请号：US17102221
申请日：2020-11-23
Applicant: Silixa Ltd , Chevron U.S.A. Inc.
Inventor： Mohammad Amir , Mahmoud Farhadiroushan , Daniel Finfer , Veronique Mahue , Tom Parker
Abstract: Embodiments of the invention provide a “tool-kit” of processing techniques which can be employed in different combinations depending on the circumstances. For example, flow speed can be found using eddy tracking techniques, or by using speed of sound measurements. Moreover, composition can be found by using speed of sound measurements and also by looking for turning points in the k-w curves, particularly in stratified multi-phase flows. Different combinations of the embodiments can therefore be put together to provide further embodiments, to meet particular flow sensing requirements, both on the surface and downhole. Once the flow speed is known, then at least in the case of a single phase flow, the flow speed can be multiplied by the interior cross-sectional area of the pipe to obtain the flow rate. The mass flow rate can then be obtained if the density of the fluid is known, once the composition has been determined.
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