• 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:
    SYSTEM AND METHOD FOR ESTIMATING DIRECTIONAL CHARACTERISTICS BASED ON THE MEASURES OF THE BENDING TIME. The present invention relates to a system for measuring directional characteristics of a drilling tool which includes: at least one bending moment measuring device (BM) disposed in a downhole component, and at least one measuring device BM configured to generate bending moment data at least one bottom depth, bending moment data, and a processor in operable communication with the BM measuring device and configured to receive bending moment data a from the BM measuring device, a sinuosity factor (DLS) is calculated from the bending moment and a well tooling angle (WTF) from the BTF angle, and calculated at least one change in slope and one Enzyme change based on DLS and WTF angle.
    公开号:BR112013003751B1
    申请号:R112013003751-2
    申请日:2011-08-18
    公开日:2020-06-30
    发明作者:Gerald Heisig；John D. Macpherson
    申请人:Baker Hughes Incorporated；
    IPC主号:
    专利说明:

    [0001] [0001] This order claims the benefit of an earlier filing date for US Provisional Order Serial No. 61 / 374,795 filed on August 18, 2010, the entire description of which is incorporated herein by reference. BACKGROUND
    [0002] [0002] In the practice of directional drilling, the course of a well is determined by measuring the bottom of the well in the direction of the well with inclinometers and magnetometers at discrete survey points, mainly taken after drilling, using a pipe support and making a connection. The directional sensors provide an angle of inclination with respect to the vertical angle and an azimuth B in relation to the magnetic North. In addition to the depth measured at the inclination and survey points, a number of research stations can be obtained. In most directional applications, the minimum curvature method is applied to calculate the course of the well from the survey stations. The minimum curvature method assumes a circular arc between research stations with constant curvature or sinuosity factor (DLS). Additional effects, such as variations in local curvature, can generate significant depth errors, in particular with maneuverable engine systems if operated alternately in sliding and rotating mode between research stations. In addition, standard directional sensors can be affected by magnetic interference, either from nearby wells or in coating exit operations. SUMMARY
    [0003] [0003] A system for measuring directional characteristics of a downhole tool includes: at least one bending moment measurement device (BM) disposed in a downhole component that is configured to be mobile within a drilling, o at least one BM measuring device configured to generate bending moment data at at least one depth in the bore, the bending moment data including a borehole tool bending vector, a bending moment representing an amplitude of bending vector, and an angle of the bending tool face (BTF) representing an orientation of the bending vector; and a processor in communication operable with the measuring device BM and configured to receive bending moment data from the measuring device BM, calculating a sinuosity factor (DLS) from the bending moment based on the tool surface angle (WRF) and BTF angle, and calculated at least on a change in slope and a change in azimuth based on the DLS and the WTF angle.
    [0004] [0004] A method of measuring the directional characteristics of a downhole tool includes: arranging a downhole component and drilling in a ground formation, the downhole component operably coupled to at least one measuring device the flexion moment (BM); generate bending moment data through at least one BM measurement device at at least one depth in the bore, the bending moment data including a borehole tool bending vector, a bending moment representing an amplitude of bending vector, and an angle of the bending tool face (BTF) representing an orientation of the bending vector; receiving bending moment data from the BM measuring device on a processor; calculate a sinuosity factor (DLS) from the moment of bending and a BTF angle of the well tool face (WTF); and calculate at least one of a change in slope and a change in azimuth based on the DLS and the WTF angle. BRIEF DESCRIPTION OF THE DRAWINGS
    [0005] [0005] The following descriptions should not be considered limiting in any way. With reference to the accompanying drawings, as elements are numbered in the same way:
    [0006] [0006] Figure 1 is a cross-sectional view of an embodiment of a drilling and / or geosteering system,
    [0007] [0007] Figure 2 is a perspective view of a downhole tool for measuring the bending moment at a location in a drill string;
    [0008] [0008] Figures 3A and 3B are seen in perspective of a bottom component of the well showing an angle of the face of the bending tool (BTF);
    [0009] [0009] Figure 4 is an exemplary illustration of an angle of the face of the well tool (WTF);
    [0010] [0010] Figure 5 is a flow chart providing an exemplary method of estimating the slope and / or azimuth of a bottom component;
    [0011] [0011] Figure 6 is a perspective view of a directional bottom probe;
    [0012] [0012] Figure 7 is a close view of a directional probe from Figure 6;
    [0013] [0013] Figure 8 is an exemplary illustration of a sensor compensation angle; and
    [0014] [0014] Figure 9 is an illustration of a spreadsheet program used to estimate BTF angles. DETAILED DESCRIPTION
    [0015] [0015] The systems and methods described here for estimating or calculating various directional characteristics of measurements of bending moment in a rock bottom component. In one embodiment, a borehole tool angle (WTF) and / or bending tool face angle (BTF) is derived from bending moment sensors in a borehole tool. For example, the BTF angle is estimated from orthogonal measurements of the bending moment, and the WTF angle is estimated from the BTF angle. In one embodiment, changes in the angle of inclination and / or azimuth in a drilling are estimated in a sinuosity factor gravity (DLS) derived from measurements of the moment of bending and the WTF angle. Both DLS and WTF can be estimated using measurements from a pair of orthogonal flexural moment sensors that are both perpendicular to a drilling axis and to each other.
    [0016] [0016] With reference to Figure 1, an exemplary embodiment of a well drilling, profiling and / or geosteering system 10 includes a drilling column 11 that is shown arranged in a well or drilling 12 that penetrates at least one earth formation 13 during the drilling operation and makes measurements of properties of formation 13 and / or the bottom 12 drilling. As described here, "drilling" or "well" refers to a single hole that forms all or part of a well drilled. As described here, "formations" refers to the various characteristics and materials that can be found in a subsurface environment and around drilling.
    [0017] [0017] In one embodiment, system 10 includes a conventional mast 14 that supports a rotary table 16 that is rotated by an initiating movement at a desired rotational speed. The drill column 11 includes one or more sections of drill pipes 18 that extend downstream into the drill 12 from the rotary table 16, and is connected to a drill assembly 20. The drill fluid or drilling mud 22 it is pumped through drill column 11 and / or downhole 12. The well drilling system 10 also includes a downhole assembly (BHA) 24.
    [0018] [0018] The drilling assembly 20 is powered by a rotary surface drive, a motor using pressurized fluid (for example, a mud motor), an electrically driven motor and / or other appropriate mechanism. In one embodiment, a drilling motor or mud motor 26 is coupled to the drilling assembly 20 through a drive shaft disposed in a bearing assembly 28 that rotates the drill bit assembly 20 when the drilling fluid 22 passes through the mud engine 26 under pressure.
    [0019] [0019] In one embodiment, the drilling assembly 20 includes a steering assembly including an axis 30 connected to a drill bit 32. The axis 30, which in one embodiment is coupled to the mud motor, is used in geosteering operations to maneuver the drill bit 32 and the drill column 11 through the formation.
    [0020] [0020] In one embodiment, the drilling assembly 20 is included in the downhole assembly (BHA) 24, which is arranged within the system 10 at or near the bottom of the well section of the drilling column 11.The system 10 includes any number of downhole tools 34 by various processes including drilling formation, geosteering , and formation assessment (FE) for measurement versus depth and / or time, one or more physical quantities in or around a drilling. Tool 34 can be included in or incorporated as a BHA, drill string component or other suitable vehicle. A "vehicle" as described herein means any device, device component, combination of devices, means and / or member that may be useful to drive, house, support or otherwise facilitate the use of another device, device component, combination of devices, medium and / or member. Exemplary non-limiting vehicles include drill pipes of flexible tubing type, coiled tubing type, joint tubing type and any combination or portion thereof. Other examples of vehicles include casing tubes, electrical cables, electrical cable probes, piano string probes, droplet shots, downhole substitutes, downhole assemblies, and drill columns.
    [0021] [0021] In one embodiment, tool 34 includes sensor devices configured to measure directional characteristics at various locations along the perforation 12. Examples of such directional characteristics include slope and azimuth, from which the sinuosity factor (DLS) can be derived. Tool 34, or another tool, may include sensors for measuring the bending moment (BM), the angle of the bending tool surface (BTF), and the angle of the face of the bore tool (WTF). For example, tool 34 includes one or more sensors 36, 38 for measuring bending moments, such as an extensometer or extensometer assemblies (for example, a Wheatstone Bridge circuit). Other sensors may include an inclinometer 40 configured to provide inclination data. Although the sensor devices are shown in conjunction with tool 34 in Figure 1, the sensor devices are not so limited and can be included with any desired downhole components such as drill column 11 or another drill column, the BHA 24 and drilling assembly 20.
    [0022] [0022] An example of tool 34 is shown in Figure 2. An exemplary orthogonal coordinate system includes a z- axis that corresponds to the longitudinal axis of tool 34, and x- and y-perpendicular axes. In one embodiment, the sensor devices are configured to take two perpendicular measurements independent of the bending moment at selected cross-sectional locations of tool 34. Tool 34 may include flexure measurement sensors 36, 38 (eg, strain gauge) in a downhole assembly or other drill column component, or a flexion probe located on tool 34. The position of the flexure measurement sensors is shown on tool 34 by means of marks, indentations or other "X" indications and "Y" indicating the angular positions of the measurement sensors 36, 38 located on the x- and y- axis, respectively. For example, the X mark shows the angular position of a 36 strain gauge and the Y mark shows an angular position of a 38 strain gauge.
    [0023] [0023] Referring again to Figure 1, in a modality, tool 34 includes and / or is configured to communicate with a processor to receive, measure and / or estimate flexion moment measurements. For example, tool 34 is equipped with transmission equipment to communicate, above all, with a surface processing unit 42. In one embodiment, the surface processing unit 42 is configured as a surface drilling control unit that controls various drilling parameters such as rotational speed, weight on drill, drilling fluid flow parameters and others, and real-time record formation and display evaluation data. Such transmission equipment can take any desired shape, and different transmission media and connections can be used. Examples of connections include wired, fiber optic, acoustic, wireless and mud pulse telemetry connections.
    [0024] [0024] In one embodiment, the surface processing unit 42 and / or the tool 34 include components as needed to provide for stores and / or processing data collected from various sensors in this regard. Exemplary components include, without limitation, at least one processor, storage, memory, input devices, output devices and the like. The surface processing unit 42 is optionally configured to control tool 34.
    [0025] [0025] The tool 34 and / or the surface processing unit 42 are configured to estimate various directional characteristics based on measurements of the bending moment (BM), which are derived, for example, from orthogonal extensometers. The measurements of the orthogonal flexion moment are referred to as "BM_x" and "BM_y". The total bending moment can be obtained simply as the sum of vectors of these two measurements: BM Total = ((BM_x) 2 + (BM_y) 2 ) 1/2 . (1)
    [0026] [0026] In one embodiment, tool 34 and / or surface processing unit 42 are configured to estimate various directional characteristics, such as a slope, a change in inclination, a azimuth and a change in azimuth. For example, a slope and azimuth can be estimated based on the angle of the tool face of the well (WTF) and winding factor measurements (DLS).
    [0027] [0027] DLS can be estimated from the total flexion moment derived from two measurements of the perpendicular flexion moment. DLS can be calculated using appropriate models based on previous drilling measurements that describe the relationship between bending moment and DLS. The relationship between bending moment and DLS is predicted using, for example, a finite element model of tool 34 that takes into account the influence of flexible tool elements and stabilizers in the direct proximity of a measurement point. Such models take these influences into account so that differences in tool curvature, which are calculated based on BM measurements of tool 34, and drilling curvature can be taken into account.
    [0028] [0028] The WTF angle can also be estimated based on perpendicular BM measurements. Various mathematical models derived from drilling measurements can be used to estimate WTF. In one embodiment, the WTF is estimated from a bending tool angle (BTF) that can also be derived from two perpendicular measurements of the bending moment.
    [0029] [0029] With reference to Figures 3A and 3B, the angle of the BTF bending tool face is shown with reference to the high gravity side (the opposite direction of the gravity vector). The BTF angle is defined as the angle between the high gravity side and the flexion vectors (as illustrated, for example, in Figure 3A). The BTF angle can take values in the range of -180 degrees to +180 degrees, as shown in Figure 3B. The BTF angle can be calculated whether the drill column 11 is operating in a rotary mode, in which both the drill bit and the rotary drill bit, or in a slip mode in which only the drill rotates. For example, in slip mode, the BTF angle is calculated from measurements from the individual sensor BM_y and BM_x as follows: BTF = GTF + TF offset - arctan (BM_y / BM_x), (2)
    [0030] [0030] where "TF displaced" is the angle of displacement between the coordinate systems of directional sensors and bending sensors 36, 38, and "GTF" denotes the rotational orientation of the tool around the longitudinal axis with respect to the side of high gravity.
    [0031] [0031] In rotary mode, the BTF angle can be calculated using an algorithm that includes sampling signals, at high speed from the orthogonal pairs of magnetometer, accelerometer and flexion sensors 36, 38, on the rotary tool 34 that has the same axes orthogonal x, y and z, or that can be mathematically rotated and translated into a common orthogonal reference. The magnetometer data is processed to create an azimuth reference, and both accelerometer and bending signals are re-sampled against that azimuth reference. Filtering and processing the accelerometer and flexion signals yield two phase angles "Фaccel" and "Фbend" in reference to the azimuth position. The BTF angle is then obtained as the difference between the two phase angles Ф: BTF = Фbend - Фaccel. (3)
    [0032] [0032] In one mode, BTF calculations are performed periodically. For example, every five seconds a new BTF update is obtained and available for uphole transmission to the gong of the total bending moment BM. Additional discussion of the BTF angle is included in Heisig et al., "Bending Tool Face Measurements While Drilling Delivers New Directional Information, Improved Directional Control", IADC / SPE 128789, February 2, 2010, the material of which is incorporated herein by reference in its wholeness.
    [0033] [0033] Since tool 34 in a hole 12 generally follows the path of hole 12, the WTF angle can be derived assuming that the BTF angle is equal to the WTF angle. In one embodiment, a mathematical model, such as the finite element model, described above is used to adjust the WTF calculation based on the offset angle between BTF and WTF that could result from small potential misalignments between tool 34 and drilling 12 .
    [0034] [0034] Based on the WTF and DLS measurements, inclination and azimuth information can be calculated based on the following relationships: a '= DLS cos (WTF) and B' = DLS sin (WTF) / sign, (4)
    [0035] [0035] where a 'and B' are the first derivatives of the slope and an azimuth angle B in relation to a measured depth.
    [0036] [0036] Slope and azimuth estimation based on WTF and DLS according to the above relationship can be shown based on the derivation of various equations, through the application of differential geometry concepts. The derivation begins with the introduction of an "R" vector that describes a centerline of a directional well as a function of an arc length "s" at the center of the drilling axis: R (s) = R! (S) li + R 2 (s) I 2 + R 3 (s) l 3 , (5)
    [0037] [0037] where the length of the arc s is the measured depth of the drilling, Ri (s) is the departure (deviation) from the North, R2 (s) is the departure from the East, Rs (s) is the true depth of the vertical (TVD), and I i , l 2 and 3 are unit vectors of a fixed structure "I" at the beginning of drilling with I 3 pointing in the direction of gravity.
    [0038] [0038] A coordinate structure "b" describing the movement along the center line or length of the arc, also known as the Frenet tryro, can be calculated. A vector of tangent drilling unit b_3, in position s is obtained as the first derivative of R ("R '(s)") in relation to the length of the arc s: b 3 (s) = R '(s) = dR / ds. (6)
    [0039] [0039] The tangent unit vector b_3 can also be expressed with an angle of inclination "α" and an azimuth angle "β" of the drilling in position s: b 3 = sin α cos β li + sin α sin β l 2 + cos α I3. (7)
    [0040] [0040] Both, α slope and azimuth β are functions of the arc length s. A vector of normal unit b_ 2 perpendicular to the axis of the drilling and in the flat curvature is obtained with: b 2 (s) = R "(s) / IR" (s) 1, (8)
    [0041] [0041] where R "(s) is the second derivative of R and IR" (s) l is the absolute value of R "(s).
    [0042] [0042] The third unit vector or binormal vector b_ 1 (s) (i.e., binormal vector) of the structure of move b, is then obtained as the product vector of b _ 2 and b 3 : b_i (s) = b 2 (s) xb 3 (s). (9)
    [0043] [0043] The Frenet formula describes the change in the coordinate system b as it moves along the axis of the perforation: B 1 '= -bƛ 2 b 2 , = + ƛb 1 -Kb3 (10) b 3 ' = + ƛxb 2 ,
    [0044] [0044] where "K" is the curvature of the well defined as: k = k (s) = IR "(S) I (11) and "ƛ" is the well torsion defined as b) = (s) ƛ = ƛ 1 R "') I K. (12)
    [0045] [0045] Using the Frenet formula in equations (10), the course of a three-dimensional well is fully described by its starting and direction coordinates and curvature parameters k (s) and torsion ƛ (s). In directional drilling practice, a k (s) curvature is known as a severity factor (DLS). The torsion ƛ (s) describes the rotation of axes b 1 - and b 2 - of structure b moving while moving along the axes of the drilling.
    [0046] [0046] With reference to Figure 4, the drilling axis can be expressed in a coordinate system "u" based on the direction of gravity, having a unit vector u 1 pointing in the direction of the high gravity side of tool 34 in a section transverse through a well at the measured depth s. A vector of unit u 3 is the tangent vector of the drilling pointing downstream and is identical to the vector of unit b 3 . The unit vector u 2 is then a vector perpendicular to u 1, pointing to the right when looking down from the well. Calculating the curvature vector R "(s) using the expression for b3 (s) = R '(s) in equation (6) and expressing the results in the new coordinate system u, yields, after some coordinate transformations, the simple expression: R "(s) = α'u 1 + β'sina u 2 , (13)
    [0047] [0047] where "α"'and"β"' are the first derivatives of the α slope and the azimuth angle β with respect to the measured depth, α 'and β' can be considered as the rate of formation of snapshots and the walking rate, respectively. With equation (11) the curvature, which can be defined as the sinuosity factor (DLS), of the well depth is then obtained as: DLS = K = ((α ') 2 + (β' sin a) 2 ) 172 . (14)
    [0048] [0048] As an equivalent to torsion ƛ in equation (12), an angle of the face of the well tool (WTF) is defined as the angle between the curvature vector and the high gravity side as illustrated in Figure 4: WTF = arctan ((β 'sina) / (α')). (15)
    [0049] [0049] α 'and β' can then be expressed in terms of the sinuosity factor DLS and WTF well tool face as follows: α '= DLS cos (WTF) and β' = DLS sin (WTF) / sign. (4)
    [0050] [0050] Equations (4) make it possible to calculate the rates of change in the slope and azimuth at a measured depth, if the slope a, DLS and angle WTF are known. Specifically for azimuth, starting from a position with known azimuth, future values of azimuth can be obtained only on the basis of inclination, sinuosity factor and face of well tool.
    [0051] [0051] Generally, some of the teachings here are reduced to an algorithm that is stored in the middle of a reading machine. The algorithm is implemented by a computer or processor as the surface processing unit 42, or the tool 34, and provides operators with desired output. For example, the electronics in tool 34 can store and process downhole data, or transmit data in real time to the surface processing unit 42 via electrical cable, or by any type of telemetry such as mud pulse telemetry or tubes connected during drilling or measurement operation while drilling (MWD).
    [0052] [0052] Figure 5 illustrates a method 60 for measuring the slope and / or azimuth of a bottom component. Method 60 includes one or more stages 61-68 described here. The method can be carried out repeatedly and / or periodically, as desired, and can be carried out for multiple depths at a selected drilling length 12. The method is described here in conjunction with the well bottom tool 34, although the method can be carried out in conjunction with any number of processor, sensor and tool configurations. The method can be performed by one or more processors, or other devices capable of receiving and processing measurement data, such as the surface processing unit 42 or electronic well-bottom units. In one embodiment, the method includes performing all stages 61-68 in the order described. However, certain stages 61-68 can be omitted, stages can be added, or the order of stages changed.
    [0053] [0053] In the first stage 61, the well bottom tool 34, the BHA 24 and / or the drilling set 20 are lowered in the drilling 12 during a drilling and / or directional drilling operation.
    [0054] [0054] In the second stage 62, an inclination angle "lnc_old" and an azimuth angle "Azi old" is determined in a starting position with a known measured depth (MD) referred to as "MD_old". The MD is a measured distance extending from the drilling surface along the drilling path to a selected location in the drilling.
    [0055] [0055] In the third stage 63, the bending moment BM at one or more second depths measured in relation to the MD_old is measured or calculated. The difference between old MD and one or more second measured depths ("MDnew") defines a measured depth range ("AMD"). In one embodiment, the BM is derived from extensometers arranged perpendicularly 36 and 38, referred to as "BM_x" and "BM_y". A single BM measurement can be taken in the depth range, or multiple BM measurements can be taken at various locations along the depth axis within the depth range to derive an average BM.
    [0056] [0056] In the fourth stage 64, in one modality, the face flexion angle (BTF) tool in MD new or an average BTF during the AMD interval is estimated or calculated based on BM measurements. For example, in the case of a drilling operation in slip mode, BTF for each set of BM, BM_x and BM_y measurements are calculated based on equation (2) described above: BTF = GTF + TF offset - arctan (BM_y / BM_x). (2)
    [0057] [0057] In another example, in the case of a drilling operation in rotary mode, the BTF for each set of measurements of BM, BM_x and BM_y, is calculated based on equation (3) described above: BTF = Фbend - Фaccel. (3)
    [0058] [0058] In the fifth stage 65, WTF and DLS are estimated based on BM and / or BTF calculations. In one embodiment, the WTF and / or the DLS is estimated based on a mathematical model as a finite element model based on the previous measurements of tool 34 and / or the perforation 12. In another embodiment, the angle of WTF is supposed to be the same as the BTF angle. In yet another embodiment, the BTF angle is adjusted based on deviations between the tool 34 and the perforation 12 to determine the WTF angle. DLS can also be estimated based on BM measurements using an appropriate model.
    [0059] [0059] In the sixth stage 66, the slope and / or azimuth in the second measured MD new depth, where MD new = MD old + AMD, are calculated based on equations (4). For example, the slope in MD new is calculated based on the following equation: lnc_new = lnc_old + AMD DLS cos (WTF), (16)
    [0060] [0060] and the azimuth in MD new is calculated based on the following equation: Azi new = Azi_old + AMD DLS sin (WTF) / sin (lnc_old). (17)
    [0061] [0061] In the seventh stage 67, stages 62-66 can be repeated for additional depths by defining additional depth intervals measured along the axis of the drilling extending from the starting depth. For example, to calculate azimuth and / or slope at a third bottom depth, equations (16) and (17) are used, where lnc_old is the new estimated slope for the second depth, Azi_old is the new estimated azimuth to the second depth. In this way, one or more azimuths and / or inclination measurements can be calculated over a selected drilling length (for example, 1-10 feet) extending from the starting depth. In one embodiment, the azimuth and / or slope measurements at each interval or depth are integrated to yield a azimuth and / or slope value for a selected tool length 34.
    [0062] [0062] In the eighth stage 68, the slope and / or azimuth data are provided for a user and can be used to record and / or monitor the tool 34 and / or drilling or other downhole operations. In one embodiment, the data is stored in the tool 34 and / or transmitted to a processor such as the surface processing unit 42, and can be retrieved from it and / or displayed for analysis. As used here, a "user" can include a drilling or profiling column operator, a processing unit and / or any other entity selected to retrieve the data and / or controlling the drilling column 11 or other system for lowering tools inside the perforation. The user can take any appropriate action based on the inclination and / or azimuth data to, for example, change the direction course or drilling parameters.
    [0063] [0063] An example of a BTF calculation is shown in Figures 6-9. A non-rotating directional probe 80 shown in Figures 6 and 7 includes an alignment mark 82 and a reader port 84. Alignment mark 82 provides a reference for use in determining angular locations of BM measuring devices on probe 80 or others drilling components. Probe 80 includes a x-86 bending moment sensor (BMx sensor) and a perpendicular y-bending moment sensor 88 (BMy sensor). The BMx sensor has an angular position shown by marking 90 on the probe body.
    [0064] [0064] In this example, before measuring the BTF, a displacement of the BMx sensor is determined. The offset is the angle between the BMx sensor 86 and the alignment mark 82 relative to a longitudinal axis 92 of the probe 80. For example, the offset is determined by measuring the angle clockwise from a perspective looking at the rock bottom.
    [0065] [0065] The offset is determined and entered into a processing program shown by the spreadsheet in Figure 9. In this example, the offset is determined to be 135 degrees, which is entered in the spreadsheet. For each depth, the time, the measured depth, bending moment of the x- axis (DBMXAX), bending moment of the y- axis (DBMYAX) and the face of the high side tool (HTFX) are entered in the program automatically calculates the BTF of probe 80 at the depth measured based on equation (2). In the example shown in Figure 9, the DBMXAX entered is 5000 ft-lbs, the DBMYAX entered is -3000 ft-lbs, the HTFX is 87 degrees, and the calculated BTF is approximately -107 degrees, which indicates a left flexion with a slight tendency to bend.
    [0066] [0066] New data of the moment of flexion can be periodically (for example, every 5 minutes) entered in the processing program, as entering the data in a new row in the spreadsheet. The program can then automatically calculate the BTF for data entered for each measured depth. BTF data can be used for a variety of purposes, such as monitoring the tool face of downhole components. For example, for a drilling set that includes a deflection wedge liner, calculated BTF values that are similar to the deflection wedge tool angle can be used to verify that the deflection wedge is oriented as expected. If the calculated BTF values were due to the expected angles, the orientation of the deviation wedge may have deviated from what was expected.
    [0067] [0067] The systems and methods described here provide several advantages over the prior art techniques. For example, systems and methods allow accurate calculation of discrete local changes in the slope and azimuth of the downhole tools. This can result in more accurate directional drilling operations, improved modeling resulting in a reduction of the uncertainty ellipsoids. In addition, magnetometers are not required at least in the non-rotating systems described here, allowing tools to be made of additional materials such as standard steel, and enabling obtaining good quality azimuth data in situations with magnetic interference.
    [0068] [0068] In support of the teachings here, several analyzes and / or analytical components can be used, including digital and / or analog systems. The system can have components such as a processor, storage medium, memory, input, output, communications link (wired, wireless, pulsed mud, optical or others), user interfaces, software programs, signal processors (digital or analog) and other components (such as resistors, capacitors, inductors and others) to provide operation and analysis of the devices and methods described here in any of the several ways well perceived in the art. It is considered that these teachings can be, but need not be, implemented in conjunction with a set of executable instructions per computer stored in a computer reading medium, including memory (ROMs, RAMs), optics (CD-ROMs), or magnetic (disks, hard drives), or any other type that, when executed, make a computer implement the method of the present invention. These instructions may provide equipment operation, control, and data collection and analysis and other functions deemed relevant by a system designer, owner, user and other such person, in addition to the functions described in that description.
    [0069] [0069] Still, several other components can be included and called upon to provide aspects of the teachings here. For example, a sample line, sample storage, sample chamber, sample exhaust, pump, piston, power supply (for example, at least one from a generator, a remote supply and a battery), vacuum supply, pressure supply, cooling unit or supply (ie cooling), heating component, motive force (such as a translational force, propelling force or a rotational force), magnet, electromagnet, sensor, electrode, transmitter, receiver, transceiver , controller, optical drive, electrical drive or electromechanical drive can be included in support of several aspects discussed here or in support of functions other than this description.
    [0070] [0070] The person skilled in the art will recognize that the various components or technologies may provide certain necessary or beneficial functionalities or characteristics. Therefore, these functions and features, as may be necessary in support of the appended claims and variations thereof, are recognized as being inherently included as a part of the teachings here and a part of the described invention.
    [0071] [0071] Although the invention has been described with reference to exemplary modalities, it will be understood by those skilled in the art that various changes can be made and equivalents can be replaced by elements thereof without departing from the scope of the invention. In addition, many modifications will be perceived by those skilled in the art to adapt to a particular instrument, situation or material for the teachings of the invention without departing from its essential scope. In this way, it is intended that this invention is not limited to the particular modality described as the best way considered to carry out this invention, but that the invention will include all modalities included in the scope of the appended claims.
    权利要求:
    Claims (22)
    [0001]
    System for measuring directional characteristics of a downhole tool (34), the system characterized by the fact that it comprises: at least one measuring device (36, 38) of the bending moment (BM) disposed in a downhole component that is configured to be mobile within a bore (12), the at least one measuring device (36, 38) BM configured to generate bending moment data, bending moment data including a borehole tool bending vector (34), a bending moment representing an amplitude of the bending vector, and an angle of the face of the flexion tool (34) representing a flexion vector orientation relative to a high gravity side, the estimated BTF using a first calculation based on the bottom component of the well being in a slip mode, the estimated BTF using a second calculation based on the downhole component being in a rotating mode; and a processor (42) in operational communication with the measuring device (36, 38) BM and configured to receive bending moment data from the measuring device (36, 38) BM at a single selected depth, calculating a factor of sinuosity (DLS) of the bending moment measured only at a single selected depth and a tool surface angle (34) of the well (WTF) from the BTF angle, and calculating a change in the slope at the selected depth based on the DLS and the WTF angle.
    [0002]
    System according to claim 1, characterized by the fact that the processor (42) is configured to calculate the change in slope using the following equation: α '= DLS cos (WTF), where a 'is a first derivative of a slope angle a at a measured depth.
    [0003]
    System according to claim 1, characterized by the fact that the processor (42) is additionally configured to calculate a change in azimuth based on the bending moment data.
    [0004]
    System according to claim 1, characterized by the fact that the change in inclination is calculated in relation to the known inclination angle "lnc_old" at a known measurement depth "MD old" and the change in azimuth is calculated in relation to a known azimuth "Azi_old" on the old MD, and calculate a slope "lnc_new" at a second depth measured "MD new" based on the following equation: lnc_new = lnc_old + AMD DLS cos (WTF), where "AMD" is a difference between MD new and MD old.
    [0005]
    System according to claim 4, characterized by the fact that calculating the azimuth change includes calculating an azimuth "Azi_new" at a second depth measured "MD new" based on the following equation: Azi_new = Azi_old + AMD DLS sin (WTF) / sin (lnc_old), where "AMD" is a difference between MD new and MD old.
    [0006]
    System, according to claim 3, characterized by the fact that the processor (42) is configured to calculate the azimuth change using the following equation: β '= DLS sin (WTF) / sin α, where β 'is a first derivative of azimuth angle β at a measured depth, and α is a slope angle at a measured depth.
    [0007]
    System according to claim 1, characterized by the fact that at least one depth is different from a starting depth associated with at least one of a known slope and a known azimuth, and the BTF angle is calculated based on the bending moment in the absence of any azimuth or slope measurements at least one depth.
    [0008]
    System according to claim 7, characterized in that the at least one BM measuring device (36, 38) comprises a first extensometer configured to generate a first flexion moment "BM_x", a second extensometer oriented orthogonally to the first extensometer and configured to generate a second flexion moment "BM_y", the first and second extensometers having an angular location around a longitudinal axis of the tool (34) relative to a reference location, the reference location indicative of the orientation rotational tool (34), and the processor (42) is configured to calculate the BTF angle based on an angle of deviation between the angular location and the reference location.
    [0009]
    System, according to claim 1, characterized by the fact that the first calculation is based on the following equation: BTF = GTF + TF offset - arctan (BM_y / BM_x), where “BM_x” is a first flexion moment derived from a first extensometer and "BM_y" is a second flexion moment derived from a second extensometer oriented orthogonally to the first extensometer, "TF_deslocado" is the displacement angle between the coordinate system of a directional sensor and coordinate system for the first and second extensometers, and "GTF" is a rotational orientation of the downhole component.
    [0010]
    System, according to claim 1, characterized by the fact that the second calculation is based on the following equation: BTF = Фbend - Фaccel where “Фaccel” is a first phase angle relative to an azimuth reference, the first phase angle being estimated based on the acceleration measurements, “Фbend” is a phase angle relative to an azimuth reference, the second phase angle being estimated based on flexion measurements.
    [0011]
    System according to claim 1, characterized by the fact that the processor (42) is configured to calculate an instantaneous measurement of the snapshot formation rate and the walking rate based on the DLS and WTF angles calculated from the data of bending moment measured at only a selected depth.
    [0012]
    Method of measuring directional characteristics of a downhole tool (34), the method characterized by the fact that it comprises: arranging a downhole component in a borehole (12) in an earth formation, the downhole component operably coupled to at least one bending moment measurement device (36, 38); generate bending moment data through at least one BM measuring device (36, 38), bending moment data including a borehole tool bending vector (34), a bending moment representing an amplitude of the bending vector, and an angle of the bending tool face (BTF) representing a bending vector orientation relative to a high gravity side, the estimated BTF using a first calculation based on the bottom component of the well being at a slip mode, the estimated BTF using a second calculation based on the downhole component being in a rotating mode; receiving bending moment data from the BM measuring device (36, 38) at a single depth selected on a processor (42); calculate a sinuosity factor (DLS) from the moment of bending only at a single selected depth and a tool face angle (34) from the well (WTF) from the BTF angle; and calculate a change in slope at a selected depth based on the DLS and the WTF angle.
    [0013]
    Method, according to claim 12, characterized by the fact that the change in slope is calculated using the following equation: α '= DLS cos (WTF), where a 'is a first derivative at a slope angle a at a measured depth.
    [0014]
    Method, according to claim 12, characterized by the fact that it also comprises calculating a change in azimuth at the selected depth based on the data of the flexion moment.
    [0015]
    Method according to claim 14, characterized in that the change in inclination is calculated in relation to the known inclination angle "lnc_old" at a known measurement depth "MD_old" and the change in azimuth is calculated in relation to a known azimuth "Azi_old" in MD_old, and calculate a slope "lnc_new" at a second measured depth "MD new" based on the following equation: lnc_new = lnc_old + AMD DLS cos (WTF), where "AMD" is a difference between MD new and MD_old.
    [0016]
    Method according to claim 15, characterized by the fact that calculating the azimuth change includes calculating an azimuth "Azi new" at a second depth measured "MD new" based on the following equation: Azi_new = Azi_old + AMD DLS sin (WTF) / sin (lnc_old), where "AMD" is a difference between MD new and MD_old.
    [0017]
    Method, according to claim 14, characterized by the fact that the change in azimuth is calculated using the following equation: β '= DLS sin (WTF) / sinα, where β 'is a first derivative of azimuth angle β at an average depth, and α is an angle of inclination at the measured depth.
    [0018]
    Method according to claim 12, characterized by the fact that at least one depth is different from a starting depth associated with at least one of a known slope and a known azimuth, and the BTF angle is calculated based on the bending moment in the absence of any azimuth or slope measurements at least one depth.
    [0019]
    Method according to claim 12, characterized by the fact that the angle WTF is calculated from the angle BTF based on an angular deviation between the angle WTF and the angle BTF, the angular deviation based on a mathematical model of the hole well.
    [0020]
    Method, according to claim 12, characterized by the fact that the DLS is calculated based on a total bending moment, and the total bending moment is calculated as a sum of vectors based on the following equation: Total BM = ((BM_x) 2 + (BM_y) 2 ) 1/2 , where "BM Total" is the total flexion moment, "BM_x" is a first flexion moment derived from a first extensometer and "BM_y" is a second flexion moment derived from a second extensometer oriented orthogonally to the first extensometer.
    [0021]
    Method according to claim 14, characterized by the fact that the processor (42) is configured to calculate an instantaneous measurement of the snapshot formation rate and the walking rate based on the DLS and WTF angles calculated from the data of bending moment measured only at a selected depth.
    [0022]
    Method according to claim 12, characterized in that the at least one BM measuring device (36, 38) comprises a first extensometer configured to generate a first flexion moment "BM_x", a second extensometer oriented orthogonally to the first extensometer and configured to generate a second flexion moment "BM_y", the first and the second extensometer having an angular location around a longitudinal axis of the tool (34) relative to a reference location, the reference location indicative of the orientation tool rotation (34), and the BTF angle is calculated based on an angle of deviation between the angular location and the reference location.
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    同族专利:
    公开号 | 公开日
    US9200510B2|2015-12-01|
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    GB2496786A|2013-05-22|
    US20120046865A1|2012-02-23|
    WO2012024474A2|2012-02-23|
    GB201301521D0|2013-03-13|
    GB2496786B|2018-09-19|
    NO345240B1|2020-11-16|
    NO20130118A1|2013-01-30|
    WO2012024474A3|2012-04-26|
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    法律状态:
    2018-12-26| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2019-07-30| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|
    2020-04-28| B09A| Decision: intention to grant|
    2020-06-30| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 18/08/2011, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US37479510P| true| 2010-08-18|2010-08-18|
    US61/374,795|2010-08-18|
    PCT/US2011/048211|WO2012024474A2|2010-08-18|2011-08-18|System and method for estimating directional characteristics based on bending moment measurements|
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