Patent Application
20200032648
The present disclosure relates generally to wellbore drilling and formation evaluation and, more specifically, to sensing systems for downhole hydrocarbon and gas species detection when forming a wellbore in a subterranean rock formation.
Hydraulic fracturing, commonly known as fracking, is a technique used to release petroleum, natural gas, and other hydrocarbon-based substances for extraction from underground reservoir rock formations, especially for unconventional reservoirs. The technique includes drilling a wellbore into the rock formations, and pumping a treatment fluid into the wellbore, which causes fractures to form in the rock formations and allows for the release of trapped substances produced from these subterranean natural reservoirs. At least some known unconventional subterranean wells are evenly fractured along the length of the wellbore. However, typically less than 50 percent of the fractures formed in the rock formations contribute to hydrocarbon extraction and production for the well. As such, hydrocarbon extraction from the well is limited, and significant cost and effort is expended for completing non-producing fractures in the wellbore.
In one aspect, a sensing system for a resource recovery system is provided. The sensing system includes at least one sensing sub-assembly, and a sensing computing device. The sensing computing device is configured to receive, from the at least one sensing sub-assembly, at least one signal that includes at least one pulse having at least one pulse peak. The sensing computing device is also configured to identify the at least one pulse peak which has a magnitude and a signal-to-noise ratio, and retrieve the at least one pulse peak from the at least one signal using the magnitude and the signal-to-noise ratio of the at least one pulse peak. The sensing computing device is further configured to store the at least one pulse peak within a database that includes one or more pulse peaks, and generate a component report that identifies one or more changes of at least one component.
In a further aspect, a computer-implemented method for detecting changes of one or more components in a drilling fluid is provided. The method includes receiving, from at least one sensing sub-assembly, at least one signal that includes at least one pulse having at least one pulse peak. The method also includes identifying the at least one pulse peak which has a magnitude and a signal-to-noise ratio, and retrieving the at least one pulse peak from the at least one signal using the magnitude and the signal-to-noise ratio of the at least one pulse peak. The method further includes storing the at least one pulse peak within a database that includes one or more pulse peaks, and generating a component report that identifies one or more changes of at least one component.
In another aspect, a non-transitory computer readable medium that includes executable instructions for detecting changes of one or more components in a drilling fluid is provided. The computer executable instructions cause the sensing computing device to receive, from at least one sensing sub-assembly, at least one signal that includes at least one pulse having at least one pulse peak. The computer executable instructions also cause the sensing computing device to identify the at least one pulse peak which has a magnitude and a signal-to-noise ratio, and retrieve the at least one pulse peak from the at least one signal using the magnitude and the signal-to-noise ratio of the at least one pulse peak. The computer executable instructions further cause the sensing computing device to store the at least one pulse peak within a database that includes one or more pulse peaks, and generate a component report that identifies one or more changes of at least one component.
These and other features, aspects, and advantages of the present disclosure will become better understood when the following detailed description is read with reference to the accompanying drawings in which like characters represent like parts throughout the drawings, wherein:
Unless otherwise indicated, the drawings provided herein are meant to illustrate features of embodiments of the disclosure. These features are believed to be applicable in a wide variety of systems comprising one or more embodiments of the disclosure. As such, the drawings are not meant to include all conventional features known by those of ordinary skill in the art to be required for the practice of the embodiments disclosed herein.
In the following specification and the claims, reference will be made to a number of terms, which shall be defined to have the following meanings.
The singular forms “a”, “an”, and “the” include plural references unless the context clearly dictates otherwise.
“Optional” or “optionally” means that the subsequently described event or circumstance may or may not occur, and that the description includes instances where the event occurs and instances where it does not.
Approximating language, as used herein throughout the specification and claims, may be applied to modify any quantitative representation that could permissibly vary without resulting in a change in the basic function to which it is related. Accordingly, a value modified by a term or terms, such as “about”, “approximately”, and “substantially”, are not to be limited to the precise value specified. In at least some instances, the approximating language may correspond to the precision of an instrument for measuring the value. Here and throughout the specification and claims, range limitations may be combined and/or interchanged. Such ranges are identified and include all the sub-ranges contained therein unless context or language indicates otherwise.
As used herein, the terms “processor” and “computer,” and related terms, e.g., “processing device,” “computing device,” and “controller” are not limited to just those integrated circuits referred to in the art as a computer, but broadly refers to a microcontroller, a microcomputer, a programmable logic controller (PLC), and application specific integrated circuit, and other programmable circuits, and these terms are used interchangeably herein. In the embodiments described herein, memory may include, but it not limited to, a computer-readable medium, such as a random access memory (RAM), and/or a computer-readable non-volatile medium, such as a flash memory. Alternatively, a floppy disk, a compact disc-read only memory (CD-ROM), a magneto-optical disk (MOD), and/or a digital versatile disc (DVD) may also be used. Also, in the embodiments described herein, additional input channels may be, but are not limited to, computer peripherals associated with an operator interface such as a mouse and a keyboard. Alternatively, other computer peripherals may also be used that may include, for example, but not be limited to, a scanner. Furthermore, in the exemplary embodiment, additional output channels may include, but not be limited to, an operator interface monitor.
Further, as used herein, the terms “software” and “firmware” are interchangeable, and include any computer program storage in memory for execution by personal computers, workstations, clients, and servers.
As used herein, the term “non-transitory computer-readable media” is intended to be representative of any tangible computer-based device implemented in any method of technology for short-term and long-term storage of information, such as, computer-readable instructions, data structures, program modules and sub-modules, or other data in any device. Therefore, the methods described herein may be encoded as executable instructions embodied in a tangible, non-transitory, computer-readable medium, including, without limitation, a storage device and/or a memory device. Such instructions, when executed by a processor, cause the processor to perform at least a portion of the methods described herein. Moreover, as used herein, the term “non-transitory computer-readable media” includes all tangible, computer-readable media, including, without limitation, non-transitory computer storage devices, including without limitation, volatile and non-volatile media, and removable and non-removable media such as firmware, physical and virtual storage, CD-ROMS, DVDs, and any other digital source such as a network or the Internet, as well as yet to be developed digital means, with the sole exception being transitory, propagating signal.
Furthermore, as used herein, the term “real-time” refers to at least one of the time of occurrence of the associated events, the time of measurement and collection of predetermined data, the time to process the data, and the time of a system response to the events and the environment. In the embodiments described herein, these activities and events occur substantially instantaneously.
Embodiments of the present disclosure relate to a sensing system for detecting changes of downhole drilling fluid components when forming a wellbore in a subterranean rock formation. The sensing system is implemented as a standalone evaluation system or installed as part of a wellbore drilling assembly. The sensing system determines characteristics of a first fluid discharged from the drilling assembly, and a second fluid that flows past the drilling assembly in the wellbore. More specifically, the sensing system includes a recessed cavity that receives a continuous stream of the second fluid, separate from the main flow of the second fluid. At least one sensor is positioned within the recessed cavity to facilitate protecting the sensor from the caustic and abrasive wellbore environment. The sensor is used to determine characteristics of the fluid, and the characteristics are analyzed to determine the changes of components in the fluid. As such, the analysis results are used to identify potentially promising fracture initiation zones within the wellbore such that efficient and cost effective completion planning can be implemented.
For example, detection of changes of downhole drilling fluid components while drilling facilitates identifying zones of high permeability, such as open natural fractures, clusters of closed but unsealed natural fractures, larger pores, and other formation features where hydrocarbons are stored. The analysis results can be used to identify the most promising fracture initiation points or zones, and the information can be used for completion planning, especially for unconventional reservoirs. In addition, the analysis results can be used to identify poor zones (no gas show), which facilitates reducing the time and effort of perforating and stimulating the poor zones. Another potential application is for geosteering assistance, wherein the real time gas show/species information is used to adjust the borehole position (e.g., inclination and azimuth angles) while drilling, such that a well having increased production can be formed. Finally, the sensing system can also provide kick detection to facilitate providing real-time alerts of gas flow potential for safety and environmental considerations, thereby reducing the risk of system failure.
Memory device 110 may be configured to store operational measurements including, without limitation, real-time and historical signal data of the sensing system and/or any other type data. Also, memory device 110 includes, without limitation, sufficient data, algorithms, and commands to facilitate monitoring and detecting changes of downhole drilling fluids.
In some embodiments, computing device 105 includes a presentation interface 120 coupled to processor 115. Presentation interface 120 presents information, such as a user interface and/or an alarm, to a user 125. In some embodiments, presentation interface 120 includes one or more display devices. In some embodiments, presentation interface 120 presents an alarm associated with the associated electric power distribution system being monitored and controlled, such as by using a human machine interface (HMI) (not shown in
A communication interface 135 is coupled to processor 115 and is configured to be coupled in communication with one or more other devices, such as a sensor or another computing device 105, and to perform input and output operations with respect to such devices while performing as an input channel. Communication interface 135 may receive data from and/or transmit data to one or more remote devices. For example, a communication interface 135 of one computing device 105 may transmit an alarm to the communication interface 135 of another computing device 105.
In the exemplary embodiment, detecting and monitoring of a sensing system is performed with local control devices, i.e., a localized computing device 105. Alternatively, detecting and monitoring of such sensing systems may be performed as a portion of a larger, more comprehensive system.
CPU 215 interacts with a first operator 230, e.g., without limitation, via user input interface 130 and/or presentation interface 120 (both shown in
In some embodiments, other devices 220 include one or more storage devices that are any computer-operated hardware suitable for storing and/or retrieving data, for example, and without limitation, multiple storage units such as hard disks or solid state disks in a redundant array of inexpensive disks (RAID) configuration, a storage area network (SAN), and/or a network attached storage (NAS) system.
Sensing sub-assembly 201 includes one or more monitoring sensors 240 coupled to CPU 215 through at least one input channel 245. Monitoring sensors 240 collect operational measurements including, without limitation, viscosity changes, compressibility changes, and/or type of components in downhole drilling fluids in contact with mechanical devices of sensing sub-assembly 201. Monitoring sensors 240 repeatedly, e.g., periodically, continuously, and/or upon request, transmit operational measurement readings at the time of measurement. CPU 215 receives and processes the operational measurement readings. In one embodiment, such data may be transmitted across network 225 and may be accessed by any device capable of accessing network 225 including, without limitation, desktop computers, laptop computers, and personal digital assistants (PDAs) (neither shown).
In some embodiments, some components described for
Cylindrical body 530 further includes a recessed cavity 638 defined therein. Recessed cavity 638 is either at least partially obstructed from or fully exposed to an ambient environment 640 exterior of cylindrical body 530, as will be explained in more detail below. As shown in
During operation of drilling assembly 301 (shown in
In the exemplary embodiment, sensing sub-assembly 201 (shown in
In one embodiment, referring to
Alternatively, the at least one sensor includes first pair 652 of sensors and a second pair 658 of sensors, including a third sensor 660 and a fourth sensor 662. Similar to first pair 652 of sensors, third sensor 660 is positioned for determining characteristics of first fluid 648 within internal flow channel 536, and fourth sensor 662 is positioned for determining characteristics of second fluid 650 within recessed cavity 638. In addition, first pair 652 of sensors operates at the same first frequency, and second pair 658 of sensors operates at the same second frequency. In the exemplary embodiment, the operating frequencies of first pair 652 and second pair 658 are defined within a sub-range of the operating frequency of the wide band transducer described above (i.e., sub-ranges spanning a portion of the range defined between and including about 100 kHz and about 2.5 MHz that collectively span a wide frequency range. As such, the data obtained from third sensor 660 and fourth sensor 662 are comparable relative to each other for determining the hydrocarbon content in second fluid 650.
In some embodiments, the at least one sensor further includes a third pair 664 of sensors, including a fifth sensor 666 and a sixth sensor 668. Fifth sensor 666 and sixth sensor 668 are positioned for determining characteristics of second fluid 650 within recessed cavity 638. More specifically, one of fifth sensor 666 and sixth sensor 668 is an emitter, and the other sensor is a receiver. In addition, recessed cavity 638 has a length L and a width W shorter than length L. Fifth sensor 666 and sixth sensor 668 are longitudinally spaced from each other within recessed cavity 638 relative to length L. Longitudinally spacing fifth sensor 666 and sixth sensor 668 from each other facilitates increasing the distance therebetween, such that the distance is not limited by the diameter of cylindrical body 530. Moreover, in one embodiment, fifth sensor 666 and sixth sensor 668 are low frequency transducers that operate at a frequency defined within a range between and including about 10 kHz and about 20 kHz. When compared to higher frequency transducers, the sensor readings obtained from third pair 664 of sensors are less likely to be scattered by gas bubbles contained in second fluid 650, for example. As such, operating third pair 664 of sensors at a low frequency range facilitates increasing the amount of useful data obtained for later analysis and evaluation, by computing device 105 (shown in
Methods 700 and 800 further include retrieving 706 the at least one pulse peak from the one or more signals using the magnitude and the signal-to-noise ratio. In alternative embodiments, methods 700 and 800 include removing at least one pulse peak that is not retrieved from the one or more signals included in the pulse train. Methods 700 and 800 also include storing 708 the at least one pulse peak within a database, the database including one or more pulse peaks.
Referring to
For example, in method 700 determining 710 may include calculating a magnitude spectrum and a phase spectrum from the at least one pulse peak, and a sound speed with respect to a time the at least one pulse peak was received. Method 700 also may include calculating 712 the one or more features using the calculated magnitude spectrum and phase spectrum from the retrieved signal and a magnitude spectrum and a phase spectrum from a water immersion testing. Calculating 712 the one or more features may at least include:
Method 700 may use any suitable signal processing method to calculate features mentioned above, such as, for example, a subband decomposing and reconstructing signal by wavelet.
Method 700 also includes using 714 the calculated one or more feature to instruct a computational discriminant model to identify at least one component. The output of the computational discriminant model includes at least one predetermined component type. The method for designing the computational discriminant model may include, but is not limited to, randomly partitioning the storage signal in a database, automatically tuning the super parameters on at least one computational discriminant model, quantifying metric and automatically voting the computational discriminant model. Method 700 may also include overwhelming, overfitting, maintaining, and/or managing the computational discriminant model version in the database, as well as online learning and updating the computational discriminant model once new retrieved signals are received reinforcement learning. The computational discriminant model may include, but is not limited to, supervised machine learning models, such as LDA, logistic regression, SVM, decision tree, random forest, or the like.
Referring to
Methods 700 and 800 further include generating 716 a component report that identifies one or more changes of at the least one component. The component report may also include the one or more of features of the at least one signal.
The systems and assemblies described herein facilitate providing at least semi-continuous hydrocarbon and gas species detection feedback when drilling unconventional subterranean wells. More specifically, the drilling assembly facilitates analyzing fluid used in the drilling process in a fast and efficient manner. The data obtained from the analysis of the fluid samples can then be used to determine zones within a wellbore that have either a low likelihood or a high likelihood of having high hydrocarbon content. As such, the zones having high hydrocarbon content are identified, and fracture completion planning resulting in improved well production is determined.
An exemplary technical effect of the systems and assemblies described herein includes at least one of: (a) providing real-time and continuous downhole drilling fluid components state detection feedback when forming a well in a subterranean rock formation; (b) identifying potentially promising fracture initiation zones within a wellbore; (c) improving hydrocarbon production for wells; (d) providing geosteering assistance for the drilling assembly; and (e) providing kick detection for real-time gas flow potential safety alerts.
Exemplary embodiments of a drilling assembly and related components are described above in detail. The drilling assembly is not limited to the specific embodiments described herein, but rather, components of systems and/or steps of the methods may be utilized independently and separately from other components and/or steps described herein. For example, the configuration of components described herein may also be used in combination with other processes, and is not limited to practice with only drilling and sensing assemblies and related methods as described herein. Rather, the exemplary embodiment can be implemented and utilized in connection with many applications where analyzing one or more fluids is desired.
Although specific features of various embodiments of the present disclosure may be shown in some drawings and not in others, this is for convenience only. In accordance with the principles of embodiments of the present disclosure, any feature of a drawing may be referenced and/or claimed in combination with any feature of any other drawing.
Some embodiments involve the use of one or more electronic or computing devices. Such devices typically include a processor, processing device, or controller, such as a general purpose central processing unit (CPU), a graphics processing unit (GPU), a microcontroller, a reduced instruction set computer (RISC) processor, an application specific integrated circuit (ASIC), a programmable logic circuit (PLC), a field programmable gate array (FPGA), a digital signal processing (DSP) device, and/or any other circuit or processing device capable of executing the functions described herein. The methods described herein may be encoded as executable instructions embodied in a computer readable medium, including, without limitation, a storage device and/or a memory device. Such instructions, when executed by a processing device, cause the processing device to perform at least a portion of the methods described herein. The above examples are exemplary only, and thus are not intended to limit in any way the definition and/or meaning of the term processor and processing device.
This written description uses examples to disclose the embodiments, including the best mode, and also to enable any person skilled in the art to practice the embodiments, including making and using any devices or systems and performing any incorporated methods. The patentable scope of the disclosure is defined by the claims, and may include other examples that occur to those skilled in the art. Such other examples are intended to be within the scope of the claims if they have structural elements that do not differ from the literal language of the claims, or if they include equivalent structural elements with insubstantial differences from the literal language of the claims.
| Filing Document | Filing Date | Country | Kind |
|---|---|---|---|
| PCT/CN2017/077883 | 3/23/2017 | WO | 00 |
