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WO1993002289A1 - Commande de fonctionnement d'une pompe au moyen de donnees dynagraphiques calculees au fond du puits - Google Patents

Commande de fonctionnement d'une pompe au moyen de donnees dynagraphiques calculees au fond du puits Download PDF

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Publication number
WO1993002289A1
WO1993002289A1 PCT/US1992/006105 US9206105W WO9302289A1 WO 1993002289 A1 WO1993002289 A1 WO 1993002289A1 US 9206105 W US9206105 W US 9206105W WO 9302289 A1 WO9302289 A1 WO 9302289A1
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Prior art keywords
downhole
load
pump
data
dynagraph
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PCT/US1992/006105
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English (en)
Inventor
G. Wayne Westerman
Richard C. Montgomery
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Publication of WO1993002289A1 publication Critical patent/WO1993002289A1/fr
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Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04B—POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS
    • F04B47/00—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps
    • F04B47/02—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps the driving mechanisms being situated at ground level
    • C—CHEMISTRY; METALLURGY
    • C12—BIOCHEMISTRY; BEER; SPIRITS; WINE; VINEGAR; MICROBIOLOGY; ENZYMOLOGY; MUTATION OR GENETIC ENGINEERING
    • C12M—APPARATUS FOR ENZYMOLOGY OR MICROBIOLOGY; APPARATUS FOR CULTURING MICROORGANISMS FOR PRODUCING BIOMASS, FOR GROWING CELLS OR FOR OBTAINING FERMENTATION OR METABOLIC PRODUCTS, i.e. BIOREACTORS OR FERMENTERS
    • C12M45/00—Means for pre-treatment of biological substances
    • C12M45/03—Means for pre-treatment of biological substances by control of the humidity or content of liquids; Drying
    • C—CHEMISTRY; METALLURGY
    • C12—BIOCHEMISTRY; BEER; SPIRITS; WINE; VINEGAR; MICROBIOLOGY; ENZYMOLOGY; MUTATION OR GENETIC ENGINEERING
    • C12M—APPARATUS FOR ENZYMOLOGY OR MICROBIOLOGY; APPARATUS FOR CULTURING MICROORGANISMS FOR PRODUCING BIOMASS, FOR GROWING CELLS OR FOR OBTAINING FERMENTATION OR METABOLIC PRODUCTS, i.e. BIOREACTORS OR FERMENTERS
    • C12M45/00—Means for pre-treatment of biological substances
    • C12M45/22—Means for packing or storing viable microorganisms
    • C—CHEMISTRY; METALLURGY
    • C12—BIOCHEMISTRY; BEER; SPIRITS; WINE; VINEGAR; MICROBIOLOGY; ENZYMOLOGY; MUTATION OR GENETIC ENGINEERING
    • C12N—MICROORGANISMS OR ENZYMES; COMPOSITIONS THEREOF; PROPAGATING, PRESERVING, OR MAINTAINING MICROORGANISMS; MUTATION OR GENETIC ENGINEERING; CULTURE MEDIA
    • C12N1/00—Microorganisms, e.g. protozoa; Compositions thereof; Processes of propagating, maintaining or preserving microorganisms or compositions thereof; Processes of preparing or isolating a composition containing a microorganism; Culture media therefor
    • C12N1/04—Preserving or maintaining viable microorganisms
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/007—Measuring stresses in a pipe string or casing
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/008—Monitoring of down-hole pump systems, e.g. for the detection of "pumped-off" conditions
    • E21B47/009—Monitoring of walking-beam pump systems
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04B—POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS
    • F04B49/00—Control, e.g. of pump delivery, or pump pressure of, or safety measures for, machines, pumps, or pumping installations, not otherwise provided for, or of interest apart from, groups F04B1/00 - F04B47/00
    • F04B49/06—Control using electricity
    • F04B49/065—Control using electricity and making use of computers

Definitions

  • This invention relates to a method for determining the operating characteristics of a pumping well and for making control decisions based on those determinations.
  • the invention is directed to a process for automatically determining downhole conditions of a pumping well on a real-time basis from data that are received, measured, and manipulated at the surface of the well.
  • the invention has specific applications in the control of well operations based on calculated changes that occur at the subsurface, or downhole, pump.
  • the rod string can stretch, causing the movement of the downhole pump, in displacement and phase, to differ from the movement of the driving equipment at the surface.
  • the actual load at the downhole pump also differs from the load measured simultaneously at the surface. Those differences become more significant with well depth. As a result, interpretation of surface data is difficult, and methods of detecting pump-off based on surface measurements may be inaccurate.
  • control devices that operate based on surface data tend for those same reasons to lack consistency. Methods are also known to infer mathematically downhole load and position data from surface measurements. For example, see U.S. Patent No.3,343,409, issued to Gibbs, and U.S. Patent No. 3,527,094, issued to Yew, et al, which are hereby incorporated by reference.
  • One advantage of using downhole data in pump control is to permit more rapid and accurate adjustment of the pump controller by personnel with a lower level of dynagraph-analysis capabilities. It would also be advantageous to control the well on a "real-time" basis, whereby data are analyzed on-site as the well operates. Prior systems have been unable to transform surface data into downhole data fast enough to perform the calculations for each stroke simultaneously with the operation of the well.
  • the shape of the surface dynagraph is affected by such factors as length, size, and thickness of the rod string, type of material used in the rods, well depth, stroke length, pump size, pumping speed, degree of slip of the prime mover, pumping friction, presence or absence of a tubing anchor, andpumping-unit geometry. Accordingly, differently configured systems often have widely varying dynagraph shapes even though they are experiencing the same condition, such as a stuck pump or a leaking valve. Such variation results in a vast number of possible dynagraph shapes, as reflected in API Bulletin 11L2, for example, which presents over 1100 dynagraph shapes for full- pump conditions in a single pumping unit geometry.
  • the presence of pump-off will often have a major effect on the shape of the surface dynagraph.
  • Such variation causes difficulty in correctly adjusting the operation of a pump controller.
  • the shape of the downhole dynagraph, calculated at the downhole pump is more regular and consistent across variations in pumping equipment and conditions. Consequently, the tasks of recognizing pump faults or alarm conditions, such as pump-off, and of properly adjusting the pump controller are greatly simplified.
  • the current system eliminates the need for the user to set up the controller for each well, for example by determining "full-pump" and “pumped-of " conditions and saving data collected during those states for later reference by the controller.
  • the controller can more easily and reliably detect and classify downhole faults using downhole data. Disclosure of Invention It is therefore an object of the invention to provide an automatic, real-time pump controller using downhole-analysis techniques.
  • load and position data are measured at frequent time intervals at the surface by transducers.
  • the data are conditioned and converted for use by a computer controller.
  • Data stored in the controller describe the physical characteristics of the rod string in the well.
  • the controller includes a processor programmed to implement a wave-form transformation to create, on a real-time basis, an inferred downhole dynagraph, describing the load and position at the pump, based on the surface load and position data and the known physical parameters or configuration of the well.
  • a computer program determines whether a fault, such as a pumped-off condition, exists by evaluating the downhole dynagraph data. Upon recognition of a fault, such as pump-off, control of the pump motor may be transferred or the pump maybe stopped for a time.
  • the system is flexible enough to implement several transformation algorithms or fault-recognition methods.
  • the system could choose among the several alternatives manually or automatically, or the system could implement multiple algorithms simultaneously and reach an average or consensus result.
  • Other aspects of the invention will be appreciated by those skilled in the art after a reading of the detailed disclosure of the present invention, below.
  • FIG. 1 shows a cross-section of the pumping equipment, both at the surface and downhole.
  • FIG.2 shows a close-up view of a polished-rod load transducer.
  • FIG.3 shows a close-up view of the downhole pump, shown in a pumped-off condition.
  • FIG.4 shows a conceptual block diagram of the computer hardware and software used in the pump controller, together with the computer's input and output signals.
  • FIG.5 shows a general logic flowchart for a preferred embodiment of the invention.
  • FIG. 6 shows example surface and calculated downhole dynagraphs for both "full pump” and “pumped-off” conditions, with indications of how the downhole cards are used in several preferred embodiments to detect pump-off.
  • FIG. 7 shows a high-level software flowchart for one embodiment of the pump-off-detection algorithms described in Fig. 6, the full stroke integration method.
  • FIG. 8 shows a high-level software flowchart for another embodiment of the pump-off-detection algorithms described in Fig. 6, the downstroke integration method.
  • FIG. 9 is a software flowchart for a preferred embodiment of the downhole- conversion algorithm using a discrete Fourier-series solution.
  • FIG. 10 is a software flowchart for a preferred embodiment of the downhole- conversion algorithm using the fast Fourier algorithm.
  • FIG. 11 is a software flowchart for a preferred embodiment of the downhole- conversion algorithm using a finite differences solution.
  • Fig. 1 is an overview of a typical oil well and pumping unit 2. It is common practice to employ a series of interconnected rods, called sucker rods, comprising the rod string 4, for coupling pumping unit 2 to subsurface pump 6.
  • the uppermost rod generally referred to as polished rod 8
  • the uppermost rod passes through stuffing box 10, allowing the rod string to move up and down in the well without leaking well fluid.
  • rod string 4 is suspended from pumping unit bridle 12 on carrier bar 14 by means of polished rod clamp 16.
  • rod string 4 connects the pumping unit to plunger 18 of the pump, which is moved up and down in barrel 20 by the reciprocating motion of rod string 4.
  • the fluid (shaded) in tubing 22 is raised by the pump, and all of the fluid load is supported by plunger 18 and travelling valve 24.
  • plunger 18 moves downward into pump barrel 20 filled with liquid.
  • the pressure of the fluid in barrel 20 causes the ball of travelling valve 24 to open and allows plunger 18 to travel downward through the liquid in pump barrel 20.
  • the fluid load is transferred from plunger 18 and travelling valve 24 to standing valve 26 and tubing 22.
  • a load transducer 30 maybe inserted between carrier bar 14 and polished-rod claim 16, which thereby carries all of the rod load.
  • the electrical output from such a polished- rod-mounted load transducer 30 is directly proportional to the load on polished rod 8. See, e.g.. U.S. Patent No.4,363,605, issued to Mills, incorporated herein by reference.
  • load on polished rod 8 can be measured by welding a load transducer 32 to the top flange of the walking beam 34. See, e.g. f U.S. Patent No. 3,817,094, issued to Montgomery, et al., incorporated herein by reference. Polished rod 8 imposes a load on the walking beam — through carrier bar 14, polished rod claim 16, and bridle 12 — which causes the walking beam to bend slightly, thus elongating the top flange of the walking beam 34.
  • Such a beam-mounted load transducer 32 measures the elongation in the top flange of the walking beam 34, which is proportional to the load on polished rod 8.
  • the walking beam is also subjected to deformation due to differential heating of the top and bottom flanges of the walking beam 34 and 36.
  • the temperature of the top flange of the walking beam 34 is higher than the temperature of the bottom flange of the walking beam 36, elongation of the top flange of the walking beam 34 occurs.
  • the angle of the walking beam 38 maybe measured by connecting the body of a position transducer or potentiometer 40 to the static structure of the pumping unit, for example to sampsonpost 42. Potentiometer 40 contains a shaft connected parallel to the walking beam through a shaft extension 44 and a chain 46. As the walking beam rotates through its pumping arc, the shaft extension 44, and thus the internal wiper in potentiometer 40, is rotated through the same angle 38 as the walking beam. The position of the potentiometer wiper is thus proportional to the position of polished rod 8.
  • an inclinometer 48 may be mounted on the top flange of the walking beam 34, which produces an electronic signal proportional to the angle 38 of the walking beam and thus to the position of polished rod 8. See, e.g. f U.S. Patent No. 4,561,299, issued to Orlando, et al., incorporated herein by reference.
  • detei_____ning position is to mount a position switch 50 to the static structure of the pumping unit in such a way as to allow detection of the passage of crank arm 52, giving an inferred indication of the position of polished rod 8 at one point in each pumping stroke. Because the motion of polished rod 8 is generally sinusoidal, and the period of the stroke is known, a good representation of the polished rod position is possible through analysis of the period of the stroke, the geometry of the pumping unit and the slip in the prime mover, motor 54.
  • Pump-off controller 58 analyzes the load and position data and determines pump-off. Upon detection of a pump-off condition, pump-off controller 58 issues an electronic signal to motor starter 60, which may be integrated with pumping unit 2. Upon receipt of such a signal, motor starter 60 may turn off motor 54. Alternatively, pumping unit 2 may be configured to switch control of motor 54 to a timer or other control mechanism (not shown).
  • Fig. 4 shows a system block diagram of the hardware and software within controller 58, including its inputs and outputs. Reference is also made to the high- level general logic flowchart shown in Fig. 5.
  • Load-transducer signals 62 and position-transducer signals 64 pass to a signal-conditioning module 66, which in turn passes the signals to analog-to-digital converter 68 within controller 58, which translates the data into digital form for use by the computer.
  • Controller 58 may be controlled by a user entering commands at an external keypad 70.
  • Control processor 72 supervises collection and storage of digitized load and position data from analog-to-digital converter 68. Control processor 72 also provides control of input and output functions 84. Control processor 72 can access data from data storage 88, which may include operating information, data presenting historic dynamometer information, and operating parameters input from keypad 70. The major function of control processor 72 is to provide a control signal to output control 90 to stop motor 54 (or otherwise transfer control) when a condition, such as pump- off, exists, and to send signals instructing a re-start of motor 54 when a user- programmed down-time has elapsed (or when control is otherwise returned to the pump-off controller). Control processor 72 maybe an off-the-shelf micro-controller integrated circuit such as those manufactured by Intel Corp.
  • Math processor 74 uses load, time, and position data collected by control processor 72, together with information regarding the rod string and system damping contained in input data files 76 (stored in random access memory), to perform the downhole conversion according to a program 78 (stored in read-only memory). Math processor 74 may also perform calculations necessary to run fault- control algorithm 82.
  • Math processor 74 may be an off-the-shelf integrated circuit microprocessor such as those manufactured by the Intel Corp. in the 80x86 series (8086, 80286, 80386, 80486). For additional speed in solving the wave equation for making the downhole conversion, a math coprocessor, such as those manufactured by the Intel Corp. in the 80x87 series may also be used.
  • Math processor 74 creates an output data file 80, also stored in random access memory, containing the converted transducer data intended to represent the downhole dynagraph. Math processor 74 then evaluates data from output data file 80 pursuant to a fault-detection control program 82, also stored in read-only memory. When a fault, such as pump-off, occurs, math processor 74 passes a violation signal to control processor 72, which increments a violation counter. For each stroke that a fault violation is not found, a reset command is passed to control processor 72 to reset the violation counter.
  • a fault-detection control program 82 also stored in read-only memory.
  • control processor 72 When control processor 72 determines that the violation counter has exceeded a user preset limit, it sends a signal to output control 92, which signals motor 54 to transfer operation.
  • An optional communications port 94 may permit control processor 72 to inform the user of the fault in another fashion, for example by radio transmission to a central location.
  • Control processor 72 also has access to control programs for input/output 84 and display control programs 86, which permits it to indicate the detection of a fault on an external display 90.
  • control processor 72 maybe instructed by the user, through instructions entered on keypad 70, to store the results in data storage 88, which may be random access memory or permanent memory such as tape or disk storage, upon recognition of a fault.
  • Fig. 6 illustrates example shapes of the surface and downhole dynagraphs.
  • the dynagraph for a pump operating under normal conditions may appear as a highly irregular shape 96.
  • the calculated downhole dynagraph would look more like a regular, rectangular figure 110.
  • the irregularity in the surface dynagraph results from the stretching of the rod string and delays in sensing changes in load in the downhole pump.
  • the vertical axis indicates load
  • the horizontal axis indicates position (up or down) relative to the casing.
  • the load-position point moves in a clockwise direction around the dynagraph.
  • the downhole dynagraph changes its appearance 111.
  • a normally operating pump immediately transfers load on the downstroke from travelling valve 24 to standing valve 26.
  • the pump moves downwards rapidly through vapor before contacting the fluid-vapor interface, which delays travelling valve 24 from opening. That change in position without decrease in load is indicated in Fig. 6 on downhole dynagraph 111 as a horizontal line moving to the left from near the top right corner of the figure.
  • the surface dynagraph also changes 102, although the change may be more difficult to recognize.
  • the calculated area for each stroke is compared to the area within a calculated downhole dynagraph card 110, taken when the pump is expected to be filled, i.e., after the well is operational for long enough to begin pumping all fluid and no gas. If the calculated area drops below a preset percentage of the "full pump" dynagraph's area, as in card 111, the well is declared pumped-off.
  • Another possible test for pump-off is to calculate the area within the lower portion of the downhole dynamometer card 116, which corresponds to the pump work done on the downstroke.
  • An integration reference line 114 may be calculated by dividing the difference between measured maximum load and measured minimum load by a factor, either preset or manually input. In Figs. 6 and 8, that factor has been set at two.
  • the area between reference line 114 and the bottom of the dynagraph is calculated for each stroke and the result is compared to a preset value.
  • the preset value may be a percentage of the area of the full-pump dynagraph's downstroke work or an absolute, manually entered value. When the area is determined to be less than the preset value (compare dynagraph 115 to dynagraph 116), pump-off is declared.
  • fault-detection algorithms can be utilized to achieve similar results.
  • the system can be calibrated easily and is more stable across wells with difference characteristics.
  • the fault- recognition algorithm can be more simple inform than those developed for use on surface data.
  • the downhole dynagraph may be obtained by mathematically manipulating the load, position, and time data measured at the surface of the well to determine the forces and displacements that would have been required at the pump to produce the measured surface data.
  • the sucker rod string can be modelled as a long, slender, vibrating rod.
  • the rod has a known weight and is subject to tensional forces. As the rod is reciprocated, the rod accelerates, but because it is elastic, the acceleration is not constant along the rod's length. Some energy is lost by viscous damping effects.
  • Those characteristics maybe captured in a one-dimensional damped wave equation, shown in Gibbs' U.S. Patent No. 3,343,409 as equation (1). That equation is a second-order differential equation, which can be split into two first-order differential equations, one equation representing load and the other, position. When accompanied by knowledge of boundary conditions, the equations can be solved simultaneously. See Master's Thesis by D.J.
  • Known numerical-analysis methods can be used to solve the differential equations to calculate the force-displacement curve at the pump.
  • Software flowcharts illustrating those methods are shown in Figs. 9, 10, and 11.
  • the shape of the downhole dynagraph can be calculated using those techniques or other wave-form-analysis techniques.
  • measured surface load and position data points are transformed by the use of a standard discrete Fourier expansion into phase and amplitude terms.
  • stored data regarding the top-most discrete length, or "taper,” of the rod string are analyzed by a damping formula to create coefficients for the Fourier series.
  • the data include such information as the thickness, material composition, and length of the taper.
  • the damping formula may be derived experimentally, such as explained in Gibbs' U.S. Patent No. 3,343,409 (although Gibbs assumes that the data are consistent throughout the rod string).
  • Applying the coefficients to the transformed data results in the phase and amplitude of the set of points representing the load and position of the first taper as a function of time.
  • the process is then iterated for subsequent, lower tapers, using the (possibly different) data stored for each taper.
  • the result calculated for the bottom-most taper is the phase and amplitude of the set of points representing the load and position of the downhole pump over time.
  • the program then converts the data back into load and position points at specific time intervals by performing an inverse Fourier transform.
  • the results are then stored for analysis by the fault- detection algorithm.
  • Fig. 10 shows the so-called fast Fourier transform, a known algorithm for performing discrete Fourier analysis more efficiently.
  • the number of load and position points are first counted and tested to see if they are equal to a power of two. If not, additional points are interpolated to make the total number of points equal to the next higher power of two.
  • the fast Fourier transform algorithm permits a faster calculation by restricting the number of data points to factors of two. The analysis then proceeds, in the same fashion as described above, to work down through the tapers to the pump.
  • the finite differences analysis illustrated in Fig.11, uses an iterative process. At the beginning of this procedure, the position data are differentiated to determine velocity as a function of time, and at the end of the procedure, the calculated velocity data are converted back to position data by integration. Load data are not similarly converted.
  • the finite differences analysis proceeds from the observation that it is possible to calculate the velocity and load at any segment in the rod string from knowledge of velocity and load of the immediately preceding segment and the characteristics of the current segment. Therefore, the rod string is divided into a number of segments of equal, arbitrary length, for example 150 meters per segment. The program then calculates the average physical properties for the segment, for each segment that contains rods of different sizes or materials, using the ratio of the length of each different rod to the overall length of the segment.
  • the method starts at the first segment and, using the average characteristics of that segment and the surface load and velocity data, calculates the velocity that would prevail at the bottom of the segment as a function of time. From that velocity data and the surface load data, it is possible to calculate the load at the bottom of the segment over time, taking into account the weight of the rod string below the segment, the fluid weight, and the acceleration, which alters the load. The process is then repeated for the next segment. The calculated velocity and load at the bottom of the first segment is used, together with the average characteristics of the second segment, to calculate the velocity and load functions at the bottom of the second segment. The process is iterated until the calculation is made for the last, bottom segment, which results in the downhole data.
  • a preferred embodiment of the invention might operate as follows.
  • rod-mounted load transducer 30 and position transducer 40 collect data representing the load and position of polished rod 8, which is located at the surface.
  • the data pass through transducer cables 56 to on-site pump controller 58, where they are conditioned and converted to digital form.
  • control processor 72 collects a stroke's worth of such data and passes them to math processor 74 for analysis.
  • math processor 74 uses pre-stored information about the characteristics of the various tapers of rod string 4, math processor 74 utilizes wave-form downhole-calculation program 78 to convert the surface load and position data to a stroke's worth of data representing the load and position at the pump, which are then stored in an output data file 80.
  • Downhole-calculation program 78 might operate according to the finite differences method illustrated in Fig. 11.
  • math processor 74 evaluates a stroke's worth of downhole data stored in data file 80 using control calculation 82, which tests for the existence of a fault, such as pump-off. That test might be the downstroke integration method illustrated in the right column of Fig.6 and in Fig.8, in which the portion of the card below an integration reference (load) limit 114 is integrated. If the integral exceeds a preset value, the well is considered not pumped off, and a reset signal is sent to control processor 72. Otherwise, control processor 72 increments a fault counter, which, when it exceeds a user-selected limit, causes control processor 72 to signal a fault, as shown in Fig.5. The user might opt to have control processor 72, upon recognition of a fault, issue a command to motor controller 60 (in Fig. 1) to shut down motor 54 for a preset time.
  • control processor 72 upon recognition of a fault, issue a command to motor controller 60 (in Fig. 1) to shut down motor 54 for a preset time.

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Abstract

Dispositif et procédé permettant de commander l'exploitation d'un puits de pétrole par pompe à tige sur la base de la capacité calculée de pompage de la pompe souterraine (6). La charge et la position de surface sont mesurées à intervalles réguliers. Les valeurs mesurées de charge et de position, combinées à des paramètres physiques du système de pompage tels que la taille, le poids, les propriétés d'élasticité et la longueur de la chaîne de tiges (4), sont utilisées selon l'une des trois techniques d'analyse mathématique préférées (figures 9-11) pour tracer une courbe dynagraphique de fond de puits entre la charge et la position, dans le temps, courbe qui représente les conditions existant au niveau de la pompe souterraine (par exemple 110 ou 111). Les caractéristiques de cette courbe de représentation dynagraphique entre la charge et au fond du puits sont ensuite analysées par l'un des algorithmes (figures 7 ou 8) pour détecter les problèmes de désamorçage et autres problèmes de pompage.
PCT/US1992/006105 1991-07-22 1992-07-22 Commande de fonctionnement d'une pompe au moyen de donnees dynagraphiques calculees au fond du puits Ceased WO1993002289A1 (fr)

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US73369691A 1991-07-22 1991-07-22
US733,696 1991-07-22

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PCT/US1992/006135 Ceased WO1993002210A1 (fr) 1991-07-22 1992-07-21 Dispositif et procedes de conservation, transport, stockage, rehydratation et administration de micro-organismes viables
PCT/US1992/006105 Ceased WO1993002289A1 (fr) 1991-07-22 1992-07-22 Commande de fonctionnement d'une pompe au moyen de donnees dynagraphiques calculees au fond du puits

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Cited By (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2427661A (en) * 2005-06-29 2007-01-03 Weatherford Lamb Method for estimating pump efficiency
US9033676B2 (en) 2005-10-13 2015-05-19 Pumpwell Solutions Ltd. Method and system for optimizing downhole fluid production
US9200629B2 (en) 2011-06-27 2015-12-01 Krzysztof Palka System and method for determination of polished rod position for reciprocating rod pumps
EA023666B1 (ru) * 2014-04-29 2016-06-30 Институт Систем Управления Национальной Академии Наук Азербайджанской Республики Способ диагностики состояния глубинного насоса
US10024314B2 (en) 2015-07-30 2018-07-17 General Electric Company Control system and method of controlling a rod pumping unit
US10145230B2 (en) 2014-10-10 2018-12-04 Henry Research And Development, Llc Systems and methods for real-time monitoring of downhole pump conditions
US10260500B2 (en) 2017-05-15 2019-04-16 General Electric Company Downhole dynamometer and method of operation
CN113027387A (zh) * 2021-02-22 2021-06-25 中国石油天然气股份有限公司 一种油井间抽控制系统及方法
US20220178365A1 (en) * 2020-12-08 2022-06-09 International Business Machines Corporation Identifying potential problems in a pumpjack

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NO337765B1 (no) * 2005-06-29 2016-06-20 Weatherford Tech Holdings Llc Fremgangsmåte for estimering av pumpevirkningsgrad
GB2427661A (en) * 2005-06-29 2007-01-03 Weatherford Lamb Method for estimating pump efficiency
US7891237B2 (en) 2005-06-29 2011-02-22 Weatherford/Lamb, Inc. Method for estimating pump efficiency
GB2427661B (en) * 2005-06-29 2011-05-18 Weatherford Lamb Method for estimating pump efficiency
US7500390B2 (en) 2005-06-29 2009-03-10 Weatherford/Lamb, Inc. Method for estimating pump efficiency
US9033676B2 (en) 2005-10-13 2015-05-19 Pumpwell Solutions Ltd. Method and system for optimizing downhole fluid production
US9200629B2 (en) 2011-06-27 2015-12-01 Krzysztof Palka System and method for determination of polished rod position for reciprocating rod pumps
EA023666B1 (ru) * 2014-04-29 2016-06-30 Институт Систем Управления Национальной Академии Наук Азербайджанской Республики Способ диагностики состояния глубинного насоса
US10145230B2 (en) 2014-10-10 2018-12-04 Henry Research And Development, Llc Systems and methods for real-time monitoring of downhole pump conditions
US10024314B2 (en) 2015-07-30 2018-07-17 General Electric Company Control system and method of controlling a rod pumping unit
US10260500B2 (en) 2017-05-15 2019-04-16 General Electric Company Downhole dynamometer and method of operation
US20220178365A1 (en) * 2020-12-08 2022-06-09 International Business Machines Corporation Identifying potential problems in a pumpjack
US11619225B2 (en) * 2020-12-08 2023-04-04 International Business Machines Corporation Identifying potential problems in a pumpjack
CN113027387A (zh) * 2021-02-22 2021-06-25 中国石油天然气股份有限公司 一种油井间抽控制系统及方法

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