• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    An exemplary method includes receiving a data set containing combinations of drilling parameter values (WOB, RPM) and operating condition values (ROP) for a drilling system (100) corresponding to each combination of drilling parameter values (WOB, RPM). At least one of a frequency and a duration of use can be determined for each of the combinations of drilling parameter values (WOB, RPM) in the data set. For at least some of the combinations of drilling parameter values, a topographic map (400-600) identifying the combinations of drilling parameter values (WOB, RPM), the operating condition values (ROP) corresponding to the combinations of values of a drilling parameter (WOB, RPM), and at least one of the frequency and the duration of use can be displayed for at least some of the combinations of drilling parameter values (WOB, RPM).
    公开号:FR3031131A1
    申请号:FR1561437
    申请日:2015-11-26
    公开日:2016-07-01
    发明作者:Giulia Toti；Peter C Yu；Avinash Wesley
    申请人:Halliburton Energy Services Inc；
    IPC主号:
    专利说明:

    [0001] BACKGROUND The present disclosure generally relates to well drilling operations, more particularly, to a real-time performance analyzer of drilling operations. Hydrocarbons, such as oil and gas, are generally obtained from underground formations that may be on land or offshore. The development of underground operations and the processes involved in hydrocarbon recovery from an underground formation are complex. Generally, underground operations involve a number of different steps, such as, for example, drilling a wellbore at a desired wellsite with a drilling rig, drilling the wellbore to optimize the production of hydrocarbons and the completion of the necessary steps to produce and treat hydrocarbons from the underground formation. A surface operator can control aspects of the drilling operation by defining drilling parameters for the elements of the drilling device. The drilling parameters can affect the performance of the drilling operation, including, without limitation, the penetration velocity (VdP) of the drilling rig in the formation. The evaluation of the operator's performance in the choice of operational parameters can be problematic and usually requires greedy processing in calculating the raw data after drilling the wellbore. FIGURES Some of the specific exemplary embodiments of this disclosure may be understood by reference, in part, to the following description and illustrations. Figure 1 is a diagram of an exemplary drilling system, according to aspects of the present disclosure.
    [0002] Fig. 2 is a diagram illustrating an example of a set of raw data of drilling parameter values and operating conditions collected during a drilling operation, according to aspects of the present disclosure. Figure 3 is a diagram of examples of visualizations generally used by operators to identify optimal values for drilling parameters.
    [0003] Fig. 4 is a diagram illustrating an example of a real-time or near real-time multidimensional topographic map that represents operational parameters resulting from combinations of drilling parameters on particular data ranges, according to aspects of the present disclosure.
    [0004] Figure 5 is a diagram of an exemplary topographic map with overlap, according to aspects of the present disclosure. Figure 6 is a diagram illustrating an example of a 4-dimensional topographic map, according to aspects of the present disclosure.
    [0005] Figure 7 is a diagram illustrating an example of a coordinate system divided by N by M container grids, according to aspects of the present disclosure. Figure 8 is a diagram illustrating an exemplary graph of the results of a "binning" operation described above, according to aspects of the present disclosure. Figure 9 is a diagram illustrating an exemplary workflow for generating and consulting a topographic map, according to aspects of the present disclosure. Fig. 10 is a diagram of an exemplary information processing system, according to aspects of the present disclosure. Although the embodiments of the present disclosure have been illustrated and described and are defined with reference to the exemplary embodiments of this disclosure, such references do not imply a limit on disclosure, and no such limitation. should not be deducted. The subject matter of the disclosed invention may be subject to substantial modifications, alterations and equivalents in form and function, as will be apparent to those skilled in the art who benefit from this disclosure. The illustrated and described embodiments of this disclosure are only examples, and do not include the full scope of this disclosure.
    [0006] DETAILED DESCRIPTION In the context of this disclosure, an information processing system may comprise any instrumentality or grouping of instrumentalities that may be used to calculate, classify, process, transmit, receive, retrieve, be the source of, switch, store, display, display, record, reproduce, manipulate or use any form of information, intelligence or data for commercial, scientific, control, or other purposes. For example, an information processing system may be a personal computer, a networked storage device, or any other suitable device and may vary in size, shape, performance, functionality, and price. The information processing system 30 may comprise a RAM, one or more processing resources such as a central processing unit (CPU) or hardware or software control logic, a ROM and / or other types of hardware. non-volatile memory. Additional components of the information processing system may include one or more disks, one or more network ports for communication with external devices as well as various input and output (I / O) devices, such as a keyboard, a mouse and a video screen. The information processing system may also include one or more buses that operate to transmit communications between the various hardware components. It may also include one or more interface units that can transmit one or more signals to a control, actuator, or device of this type. As part of this disclosure, a computer-readable medium may include any instrumentality or grouping of instrumentalities that may retain data and / or instructions for a period of time. The computer readable medium may include, for example, without limitation, a storage medium such as a direct access storage device (e.g., a hard disk or floppy disk), a sequential access storage device (eg, tape drive), CD, CD-ROM, DVD, RAM, ROM, EEPROM and / or flash memory; as well as communication media such as wires, optical fibers, microwaves, radio waves, and other types of electromagnetic and / or optical waves; and / or any combination of the foregoing elements. Illustrative embodiments of the present disclosure are described in detail herein. For the sake of clarity, all features of an actual implementation may not be described in this specification. It will of course be appreciated that in developing such a real embodiment, many implementation-specific decisions are made in order to achieve the specific implementation objectives, which will vary from one implementation to another. . In addition, it will be appreciated that such a development effort can be complex and time-consuming, but would, nevertheless, be a routine task for those skilled tradesmen who benefit from the present disclosure. In order to facilitate a better understanding of the present disclosure, the following examples of certain embodiments are given. In no way should such examples be construed as a limitation, or definition, of the scope of this disclosure. Embodiments of the present disclosure may be applicable to horizontal, vertical, deviated, or otherwise non-linear drilling wells in any type of subterranean formation. The embodiments may be applicable to injection wells as well as production wells, including hydrocarbon wells. Embodiments may be implemented using a tool that is suitable for testing, retrieving, and sampling along sections of the formation. Embodiments may be implemented with tools that, for example, may be transmitted through a flow passage in a tubular train or by using a log, a smooth cable, a spiral tube, bottom robots, and the like. wells, etc. The terms "coupled" or "coupled" as used herein are intended to describe either an indirect connection or a direct connection. Thus, if a first device is coupled to a second device, this connection can be through a direct connection or through an indirect mechanical or electrical connection through other devices and connections. In the same way, the term "communicatively coupled" as used herein is intended to describe either a direct or indirect communication connection. Such a connection may be a wired connection or not, such as, for example, an Ethernet or LAN connection. Such wired or unconnected connections are well known to those skilled in the art and will not be discussed in detail here. Thus, if a first device is communicatively coupled to a second device, this connection can be through a direct connection or through an indirect communication connection or through other devices and connections. Modern drilling and oil production operations require information on downhole parameters and conditions. Various methods exist for the collection of downhole information, such as logging during drilling ("LWD") and measurement during drilling ("MWD"). In the LWD, data is typically collected during the drilling process, thus avoiding the need to remove the drilling device to insert the wireline logging tools. The LWD therefore allows the driller to make precise modifications or corrections in real time in order to optimize performance while minimizing downtime. MWD is the term used to measure downhole conditions for the movement and location of the drilling rig while drilling is in progress. The LWD focuses more on measuring training parameters. Although distinctions between MWD and LWD may exist, the terms MWD and LWD are often used interchangeably. Within the scope of this disclosure, the term LWD can be used with the understanding that this term covers both the collection of the parameters of the formation and the collection of information concerning the movement and position of the drilling device. Figure 1 is a diagram illustrating an example of a drilling system 100, according to aspects of the present disclosure. In the illustrated embodiment, the system 100 includes a soil-mounted derrick 102 that is in contact with the surface 106 of a formation 108 through supports 110. The formation 108 may comprise a plurality of rock strata. 108a-e, each of which may consist of different types of rock with different characteristics. At least some of the layers 108a-e may be porous and contain entrapped liquids or gases. Even if the system 100 includes an "on-land" drilling system in which the soil 104 is at or near the surface, similar "off-shore" drilling systems are also possible and can characterized in that the soil 104 is separated from the surface 106 by a volume of water. The drilling system 100 may comprise a drilling device that includes a drill string 118, a well bottom module (BHA) 120, a drill bit 122. The drill string 118 may comprise multiple pipe segments of which are connected in the form of wire and can extend down through a bell nipple 132, a blowout preventer (BOP) 134 and a wellhead 136 into a wellbore 116 within the borehole. The wellhead 132 may comprise a portion that extends within the wellbore 116. In some embodiments, the wellhead 136 may be secured within the wellbore 116 with the wellbore 116. cement. The BOP 134 may be coupled to the wellhead 136 and the fountain tube 1232, and may operate with the fountain tube 132 to prevent excessive pressures from the formation 108 and the wellbore 116 from being released at the surface. For example, BOP 134 may have a ram type BOP which closes the ring between the drill string 118 and the wellbore 116 in the case of a blowout. The BHA 120 may be coupled to the drill string 118, and the drill bit 122 may be coupled to the BHA 122. The BHA 120 may include tools such as LWD / MWD elements 120a and telemetry elements 120b. The LWD / MWD elements 120a may include downhole instruments, such as sensors, that continually or intermittently monitor downhole conditions, drilling parameters, and other formation data. The information generated by the LWD / MWD element 120a can be stored while the instruments are downhole and later recovered at the surface, or communicated through the telemetry system 120b. The derrick 102 may comprise a movable muffle 112 for raising or lowering the drilling device into the wellbore 116. The drilling device may be suspended from the movable muffle 112 by a hook 180 coupled to the movable muffle 112. In the illustrated embodiment, the drilling device is suspended from the hook 180 through a pivot 126 which is coupled to the drill string 118 through a kelly 128, which supports the drill string 118 when lowered. through a workout from the top or a turntable 130.
    [0007] A motor 124 can control the relative position of the movable block 122 and thus the position of the drilling device within the wellbore 116. Once the drill bit 122 contacts the bottom of the wellbore 116, motor 124 and movable muffle 122 may be used to control the downward force applied to drill bit 122 from the drill rig. Specifically, lowering the movable muffle will increase the downward force applied to the drill bit 122 by increasing the amount of the weight of the drill device carried by the formation 108 through the drill bit 122 rather than by the hook. 180. On the other hand, lifting the movable muffle 122 will decrease the downward force applied to the drill bit 122 by increasing the amount of weight of the drill device carried by the formation 108 through the drill bit 122. Downward force on the drill bit 122 may include a drilling parameter of the drilling system 100 called "weight on the bit". During drilling operations, the drilling fluid, such as drilling mud, can be pumped by a slurry pump 138 from a tank 140 through a suction line 142. The drilling mud can flow from slurry pump 138 into drill string 118 at pivot 126 through one or more fluid conduits, including pipe 144, riser 146 and hose 148. Drilling mud may then flow to the bottom of the well through the drill string 118, and exit at the drill string 122 and return upwardly through a ring 150 between the drill string 118 and the drill well 116 in an open-well embodiment, or between the drill string 118 and a housing (not shown) in a recessed wellbore embodiment. The rate at which the drilling mud flows to the bottom of the well may be controlled by the pump 138 and may include a drilling parameter of the drilling system 100 referred to as the "flow rate". When in the wellbore 116, the drilling mud can pick up fluids and gases from the formation 108 as well as particles and drill cuttings that are generated by the drill bit 122 during drilling. contact with the formation 108. The fountain tube 132 may be in fluid communication with the ring 150, and the drilling mud may flow through the ring 150 to the teat bell 132 where it exits through a line of Return 152. The return line 152 may be coupled to one or more fluid treatment mechanisms 154/156, and allow fluid communication between the ring 150 and the fluid treatment mechanisms 154/156. The 154/156 fluid treatment mechanisms may separate the particles from the return of the drilling mud before returning the drilling mud to the tank 140, where it may be re-circulated through the drilling system 100. The drill bit Drill 122 may be driven by the rotation of the drill string 114 by a top drive 130. The top drive 130 may be coupled to the drill bit 118 and driven by a motor 124 or a separate motor. The motor 124 or other motor of the system 100 may cause the top drive 130 to rotate and thus the drill string 118 and the drill bit 122 to a given number of revolutions per minute (RPM). In alternative embodiments, a downhole motor, such as a fluid drive turbine, may be deployed in the BHA 120 and may rotate the drill bit 122 only, or may rotate the drill bit. drilling 122 in addition to the rotation applied to the drill bit 122 through the top drive 130 and the drill string 118. In these cases, the rotational speed of the drill bit 122 may be based, at least in part , on the flow rate of the drilling fluid through the drill string 118. The rotational speed of the drill bit 122 may include a drilling parameter of the drill system 100 referred to as "drill string RPM". Other arrangements of drilling devices are possible, as will be apparent to one skilled in the art in light of this disclosure. In some embodiments, the system 100 may also include one or more sensors that monitor the operating conditions of the system 100 in real time or near real time. The sensors may be placed within the drilling device, eg within the LWD / MWD 120a of the BHA 120, and at other surface locations 106, such as pressure sensors 182. The operating conditions include, without limitation, the torque of the drill bit 122, the penetration velocity (ROP) of the drilling device and the pressures within the fluid circulation system. The data from the sensors can be collected on the surface and stored, eg in a database or in a database for later retrieval. In some embodiments, the drilling system 100 may include a surface-positioned controller 106. The controller 160 may include an information processing system that may be communicatively coupled to one or more elements. Controllable elements may include drilling equipment whose operating states may be altered or modified through electronic control signals. An operator can interact with the controllable elements through the control unit 160 to alter the drilling parameters of the system 100. For example, an operator can set the RPM of the drill bit to a given value, which can, in turn, causing the control unit 160 to transmit a control signal to the motor 124 to alter the RPM of the top drive 130 and / or to issue a control signal to the pump 138 enabling modify the flow rate of the drilling fluid. In the same way, the operator can set the WOB to a given value, which can, in turn, cause the control unit 160 to transmit a control signal to the motor 124 for moving the movable muffle 112. The Operator-defined system 100 drilling parameters can affect the operating conditions of the system 100. For example, the ROP of the drilling device, the torque at the drill bit and the SPP may depend, in part , on the WOB, the flow rate and the RPM of the drill bit. As a general rule, the operator can try to maintain the operating conditions in the optimal ranges by searching for and identifying the optimal combinations for the drilling parameters. Relative to the ROP, e.g., the operator 5 may attempt to modify the definition points of the drilling parameters to maximize the ROP and thus reduce the overall well drilling time. It may be difficult, however, for an operator to synthesize and account for the ROP of a combination of real-time drill parameters. In addition, the analysis of the performance of the drilling operation generally requires a massive download of data from the sensors and drill parameter data and a rough approximation of the performance in the absence of sufficient granularity allowing to identify the performance of a single operator in relation to the identification of optimal drilling parameter combinations. According to aspects of the present disclosure, the performance of a drilling operation can be analyzed through the generation of real-time or quasi-real-time multidimensional topographic maps that visualize the operational parameters resulting from the combination of the drilling parameters defined. by the operator on data ranges defined by the operator or another user. The data ranges may include time ranges or depth ranges from the drilling operation for which sensor data from the system 100 is collected and the setting points of the drilling parameter are tracked and recorded. In some embodiments, the topographic maps may be overlaid or augmented by statistical analyzes identifying the behavior of the operator within the range of data. As will be described below, the topographic maps can be generated in real time or near real-time as the drilling operation evolves, allowing an operator to adjust "on the flap", or 25 can be generated, stored and subsequently retrieved to thoroughly evaluate the performance of the drilling operation and the operator at each time and depth range. Fig. 2 is a diagram illustrating an example of a raw data set of drilling parameter values and operating conditions collected during a drilling operation. In the illustrated embodiment, the data set 30 includes the WOB values 201 and drill bit RPM value 202 defined by an operator when the drill bit and at a given depth 203 in the formation, and the ROP 204 values resulting from the corresponding WOB and drill bit RPM values 201/202. Although the illustrated data set includes WOB and drill bit RPM as monitored drilling parameters, other drilling parameters, such as flow, can also be tracked. In addition, other operating conditions, such as torque and SPP, may be followed in addition to the ROP, and all operating conditions and drilling parameters may be tracked in terms of time segments rather than depths. of hole. In some cases, the generation of the raw data set may include the collection and storage of sensor data and drill parameter values at a site-level information processing system. drilling, or the collection of sensor data and values of the drilling parameter and the transmission of the sensor data and the defined values of the drilling parameter to a data center, server or other storage device located remote from the drilling site.
    [0008] Figure 3 is a diagram of an example of a visualization generally used by the operators to identify optimal values for the drilling parameters. In the illustrated embodiment, the visualizations are generated using a raw data set similar to that described above, with the visualization 301 corresponding to the WOB values defined by the depth of the hole, the visualization 302 corresponding to the RPM values of the 15 drill bit defined by the depth of the hole and the visualization 303 corresponding to the ROP resulting from the associated values of WOB and RPM of the drill bit at the corresponding hole depth. As can be seen, visualizations 301-303 provide little or no context for combinations of drilling parameters that result in optimized ROP, and visualizations also do not provide a mechanism through which the performance of the operator in identifying and maintaining combinations of drilling parameters that give an optimized ROP can be evaluated. Figure 4 is a diagram of an example of a real-time or near-real-time multidimensional topographic map that displays the operating conditions resulting from combinations of drilling parameters over particular data ranges, according to aspects of the present disclosure. . As will be described in detail below, the topographic map can be generated as part of a user interface in a control unit of a drilling system similar to the control unit described above with respect to the Figure 1. The topographic map can be generated from a set of raw data similar to the one described above. In the illustrated embodiment, a drilling parameter (WOB) is reported on the x-axis of the card 400, another drilling parameter (drill bit RPM) is reported on the y-axis of the map 400, and the operating condition (ROP) resulting from the combination of the drill parameter values corresponding to an x / y coordinate given on the map 400 is reported as a color gradient at that position. Other drilling parameters and operating conditions may be reported in similar topographic maps within the scope of this disclosure. Each of the topographic maps a, b and c may be associated with a different time or depth range from the drilling operation. In the illustrated embodiment, the time or depth range may be selected using a graphical cursor 402 in which an upper and lower limit of the time or depth range is selected. Specifically, the slider may correspond to the available time range or depth data available to be viewed within the map, and the buttons 402a / 402b may be manipulated by the operator within a range of times. user interface of an information processing system, e.g., to select the range of raw data to be displayed within the map 400. The time or depth range may be selected by other ways, including other graphical interfaces, as would be understood by one skilled in the art. Although static ranges of time and depths are illustrated, in some embodiments, the time or depth range may "float" or move forward as time passes or the depth of drilling increases, so that the topographic map updates with real-time or near-real data corresponding to the current operating conditions corresponding to the current values of the drilling parameter defined by the operator. In some embodiments, at least one map overlay or augmentation may be used to identify, in the topographic map, significant drilling behaviors by the operator for the purpose of determining the performance of the operator. Fig. 5 is a diagram illustrating an example of a topographic map with an overlay, according to aspects of the present disclosure. Like the map described above, the map 500 reports ROP values as a color gradient at the combinations of WOB and RPM values that are reported on the x- and y- axes, respectively. In the illustrated embodiment, however, the card 500 includes indicators 502 reported at certain combinations of the drill parameters within the card 500. In some embodiments, the indicators 502 may correspond, e.g. ., to the combinations of drilling parameters that the operator has used at certain minimum thresholds of time and / or depth. In these cases, the raw data can be received by a processor of an information processing system and the time / depth of use of each combination of drilling parameters can be accumulated. The processor can then display indicators for each combination of drilling parameters with accumulated time / depth above a certain threshold. The threshold may be set by a user of the information processing system, such as an operator, through the graphical user interface (GUI) as will be explained below. In other embodiments, the indicators 502 may correspond, e.g., to the combinations of the drilling parameters that are used with a frequency above a minimum frequency threshold. In these cases, the raw data may be received by a processor of an information processing system and occurrences of each combination of drilling parameters may be tracked. The processor can then display the indicators for each combination of drilling parameters with a number of occurrences above a certain percentage of the total number of entries in the selected raw data set. This percentage may be defined by a user of the information processing system, such as an operator, through the GUI. The location and distribution of the indicators 502 within the card 500 can be used to determine the performance of an operator. For example, if the indicators 502 are grouped within an area of the map 500 with a relatively high ROP, then the operator has generally been able to identify and maintain optimal combinations for the drill parameters. . If, on the other hand, the indicators 502 are distributed or generally grouped in an area of the map 500 with a relatively low ROP 502, then the operator has generally failed to identify and maintain optimal combinations for the parameters of the map. drilling. In some embodiments, the actual frequency / time of use for the combinations of drilling parameters used in the time or depth range can be reported. Fig. 6 is a diagram illustrating an example of a 4-dimensional topographic map 600 in which the actual frequency / time of use for each combination of drilling parameters is reported as an elevation along the axis of z of the map 600, and the x and y axes and the color gradients are reported in the same way on the maps described above. The map 600 provides additional information for determining the performance of an operator because it allows a visual determination of the distribution of the combination of the drilling parameter as well as the frequency / duration of use of the parameter combinations. drilling. In the illustrated embodiment, the card 600 illustrates a single peak located in an area with a relatively high ROP, indicating a generally good performance of the operator. If, on the other hand, the map 600 illustrates multiple peaks with low heights located in relatively low ROP areas, then the operator generally failed to identify and maintain optimal combinations of the drill parameters. An example of a method for generating 4-dimensional cards similar to the card 600 may include receiving a raw data set at a processor of an information processing system and preprocessing Datas. Reception of the raw data set may include receiving and accumulating data directly from the drilling system, similar to that described above, or receiving the raw data set from a data storage site in which data from a drilling system is accumulated and stored. Pretreatment of the raw data set may include eliminating data points lying outside the raw data set, including any combination of drill parameters whose frequency and / or duration of use is below. of a certain threshold and combinations of drilling parameters / operating condition values that lie outside the digital ranges that are displayed on the map. For example, the maximum and minimum values of the drilling parameter (eg WOBmin / WOBmax and the RPM ',' of the drill bit / RPMmax of the drill bit) and a range of operating condition values can be defined. by a user and values out of range can be excluded from the data set. The method may also include determining a frequency / duration of use for each combination of drilling parameters in the pretreated raw data set. In some embodiments, this may include dividing the pretreated raw data set into a plurality of containers corresponding to the maximum and minimum drill parameter values to be displayed on the topographic map. Figure 7 illustrates an example of a coordinate system 700 divided by an N-by-M grid of containers, according to aspects of the present disclosure. In the illustrated embodiment, a range of values of the first drilling parameter, WOBmin to WOBmax, is reported on the x-axis and a range of values of the second drilling parameter, RPMmin drill bit to 25 RPMmax drill bit , is reported on the y-axis. Each column of the grid may correspond to one of the N different ranges of WOB values between WOBmin and WOBmax (WOBi_N), and each row of the grid may correspond to one of the M different ranges of RPM values of the bit. drilling between the RPMmm of the drill bit and the RPMmax of the drill bit (RPMi_m of the drill bit). The number of containers can be varied to reflect the particular application that is needed, with a larger number of containers giving a more detailed view. In some embodiments, the pre-processed raw data set may be divided into a plurality of containers by sorting each of the data points of the pre-processed data set into one of the containers. As used herein, a data point may comprise a combination of values of the drilling parameter and the value of the operating condition associated with that combination of drilling parameter values within a parameter. dataset. The division of these data points in the containers may include processing the drilling parameter values at each data point to determine the column and line to which the values of the drilling parameter correspond. In some embodiments, processing the values of the drilling parameter at each data point to determine the column and line to which the values of the drilling parameter correspond may include the use of the following equations: column = ground ((WOB (k) - WOB ..) * N / (WOBmax - WOB ..)); and 10 line = ground ((RPM drill bit (k) - RPM '' 'drill bit) * M / (RPMmax drill bit - RPM' '' drill bit)); wherein k is a numerical identifier assigned to each unique data point in the pretreated raw data; WOB (k) is the value of WOB at the ke single data point; and the drill bit RPM (k) is the RPM value of the drill bit at the single data point. In particular, the aforementioned equations may be adapted to use other drilling parameter values, if any. Once a column and a row are determined for each data point in the preprocessed raw dataset, the value of the operating condition at each data point can be associated with the correct container. This association may include increasing a counter for the container indicating the number of data points associated with the container, and adding the value of the operating condition of the data point to a cumulative total of all the condition values. operation of all the data points associated with the container. For example, if two data points are associated with the drill bit container WOBi / RPM1, with one data point corresponding to one operating condition value of 100 and the other corresponding to an operating condition value. of 200, the counter for this container can be set to 2, and the cumulative total of the value of the operating condition can be set to 300. In some cases, an average value of the operating condition for the container can be calculated dividing the cumulative value of the operating condition by the counter value.
    [0009] Figure 8 is an example of graph 800 illustrating the results of a "binning" operation described above, according to the aspects of the present disclosure. Each line 800 of the grid may correspond to a container (tray) different from the plurality of containers illustrated in FIG. 7, the first two columns 801/802 of the graph 800 indicating the column / line coordinates of the associated container, respectively. Column 3031131 14 803 indicates the counter value for each container, indicating the number of data points from the pretreated raw dataset associated with the container. Column 804 indicates the average value of the operating condition described above, here the average ROP value of each data point being associated with the container.
    [0010] In some embodiments, the method may also include generating a visualization that identifies the determined frequency / duration of a combination of the drilling parameter in the pretreated raw data set. This state may include generating the visualization using the counter value and / or the average value of the operating condition calculated above, with the plurality of containers described above.
    [0011] Specifically, the visualization may include reported drilling parameter values with respect to the x and y axes, except for the value of the drilling parameter that is reported relative to the container grid, and the value of the counter at level of each container is reported on the z axis. In addition, the average value of the condition for each container can be reported as a color gradient.
    [0012] Figure 9 is a diagram illustrating an exemplary workflow for generating and viewing a topographic map, according to aspects of the present disclosure. At block 901, real-time data from a drilling operation can be captured. This real-time data may include operator-defined drilling parameters as well as the operating condition values derived from the drilling parameter values. At block 902, the captured data can be stored in a database or in a data server. This can occur, for example, through wireless transmission from a site of the drilling operation to a remote data center, or through other forms of data transmission to a storage unit. located at the drill site or at any location.
    [0013] At block 903, a surface control unit 950 located at the drilling site can receive real time data and display the data on a GUI. The displayed data may include the raw data set captured from the drilling operation. At any time before, during, and after the real-time data display on a GUI at block 903, a user of the surface control unit 950, such as an operator, can choose the parameters of drilling and operating conditions that must be reported on a topographic map similar to those described above. The operator can choose the drilling parameters and operating conditions through a GUI at the control unit 950. At block 905, the control unit 950 can pretreat and verify the quality of the data in order to determine the quality of the data. eliminate all those in the margin as described above. At block 906, the control unit 950 may generate the topographic map based, at least in part, on the drilling parameters and operating conditions selected by the user. At block 907, control unit 950 may display the generated topographic map with the display of raw data at block 903. Notably, both may be displayed to the user simultaneously. As the drilling operation progresses, the topographic map of block 907 can be updated in real time, allowing the operator to identify drill parameter values that optimize the operating condition. In addition, at block 952, the operator or other user, such as a drilling engineer, can manipulate the topographic map to identify trends in operating conditions. At block 908, the generated topographic map can be exported from control unit 950 and stored with the real-time data stored at block 902. This data can be exported in real time, daily, weekly, at 15. the end of the drilling operation, or at any time period when it is necessary. At block 909, the real-time data from block 902 with the exported topographic map data may be downloaded by a drilling engineer or other user for the purpose of evaluating the performance of the drilling operation. The collated information of the topographic map can be viewed and processed by a drill engineer at a GUI similar to that generated in the control unit 950. This may allow the drilling engineer to manipulate the data, including identifying and focusing on certain time periods or drilling depths to evaluate operator performance in identifying and selecting drill parameter values that optimize operating conditions.
    [0014] Figure 10 is a flowchart showing an exemplary information processing system 1000, according to aspects of the present disclosure. The information processing system 1000 may be used, for example, as part of a system or control unit for a drilling device. For example, a drilling operator may interact with the information processing system 1000 to modify the drilling parameters or to issue control signals to the coupled drilling equipment in communication with the processing system. 1000. The information processing system 1000 may comprise a processor or a CPU 1001 which is communicatively coupled to a memory control hub or a Northbridge 1002. The memory control hub 1002 may include a processor. memory control for directing information to and from various system memory components within the information processing system, such as a RAM 1003, a storage element 1006 and a hard disk 1007. The memory control hub 1002 can be coupled to the RAM 1003 and graphics processing unit 1004. The memory control hub 1002 can also be coupled to a hub The I / O hub 1005 is coupled to storage elements of the computer system, including the storage system 1006, which may include a flash ROM that includes an input / output system (BIOS). ) of the computer system. The I / O hub 1005 is also coupled to a hard disk 1007 of a computer system. The I / O hub 1005 can also be coupled to a super I / O chip 1008, which itself is coupled to multiple I / O ports 10 of the computer system, including a keyboard 1009 and a mouse 1010. The computer processing system 1000 may also be communicatively coupled to one or more elements of a drilling system through a chip 1008. According to aspects of the present disclosure, an example of a computer-readable non-transitory medium may contain a set of instructions. which, when executed by a processor, causes the processor to receive a data set containing combinations of drilling parameter values and operating condition values for a drilling system corresponding to each combination of drilling parameter values. ; and determining at least one of a frequency and a duration of use for each of the combinations of drilling parameter values in the data set. For at least some of the 20 combinations of the drilling parameter values, the instructions may cause the processor to display a topographic map identifying the combinations of drilling parameter values, the operating condition values corresponding to the combinations of the drilling parameter values. , is at least one of the frequency and duration of use for at least some of the combinations of drilling parameter values.
    [0015] In some embodiments, combinations of drilling parameter values include values corresponding to at least two of a bit weight of the drilling system, a rotation per minute of a drill bit of the drilling system, and a flow of drilling fluid through the drilling system. In some embodiments, the operating condition values include values corresponding to at least one of a penetration rate of the drilling system, a riser pressure of the drilling system and a torque on the surface of the drilling system. In any one of the embodiments described in the preceding two paragraphs, the set of instructions that causes the processor to determine at least one of the frequency and the duration of use for each of the combinations of parameter values. drilling in the data set, further causes the processor to sort the data set into a plurality of containers corresponding to the minimum and maximum drilling parameter values to be displayed on the topographic map. In some embodiments, the set of instructions that cause the processor to sort the data set into a plurality of containers corresponding to the minimum and maximum drilling parameter values to be displayed on the topographic map further causes the processor to increasing a counter value associated with a container of a plurality of containers for each data point of the data set sorted in the container of the plurality of containers; adding to a cumulative operating condition value the operating condition value of each data point of the data set sorted into the container of the plurality of containers; determining an average operating condition value by dividing the cumulative operating condition value by the counter value. In some embodiments, the instructions that cause the processor to display the topographic map identifying combinations of drill parameter values, the operation condition values corresponding to the drill parameter value combinations, and at least one of frequency and duration of use for at least some of the combinations of drilling parameter values further causes the processor to display the topographic map identifying the operating condition values corresponding to the combinations of drilling parameter values by displaying the average value of the operating condition; and displaying the topographic map identifying the at least one of the frequency and duration of use for at least some of the combinations of drill parameter values by displaying the counter value. In some embodiments, the instruction set further causes the processor to receive a selection from the user of a range of time or depth of 25 data points within the data set; and for combinations of drilling parameter values and corresponding operating condition values within the selected range of time or depth of the data points within the data set, displaying a topographic map identifying combinations of drilling parameter values, the operating condition values corresponding to the combinations of drilling parameter values, and at least one of the frequency and the duration of use for at least some of the combinations of values drilling parameter. According to aspects of the present disclosure, an exemplary method includes receiving a dataset containing combinations of drilling parameter values and operating condition values for a drilling system corresponding to each combination of values. drilling parameter. At least one of a frequency and a duration of use can be determined for each of the combinations of drill parameter values in the data set. For at least some of the combinations of drilling parameter values, a topographic map identifying combinations of drilling parameter values, the operating condition values corresponding to the drill parameter value combinations, and at least one of the frequency and duration of use can be displayed for at least some of the combinations of drilling parameter values. In some embodiments, the combinations of drilling parameter values include values corresponding to at least two of a bit weight of the drilling system, a rotation per minute of a drill bit of the drilling system. and a flow of drilling fluid through the drilling system. In some embodiments, the operating condition values include values corresponding to at least one of a penetration rate of the drilling system, a riser pressure of the drilling system and a torque. on the surface of the drilling system. In any of the embodiments described in the previous two paragraphs, determining at least one of the frequency and duration of use for each of the combinations of drill parameter values in the data set may include sorting the dataset into a plurality of containers corresponding to the minimum and maximum drilling parameter values to be displayed on the topographic map. In some embodiments, sorting the data set into a plurality of containers corresponding to the minimum and maximum values of drilling parameter to be displayed on the topographic map includes increasing a counter value associated with a container of the plurality of containers for each data point of the data set sorted into the container of the plurality of containers; adding to a cumulative operating condition value the operating condition value of each data point of the data set sorted in the container of the plurality of containers; determining an average operating condition value by dividing the cumulative operating condition value by the counter value. In some embodiments, the topographic map display identifying the combinations of drill parameter values, the operating condition values corresponding to the drill parameter value combinations, and at least one of the frequency and the duration of use for at least some of the combinations of drilling parameter values further comprises displaying the topographic map identifying the operating condition values corresponding to the 3031131 combinations of drilling parameter values by displaying the value average operating condition; and displaying the topographic map identifying the at least one of the frequency and duration of use for at least some of the combinations of drilling parameter values by displaying the counter value.
    [0016] In some embodiments, the method further comprises receiving a selection of the user of a range of time or depth of data points within the data set; and for combinations of drilling parameter values and corresponding operating condition values within the selected range of time or depth of the data points within the data set, displaying a 10 topographic map identifying the combinations of drill parameter values, the operating condition values corresponding to the drill parameter value combinations, and at least one of the frequency and the duration of use for at least some of the drill parameter values; combinations of drilling parameter values. According to aspects of the present disclosure, an exemplary drilling system 15 includes controllable elements each positioned to control one or more drilling parameter values of the drilling system and at least one sensor positioned to measure at least one condition value. operation of the drilling system, wherein the operating condition value is based, at least in part, on one or more of the drilling parameters. A control unit may be coupled to the controllable elements, wherein the control unit comprises a processor and a memory coupled to the processor, the memory containing a set of instructions which, when executed by the processor, cause the processor to receiving a data set containing combinations of drilling parameter values and operating condition values corresponding to each combination of drilling parameter values; determining at least one frequency and duration of use for each of the combinations of drill parameter values in the data set; and for at least some of the combinations of drilling parameter values, displaying a topographic map identifying combinations of drilling parameter values, the operating condition values corresponding to the drill parameter value combinations, and at least one the frequency and duration of use for at least some of the 30 combinations of drilling parameter values. In some embodiments, the one or more drilling parameters comprise at least two of a bit weight of the drilling system, one rotation per minute of a drill bit of the drilling system, and one or more of a flow rate of the drilling fluid through the drilling system, and the operating condition values include at least one of a penetration rate of the drilling system, a riser pressure of the drilling system and a torque on the surface of the drilling system. In some embodiments, the set of instructions that cause the processor to determine at least one of the frequency and duration of use for each of the combinations of drill parameter values in the data set, cause in addition the processor to sort the data set into a plurality of containers corresponding to the minimum and maximum values of drilling parameter to be displayed on the topographic map. In some embodiments, the set of instructions that cause the processor to sort the data set into a plurality of containers corresponding to the minimum and maximum values of the drill parameter to be displayed on the topographic map further causes the processor to increasing a counter value associated with a container of the plurality of containers for each data point of the data set sorted into the container of the plurality of containers; adding to a cumulative operating condition value the operating condition value of each data point of the dataset sorted into the container of the plurality of containers; determine an average operating condition value by dividing the cumulative operating condition value by the counter value. In some embodiments, the instructions that cause the processor to display the topographic map identifying the combinations of drill parameter values, the operating condition values corresponding to the drill parameter value combinations, and at least one frequency and duration of use for at least some of the combinations of drilling parameter values further causes the processor to display the topographic map identifying the operating condition values corresponding to the combinations of drilling parameter values by displaying the average value of the operating condition; and displaying the topographic map identifying at least one of the frequency and duration of use for at least some of the combinations of drill parameter values by displaying the counter value. In some embodiments, the instruction set further causes the processor to receive a selection from the user of a range of time or depth of the data points within the data set; and for combinations of drilling parameter values and corresponding operating condition values within the selected range of time or depth of the data points within the data set, displaying a topographic map identifying the combinations of drilling parameter values, the operating condition values corresponding to the combinations of drilling parameter values, and at least one of the frequency and the duration of use for at least some of the combinations of 3031131 21 drilling parameter values. Therefore, this disclosure is well suited to achieving the stated objectives and benefits as well as those inherent in it. The particular embodiments disclosed above are illustrative only, since the present disclosure may be modified and practiced in a different but equivalent manner which would be apparent to those skilled in the art who benefit from the teachings of the present disclosure. In addition, no limit is contemplated for the construction or design details illustrated herein, other than those described in the appended claims. It is therefore apparent that the particular illustrative embodiments disclosed above may be altered or modified and such variations are considered within the scope and spirit of the present disclosure. In addition, the terms mentioned in the claims have a clear and ordinary meaning unless explicitly stated otherwise and clearly defined by the applicant. The undefined articles "a" or "an" as used in the claims are defined herein to mean one or more of the elements they introduce. 19-042 16 15:06 DE-DEJADE & B I SET '+33142800183 T-222 P0011 / 0015310> ISLAND 131
    权利要求:
    Claims (14)
    [0001]
    REVENDICATIONS1. Method for analyzing the performance of a drilling operation, characterized in that it comprises: receiving a data set containing combinations of drilling parameter values (WOB, RPM) and condition values operating system (ROP) for a drilling system (100) corresponding to each combination of drilling parameter values (WOB, RPM); determining at least one of a frequency and a duration of use for each of the combinations of drilling parameter values (WOB, RPM) in the data set; and for at least some of the combinations of drilling parameter values, displaying a topographic map (400-600) identifying the combinations of drilling parameter values (WOB, RPM), the operating condition values (ROP) ) corresponding to the combinations of drilling parameter values, and at least one of the frequency and the duration of use for at least some of the combinations of drilling parameter values
    [0002]
    2. The method of claim 1, wherein the combinations of drilling parameter values (WOB, RPM) comprise values corresponding to at least two of a bit weight of the drilling system (100), a rotation by minute of a drill bit (122) for drilling the drilling system (100) and a flow rate of drilling fluid through the drilling system (100).
    [0003]
    The method of claim 1, wherein the operating condition values (ROP) comprise values corresponding to at least one of a penetration rate of the drilling system (100), a pressure of one riser (146) of the drilling system (100) and a surface torque (106) of the drilling system (100).
    [0004]
    4. A method according to any one of claims 1 to 3, wherein the determination of at least one of the frequency and duration of use for each 19-04- '16 15:06 DE- DEJADE & BISET +33142800183 T-222 P0012 / 00154411313 1 23 combinations of drilling parameter values (WOB, RPM) in the data set includes sorting the data set into a plurality of containers corresponding to the minimum and maximum parameter values of drilling to be displayed on the topographic map (400-600). 5
    [0005]
    The method of claim 4, wherein sorting the data set into a plurality of containers corresponding to the minimum and maximum drill parameter values to be displayed on the topographic map (400-600) includes increasing a counter value associated with a container of the plurality of containers for each data point of the data set sorted into the container of the plurality of containers; adding to a cumulative operating condition value the operating condition value (ROP) of each data point of the dataset sorted into the container of the plurality of containers; and determining an average operating condition value by dividing the cumulative operating condition value by the counter value.
    [0006]
    The method of claim 5, wherein the display of the topographic map (400-600) identifying the combinations of drilling parameter values (WOB, RPM), the operating condition values (ROP) corresponding to the combinations. of drilling parameter values, and at least one of the frequency and duration of use for at least some of the combinations of values of the drilling parameter further includes displaying the topographic map (400-600) identifying the operating condition values corresponding to the combinations of drilling parameter values (WOB, RPM) by displaying the average operating condition value; and displaying the topographic map (400-600) identifying the at least one of the frequency and duration of use for at least some of the combinations of drill parameter values by displaying the counter value. 30
    [0007]
    The method of any one of claims 1 to 6, wherein the method further comprises receiving a selection of the user of a time period or a time period of 19-4. DEJADE & BI SET '+33142800183 T-222 P0013 / 001 53Ial1413 1 24 depth (203) of the data points within the data set; and for combinations of drilling parameter values (WOB, RPM) and corresponding operating condition values (ROP) within the selected range of time or depth of the data points within the set of data, the display of a topographic map (400-600) identifying the combinations of drilling parameter values, the operating condition values corresponding to the combinations of drilling parameter values and at least one of the frequency and the duration of use for at least some of the combinations of the drilling parameter values (WOB, RPM). 10
    [0008]
    A computer-readable non-transitory medium containing a set of instructions which, when executed by a processor (1001), causes the processor (1001) to implement the method of any one of claims 1 to 7.
    [0009]
    A drilling system (100), characterized in that it comprises: controllable elements each positioned to control one or more drilling parameter values of the drilling system (100); at least one sensor (182) positioned to measure at least one operating condition value (ROP) of the drilling system (100), wherein the operating condition value is based, at least in part, on one or the several drilling parameters; a control unit (160) coupled to the controllable elements, wherein the control unit (160) comprises a processor (1001) and a memory coupled to the processor (1001), the memory containing a set of instructions which, when performed by the processor (1001), cause the processor to receive a data set containing combinations of drilling parameter values (WOB, RPM) and operating condition values (ROP) for each combination of parameter values of drilling; determining at least one of a frequency and a duration of use for each of the combinations of drilling parameter values (WOB, RPM) in the data set; and for at least some of the combinations of drilling parameter values (WOB, RPM), displaying a topographic map (400-600) identifying the parameters of the drilling parameters (19-32). 0015 0'1311131. 25 combinations of drilling parameter values, the operating condition values (ROP) corresponding to the combinations of drilling parameter values, and at least one of the frequency and the duration of use for at least some of the combinations drilling parameter values (WOB, 5 RPM).
    [0010]
    The system (100) of claim 9, wherein the one or more drilling parameters comprise at least two of a bit weight of the drilling system (100), a rotation per minute of a drill bit. (122) drilling the drilling system (100) and a drilling fluid flow through the drilling system, the operating condition values (ROP) comprise at least one of a penetration rate drilling system (100), riser pressure (146) of the drilling system (100) and surface torque (106) of the drilling system (100).
    [0011]
    The system (100) of any one of claims 9 and 10, wherein the set of instructions that cause the processor (1001) to determine at least one of the frequency and duration of use for each combinations of drilling parameter values (WOB, RPM) in the data set further cause the processor to sort the data set into a plurality of containers corresponding to the minimum and maximum values of the drilling parameter to be displayed on the data set. the topographic map (400-600). 25
    [0012]
    The system (100) of claim 11, wherein the set of instructions that cause the processor (1001) to sort the data set into a plurality of containers corresponding to the minimum and maximum values of drilling parameter to be displayed in the topographic map (400-600) further causes the processor (1001) to increase a counter value associated with one of the plurality of containers for each data point of the data set sorted into the container of the plurality of containers ; add to a running condition cumulative value the operating condition value of each data point of the dataset sorted in the 19-042 16 15:07 DE- DEJADE & BISET '+33142800183 T-222 P0015 / 0015310311313 1 26 container of the plurality of containers; determining an average operating condition value by dividing the cumulative operating condition value by the counter value. 5
    [0013]
    The system (100) of claim 12, wherein the instructions that cause the processor (1001) to display the topographic map (400-600) identifying the combinations of drilling parameter values (WOB, RPIv1), the values of The operating condition (ROP) corresponding to the combinations of drilling parameter values, and at least one of the frequency and the duration of use for at least some of the combinations of the drilling parameter values further brings the processor (1001) displaying the topographic map (400-600) identifying the operating condition values corresponding to the drill parameter value combinations by displaying the average operating condition value; and displaying the topographic map (400-600) identifying the at least one of the frequency and duration of use for at least some of the combinations of drilling parameter values (WOB, RPM) by displaying the counter value .
    [0014]
    The system (100) of any one of claims 9 to 13, wherein the instruction set further causes the processor (1001) to receive a selection from the user of a time or depth range. (203) data points within the data set; and for combinations of drilling parameter values (WOB, RPM) and corresponding operating condition values (ROI ') within the selected range of time or depth of data points within the game displaying a topographic map (400-600) identifying the combinations of drilling parameter values (WOB, RPM), the operating condition values (ROP) corresponding to the combinations of drilling parameter values (WOB, RPM). and at least one of the frequency and duration of use for at least some of the combinations of drilling parameter values (WOB, RPM).
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    法律状态:
    2016-10-21| PLFP| Fee payment|Year of fee payment: 2 |
    2017-10-26| PLFP| Fee payment|Year of fee payment: 3 |
    2018-07-13| PLSC| Search report ready|Effective date: 20180713 |
    2018-09-28| PLFP| Fee payment|Year of fee payment: 4 |
    2019-11-29| PLFP| Fee payment|Year of fee payment: 5 |
    2021-08-06| ST| Notification of lapse|Effective date: 20210705 |
    优先权:
    申请号 | 申请日 | 专利标题
    IBWOUS2014072582|2014-12-29|
    PCT/US2014/072582|WO2016108827A1|2014-12-29|2014-12-29|Real-time performance analyzer for drilling operations|
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