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    • 专利摘要:
    calculation of well cards in deviated wells the diagnosis of a pump apparatus having a well pump below arranged in a deviated well bore characterizes an axial and transversal displacement of a stem column with two fourth order coupled nonlinear differential equations which include axial and transversal equations of motion. for solving the equations, derivatives are replaced by finite difference analogs. an initial axial displacement of the stem column is calculated assuming that there is no transverse displacement and solving the axial equation. an initial axial force is calculated using the initial axial displacement and assuming that there is no transverse displacement. an initial transverse displacement is calculated using the initial axial force and the initial axial displacement. the axial force and the frictional force are calculated using the initial displacements, and the axial displacement at the well pump below is calculated by solving the axial equation with the axial force and the frictional force. the load on the well pump below is calculated so that a well plate below can be generated.
    公开号:BR112014010219B1
    申请号:R112014010219-8
    申请日:2012-10-29
    公开日:2020-12-15
    发明作者:Victoria M. Pons
    申请人:Weatherford Technology Holdings, Llc；
    IPC主号:
    专利说明:

    CROSS REFERENCE TO RELATED ORDERS
    [0001] This application claims the benefit of US Patent Application Serial No. 61 / 552,812 entitled “Modified Everitt-Jennings With Dual Iteration on the Damping Factors and Adaptation to Deviated Wells by Including Coulombs Friction” and filed on October 28, 2011; Serial No. 61 / 598,438 entitled “Modified Everitt-Jennings With Dual Iteration on the Damping Factors” and filed on February 14, 2012; Serial No. 61 / 605,325 entitled “Implementing Coulombs Friction for the Calculation of Downhole Cards in Deviated Wells” and filed on March 1, 2012; and Serial No. 61 / 706,489 entitled “Iterating on Damping when Solving the Wave Equation and Computation of Fluid Load Lines and Concavity Testing” and filed on September 27, 2012, each of which is incorporated herein as a reference in its entirety. This order is also filed concurrently with the copending orders __ / (205-0322US1) entitled “Fluid Load Line Calculation and Concavity Test for Downhole Pump Card”, / (205-0322US2) entitled “Calculating Downhole Pump Card With Iterations on Single Damping Factor ”, And / (205-0322US3) entitled“ Calculating Downhole Pump Card With Iterations on Dual Damping Factors ”, each of which is incorporated herein by reference. BACKGROUND OF THE EXHIBITION A. Pumping Rod Pump System
    [0002] Alternative pump systems, such as pumping rod pump systems, draw fluids from a well and employ a well pump below connected to a surface drive source. A stem column connects the surface drive force to the well pump below in the well. When operated, the drive source raises and lowers the well pump below, and with each stroke, the well pump below raises the well fluids towards the surface.
    [0003] For example, figure 1 shows a pump rod pump system 10 used for the production of fluid from a well. A well pump below 14 has a cylinder 16 with a foot valve 24 located at the bottom. Foot valve 24 allows fluid to enter from the well bore, but does not allow fluid to escape. Within the pump cylinder 16, a plunger 20 has a movable valve 22 located at the top. The movable valve 22 allows the fluid to move from under the plunger 20 to the production line 18 above, but does not allow the fluid to return from the line 18 to the pump cylinder 16 below the plunger 20. A source actuator (for example, a boom pump 11) on the surface connects by means of a rod column 12 to the plunger 20 and the plunger 20paracimae downwards in cyclic form in upward and downward strokes.
    [0004] During the cursoparacima, the movable valve22 is closed, and any fluid above the plunger 20 in the production tube 18 is raised towards the surface. Meanwhile, foot valve 24 opens and allows fluid to enter pump cylinder 16 from the well bore. The highest point of piston movement is typically referred to as the “top of stroke” (TOS), while the lowest point of pump piston movement is typically referred to as the “bottom of stroke” (BOS).
    [0005] In the TOS, the foot valve 24 closes and maintains the fluid that entered the pump cylinder 16. Additionally, in the TOS, the weight of the fluid in the production pipe 18 is supported by the movable valve 22 in the piston 20 and, therefore, also through the stem column 12, which causes the stem column 12 to stretch.
    [0006] During the downward stroke, the movable valve 22 initially remains closed until the plunger 20 reaches the fluid surface in the cylinder 16. A sufficient pressure builds up in the fluid below the movable valve 22 to balance the pressure. The accumulation of pressure in the pump cylinder 16 reduces the load on the stem column 12, so that the stem column 12 relaxes.
    [0007] This process occurs for a finite amount of time, when the plunger 20 rests on the fluid, and the rocker pump 11 on the surface allows the top of the stem column 12 to move downwards. The position of the pump plunger 20 at this point is known as the “transfer point”, because the load from the fluid column in the production line 18 is transferred from the movable valve 22 to the foot valve 24. This results in a rapid decrease in load on stem column 12 during transfer.
    [0008] After the pressure is balanced, the movable valve 22 opens and the plunger 20 continues to move downward to its lowest position (i.e., the BOS). The movement of the plunger 20 from the point of transfer to the BOS is known as the "fluid stroke", and is a measure of the amount of fluid raised by the pump 14 in each stroke. In other words, the portion of the pump stroke below the transfer point can be interpreted as the percentage of the pump stroke containing a fluid, and this percentage corresponds to the pump fill. Thus, the transfer point can be computed using a pump fill calculation.
    [0009] If there is sufficient fluid in the well bore, the pump cylinder 16 can be completely filled during an upward stroke. Also, under some conditions, pump 14 may not be completely filled with fluid in the upward stroke, so that there may be a void left between the fluid and plunger 20 as it continues to rise. The operation of the pump system 10 with only a partially filled pump cylinder 16 is inefficient and therefore undesirable. In this case, the well is said to have the “pump off”, and the condition is known as “puddling”, which can damage various components of the pump system. For a well with pump off, the transfer point most likely occurs after the TOS of the plunger 20.
    [0010] Typically, there are no sensors for measuring conditions in the well pump below 14, which can be located thousands of feet (1 foot = 0.3048 m) below the ground. Instead, numerical methods are used to calculate the position of the pump plunger 20 and the load acting on the plunger 20 from measurements of the position and the load for the stem column 12 on the rocker pump 11 located on the surface. These measurements are typically made at the top of the polished stem 28, which is a portion of the stem column 12 passing through a gasket 13 at the wellhead. A pump controller 26 is used for the monitoring and control of the pump system 10.
    [0011] To control the alternate pump system 10 and avoid costly maintenance, a stem pump controller 26 can accumulate system data and adjust the operating parameters of system 10 accordingly. Typically, the stem pump controller 26 accumulates stem column displacement and system data by measuring these properties on the surface. Although these data measured on the surface provide useful diagnostic information, they do not provide an accurate representation of the same properties observed below the pump well. Because these well properties below cannot be easily measured directly, they are typically calculated from the properties measured on the surface.
    [0012] The methods for determining the operational characteristics of the well pump below 20 used the format of the graphical representation of the well data below for the computation of various details. For example, US Patent No. 5,252,031 to Gibbs, entitled “Monitoring and Pump-Off Control with Downhole Pump Cards”, teaches a method for monitoring a shaft pumped well to detect various pump problems by using of measurements made on the surface to generate a well pump plate below. The well pump plate shown below can then be used for detecting the various pump problems and controlling the pumping unit. Other techniques for determining operational characteristics are set out in U.S. Patent Publications No. 2011/0091332 and 2011/0091335, both of which are incorporated herein by reference in their entirety. B. Everitt-Jennings method
    [0013] In techniques for determining the operational characteristics of a pumping rod 10 pump system, as mentioned above, a software analysis computes well data below (ie, a pump plate) using position and load data measured on the surface. The most accurate and popular of these methods is to compute the downhole plate from the surface data by solving a one-dimensional damped wave equation, which uses the position and surface charge, as recorded on the surface.
    [0014] There are several algorithms for solving the wave equation. Snyder solved the wave equation using a characteristic method. See Snyder, WE, “A Method for Computing Down-Hole Forces and Displacements in Oil Wells Pumped With Sucker Rods”, Paper 851-37-K, 1963. Gibbs employed separation of variables and a Fourier series in what can be termed the “Gibbs method”. See Gibbs, S. G. et al., "Computer Diagnosis of Down-Hole Conditions in Sucker Rod Pumping Wells", JPT (Jan. 1996) 91-98; Trans., AIME, 237; Gibbs, S. G., “A Review of Methods for Design and Analysis of Rod Pumping Installations”, SPE 9980, 1982; and U.S. Patent No. 3,343,409.
    [0015] In 1969, Knapp introduced finite differences for solving the wave equation. See Knapp, R. M., “A Dynamic Investigation of Sucker-Rod Pumping”, master's thesis, U. of Kansas, Topeka (Jan. 1969). This is also the method used by Everitt and Jennings. See Everitt, T. A. and Jennings, J. W., “An Improved Finite-Difference Calculation of Downhole Dynamometer Cards for Sucker-Rod Pumps”, SPE 18189, 1992; and Pons-Ehimeakhe, V., “Modified Everitt-Jennings Algorithm With Dual Iteration on the Damping Factors”, 2012 SouthWestern Petroleum Short Course. The Everitt-Jennings method was also implemented and modified by Weatherford International. see Ehimeakhe, V., “Comparative Study of Downhole Cards Using Modified Everitt-Jennings Method and Gibbs Method”, Southwestern Petroleum Short Course 2010.
    [0016] For solving the one-dimensional wave equation, the Everitt-Jennings method uses finite differences. The stem column is divided into M nodes of finite differences in length L [(ft), specific weight pt (lbm / ft3) and area A ^ (in2). If we make u - u (x, t) to be the displacement of the position x at time t in a pumping rod pump system, the condensed one-dimensional wave equation will be read as:

    [0017] in which the acoustic speed is given by:
    D represents a damping factor.
    [0018] The first and second derivatives with respect to time are replaced by the correct forward differences of the first order and the correct central differences of the second order. The second derivative with respect to the position is replaced by a correct second order slightly rearranged central difference.
    [0019] In the method, the damping factor D is automatically selected by using an iteration in the net course of the system (NS) and the damping factor D. The damping factor D can be computed by the equation:
    D = (550) (144g) (HPR-HH) T2 (2)
    [0020] where HPR is the mechanical power of the polished rod (hp), S is the liquid stroke (in), T is the period of a stroke (s), and HHYD is the hydraulic power (hp) obtained as follows : HHYD = (7.36 • 10-6) QyFz (3) where Q is the pump production rate (B / D), y is the specific gravity of fluid, and Ft is the fluid level (ft). The pump production rate is given by: Q = (0.1166) (SFM) Sd2 where SPM is the speed of the pumping unit in strokes / minute, and d is the piston diameter.
    [0021] Additional details of the derivation of the damping factor D in equation (2) and the original iteration in the net stroke and the damping factor algorithm are provided in Everitt, TA and Jennings, JW, “An Improved Finite-Difference Calculation of Downhole Dynamometer Cards for Sucker-Rod Pumps ”, SPE 18189, 1992.
    [0022] A modified Everitt-Jennings method also uses finite differences for solving the wave equation. As before, the stem column is discretized into M elements of finite differences, and position and load (including tension) are computed in each increment down the well hole. Then, as shown in figure 2, an iteration is performed on the net stroke and the damping factor, which automatically selects a damping factor for each stroke.
    [0023] The wave equation is initially solved to calculate the downhole plate using surface measurements and an initial damping factor D set to 0.5 (Block 42). The initial net stroke S0 is determined from the computed plate, and the fluid level in the well is calculated (Block 44). At this point, a new damping factor D is calculated from equation (2) (Block 46) and so on, and the downhole plate is computed again with the new damping factor D (Block 48). Based on the recalculated well plate below, a new liquid stroke S is determined (Block 50).
    [0024] At this point, then, a check is made to determine if the newly determined net course S is close to some tolerance £ of the initial or previous net course (Decision 52). If not, then another iteration is necessary, and process 40 returns to the calculation of the damping factor D (Block 46). If the newly determined net course is close to the previously determined net course (yes in Decision 52), then the iteration for determining the net course can stop, and process 40 remains active to iterate over the damping factor D using the converged net course S (Block 54). The well data below is then calculated using the newly calculated damping factor D (Block 56), and the mechanical power of the HPump pump is then calculated (Block 58).
    [0025] At this point, a check is made to see if the mechanical power of the Hpump pump is close to the same tolerance as the hydraulic power Hhyd (Decision 60). If so, then process 40 will end as a successful calculation of the well pump plate below with converged liquid stroke and damping factor D (Block 62). If the mechanical power of the Hpump pump and the hydraulic power Hhyd are not close enough (not in Decision 60), then process 40 will adjust the current damping factor D by a ratio of the mechanical power of the HPump pump and the hydraulic power HHyd ( Block 64). The process 40 of calculating a pump plate with its adjusted damping factor D is repeated until the values for the mechanical pump and hydraulic power HPump and HHyd are close to the specified tolerance (Blocks 56 to 64).
    [0026] The advantage of automatic iteration in the liquid course and in the damping factor D, as established above, is that the damping factor D is adjusted automatically, without human intervention. Thus, users managing a medium group to a large group of wells do not have to spend time manually adjusting the damping factor D, as may be required by other methods. C. Bypass Well Model
    [0027] As mentioned above, most of the methods currently used for computing downhole data using position and surface load, as recorded by a surface dynamometer system, are based on a vertical hole model that does not take into account deviation from the well. For example, figure 3A schematically shows a vertical model 30 of the vertical well 18 having a stem column 28 arranged there. With the well model 30 being vertical, the only relevant frictional forces are viscous in nature. Viscous friction Fv is the result of viscous forces that arise in the annular space during a pumping cycle, which are proportional to the speed of axial displacement u.
    [0028] However, when dealing with a deviated well, as shown in a deviated model 32 shown somewhat exaggerated in figure 3B, a mechanical friction Fm arises from the contact between the pipe 18, the stem column 28, and the couplings 29. Even when those forces Fm can be ignored, when the well is almost vertical, they have to be accounted for, when the well is diverted. If the algorithm used for computing the well data below does not take into account the mechanical friction For a deviated well, the resulting well plate below may appear distorted. This condition cannot be helped by changing the viscous damping factor D in the wave equation.
    [0029] Thus, the vertical model is not well suited for the calculation of well data below, when the pump rod pump system is used in a deviated well. Primarily, the dynamic behavior of stem column 28 is different for wells deviated from vertical wells. In fact, in vertical wells, stem column 28 is assumed not to move laterally. In deviated wells, however, the mechanical friction Fm becomes not negligible, because there is extensive contact between the stem column 28, the couplings 29, and the pipe 18. Also, once the well is deflected, some sections of the column of stem 28 can be flexed between the two couplings 29 in the middle of the dog leg curve, which introduces the concept of curvature of the stem column 28 in the same way.
    [0030] The equations discussed above for the wave equation only consider frictional forces of a viscous nature in the vertical model, yet the frictional forces in particular for deviated wells are of a viscous and mechanical nature, as detailed above. Although Fm mechanical friction has generally been ignored, it has been considered ever since. For example, to deal with Coulombs friction that results from mechanical friction in a deviated well, the most well-known technique was exposed by Gibbs and Lukasiewicz. See Gibbs, S. G., "Design and Diagnosis of Deviated Rod-Pumped Wells", SPE Annual Technical Conference and Exhibition, October 6 - 9, 1991; and Lukasiewicz, S. A., "Dynamic Behavior of the Sucker Rod String in the Inclined Well", Production Operations Symposium, April 7-9, 1991, both of which are incorporated by reference here.
    [0031] To deal with mechanical friction in deviated wells, Gibbs modified the wave equation by adding Coulombs' friction term to it. For example, U.S. Patent Publication No. 2010/0111716 to Gibbs et al. includes a C (x) term in the wave equation that represents the rod and pipe drag force. In contrast, Lukasiewicz derived equations for axial and transverse displacement of the stem element, creating a system of coupled differential equations. D. Equations for Axial and Transverse Displacement of Rod Element
    [0032] As recognized in Lukasiewicz, a stem column in a deflected well moves longitudinally up and down (that is, axially) and also moves laterally (that is, transversely). Thus, the behavior of axial stress waves, as well as transverse stress waves, can be analyzed to better characterize the behavior of stem column 28 in the deviated well.
    [0033] For this purpose, figure 4 shows a diagram of dynamic behavior of a rod element 34 of a pumping rod pump system for a bypassed well model 32. This diagram shows the various forces acting on the rod 34 in axial and transverse directions. As shown here, u (s, t) is the axial displacement of the stem element 34 of length ds, and v (s, t) is the transverse displacement of the stem element 34. The radius of curvature R (f) can be calculated along with the Cartesian coordinates of the well bore path, using a deviation search. Several methods are available for these calculations, such as a minimum curvature method or a radius of curvature method, as explained in Gibbs, SG, “Design and Diagnosis of Deviated Rod-Pumped Wells”, SPE Annual Technical Conference and Exhibition, 6 on October 9, 1991, which is incorporated here by reference.
    [0034] In the diagram of the forces acting on the stem element 34, the radius of curvature R ^ is displayed as an arrow going from the center of the curvature to the stem element 34 of length ds. The denoted axial force F acts up and down on the stem element 34. The axial force, therefore, has an axial component as well as a transverse component. Coulombs Ft's frictional force opposes the movement of the stem element 34 at the point of contact between the stem element 34 and the pipe 18. The weight W is shown as the gravitational force pulling the stem element 34 down. normal force N acts perpendicularly on the stem element 34 facing the center of curvature. Both the weight W and the normal force N have axial and transverse components in the same way.
    [0035] Thus, the axial direction (that is, the tangential direction to the rod) can be characterized with the following axial equation of motion:

    [0036] Here, F is the axial force on the stem, u (t) is the axial displacement, A is the cross-sectional area of the stem, Y is the specific weight, g is the acceleration of gravity, θ is the angle of inclination , D is the viscous damping coefficient, Ft is the frictional force from the pipe 18, s is the length measured along the curved rod, and t is the time.
    [0037] As mentioned above, the force Ft is the frictional force of Coulombs, which is a non-linear force that tends to oppose the movement of bodies in a mechanical system. Coulombs friction is representative of dry friction, which resists a relative lateral movement of two solid surfaces in contact. The relative movement of the stem column 28, tubing 18 and couplings 28, as seen in figure 1, pressing against each other is a source of energy dissipation when the well is pumping.
    [0038] In the transversal direction, the transversal equation of motion can be characterized as:

    [0039] Here, EI is the flexural stiffness, E is the Young modulus of elasticity, / is the flexural moment, Dt is the viscous damping factor in the transverse direction, nt is the normal transverse force from the pipe 18 , an np is the normal transverse force from the liquid under pressure p, and - is a real radius of curvature given by


    [0040] As demonstrated by Lukasiewicz, axial force can be introduced in the axial equation of motion (1) to provide:

    [0041] Here, a is the acoustic velocity of the stem element 34. Furthermore, when assuming that the stem element 34 is in the pipe 18 between the couplings 29, the axial motion equation (1) can be written as:

    [0042] Additional details on these equations and axial force are set out in Lukasiewicz, SA, “Dynamic Behavior of the Sucker Rod String in the Inclined Well”, Production Operations Symposium, April 7-9, 1991, which has been incorporated here as a reference.
    [0043] As can be seen, the axial motion equation (3) uses the surface position of the stem column to calculate the down well position for each node of finite differences down through the well hole, to the node just above the well pump below. The axial and transverse equations of motion (3) and (2) are combined to form a system of two fourth order coupled nonlinear differential equations.
    [0044] It is important to note that Coulombs friction (that is, the mechanical friction that arises from a contact between the rods 28, the tubing 18 and the couplings 29) can be consequent in a deviated well and cannot be simulated using if viscous damping. In particular, Coulombs' frictional forces are not proportional to the vector velocity of the rod element as are the viscous frictional forces. In some cases, the viscous damping factor may be increased to remove extra friction, but the friction below the well due to the mechanical part cannot be removed. If the viscous damping is pushed too far, the effects of mechanical friction may appear to have been removed, but in reality, the well data below no longer represents what is happening at the well pump below.
    [0045] In equation (2), the second term is non-linear and represents the effect of vertical deflection on axial displacement. It is noted that the equations given above are the same equations presented by Lukasiewicz, and that the model developed by Gibbs ignores the transverse movement of the stem column 28.
    [0046] Being able to treat mechanical friction when dealing with deviated wells is a constant concern in the industry. Users often try to remedy friction from the well below in a well plate below by modifying the viscous damping factor or by adding a drag force term (as done by Gibbs). Yet, this can essentially distort the results for the well below and can hide well conditions below.
    [0047] Although the previous technique (and especially Lukasiewicz) characterized the equations for movement of a stem column in a deviated well, practical techniques for performing the calculations are necessary. This is especially true when calculations are performed by a pump controller or other processing device, which may have limited processing capabilities. BRIEF DESCRIPTION OF THE DRAWINGS
    [0048] Figure 1 illustrates a pump rod pump system with a controller for controlling the pump system.
    [0049] Figure 2 illustrates an iteration in a net stroke and damping factor for the modified Everitt-Jennings algorithm for computing a pump plate according to the prior art.
    [0050] Figure 3A shows a diagram of a vertical well model.
    [0051] Figure 3B shows a diagram of a deviated well model.
    [0052] Figure 4 shows a diagram of the dynamic behavior of a rod element of a pumping rod pump system for a deviated well.
    [0053] Figure 5 illustrates a flowchart of a process for calculating well data below for a pump rod pump system in a bypassed well.
    [0054] Figure 6A illustrates a pump controller according to the present exhibit for a pumping rod pump system.
    [0055] Figure 6B illustrates a diagram of the pump controller for control / diagnosis of the pumping rod pump system according to the present exhibition. DETAILED DESCRIPTION OF THE EXHIBITION
    [0056] According to the present exhibition, the modified Everitt-Jennings algorithm is used for computing downhole data by solving the one-dimensional damped wave equation with finite differences. The one-dimensional damped wave equation, however, only takes take into account friction of a viscous nature and ignores any type of mechanical friction. If the well is substantially vertical, the mechanical friction will be negligible, and the well data obtained below may be accurate. However, in deviated or horizontal wells, the mechanical friction between the rods, the couplings and the piping needs to be considered. According to this exposition, the modified Everitt-Jennings method is adapted for the use of finite differences to incorporate the mechanical friction factors in the calculation of downhole data in deviated or horizontal wells.
    [0057] To do this, the teachings of the present exhibition use a finite difference approach for the treatment of a system of two coupled nonlinear differential equations, which involves the forces acting on a rod element in a deviated well. Axial displacement and transverse displacement of the stem element are considered, providing a complete model for analyzing well conditions below. As such, the teachings of the present exhibition use the equations as derived by Lukasiewicz, which was previously described and incorporated here as a reference. The equations of axial and transverse motion for the stem element were mentioned in the background section of the present exhibition.
    [0058] Referring now to figure 5, a process 100 is illustrated in the form of a flow chart for solving the system of coupled differential equations for axial and transverse displacement of a stem element in a deviated well. For the derivatives that appear in the previous equations (2), (3), and (4), Taylor series approximations are used for the generation of finite difference analogs (Block 102). For the first and second derivatives, a difference correct first order center and a correct second order center difference are used, respectively. For more details on the derivation of the second derivative analog with respect to displacement, see Everitt, TA and Jennings, JW: “An Improved Finite-Difference Calculation of Downhole Dynamometer Cards for Sucker-Rod Pumps”, SPE 18189, 1988, which is incorporated here as a reference.
    [0059] In particular, the finite difference analogs are as follows (subscript i represents the node at an axial distance from the stem column and subscript j represents the time interval). For space discretization, the finite difference analogs are:

    [0060] For time discretization, the finite difference analogs are:

    [0061] The analogues for derivatives with respect to time are straightforward. However, derivatives with respect to space of a degree greater than one preferably have finite difference analogs divided into several equations, to accommodate the different tapering properties of stem column 28. The division of finite difference analogs into several equations primarily allow you to capture a change in length Δs of the curved stem, so that the values for position, load and tension can be calculated in chosen increments down the well hole, as opposed to having to interpolate between fixed points. This option allows a user more freedom to refine discretization to optimize stress analysis.
    [0062] To deal with the fourth order derivative with respect to displacement, a second order central finite difference scheme is used:

    [0063] To run a diagnostic model of a deviated well based on surface measurements and calculate a well pump plate below, the equations of transverse and axial movement (2) and (3) must be solved simultaneously. The teachings in the present exhibition provide a solution for the model for a deviated well, as discussed in detail below.
    [0064] Without loss of generality, as an initialization step (Block 104), the stem column 28 can be assumed to be in the pipe 18, for resolution to an initial value for the axial displacement u. In other words, it is assumed that there is no transverse displacement, that is, v = 0. In this case, a value of the friction coefficient (μ) (for the frictional force acting on the stem column 28 from the pipe 18 ) is selected as 0.05, which can be based on empirical evidence or other information (Block 106), and the simplified version of the axial motion equation (4) assuming that there is no transverse motion is resolved first (Block 108) .
    [0065] In particular, the introduction of finite difference analogs in the simplified version of the axial motion equation (4) produces:

    [0066] Then, even assuming that there is no transverse displacement, the axial force F is calculated (Block 110), and the transverse equation of motion (2) is solved accordingly (Block 112). In particular, the introduction of finite difference analogs in axial force and in the transversal equation of motion (2) produces:

    [0067] At this point, the initial values for transverse displacement v and axial displacement u are available. The axial force F and the frictional force Ft are resolved (Block 114), and the axial motion equation (3) is resolved (Block 116). In particular, the introduction of finite difference analogs in the axial force F, in the frictional force Ft, and in the axial motion equation (3) produces:

    [0068] Finally, the resolution for displacement Uj + 1j in the system above produces the well-below position in the well-pump below used to calculate the well-pump plate below (Block 116). The load on the well pump below is then to follow the shape used in the Everitt-Jennings method.
    [0069] In particular, the resolution for displacement Ut + 1j in the system above requires knowledge of the displacement of the two nodes back in space, UÍJ and uí_1J- in relation to the node being calculated ui + 1j. To begin the solution, the displacements uoj and u1: j need to be known for all time increments j. The initial displacement u0 j is known from the surface measurements of the pumping rod pump system, but the displacement of the next node u1: j is calculated with Hook's law, when the polished rod load, LoadPR (the load surface minus the float weight of the rods), is replaced by Load and a first order correct forward difference analog is replaced by, which produces:

    [0070] Since the numerical methodology for solving the system of coupled nonlinear differential equations is similar to the numerical methodology for solving the system of coupled nonlinear differential equations is similar to the numerical implementation of the modified Everitt-Jennings method, an iterative method similar can be used to calculate the net stroke and damping factor for the deviated well model shown here. See, for example, Pons-Ehimeakhe, V., “Modified Everitt- Jennings Algorithm With Dual Iteration on the Damping Factors”, 2012 SouthWestern Petroleum Short Course, Lubbock, Texas, April 18-19. Furthermore, to optimize the resolution of the viscous damping in the deviated model shown here, the current algorithm may also include an iteration in single or double damping factors, as explained in copending orders N ° / (205-0322US2) entitled “ Calculating Downhole Pump Card With Iterations on Single Damping Factor ”and __ / (205-3222US3) entitled“ Calculating Downhole Pump Card With Iterations on Dual Damping Factors ”, which are incorporated herein by reference. Thus, a single damping factor D covering the double viscous damping factors or the double damping factors Dup and Ddown in the above equations, the up stroke and the down stroke can be iterated in conjunction with fluid load line and test calculations. of concavity for better convergence in the appropriate damping for the well pump plate generated below.
    [0071] Using finite differences to solve the system of coupled differential equations is a useful method for stress analysis in the pumping rod pump system. The division of finite difference analogs for space discretization allows the model to be valid for a tapered stem column, including steel rods and fiberglass rods with heavy bars. Finally, including Coulombs friction in the analysis of the deviated well model provides a better approximation of the well below conditions than using a vertical hole model.
    [0072] Process 100 exposed here, when applied as a diagnostic tool, generates a downhole plate without the excess downstream friction caused by the deviation and with optimum viscous damping. This process 100 is particularly useful for controlling wells based on well data below. As will be appreciated, the teachings of this exhibition can be implemented in a digital electronic circuit, computer hardware, computer firmware, computer software, or any combination of them. The teachings in this exhibition can be implemented in a product of a computer program made tangible in a storage device that can be read on a machine, for execution by a programmable processor, so that the programmable processor executing program instructions can perform the functions of the present exhibition.
    [0073] For this purpose, the teachings of the present exhibition can be implemented in a remote processing device or a pump controller. For example, figure 6A shows an embodiment of a pump controller 200 installed in a pumping rod pump system 10, such as a rocker pump commonly used for the production of fluid from a well. Pump system 10 includes a rocker 11 connected to a frame 15. Rocker 11 operatively connects to a polished rod 12 connected via a rod column (not shown) to a wellhead pump below (not shown), which can be any alternative well pump below, as discussed here. A motor control panel 19 controls a motor 17 to move the rocker 11 and toggle the polished rod 12, which in turn operates the downhole pump. Although a rocker pump is shown, other pump rod pump systems can be used, such as a strap jack, or any other system that alternates a rod column using cables, straps, chains and hydraulic and pneumatic power systems.
    [0074] In general, sensors 202 and 204 measure load data and position of the pump system 10 on the surface, and the data measured from sensors 202 and 204 are retransmitted to controller 200. After processing the information, the controller 200 sends signals to engine control panel 19 for operation of pump system 10. A particular arrangement of controller 200 and sensors 202 and 204 is set out in US Patent No. 7,032,659, which is incorporated herein by reference.
    [0075] As shown, controller 200 uses a load sensor 202 to detect the weight of the fluid in the production pipeline during a pump system 10 operation and uses a position sensor 204 to measure the position of the pump system 10 through each stroke cycle. The position sensor 204 can be any position measuring device for measuring the position in relation to the top or bottom of the stroke. For example, the position sensor 204 can be a double position sensor that produces a continuous position measurement and a discrete switch output that closes and opens at the pre-set positions of the polished rod 12.
    [0076] Alternatively, the degree of rotation of the pump system crank arm can provide displacement data. For example, a sensor can determine when the system crank arm moves from a specific location, and a simulated pattern of displacement versus polished rod time can be adjusted to provide an estimate of polished rod positions in times between these indications crank arm. In another alternative, a degree of inclination of the rocker 11 can provide displacement data. For example, a device can be attached to the rocker 11 for measuring the degree of inclination of the pumping unit.
    [0077] The loading data of system 10 can be measured directly using a load cell inserted between a polished rod clamp and a transport bar. Alternatively, the deformation in the rocker 11 can provide the load data. Using a load sensor 202, for example, controller 200 can measure the strain on the polished rod 12 and then can control the pump system 10, based on the measured strain. The load sensor 202 can use any of a variety of strain measurement devices known to a person of ordinary skill in the art. For example, load sensor 202 may be a load measuring device used in pump system 10 that includes a load cell installed on pumping rod 12 or mounted on rocker 11. Load sensor 202 can measure strain in the polished rod 12 and can use a straingage strain gauge transducer welded to the rocker top flange 11.
    Alternatively, load sensor 202 may be a strain measurement device that is clamped to a load-bearing surface of rocker 11 or any convenient location as set forth in U.S. Patent No. 5,423,224. In another example, load sensor 202 may use an assembly similar to that disclosed in U.S. Patent No. 7,032,659, which is incorporated herein by reference in its entirety.
    [0079] Finally, the amplitude and frequency of the electrical power signal applied to the motor 17 can be used for the determination of a motor rotation (that is, displacement data) and motor torque (that is, load data) . In this way, the motor speed and the displacement of the polished rod can provide a series of pairs and data of speed and displacement of the motor in a plurality of displacements along the polished rod. These displacement data, which represent a full stroke of the pump system 10, can then be converted into load on the stem column and the displacement of the stem column into a plurality of displacements along the polished stem, as described in US Patent No. 4,490,094.
    [0080] The details of the pump controller 200 are shown schematically in figure 6B. In general, controller 200 includes one or more sensor interfaces 212 receiving measurements from load and position sensors 202 and 204. Additional inputs from controller 200 can connect to other devices, such as a water cut-off meter with infrared, an acoustic sound device (ASD) providing real-time data, which can be logged for pressure build-up analysis and real-time calibration for fluid level control. Controller 200 also includes a power system (not shown), as provided conventionally.
    [0081] Controller 200 may have software 222 and data 224 stored in memory 220. Memory 220 may be a volatile memory with battery backup or a non-volatile memory, such as a once-programmable memory or a flash memory. In addition, memory 220 can be any combination of suitable external and internal memories.
    [0082] Software 222 can include motor control software and pump diagnostics software, and stored data 224 can be measurements logged from various load sensors and position 202 and 204 and calculation results. Data 224 in memory 220 stores characteristics of the well, including depth, azimuth and slope of points along the well, which can be derived from drilling and survey data. Due to the fact that the stem column can be tapered, as the case may be, data 224 in memory 220 can also sometimes store characteristics of the tapering of pump rods, such as depth, diameter, weight and length of the various sections of the stem.
    [0083] A processing unit 210 having one or more processors then processes the measurements by storing the measurement as data 224 in memory 220 and by running the software 222 to perform various calculations, as detailed here. For example, processing unit 210 obtains output from surface sensors, such as load and position measurements from sensors 202 and 204. In turn, processing unit 210 correlates the output of the load sensor 202 with the position of the polished rod 12 and determines the load experienced by the polished rod 12 during the stroke cycles. Using software 212, processing unit 210 then calculates the downhole plate indicating the load and position of the downhole pump.
    [0084] For control of the pump system 10, the pump controller 200 preferably uses an Everitt-Jennings algorithm not abbreviated with finite differences for solving the wave equation. Controller 200 calculates a pump fill and optimizes production on each stroke. This information is used to minimize the pooling of fluid by stopping or decelerating the pump system 10 in the assigned pump filling regulation. The pump controller 200 can also analyze the well pump plate below and determine potential problems associated with the pump and its operation. This is also because the shape, pattern and other features associated with the well pump plate below represent various conditions of the pump and its operation.
    [0085] After the measurements are processed, the controller 200 sends signals to the motor control panel 19 for operation of the pump system 10. For example, one or more communication interfaces 214 communicate with the motor control panel 19 to control the operation of the pump system 10, such as stopping the motor 17 to prevent a pump shutdown, etc. Communication interfaces 214 may be capable of suitable forms of communications, and they may also communicate data and calculation results to a remote location using any appropriate method of communication.
    [0086] The foregoing description of preferred or other modalities is not intended to limit or restrict the scope or applicability of the inventive concepts designed by the Applicants. It will be appreciated with the benefit of the present exhibition that the resources described above according to any modality or aspect of the exposed subject can be used, alone or in combination, with any other described resource, in any other modality or aspect of the exposed subject.
    [0087] In exchange for exposing the inventive concepts contained herein, claimants desire all patent rights guaranteed by the appended claims. Therefore, it is intended that all appended claims include all modifications and changes to the full extent that they come within the scope of the following claims or the equivalent thereof.
    权利要求:
    Claims (15)
    [0001]
    1. Diagnostic method of a pump apparatus having a downhole pump (14) arranged in a bypassed well hole and having a motor (17) on a surface of the bypassed well hole, the downwell pump (14) alternating in the hole of well deviated by a column of stem (28) operatively moved by the engine (17), the method characterized by the fact that it comprises: obtaining surface measurements indicative of surface load and surface position of the stem column (28) on the surface; the characterization of axial and transverse displacement of the stem column (28) with two coupled fourth order nonlinear differential equations including an axial equation of motion and a transverse equation of motion; the calculation of the initial axial displacement of the stem column (28) assuming that there is no transverse displacement and by solving the axial motion equation (108); the calculation of the initial axial force using the initial axial displacement and assuming that there is no transverse displacement (110); calculating the initial transverse displacement of the stem column (28) using the initial axial force and the initial axial displacement (112); the calculation of the axial force and the frictional force using the initial axial and transverse displacements (114); the calculation of the axial displacement in the well pump below (14) by solving the axial equation of motion with the axial force and the frictional force (116); the calculation of the load on the well pump below (14); and the generation of a downhole plate representative of the load in relation to the axial displacement of the downhole pump (118).
    [0002]
    2. Method, according to claim 1, characterized by the fact that obtaining the surface measurements comprises the measurement of the surface load and the surface position of the stem column (28) on the surface; or obtaining the surface measurement from a memory (220).
    [0003]
    3. Method, according to claim 1 or 2, characterized by the fact that the transversal equation of motion is defined by:
    [0004]
    4. Method according to claim 1, 2, or 3, characterized by the fact that the axial equation of motion is defined by:
    [0005]
    5. Method according to any one of claims 1 to 4, characterized by the fact that the characterization of the axial and transverse displacement of the stem column (28) with the two fourth order coupled nonlinear differential equations including the axial equation of motion and the transverse equation of motion comprises replacing the derivatives of the two nonlinear differential equations coupled by finite difference analogs.
    [0006]
    6. Method according to any one of claims 1 to 5, characterized by the fact that it still comprises the modification of at least one parameter of the pump apparatus based on the generated downhole plate.
    [0007]
    Method according to claim 6, characterized in that the modification of at least one parameter of the pump apparatus based on the generated downhole plate data comprises stopping the motor (17) or adjusting a motor speed ( 17).
    [0008]
    8. Computer-readable storage medium, comprising instructions for execution on a processor, characterized by the fact that the instructions, when executed by the processor, cause the processor to execute a method as defined in any of claims 1 to 7.
    [0009]
    9. Controller (200) of a pump apparatus, the pump apparatus having a surface motor (17) and having a well pump below (14), the well pump below (14) arranged in a bypassed well hole and alternated by a rod column (28) arranged in the deviated well hole, the controller (200) characterized by the fact that it comprises: one or more interfaces (212) for obtaining surface measurements indicative of surface load and surface position the stem column (28) on the surface; a memory (220) in communication with one or more interfaces (212) and storing first characteristics of the deviated well and second characteristics of the stem column (28), the memory (200) storing a model of the axial and transversal displacement characterization of the column stem (28) with two fourth order coupled nonlinear differential equations including an axial equation of motion and a transverse equation of motion; and a processing unit (210) in communication with one or more interfaces (212) and the memory (220) and configured to: calculate the initial axial displacement of the stem column (28) assuming that there is no transversal displacement and by the resolution of the axial motion equation (108), calculate the initial axial force using the initial axial displacement and assuming there is no transverse displacement (110), calculate the initial transversal displacement of the stem column (28) using the initial axial force and the axial displacement initial (112), calculate the axial force and the frictional force using the initial axial and transverse displacements, solve the axial motion equation with the axial force and the frictional force to calculate the axial displacement at the well pump below (116) , calculate the load on the well pump below (14), and generate a wellhead plate representative of the load in relation to the axial displacement of the well pump below (118).
    [0010]
    10. Controller according to claim 9, characterized in that to obtain surface measurements, the controller comprises one or more sensors (202, 204) measuring the surface load and the surface position of the stem column ( 28) on the surface or the controller (200) obtains the surface measurement from a memory (220).
    [0011]
    11. Controller, according to claim 9 or 10, characterized by the fact that the transversal equation of motion is defined by:
    [0012]
    12.Controller according to claim 9, 10, or 11, characterized in that the axial equation of motion is defined by:
    [0013]
    13. Controller according to any of claims 9 to 12, characterized by the fact that for the characterization of the axial and transverse displacement of the stem column (28) with the two fourth order coupled nonlinear differential equations including the axial equation of motion and the transverse equation of motion, the controller (200) is configured to replace the derivatives of the two nonlinear differential equations coupled with finite difference analogs.
    [0014]
    14. Controller according to any one of claims 9 to 13, characterized in that the controller (200) is further configured to modify at least one parameter of the pump apparatus based on the generated downhole plate.
    [0015]
    15. Controller, according to claim 14, characterized by the fact that for the modification of at least one pump device parameter based on the generated downhole plate data, the controller (200) is configured to stop the motor (17) or adjust a motor speed (17).
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    同族专利:
    公开号 | 公开日
    EP2776714B1|2018-08-29|
    EP2776714A1|2014-09-17|
    BR112014010219A2|2017-06-27|
    EP2771541A2|2014-09-03|
    US9810213B2|2017-11-07|
    RU2014121401A|2015-12-10|
    US20130115107A1|2013-05-09|
    EP2771541B8|2017-09-20|
    CA2856090A1|2013-05-02|
    CN104185735A|2014-12-03|
    RU2602719C2|2016-11-20|
    US9897083B2|2018-02-20|
    AU2012348346B2|2015-09-17|
    CN104185735B|2017-05-10|
    BR112014010227A2|2017-06-27|
    US20130108472A1|2013-05-02|
    EP2771541A4|2016-06-29|
    EP2771541B1|2017-08-09|
    WO2013063591A2|2013-05-02|
    CN104334825A|2015-02-04|
    CA2856090C|2016-11-22|
    US20130115104A1|2013-05-09|
    CN104334825B|2018-07-17|
    US20130104645A1|2013-05-02|
    AU2012328426A1|2014-05-22|
    AU2012328426B2|2016-06-09|
    WO2013085637A1|2013-06-13|
    CA2857144A1|2013-06-13|
    EP2776714A4|2016-06-29|
    US9810212B2|2017-11-07|
    RU2567567C1|2015-11-10|
    AU2012348346A1|2014-05-22|
    WO2013063591A3|2015-06-18|
    US9810214B2|2017-11-07|
    CA2857144C|2018-01-02|
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    法律状态:
    2018-03-06| B25A| Requested transfer of rights approved|Owner name: WEATHERFORD TECHNOLOGY HOLDINGS, LLC (US) |
    2018-12-04| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2019-11-19| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|
    2020-06-16| B06A| Notification to applicant to reply to the report for non-patentability or inadequacy of the application according art. 36 industrial patent law|
    2020-09-29| B09A| Decision: intention to grant|
    2020-12-15| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 29/10/2012, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US201161552812P| true| 2011-10-28|2011-10-28|
    US61/552,812|2011-10-28|
    US201261598438P| true| 2012-02-14|2012-02-14|
    US61/598,438|2012-02-14|
    US201261605325P| true| 2012-03-01|2012-03-01|
    US61/605,325|2012-03-01|
    US201261706489P| true| 2012-09-27|2012-09-27|
    US61/706,489|2012-09-27|
    PCT/US2012/062459|WO2013063591A2|2011-10-28|2012-10-29|Calculating downhole cards in deviated wells|
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