RU2636989C1 - Fiber-optic probing of drilling string bottom hole assembly - Google Patents

Abstract

FIELD: mining.

SUBSTANCE: control system of bottom hole assembly of the drilling string comprises bottom hole assembly comprising one or more drill pipes and a drill bit connected to one or more drill pipes, and a system of sensors for monitoring the BHA, containing: one or more sections of optical fiber, a signal source module comprising an optical signal source arranged to emit an optical signal into one or more optical fiber segments, a signal detection module comprising an optical signal receiver arranged to detect an optical signal, a signal processing module which contains an electronic processor which is directed from the signal source module along one or more sections of optical fiber and which is capable of communicating with the detection module, and an operator's console or interface configured to communicate with the signal processing module. At that the signal processing module is programmed so that during the operation of the system: is determines the measurement data based on detected optical signal of thermomechanical properties at a plurality of different locations on one or more drill pipes, while the BHA is used to drill a well and send a signal to the operator's console or interface when the measurement data exceeds the threshold value.

EFFECT: maintenance of downhole tools within safe operating limits.

27 cl, 8 dwg

Description

FIELD OF TECHNOLOGY

The present invention relates to well construction and, in particular, to monitoring the properties of downhole tools during well construction.

BACKGROUND

Wells are typically used for access to areas below the surface of the earth, for the extraction of materials from these areas, for example, during the exploration and extraction of petroleum hydrocarbons from an underground location. Well construction typically involves drilling a wellbore and constructing a pipe structure in the wellbore. After completion, the pipe construction provides access to underground locations and allows materials to be transported to the surface.

Various tools are commonly used during well construction, and monitoring systems can be used to evaluate tool integrity during use. For example, a drill string with bottomhole assembly (BHA) equipment can be used to drill a borehole, and monitoring systems can be used to monitor parameters related to BHA integrity during drilling to ensure that BHA does not malfunction exposed to extreme environmental conditions (e.g. high temperature and / or pressure). These monitoring systems allow the operator to maintain downhole tools within safe operating limits.

DESCRIPTION OF DRAWINGS

In FIG. 1 shows an example of a system for drilling a wellbore.

In FIG. 2 is a diagram of an example control system.

In FIG. 3 is a diagram of an example of a fiber with Bragg gratings.

In FIG. 4 shows light interference due to reflections in an example fiber.

In FIG. 5A-D show various kinds of example BHA and fiber.

In FIG. 6 shows another example of a BHA and fiber.

In FIG. 7A-C show various views of an example of a connecting element.

In FIG. 8A shows an example of a drill pipe.

In FIG. 8B-C shows an example of drill pipe devices and fittings.

The same reference characters in the various drawings denote the same elements.

DETAILED DESCRIPTION OF THE INVENTION

Well construction typically involves drilling a wellbore and constructing a pipe structure in the wellbore. For example, as shown in FIG. 1, an operator may use a measurement while drilling (MWD) system 100 or logging while drilling (LWD) to drill a wellbore 102. System 100 comprises a surface control unit 110 and a drill string 120.

The drill string 120 comprises bottom hole assembly (BHA) equipment 122 along its lower part and a drill pipe 128 that extends between the BHA 122 and the surface control unit 110.

BHA 122 is a component that allows the drill string 120 to drill through the environment 130, and provides the mechanical force and support necessary to complete the drilling operation. BHA 122 contains one or more components to perform these functions. For example, BHA 122 contains one or more drill bits 124. A drill bit 124 is mounted at the end of BHA 122 and contains one or more removable drill elements. In operation, the drill bit 124 crushes, scrapes, or cuts the environment 130 due to the crushing or rotational movement of its drill elements.

BHA 122 also includes one or more drill pipes 126. Drill pipes 126 are located between drill bit 124 and drill string 128 and provide a support structure for drill bit 124 and other components of BHA 122. Drill pipes 126 are generally tubular and allow passage fluids from drill string 128 to drill bit 124 through an internal channel. The drill pipe 126 also exerts a load on the drill bit 124 and, using the load, creates a downward force necessary to efficiently drill the drill bit 124 into the environment 130.

BHA 122 may also contain other components that support the operation of drill string 120. For example, BHA 122 may contain one or more motors (not shown) for operating the drill bit and / or circulating the drilling fluid.

The BHA 122 is connected to the surface by a drill string 128. The drill pipe 128 provides a channel for transmitting energy, fluid, and / or communication signals between the BHA 122 and the surface control unit 110, and also provides a connection through which the surface control unit 100 performs raising, lowering and rotating the BHA 122. Using the control unit 110 on the surface, the operator can direct the BHA 122 along three-dimensional channels (for example, variable drilling perpendicularly, horizontally or at an intermediate angle relative to the surface), c give rise to piling barrel 102 wells.

During the drilling process, components of system 100 are typically exposed to harsh environmental conditions, such as stress, pressure, temperature, and other external stress factors. When the components of the system 100 are exposed to these stress factors, this can lead to changes in the temperature of the components, changes in the shape of the components (for example, distortion due to pressure and / or heating) and / or changes in the deformation, load or pressure experienced by these components. In this example, the environment 130 may exert physical force on the BHA 122 that may increase the deformation or stress experienced by the BHA 122. In another example, the environment 130 may be hotter or colder than the BHA 122 and may cause the BHA 122 to heat or cool. as it moves through the environment 130. In another example, the environment 130 may exert physical force on the BHA 122, which may cause deformation of the BHA 122. Since the BHA 122 can be damaged if it experiences severe deformation, stress, pressure, and temperature a tour, or if the BHA 122 undergoes a severe change in shape, the operator uses a control system to track the thermomechanical properties of the BHA (for example, the deformation, stress and pressure experienced by the BHA 112, the shape of the BHA, or the temperature of the BHA) during operation to maintain the BHA 122 safe working limits. These operating limits generally determine the conditions under which the BHA 122 can operate in a safe manner to prevent damage or destruction. In general, operating limits may differ between different BHAs and may be determined based on theoretical safety limits for a particular BHA, or may be determined empirically based on previously obtained performance data. In some embodiments, safe operating limits are used to set thresholds for one or more thermomechanical properties, for example, determining a maximum and / or minimum safe value for each thermomechanical property. One or more of the thermomechanical properties of the BHA 122 can be monitored using a fiber optic monitoring system that allows the operator to stop or change the operating mode of the BHA 122 until a dangerous threshold for the BHA is exceeded. An example of a fiber optic monitoring system 200 is shown schematically in FIG. 2. The monitoring system 200 includes a signal processing module 202, a visualization module 212, a signal source module 204, a signal detection module 206 and one or more optical fibers 208. Each fiber 208 includes one or more sensors 210. The signal source module 204 creates an optical the signal and emits an optical signal into one or more optical fibers 208. One or more sensors 210 along the fiber 208 interact with the optical signal and change the optical signal based on the thermomechanical properties of the sensor 210. The resulting optical s signal 206 detected by the signal detection module. Based on the detected optical signal, the signal processing module 202 determines data regarding one or more thermomechanical properties of the sensor 210. This information is displayed to the operator using the imaging module 212.

When the optical fibers 208 are located at the BHA 122 so that the optical fibers 208 conform to the shape of the BHA 122 and are exposed to the same external stress factors as the BHA 122, the control system 200 provides an assessment of the thermomechanical properties of the BHA 122. Thus, the operator can use the system 200 monitoring to monitor and track data on the thermomechanical properties of BHA 122 during operation of drill string 120.

The signal source module 204 creates light and modulates the light to produce an optical signal. The signal source module 204 is connected to the fiber 208 so that the generated optical signals are radiated into the fiber 208. The signal source module can produce single wavelength optical signals, or it can generate optical signals of more than one wavelength. For example, in some embodiments, the implementation of the signal source module 204 contains one or more optical transmitters that can create a spectrum of optical signals in the wavelength range. In some embodiments, optical transmitters may generate optical signals with varying data rates. In some embodiments, the implementation of the signal source module 204 is in communication with the signal processing module 202, and the operation of the signal source module 204 may be controlled by the signal processing module 202.

The signal source module 204 includes an optical transmitter to create an optical signal. An example of optical transmitters includes semiconductor devices such as light emitting diodes (LEDs) and laser diodes. In some embodiments, the optical transmitter includes LEDs that are made, inter alia, of, for example, indium gallium arsenide phosphide or gallium arsenide.

The signal detection module 206 detects optical signals routed by the fibers 208, and allows the system 200 to interpret the optical signals. The signal detection module can detect optical signals in the wavelength range and in the range of data rates. In some embodiments, the signal source module 204 is in communication with the signal processing module 202, and data collected by the signal detection module 206 can be interpreted by the signal processing module 202.

Signal detection module 206 comprises an optical receiver. An optical receiver converts light into electricity using the photoelectric effect, and allows the electrical system to detect and interpret optical signals. An example of optical receivers includes photodetectors or other optoelectric converters. In some embodiments, the implementation of photodetectors include semiconductor photodiodes, which are made, inter alia, of indium gallium arsenide.

In some embodiments, the functions of the signal source module 204 and the signal detection module 206 may be combined. For example, the transceiver may be used to combine the optical signal transmission functions of the signal source module 204 and the optical signal detection functions of the signal detection module 206. In this example, the transceiver includes both an optical transmitter and an optical receiver. The optical transmitter and the optical receiver can share common components, such as a common circuit or a common housing.

In some embodiments, the monitoring system 200 may measure one or more thermomechanical properties of the BHA 122 before, during, or after the drilling process. For example, the control system 200 may monitor the pressure, deformation, or load experienced by the BHA 122, the shape of the BHA 122, or the temperature of the BHA 122 during a drilling operation. In some embodiments, the monitoring system may collect data about one or more of these properties in real time, or in a mode close to real time, and display this data for an operator (for example, an operator using a surface control unit 110), so that the operator has the ability to control the operation of the drill string 120. In some embodiments, a monitoring system may store data so that it can be retrieved later.

In some embodiments, the monitoring system 200 may determine spatial information related to thermomechanical properties. That is, the monitoring system 200 can measure the thermomechanical properties and determine the location, direction and / or orientation of the measurements relative to the drill string 120. As an example, the monitoring system 200 can measure the localized strain experienced by the BHA 122, and can also identify the location on the BHA 122, which experiences localized deformation, and the orientation of the strain measurements (for example, whether there was a measured strain from the sensor located at the top of BHA 122, bottom of BHA 122, side of BHA 122 etc.).

In some embodiments, the monitoring system 200 may track the shape of one or more components of the drill string 120. For example, the monitoring system 200 may detect the shape of BHA 122 (for example, one or more drill pipes 126) and / or drill string 128. This allows the operator to observe the shape and the relative orientation of the components of the drill string 120, so that the operator can determine whether the components of the drill string 120 are installed and located according to plan. It also allows the operator to determine if one or more components are bent or skewed during the drilling operation, and allows the operator to determine if the drill string 120 is bent or skewed in such a way that the drill string 120 may be damaged or inoperative. Thus, the operator can use a monitoring system 200 to control the operation of drill string 120 in a safe manner.

The imaging module 212 displays data related to the monitoring system 200 to the operator through the console, or interface, of the operator. The displayed data may include, for example, one or more thermomechanical properties measured by the control system 200, the characteristics of the control system 200 (for example, the operating state of the control system 200 and / or one or more of its components, or the operating parameters of the control system 200), or other data related to the operation of the system 200. Data can be output either as text data, graphic data, or as a combination of text and graphic data. For example, an operator console may output data in the form of tables (for example, a table of thermomechanical properties), graphs (for example, a graph of changes in thermomechanical properties over time) or images (for example, an image illustrating basic data on one or more thermomechanical properties, or an image illustrating form of drill string components).

In some embodiments, the signal processing module 202 sends a signal to the operator console to alert the operator when a measured property crosses a specific threshold, such as a known safety threshold. For example, if the measured property has not crossed the threshold, the signal processing module 202 sends the corresponding signal to the operator console, and the operator console provides an indication that the BHA 122 is operating in safe mode. If the measured property approaches the intersection of the threshold value, the signal processing module 202 sends the corresponding signal to the operator panel, and the operator panel provides an indication that the BHA 122 is approaching safety limits. If the measured property crosses the threshold value, the signal processing module 202 sends the corresponding signal to the operator panel, and the operator panel provides an indication that the BHA 122 has exceeded safety limits. For example, if the measured form of BHA 122 crosses a specific threshold value (for example, if the curvature exceeds a specific threshold of curvature), the signal processing unit 202 sends a signal to the operator panel and the operator panel provides an indication that the form of BHA 122 has exceeded safety limits.

In some embodiments, the signal processing module 202 provides guidance to the operator console, which helps the user maintain the BHA 122 within safe operating limits. For example, if the measured property approaches the intersection of the safe limit, the signal processing module 202 provides recommendations on the operator panel on how to prevent unsafe operation (for example, recommendations to remove the drill string 120, pause or slow down drilling operations, or change other aspects of the drill string 120). If the measured property crosses a safe limit, the signal processing module 202 provides recommendations on the operator panel on how to prevent further operation in unsafe mode. Recommendations can be displayed for review by the user.

The signal processing module 202 and the operator console may provide indications and safety recommendations based on recently acquired measurements or based on retrospective trends across multiple measurements. For example, in some embodiments, the signal processing module 202 and the operator console provide an indication that the BHA 122 is returning to safe operating limits if it determines that the property falls to the extent that it is below the threshold for a specific period of time and provides recommendations for continuing the current operation. In another example, the signal processing unit 202 and the operator console provide an indication that the BHA 122 is operating in unsafe mode if the signal processing unit 202 determines that the property is being raised to a degree that it exceeds a threshold value over a specific period of time, and provide recommendations to pause the current operation.

In some embodiments, the system can automatically (i.e., without additional operator input) stop or otherwise change the BHA operation if the safe limit is exceeded.

The imaging module 212 may include one or more data output devices for presenting information to the operator, such as status indicators (e.g., indicator lights that light up to indicate information), or a video display, such as a flat-screen display (e.g., a monitor with a liquid crystal display (LCD) )). In some embodiments, the imaging module 212 is located in the surface control system 110 so that the operator can see information related to the control system 200 during operation of the drill string 120.

The control system 200 may determine thermomechanical properties in various ways. For example, the sensors 210 may be fiber sensors with Bragg grating (Fiber Bragg Grating, FGB) that can measure at one or more individual points along the fiber 208. As shown in FIG. 3, an example of an FGB sensor 210 includes several Bragg gratings 302 located with a period λ (i.e., the wavelength of the FBG sensor) along the length of a single-mode fiber optic fiber 208 (i.e., an optical fiber that carries one light beam).

In some embodiments, fiber 208 comprises a smaller inner core (e.g., about 4 to 9 microns in diameter) and an outer part (i.e., sheath) of a larger diameter (e.g., about 125 microns in diameter). The inner core can be made, for example, of glass (SiO ₂ ) and has a high refractive index caused by strong doping of the element, for example, doping with germanium. The difference in refractive indices between the inner core and the sheath leads to the propagation of light only inside the inner core.

Each Bragg grating 302 has a region with a refractive index different from the refractive index of the fiber 208, and as a result reflects light with a specific frequency band at the interface (i.e., the interface between the grating 302 and the fiber 208). For example, as shown in FIG. 3, the light emitted by the signal source module 204 having wavelengths λ _a and λ _b is not reflected and is directed by the fiber 208 to the signal detection module 206. However, a part of the light with a wavelength λ _{c is} reflected by the boundaries of each Bragg grating 302 back to the signal source module 204, while a part of the light continues to move to the signal detection module 206. The reflection coefficient (i.e., the part of the light reflected by each boundary of the Bragg grating) can be relatively small, for example between 0.001% and 0.1%.

In addition, since each Bragg grating 302 reflects light with a different phase shift, interference occurs and most of the reflected light is suppressed. However, reflections with an equal phase shift accumulate in the form of strong reflection peaks. This is illustrated in FIG. 4. The upper part of FIG. 4 shows a fiber 208 with a 10-boundary Bragg grating 402. Light enters from the left side of the fiber 208. Three light beams 404a-c with different wavelengths are shown below. The upper light beam 404a has a specific wavelength λ ₀ of the grating period, and all individual reflections of the boundary are reflected in phase and therefore add up to a reflected energy level 406a ten times larger than a single reflection of the boundary. The next light beam 406b has a 10% higher frequency, so that 11 light periods λ _{0 + 1} have a length of 10 grating periods λ ₀ . Thus, all unitary reflections of the boundary have different phases and are quenched, which leads to a level 406b of reflected energy of zero magnitude. A similar damping effect occurs with the lowest light beam 404c, which has a 10% lower frequency, so that 9 light periods λ _0-1 have a length of 10 lattice periods λ ₀ , which leads to a level of reflected energy of zero value 406c.

Thus, the reflection bandwidth and the resulting function of the reflected energy depend on the wavelength λ of the FBG sensor. This wavelength λ depends on various thermomechanical properties exhibited by fiber 208. For example, deformation and temperature are related to wavelength λ according to the following equation:

Where

Δλ = wavelength shift,

λ0 = beginning of the base wavelength,

k = 1 - p,

p = photoelectric conversion coefficient,

k = calibration factor

ΔT = temperature change in degrees Kelvin, K,

α _δ = change in refractive index,

равен 0,22, калибровочный множитель

равен 0,78 и изменение показателя преломления

равно

.In an example embodiment, the photoelasticity coefficient

0.22 calibration factor

equal to 0.78 and the change in refractive index

equally

.

уравнения описывает импульс деформации, вызванный усилием

и температурой

. Второе выражение

описывает изменение показателя преломления

стекла, вызванное только температурой.First expression

equation describes the strain momentum caused by the force

and temperature

. Second expression

describes the change in refractive index

glass caused only by temperature.

Further,

Where

εm = the deformation caused by mechanical means,

εT = deformation caused by temperature,

ε T = αsp * ΔT,

αsp = coefficient of expansion per degree Kelvin, K, of the sample.

This gives the following equations, which describe the behavior of the FBG sensor under the influence of both deformation and temperature:

and

- коэффициент теплового расширения,

- коэффициент теплового расширения

волокна.In the case of a temperature sensor only, the Bragg grating is not deformed. The signal Δλ / λ ₀ of the FBG sensor then changes only with temperature. In this case

- coefficient of thermal expansion,

- coefficient of thermal expansion

fiber.

or

which gives the equation for temperature measuring FBG sensors:

волокна является весьма малым. Например, в данном варианте осуществления

=0,55*10^-6/K. Самый большой импульс вытекает из изменения, зависимого от температуры, показателя преломления

.Когда волокно прикреплено к образцу, сигнал Δλ/λ₀ датчика FBG изменяется с деформацией

образца и, таким образом, коэффициент теплового расширения равен

, а не

.Таким образом,Expansion coefficient

fiber is very small. For example, in this embodiment

= 0.55 * 10 ^-6 / K. The largest momentum results from a change in temperature-dependent refractive index

.When the fiber is attached to the sample, the signal Δλ / λ ₀ of the FBG sensor changes with deformation

sample and, thus, the coefficient of thermal expansion is equal to

, but not

.In this way,

which gives the equation for the strain gauge FBG:

, он работает как датчик FBG температурной компенсации. Его сигнал вычисляют в соответствии с уравнениями:When the FBG sensor is attached to the sample in an area without mechanical deformation

It works as an FBG temperature compensation sensor. Its signal is calculated in accordance with the equations:

Thus, the FGB sensor can determine the strain and temperature data at individual points along the fiber based on measurements of the reflected signal of the sensor using these ratios. Based on this data, additional data regarding stress at individual points along the fiber can also be determined. For example, for materials with a known stress-strain ratio, stress data can be determined as a function of the measured strain.

In some embodiments, one or more light wavelengths may be guided through fiber 208, and the FGB sensor may interact with each light wavelength in different ways. In some embodiments, an optical signal including a light spectrum is sent through fiber 208, and a reflection spectrum is analyzed to measure several FBG signals simultaneously. The reflection spectrum can be analyzed, for example, using an interferometer to separate the spectrum according to the wavelengths of the component light rays.

In some embodiments, the FBG sensors can be used to determine the shape of the fiber 208. For example, in some embodiments, the fiber 208 contains two or more cores spaced, each core including several sensors 210. As described above, the sensors 210 of each fiber core 208 can be used to determine the deformation data relative to fiber 208. If the cores are mounted so that they are not located in the same plane when the fiber 208 bends I, each core will experience a different strain. The difference in deformation between each core can be used to determine the curvature along individual points along the fiber and can be used to determine the shape of the fiber 208. By determining the deformation along several cores not lying on the same plane, a multidimensional differential strain vector can be determined. Using the differential strain vector, data on the curvature and shape of the fiber 208 can be determined. In an example embodiment, fiber 208 with three non-lying cores can be used to determine the three-dimensional shape of fiber 208. In some embodiments, multiple fibers 208 each with a single core, can be used instead of a single fiber 208 with multiple cores. In some embodiments, shape determination may be performed using commercially available instruments, for example, using a distributed fiber optic interrogator, a distributed measurement system, or an optical backscatter reflectometer of a Luna Innovations Incorporated product line (Roanoke, Virginia).

In some embodiments, the monitoring system 200 may determine spatial information related to each of the measurements. That is, the control system 200 can measure the thermomechanical properties and determine the location, direction and / or orientation of the measurements relative to the drill string 120. This can be done in various ways. For example, in some embodiments, the monitoring system 200 can take measurements from individual points of the fiber 208. If the spatial arrangement of the fiber 208 is known, the monitoring system 200 can use this data to determine the specific position and / or orientation of the measurement source. For example, if it is known that fiber 208 is wound in a spiral around BHA 122, measurements from a single point of fiber 208 can be correlated with a specific point along a given spiral. This point can be used to determine the location, direction and orientation of the measurement relative to the drill string 120. In some embodiments, spatial data can be determined, in part, based on the measured shape of the fiber 208.

In some embodiments, instead of FBG sensors, the monitoring system 200 may include other types of sensors 210, such as micro-bend sensors, interferometric sensors, polarimeter sensors, or combinations of two or more different types of sensors. For example, the sensors 210 may be microbend sensors. In some embodiments, if the fiber 208 is subjected to small deformation (ie, "micro-bending"), the light rays in the inner core of the fiber may exceed the critical angle of the inner core. This leads to a redistribution of energy between the inner core and cladding modes. Higher-order guided modes of the inner core are coupled to cladding modes, which reduces the propagation of light in the fiber. Such a mode coupling can be achieved, for example, by placing the fiber in contact with a number of periodically arranged deformers. Thus, microbends cause a decrease in light intensity due to the leakage of light into the shell. By monitoring and correlating the loss of light intensity, various types of microbend sensors can be developed that can measure the forces acting on them. In some embodiments, microscopic end sensors are easier to implement than other types of fiber optic sensors, and they can potentially be performed at reduced cost.

The fiber 208 and its sensors 210 may be located on one or more components of the system 100 to monitor the thermomechanical properties exhibited by these components. For example, as shown in FIG. 5A, fiber 208 can be located on drill pipe 126 of BHA 122. Fiber 208 can be wound around drill pipe 126, for example, in a spiral fashion so that it continuously wraps around the circumference of drill pipe 126 as it passes along the length of drill pipe 126. This allows the control system 200 to collect data continuously along the length along the axis of the drill pipe 126, as well as continuously in the radial directions surrounding the drill string 126. The fiber 208 is aligned with the shape of the drill pipe 126 and fixed relative to the channel, so that any Reformation of the drill pipe 126 leads to a corresponding strain fiber 208.

Fiber 208 may be located in channel 502 so that it is recessed along the outer periphery of drill pipe 126. This is illustrated in FIG. 5B, where an enlarged view shows the dotted region of FIG. 5A. Like fiber 208, channel 502 can extend along the length of drill pipe 126 and can wrap spiral pipe 126 around pipe.

In some embodiments, fiber 208 is protected by sheath 504. For example, as shown in FIG. 5C-D, the sheath 504 surrounds the fiber 208 in the channel 502, protects the fiber 208 from the external environment and ensures that the fiber 208 is fixed relative to the drill pipe 126. The sheath 504 can be applied by any process of applying solid material over the fiber 208, for example , by welding or plasma welding with a direct arc (plasma transferred arc, PTA).

The fiber 208 may connect other components of the control system 200 and the system 100 in various ways. For example, as shown in FIG. 6, an example BHA 122 may include one or more drill pipes 126 with a fiber 208 located in a channel 502 extending along the lengths of the drill pipes 126. The drill pipe 126 is connected at one end of the axis to a source element 602 that contains signal source modules 204 ( not shown) of the system 200. The source element 602 is connected to the drill pipe 126 along the bottom of the BHA 122 and provides a connection point between the fiber 208 and the signal source modules 204, so that the optical signal generated by the signal source modules 204 is directed along a Fence 208 to the upper end of BHA 122.

The signal detection modules 206 may be located at the end opposite to the signal source modules 204, for example in MWD / LWD reducers 604, on another part of the drill string 120, or on the surface (for example, on the surface control unit 110). The signal source modules 204 are coupled to the fiber 208 at the end opposite to the signal source modules 204 and can provide data on the reflection behavior of optical signals when passing through the fiber 208.

The signal processing unit 202 may be located at various locations, for example along the drill string 120 or on the surface (for example, in the surface control unit 110). The signal processing module 202 is coupled to the signal source modules 204 and the signal detection modules 206 via one or more signal transmitters (e.g., a connection for a wired or wireless signal transmission). The signal processing module 202 controls the operation of the signal source modules 204 and the signal detection modules 206 and processes the optical signal to determine data regarding one or more properties and the associated location and orientation along the fiber 208.

As shown in FIG. 6, two or more components of the drill string 120 (eg, BHA 122) can be connected using a connecting element 606. The connecting element 606 provides a reliable connection between two adjacent components and allows the fiber 208 to pass between the two components. For example, the MWD / LWD adapter sleeve 604 may be coupled to the drill pipe 126a using a connector 606a. In another example, two drill pipes 126a-b may be connected using a connecting member 606b. In yet another example, drill pipe 126b and source member 602 may be coupled using coupler 606c. In each of these examples, fiber 208 continuously passes through two connected components.

The connecting element 606 is shown in more detail in FIG. 7A-C. The connecting element 606 is generally tubular and comprises a protrusion 702 at one end of the axis and a recess 704 at the other end of the axis. The protrusion 702 and the recess 704 can reliably install the connecting element 606 in the component with the corresponding recess or protrusion, respectively. The connecting element 606 contains two channels 706 and 708. The channel 706 is located in the center along the axis of the connecting element 606 and allows the flow of material between two interconnected components. For example, in some embodiments, when a connecting member 606b is connected between two drill pipes 126a-b, a channel 706 allows drilling fluid to flow between each of the drill pipes 126a-b. Channel 708 is located along the radial perimeter of the connecting element 606 and allows the fiber 208 to pass between two interconnected components. For example, in some embodiments, when the connecting member 606b is connected between the two drill pipes 126a-b, the channel 708 allows the fiber 208 to pass between the channel 502 of the first drill pipe 126a into the channel 502 of the second drill pipe 126b. The connecting element 606 may also contain one or more couplings 710, which can slide over the ends of the connecting element 606 to secure the connection point between the connecting element 606 and the connected component.

To ensure that the fiber 208 can continuously pass between two interconnected components, one or more components can contain one or more sections with reduced outer diameters. As shown in FIG. 8A, an example of the drill pipe 126 includes an end portion 802 with a protrusion 804 corresponding to a recess 704 of the connecting member 606. The drill pipe 126 also includes a section 806 with a reduced outer diameter compared to the diameter of the main extension 808 of the drill pipe 126. As shown in FIG. 8B, when the protrusion 804 of the drill pipe 126 is seated in the recess 704 of the connecting element 606, the portion 806 remains outside the connecting element 606. This portion 806 provides a smooth passage of the fiber 208 from the channel 502 of the drill pipe 126 to the channel 708 of the drill pipe 606 so that it can continuously pass between two components. As shown in FIG. 8C, the connecting element 606 can be used to connect two components to each other (for example, two drill pipes 126a-b) so that the fiber 208 runs continuously between each of the connected components.

In some embodiments, more than one fiber 208 may be used. For example, drill pipe 126 may comprise two or more fibers 208 wound along its periphery. The fibers can be arranged so that they are at the same distance from each other (for example, are arranged so that they maintain a constant distance from each other along the drill pipe 126), or they can be arranged in other patterns. For example, in some embodiments, the fibers 208 may be located so that at one or more locations the fibers 208 are closer to each other than at one or more other locations. In some embodiments, one or more fibers 208 are bundled together with each other so that each one runs in parallel in close proximity along their length.

In some embodiments, fiber 208 may be arranged in various patterns. For example, in some embodiments, the fiber 208 may be wound in a variable pitch so that it wraps more frequently around certain sections as compared to other sections. In some embodiments, instead of a spiral pattern, the fiber 208 can be positioned so that it extends essentially parallel to the length along the axis of the drill pipe 126. In some embodiments, the fiber 208 can be positioned in accordance with any other arbitrary arrangement. In some embodiments, fiber 208 may include a combination of two or more such locations. For example, in some embodiments, the fiber 208 may have a portion with a constant helix pattern, a portion with a parallel pattern, and a portion with a variable helix pattern.

In some embodiments, the signal source model 204 and the signal detection module 206 may be located at one end of the fiber 208, rather than at opposite ends. Signal detection module 206 may include an interferometer for analyzing a spectrum of reflected light wavelengths to determine one or more thermomechanical properties.

The method described above may be embodied in digital electronic circuitry or in computer software, firmware, or hardware, including the structures disclosed herein and their structural equivalents, or in combination of one or more of them. For example, the signal processing module 202 may comprise an electronic processor, and the electronic processor may be used to process the optical signals detected by the signal detection module 206 to determine one or more thermomechanical properties, as described above. In another example, an electronic processor may be used to control the operation of a signal source module 204, a signal detection module 206, and / or a visualization module 212.

The term "electronic processor" covers all types of apparatuses, devices, and machines for processing data, including, for example, a programmable processor, a computer, a system on microcircuits, or a plurality thereof, or combinations thereof. The device may contain special-purpose logic circuits, for example, user-programmable logic arrays (FPGAs, field programmable gate arrays), or special-purpose integrated circuits (ASICs). The device may also contain, in addition to hardware, code that creates the conditions for the computer program in question, for example, code that creates the processor firmware, protocol stack, database management system, operating system, cross-platform runtime, virtual machine or a combination of one or more of them. The hardware and runtime allow you to implement a variety of different computing model infrastructures, such as web services, distributed computing, and network parallel computing infrastructures.

Processors suitable for executing a computer program include, for example, general and special purpose microprocessors and one or more processors of any kind of digital computer. Typically, the processor should receive instructions and data from read-only memory or random access memory, or both. The main elements of a computer are a processor for performing actions in accordance with commands and one or more storage devices for storing commands and data. In general, a computer should also include, or be functionally connected to receive data or transmit data, or both, with one or more mass storage devices, for example, magnetic, magneto-optical disks or optical disks. However, these devices are not required components of the computer. In addition, the computer can be integrated into another device, such as a mobile phone, personal digital assistant (PDA), mobile audio or video player, game console, Global Positioning System (GPS) receiver, or portable storage device (e.g. flash memory of a universal serial bus (universal serial bus, USB)), for example. Devices suitable for storing computer program instructions and data include all kinds of non-volatile memory, including, for example, semiconductor memory devices, for example, EPROM, EEPROM and flash memory devices; magnetic drives, such as internal hard drives or removable drives; magneto-optical disks; and compact discs and digital discs. The processor and memory can be supplemented by a specialized logic circuit or included in its package.

In general, in one aspect, a system includes a bottomhole assembly (BHA) equipment that includes one or more drill pipes and a drill bit connected to one or more drill pipes. The system also includes a sensor system for BHA monitoring. The sensor system includes one or more segments of an optical fiber spirally wound along one or more drill pipes, a signal source module arranged to radiate an optical signal into one or more segments of an optical fiber, a signal detection module located so to detect an optical signal directed from the signal source module, one or more pieces of optical fiber, a signal processing module in communication with the signal detection module, and bullets operator in communication with the signal processing module. The signal processing module is programmed to determine measurement data based on the detected optical signal of thermomechanical properties at a number of different locations on one or more drill pipes during system operation while the BHA is being used to drill a well. The signal processing module is also programmed to send a signal to the operator console during system operation when the measurement data exceeds a threshold value.

Embodiments of this aspect may include one or more of the following characteristics. The signal processing module can also be programmed to provide recommendations on the operator’s console during operation of the system based on measurement data and a threshold value. Thermomechanical property may be deformation. The thermomechanical property may be temperature. The thermomechanical property may be pressure. The thermomechanical property may be the BHA form. The BHA may comprise at least two drill pipes connected to each other by means of a connecting device, the connecting device including a tubular wall extending from the first end and second end, and a channel between the first end and the second end, and one or more segments of the optical fiber pass through the channel to continuously pass through at least two drill pipes and a connecting device. One or more segments of the optical fiber may be located in one or more channels that extend in a spiral along the BHA. The system may further comprise a containment located in one or more channels. The signal source module may be located between one or more drill pipes and a drill bit. The system may further comprise a visualization module in communication with the signal processing module, wherein the visualization module is programmed to output measurement data and indicate the location corresponding to the measurement data during system operation.

In general, in another aspect, a method for monitoring bottom hole assembly (BHA) equipment includes directing an optical signal into one or more pieces of optical fiber spirally wound around and extending along one or more BHA drill pipes, detecting an optical signal, after the optical signal is directed along one or more segments of the optical fiber, determination based on the detected optical signal of the measurement data on thermomechanical properties in a number of different locations on one one or more drill pipes at a time when BHA is used for drilling a well, and sending a signal to the operator’s console when the measurement data exceeds a threshold value.

Embodiments of this aspect may include one or more of the following characteristics. The method may further include providing recommendations to the user based on measurement data and a threshold value. Thermomechanical property may be deformation. The thermomechanical property may be temperature. The thermomechanical property may be pressure. The thermomechanical property may be the BHA form. The method may further include displaying the measurement data and indicating the location on the BHA that corresponds to the measurement data.

In general, in another aspect, the sensor system for monitoring the bottom of the drill string (BHA) includes one or more pieces of spiral-wound optical fiber extending along the BHA, a signal source module arranged to emit an optical signal in one or more segments of the optical fiber, a signal detection module, arranged so that to receive an optical signal directed from the signal source module, one or more segments of the optical fiber, the processing module signal ki, which communicates with the signal detection module, and an operator panel, which communicates with the signal processing module. The signal processing module is programmed to determine measurement data on thermomechanical properties at a number of different locations on the BHA during system operation and send a signal to the operator console when the measurement data exceeds a threshold value.

Embodiments of this aspect may include one or more of the following characteristics. The signal processing module can also be programmed to provide recommendations on the operator’s console during operation of the system based on measurement data and a threshold value. Thermomechanical property may be deformation. The thermomechanical property may be temperature. The thermomechanical property may be pressure. The thermomechanical property may be the BHA form. The signal source module may be located between the drill pipe and the drill bit. The system may further comprise a visualization module in communication with the signal processing module, wherein the visualization module is programmed to output measurement data and indicate the location on the BHA corresponding to the measurement data during system operation. The system may further comprise a connecting device connecting the first portion of the BHA to the second portion of the BHA, the connecting device comprising a wall of tubular shape extending from the first end and second end, and a channel between the first end and the second end, and one or more segments of the optical fiber pass through the channel to continuously pass through at least two drill pipes and a connecting device.

A number of embodiments have been described. Other embodiments are within the scope of the following claims.

Claims (53)

1. The control system equipment bottom of the drill string (bottomhole assembly, BHA), containing: bottom hole equipment comprising one or more drill pipes and a drill bit connected to one or more drill pipes, and A BHA sensor system comprising: one or more lengths of optical fiber spirally wound along one or more drill pipes; a signal source module comprising an optical signal source positioned to radiate an optical signal into one or more segments of an optical fiber; a signal detection module, comprising: an optical signal receiver arranged to detect an optical signal directed from one or more pieces of optical fiber from the signal source module; a signal processing module comprising an electronic processor configured to communicate with a detection module, and remote control or operator interface, configured to communicate with the signal processing module, the signal processing module is programmed so that during system operation: determine measurement data based on the detected optical signal of thermomechanical properties at many different locations on one or more drill pipes, while BHA is used for drilling a well, and send a signal to the remote control or operator interface when the measurement data exceeds a threshold value. 2. The system of claim 1, wherein the signal processing module is further programmed to provide recommendations on the remote control or operator interface based on the measurement data and the threshold value during operation of the specified system. 3. The system of claim 1, wherein the thermomechanical property is deformation. 4. The system of claim 1, wherein the thermomechanical property is temperature. 5. The system of claim 1, wherein the thermomechanical property is pressure. 6. The system of claim 1, wherein the thermomechanical property is the BHA form. 7. The system of claim 1, wherein the BHA comprises at least two drill pipes connected to each other by means of a connecting device; wherein the connecting device comprises a tubular-shaped wall extending from the first end and the second end, and a channel between the first and second end; however, one or more segments of the optical fiber pass through the channel to continuously pass through at least two drill pipes and a connecting device. 8. The system of claim 1, wherein one or more segments of the optical fiber are located in one or more channels that extend in a spiral along the BHA. 9. The system of claim 8, further comprising a containment located in one or more channels. 10. The system of claim 1, wherein the signal source module is located between one or more drill pipes and a drill bit. 11. The system of claim 1, further comprising a visualization module configured to communicate with the signal processing module, wherein the visualization module is programmed to output measurement data and indicate a location corresponding to the measurement data during system operation. 12. A method for monitoring bottom hole assembly (BHA) equipment, including: the direction of the optical signal in one or more segments of the optical fiber, wound in a spiral and passing along one or more drill pipes BHA; detecting the optical signal after the optical signal is directed along one or more segments of the optical fiber; determining, based on the detected optical signal, measurement data on thermomechanical properties at a plurality of different locations on one or more drill pipes, while BHAs are used for drilling a well, and sending a signal to the remote control or operator interface when the measurement data exceeds a threshold value. 13. The method according to p. 12, further comprising providing recommendations to the user based on measurement data and a threshold value. 14. The method according to p. 12, in which the thermomechanical property is deformation. 15. The method according to p. 12, in which the thermomechanical property is temperature. 16. The method according to p. 12, in which the thermomechanical property is pressure. 17. The method of claim 12, wherein the thermomechanical property is a BHA form. 18. The method of claim 12, further comprising displaying the measurement data and indicating the location on the BHA that corresponds to the measurement data. 19. A sensor system for monitoring bottom hole assembly (BHA) equipment, comprising: one or more pieces of optical fiber, made with the possibility of spiral winding and passing along the BHA; a signal source module comprising an optical signal source positioned to radiate an optical signal into one or more segments of an optical fiber; a signal detection module comprising an optical signal source positioned to receive an optical signal directed from one or more segments of an optical fiber from the signal source module; a signal processing module comprising an electronic processor configured to communicate with a detection module, and remote control or operator interface, configured to communicate with the signal processing module, the signal processing module is programmed so that during system operation: determine thermomechanical measurement data at a variety of different locations on the BHA and send a signal to the remote control or operator interface when the measurement data exceeds a threshold value. 20. The system of claim 19, wherein the signal processing module is further programmed to provide recommendations on the remote control or operator interface based on measurement data and a threshold value during system operation. 21. The system of claim 19, wherein the thermomechanical property is deformation. 22. The system of claim 19, wherein the thermomechanical property is temperature. 23. The system of claim 19, wherein the thermomechanical property is pressure. 24. The system of claim 19, wherein the thermomechanical property is the BHA form. 25. The system of claim 19, wherein the signal source module is located between the drill pipe and the drill bit. 26. The system of claim 19, further comprising a visualization module configured to communicate with the signal processing module, wherein the visualization module is programmed to output measurement data and indicate locations on the BHA corresponding to the measurement data during system operation. 27. The system of claim 19, further comprising a connecting device that connects the first BHA to the second BHA; wherein the connecting device comprises a tubular-shaped wall extending from the first end and the second end, and a channel between the first and second end; however, one or more segments of the optical fiber pass through the channel to continuously pass through at least two drill pipes and a connecting device.

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