US3343409A - Method of determining sucker rod pump performance - Google Patents

Method of determining sucker rod pump performance Download PDF

Info

Publication number
US3343409A
US3343409A US59637166A US3343409A US 3343409 A US3343409 A US 3343409A US 59637166 A US59637166 A US 59637166A US 3343409 A US3343409 A US 3343409A
Authority
US
Grant status
Grant
Patent type
Prior art keywords
rod
displacement
polished
sucker
load
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Expired - Lifetime
Application number
Inventor
Sam G Gibbs
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Shell Oil Co
Original Assignee
Shell Oil Co
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Grant date

Links

Images

Classifications

    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00Survey of boreholes or wells
    • E21B47/0007Survey of down-hole pump systems
    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121Lifting well fluids
    • E21B43/126Adaptations of down-hole pump systems powered by drives outside the borehole, e.g. by a rotary or oscillating drive
    • E21B43/127Adaptations of walking-beam pump systems
    • FMECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04POSITIVE DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04BPOSITIVE DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS
    • F04B49/00Control, 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
    • F04B49/02Stopping, starting, unloading or idling control

Description

S. G. GIBBS Sept.v 26, 1967 METHOD oF DETERMIMING sucKER non PUMP PERFORMANCE P 5 Sheets-Sheet l Filed oct. 21, 196e RcoRDER DISPLACEMENT TRANS DUCER,

INVENToR:

SAM G. GlBBS BWM/Jy@ HIS ATTORNEY Sept. 26, 1967 s. cs. Glass METHOD 0F DETERMINING SUCKER ROD PUMP PERFORMANCE Filed Oct. 2l, 1966 :s sheets-sheet 2 2 rms, secouns Y ne. 3

n l 2 5 IIIE, SECONDE l 2.0 POLISHED RUD SPEED (ONE DIREOUO INVENTORI yls `ATTORNEY Sept. 26, 1967 s. G. Glass 3,343,409

METHOD 0F DETERMINING SUCKER ROD PUMP PERFORMANCE med oct. 21, 196e 3 sheets-sheet 3 FIG. 7

Loan nscunnsa Pmancx slam mmsmssnou smo afnemen uns REGWDER msmcenfur ,Mmmm r y f r speso j 4|/ 42f 4s] 4o me. a

INVENTORI SAM G. GIBBS United States Patent O ABSTRACT OF THE DISCLOSURE A process for determining the downhole performance of a pumping oil well by measuring data at the surface. The size, length and weight of the sucker rod string are measured and the load and displacement of the polish rod as functions of time are recorded. From the above datait is possible to construct a load versus displacement curve for the sucker rod string at any selected depth in the well.

This application is a continuation-in-part of application Ser. No. 354,236, filed March 24, 1964, now abandoned.

This invention relates to a method for determining the performance characteristics of a pumping well. More particularly, the invention is directed to a method of determining downhole conditions of a pumping well from data which are received, measured and manipulated at the surface of the well.` The invention has specific application to the analysis of pumping problems in the operation of sucker rod pumping systems.

For pumping deep wells, such as oil wells, a common practice is to employ a series of interconnected rods for coupling an actuating device at the surface with a pump at the bottom of the well. This series of rods, generally referred to as the rod string or sucker rod, has the uppermost rod extending up through the well casinghead for connection with an actuating device, such as a pump jack of the walking beam type, through a coupling device generally referred to as the rod hanger. The well casinghead includes means for permitting sliding action of the uppermost rod which is generally referred to as the polished rod.

In deep Wells the long sucker rod has considerable stretch, distributed mass, etc., and motion at the pump end may be radically different from that imparted at the upper end. Through the years, the polished rod dynamometer has provided the principal means for analyzing the performance of rod pumped wells. The dynamometer is an instrument which records a curve, usually called a card, of polished rod load versus displacement. The shape of this curve reflects the conditions which prevail downhole in the well. Hopefully the downhole conditions can be deduced by visual inspection of the polished rod card. Owing to the diversity of card shapes, however, it is frequently impossible to make a diagnosis of downhole conditions solely on the basis of visual interpretation. In addition to being highly dependent on the skill of the dynamometer analyst, the method of visual interpretation only provides downhole data which are qualitative in nature. As a result it is frequently necessary to use complicated apparatus and procedures to directly take downhole measurements in order to accurately determine the performance characteristics at various depth levels within the well.

Broadly, the present invention provides a system for economically preparing downhole dynagraph cards at all depth levels, including the pump, from data which are measured uphole at the polished rod. As a result, the system provides a rational, quantitative method for determining downhole conditions which is independent of the skill and experience of the analyst. It is no longer necessary to guess at downhole operating conditions on the ice basis of recordings taken several thousands of feet above at the polished rod, or to undertake the expensive and time consuming operation of running an instrument to the bottom of the well in order to measure such conditions. By use of the method, it is possible to directly determine the subsurface conditions from data received at the top of the well.

The invention will now be described with reference to the accompanying drawings wherein:

FIGURE 1 is a schematic diagram partially in longitudinal section, showing the general arrangement of apparatus in a system in accordance with the invention;

FIGURE 2 is an enlarged side elevation showing a portion of the apparatus at the rod hanger;

FIGURE 3 is a graphical illustration of polished rod load versus time;

FIGURE 4 is a graphical illustration of polished rod displacement versus time;

FIGURE 5 is a curve illustrating the relation between polished rod speed and a damping factor;

FIGURE 6 is a pump dynagraph card constructed in accordance with the present invention;

FIGURE 7 is a circuit diagram of an equivalent transmission line corresponding to the sucker rod string shown in FIGURE 1; and,

FIGURE 8 is an analog computer utilizing the transmission line of FIGURE 7 for providing a dynagraph card at any selected depth in the well.

Referring to FIGURE 1, there is shown a well having the usual well casing 10 extending from the surface to the bottom thereof. Positioned Within the well casing 10 is a production tubing 11 having a pump 12 located at the lower end. The pump barrel 13 contains a standing valve 14 and a plunger or piston 15 which in turn contains a traveling valve 16. The plunger 15 is actuated by a jointed sucker rod 17 that extends from the piston 15 up through the production tubing to the surface and is connected at its upper end by a coupling 18 to a polished rod 19 which extends through a packing joint 20 in the wellhead.

As best shown in FIGURE 2, the upper end of the polished rod 19 is connected to a hanger bar 23 suspended from a pumping beam 24 by two wire cables 25. The hanger bar 23 has a U-shaped slot 26 for receiving the polished rod 19. A latching gate 27 prevents the polished rod from moving out of the slot 26. A U-shaped platform 28 is held in place on top of the hanger bar 23 by means of a clamp 29. A similar clamp 30 is located below the hanger bar 23. A strain-gauge load cell 33, described in greater detail hereafter, is shown bonded to the platform 28. An electrical cable 34 leads from the load cell 33 to a recorder 35, and a taut wire line 36 Ileads from the hanger bar 23 to a displacement transducer 37 (see FIG- URE 1). The displacement transducer 37 is also connected to the recorder 35 by the electrical lead 38.

The strain-gauge load cell 33 is a conventional device and operates in a manner well known to those in the art. A particularly suitable -load cell is the model 1011 manufactured by Lockheed Electronics Company, Los Angeles, California. When the platform 28 is loaded, it becomes shorter and fatter due to a combination of axial and transverse strain. Since the wire of the strain-gauge 28 is bonded to the platform 28, it is also strained in a similar fashion. As a result, a current passed through the straingauge wire now has a larger cross section of wire in which to iiow, and the wire is said to have less resistance. As the hanger bar 23 moves up and down, an electrical signal which relates strain-gauge resistance to polished rod load is transmitted from the load cell 33 to the recorder 35 via the electrical cable 34.

The displacement transducer 37 is a conventional unit such as the Model WR8-150-A also manufactured by Lockheed Electronics Company. The displacement transducer unit 37 is a cable-and-reel driven, infinite resolution potentiometer that is equipped with a constant tension (negator spring driven) rewind assembly. As the hanger bar 23 moves up and down, the taut wire line 36 actuates the reel driven potentiometer and a varying voltage signal is produced. This signal, which relates voltage to polished rod displacement, is also transmitted to the recorder 35 via the electrical lead 38.

The recorder 35 is a conventional instrument such as the Model G-22 Dual Channel Recorder manufactured by Varian Associates, Inc. The recorder 35 is provided with a high torque motor which drives a strip chart at the rate of 60 inches per minute. Data from the strain-gauge load cell 33 and the displacement transducer 37 are simultaneously and independently recorded on the common chart to produce curves as shown in FIGURES 3 and 4. FIGURE 3 shows a typical curve of polished rod load versus time and FIGURE 4 shows a curve illustrating polished rod displacement versus time.

The key part in the analysis of the pumping system performance is the method for deciphering the force data which are measured at the polished rod. This interpretive process is based on a boundary-value problem comprising a differential equation and a set of boundary conditions.

The sucker rod can be thought of as a transmission or communication line, the behavior of which is described by the viscously damped wave equation:

where:

a=velocity of sound in steel in feet/ second;

c=damping ooeieient, l/second;

l=time in seconds;

x=distance of a point on the unrestrained rod measured from the polished rod in feet; and,

u(x,t)=displacement from the equilibrium position of the sucker rod in feet.

In reality, damping in a sucker rod system is a complicated mixture of many effects. The viscous damping law postulated in Equation 1 lumps all of these damping effects into an equivalent viscous damping term. The criterion of equivalence is that the equivalent force removes from the system as much energy per cycle as that removed by the real damping forces.

In keeping with this viscous damping postulate, some field damping measurements have been made. FIGURE 5 shows an idealization of these measurements phrased in terms of a dimensionless damping constant, ry. The damping coefficient, c, used in our analysis can be determined from FIGURE 5 and the relation:

where:

7=dimensionless damping factor; and, L=x1+x2|. .-i-xmzcornbined length of rods (depth of pump), in feet.

An alternate way of estimating the damping coefficient is by means of Equation 2 and the relation:

where:

PRzp=polished rod horsepower, in horsepower;

Hlzp=pump hydraulic horsepower, in horsepower;

T=period of pumping cycle, in seconds;

A1, A2, Am=area of each rod size in the Combination string in square inches;

x1, x2, xm=length of each rod interval in the com,-

bination string in feet; and, S=polished rod stroke, in feet.

Equation 3 is derived by assuming that the viscous damp ing losses occur as though the integrated average velocity of the sucker rod were equivalent to the root mean square velocity of the polished rod in simple harmonic motion. Either of these two methods for estimating the damping factor may prove suitable. Investigations have shown that the wave Equation 1 including the viscous damping approximation, gives good practical results when applied to sucker rod problems.

Information regarding downhole operating conditions is transmitted through the sucker rod in the form of strain waves which travel at about 16,000 feet per second. This information is monitored at the polished rod, preferably in the form of curves of polished rod load and displacement versus time as shown respectively in FIGURES 3 and 4. The boundary conditions are then formulated with this measured information or data. Because Equation 1 contains no gravity term, the rod weight must be deducted from the polished rod load. This yields a dynamic loadtime curve which, together with the displacement time curve, constitutes the boundary condition data required for a steady-state solution. The boundary conditions are formulated analytically by approximating these curves with a truncated Fourier series of the type:

w=angular velocity in radians per second; D(wl)=dynarnic polished rod load function in pounds; L(wt)=total polished rod load function in pounds; Wr=rod weight in fluid in pounds; and,

U(wt) :polished rod displacement function in feet.

These are the force-time and displacement-time functions.

The Fourier coefficients o', r, v and shown above are evaluated from the measured data by use of harmonic analysis as set out below. To apply the method, it is necessary to evaluate Fourier coefficients associated with functions defined only in graphical form. Since no explicit equations are available for these functions, evaluation of the coefficients by the classical method of integration is not possible. The following is a simple numerical procedure for approximating these coefficients:

Consider the dynamic load-time function D(wt). This function can be approximated by a truncated Fourier series, provided that the following integrals are used to evaluate the coeflicients:

2 1an=L D030 cos nwtdt, n=0, 1, 2, u

21r ,TFL Dna) sin wat, n=1, 2, n

These integrals can be approximated as follows. Let 0=wt, and obtain, for the 1an,

1 21r 1tr=;j;) D(0) cos mida, n=0, 1,2, u

For the numerical integration, consider 0 as a discrete variable 21p 0=yp=0, 1, 2,

Adopt the shorter notation etc., and use a trapezoid rule to write Collecting like terms we have DK cos {21170} For a periodic function, D0=DK. Also, cos 0=cos 2n1r; hence,

The accuracy of the numerical integration described above depends on the number of ordinates that are taken. Determination of the optimum number of ordinates is diiicult, but a K of 75 will probably suffice -for the calculation of the force coeicients 1an and 1-rn. Fewer ordinates are -required for the displacement coeliicients 111 and 1611, because the displacement function U(wt) is quite smooth. Perhaps a K1 of 35 is sufficient.

The smooth nature of the displacement function also permits the use of fewer displacement coeicients. Perhaps a maximum of four coeicients is required; therefore, the remaining coefcients 1115, 11,5, 1v; and 165,

165, 16,1 may be neglected.

To solve the problem set forth by Equations 1, 2 and 3, let z(x,t) be a complex variable. The wave Equation 1 then becomes, in complex form,

where An is a separation constant. This separation process splits the partial differential equation into two ordinary differential equations' Products of solutions to Equations 7 and 8 satisfy Equation 6. Anticipating Fourier series expansions in t, we seek periodic solutions to Equation 7 of the type T(t) :emt

Differentiation vand substitution into Equation 7 yields nzwzelnwt l icnweinwt+ n2a2elnvt=0 Since eint=}=0, then and Using methods in complex variables, we nd nw 2 i 0.

[mwah Let us choose the positive root, and define Equation 8 is the harmonic equation which is satisfied by linear combinations of Y' X (x) :sin Mx, cos )111x Special treatment is required for the case when n=0. In this instance Equations 7 and 8 reduce to T(t) |cT'(t)=0 Solutions to these equations which are of interest are T(t) :.5 X(x)=11x, r

where .5, 17, and y are real constants. This completes the preliminary work. Our choice of product solutions is governed by the boundary conditions. Take conditions will be satisiied. As a solution to Equation 1, choose u(x,t)1=Re [z(x,t)]

therefore, boundary condition 4 can be satisfied if hence,

(M1-unan) sin mat] It is convenient to define new constants at this point. Take In order that boundary Conditions 4 -be satised, the an and Tn must be evaluated with the Fourier-Euler in integral formulas then Condition 5 will be satisfied. This concludes the procedure for evaluating the separation constants.

The formula for the displacement u(x,z) is determined by using Equation 13 and the complex identities sin Anx=sin anx cosh nx-I-i cos anx sinh nx cos nx=cos anx cosh nx-l-i sin anx sinh nx and endt--cos nwt-i-i sin nat Using these identities, -we isolate the real part of z(x,t), obtaining a t rta, haa-geil 8 We have This completes the formal solution.

In practice, rod strings often involve several rod sizes. This requires that the solution just derived be extended slightly. It is convenient to adopt a more general notation, as follows. Let A1, A2, A3, Am be the areas and x1, x2, x3, xm be the corresponding lengths of the various rod sections taken in order starting from the surface. Extend the notation for the Fourier coefficients to include two subscripts as jan, jf, jvn, jn, where the right subscript denotes the order of the coefficient, as always, and they left subscript denotes the section of the rod string with which the coeicient is associated. The coeicients 1an, lfn, lun, 16u, are understood to pertain to polished rod data (the polished rod is considered as part of the lirst rod section). Also extend the notation for the functions given in Equations 25, 26, 28, and 29, i.e., ,-O(x), JPn(x), ,-On'(x), and ,Pn(x). Here the left subscript denotes that these functions involve the jth set of Fourier coefficients.

For simplicity, consider a two-way taper. The displacement at the bottom of the rst section is given by the generalized form of Equation 24 as The force in the rod at that point is 0055 asma...

2Vn=10n(ili) z5n=1P 11(1171) Similarly, the new force coefficients become sfo-:16o 20'n=E/11 10,'n(x1) 2Tn=EA1 1P n(x1) Finally, the displacement and load at the pump can be computed from 22011052) cos nwt-l-2P(x2) sin nwt n=1 and This procedure suggests recursion formulas for strings with 4any number of rod sizes. These formulas are With j=1, 2, m-l, where m is the number of rod sizes comprising the sucker rod string.

The solution to the boundary-value problem given above is fairly lengthy; thus, it is desirable to assemble in one place all of the pertinent formulas. The following is essentially a step-by-step procedure to be followed in performing this analysis:

Step 1. Using the measured data, construct the dynamic load function Calculate the Fourier coeicients associated with the measured data from Wn= r wat) cos ma: di, 71:0, 1, 2,

The polished rod load and displacement functions will be available only in graphical form; therefore, the integrals shown above cannot be evaluated in the classical manner. Many numerical methods, such as harmonic analysis methods, for approximating these integrals are available. A simplified harmonic analysis routine has previously been set out. The number of terms in the truncated Fourier series is determined by E. If we increase the accuracy of the results is increased, but, at the same time, the computation labor is increased. This requires a compromise on the size of An of, say, 10 will probably sutlice in most cases.

Step. 2. Estimate the damping coecient c. Methods for estimating c have been set out, supra. Calculate 2202.062) eos nwt-l-2P(x2) sin met] If the rod string is untapered, calculate the pump displacement and load from 'r'i' u(x1,t) :ll-gZB-l-gliodwr) COS MOH-11311051) sin mit.

43) F xf U EA. -inm.) cos naam/(x1) sin wil If the rod string is tapered, proceed to step 3.

Step 3. Calculate recursively the quantities COSh Bash-1+ where j: 1, 2, m-l, and 11:1, 2, .,1-1..

The pump displacement and load can then be calculated from and respectively. These solutions can then be used to determine the load and displacement at any depth in the well, particularly at the pump, by using the basic diagnostic equations and ll U(a:,t)=2a+2f+0n(x) cos nwt-l-P(x) sin not The Equations 49 and 50 give force and displacement at arbitrary depth and can be used to calculate subsurface dynamometer cards such as the one shown in FIGURE 6.

The above equations 49 and 50 can be solved by programing a digital computer and then supplying the well test data in the proper form. For example, a standard digital computer can be programed and the test data transcribed to punched cards or tapes. The test data can be transcribed by measuring the polished rod load in FIGURE 3 at various times to obtain a plurality of prints. Normally 60 or more points per complete cycle will provide suiiicient points. A similar number of points are obtained for the polished rod displacement cure of FIGURE 4. In addition, a set of punched cards are prepared for the fixed data such as weight of polished rod, pump period, length of various rod segments and sizes and the unit weight of the various rod segments.

The exact program for the computer can be developed by those skilled in the art and the exact form of the program will vary from worker to worker. The computer will supply a plurality of ordinate points that can be used to plot a dynamometer card for a selected depth. Normally the selected depth will be at the junction between two different sections of rod or at level of the pump.

An analog computer can also be used to provide a solution to Equations 49 and 50. An inspection of Equation 1 shows that it has the same form as the equation of an electrical transmission line NQ Q 1 2Q L u2 +R dt *C ce2 wherein L, R and C=inductance, resistance and capacitance, respectively, Q=charge in coulombs, x=distance in feet, and t=time in seconds. This equation can be simulated by the circuit of FIGURE 7 with magnitude of the capacitance, resistance and inductance being chosen to correspond to the features of the mechanical system.

The equivalent circuit of FIGURE 7 can be incorporated in a special analog computer or solved by a general purpose computer. A specialized computer is shown in block diagram form in FIGURE 8. The computer of FIGURE 8 can be connected directly to the load cells and displacement transducers shown in FIGURES 1 and 2. The computer will then supply a dynagraph card for any desired level in the system. The level of the dynagraph card can be selected by varying the current supplied to the equivalent transmission line shown in FIGURE 7.

The circuit of FIGURE 8 uses a recorder 40 to record the load and displacement signals generated by the transducers of FIGURES l and 2. The recorder can be a magnetic tape recorder with provisions for playing back the recorded signals at approximately times the recording speed. It is preferred that the playback speed be greater to reduce the size of the equivalent transmission line of FIGURE 7 and improve the performance of the system. The recorder supplies the two signals to a signal generator 41 that adjusts the current ow to obtain the dynagraph for the desired level. The signal generator contains the necessary operational amplifiers to both shape the signals and sum the signals.

The transmission line 42 is shown in detail in FIGURE 7 and consists of resistance, inductance and capacitance. The exact size of the elements will depend upon the physical characteristics of the sucker rod string and its length. In practice it has been possible to design a single equivalent electrical circuit to accept the following range of values for a sucker rod string length of 2000 to 15,000 feet, a diameter of '1/2 to 1 inch and up to 20 subdivisions.

The transmission line 42 is connected to the recorder 43 that includes an oscilloscope for displaying the developed signal. Of course, the recorder 43 also includes circuits for adjusting the signals and adding xed constants such as the weight of the sucker rod string. The signal displayed on the oscilloscope will be in the form of a dynagraph card for the selected depth. The signal on the oscilloscope can be photographed to obtain a permanent record of the dynagraph card.

To demonstrate the type of information generated with this technique, the data shown in FIGURES 3 and 4 have been analyzed. These data pertain to a well being produced with a inch stroke unit pumping at 12 strokes per minute from a depth of 7500 feet. The rod string consists of 1425 feet of l-inch rods, 1775 feet of 7z-inch rods, and 4300 feet of 3r-inch rods.

As indicated by the equations, the forces and displacements in the solution are given as functions of time. When force is plotted versus displacement for a given time, dynagraph cards can be constructed for all positions in the sucker rod string, including the pump, FIG- URE 6 shows a closed periphery pump dynagraph card constructed from the example data. Significant quantitative information can be obtained from this card, such as differential uid load, gross pump stroke, effective volumetric displacement, and volmetric eiciency. Moreover, in the event of system malfunction, the shape of the card is indicative of the nature of the trouble. The interpretation of pump dynagraph cards is well known to those skilled in the art and will not be discussed since it is not the subject of this invention.

The plotted subsurface cards can also be used to detect tubing leaks, detect defective tubing anchors, calculate intermediate rod stresses, detect gas separation problems, calculate pump intake pressure and detect leaky pumps, to name a few applications. Thus, it can be seen that considerable quantitative information can be gained by using the hereindescribed method to plot subsurface dynamometer cards.

I claim as my invention:

1. A method of determining the performance characteristics of a pumping well wherein a reciprocating pump is located below the uid level of the well and has a piston therein with a sucker rod string extending upward to a polished rod which is connected to a reciprocating prime mover means at the top of the well, said method comprising:

(a) measuring the area of each rod size in the sucker rod string, the combined length of the rods in the sucker rod string, ,the weight of the sucker rods and the pump, and the weight of that portion of the sucker rod hanging in said fluid;

(b) actuating said sucker rod string to reciprocate the pump, whereby said pump piston generates acoustic waves which move along the sucker rod;

(c) measuring and recording the load and displacement of the polished rod as functions of time;

(d) selecting a depth within the well to be investigated and combining the corresponding components of the size and Weight data measured in step (a) with the load and displacement versus time data measured in step (c) as the boundary conditions for a wave equation which describes the linear vibrations in a long slender rod, to determine the corresponding and 3. The method of claim 1 wherein steps (d) and (e) comprise selecting a depth within the Well to be investigated and combining the corresponding components of the size and weight data measured in step (a) with the load and displacement versus time data measured in step (c) as the boundary conditions for a wave equation which describes the liner vibrations in a long slender rod to determine the corresponding forces and displacements in the sucker rod string at the selected depth to obtain a plurality of coordinates of load versus displacement; and plotting the load versus displacement coordinates to obtain a dynagraph card for the selected depth.

References Cited UNITED STATES PATENTS 2,107,151 2/1938 Higginson 73-168 X 2,596,361 5/1952 Blanchet 73--151 X 2,741,915 4/1956 Renken et al. 73-151 X JAMES I. GILL, Acting Primary Examiner.

I. H. WILLIAMSON, Assistant Examiner.

Claims (1)

1. A METHOD OF DETERMINING THE PERFORMANCE CHARACTERISTICS OF A PUMPING WELL WHEREIN A RECIPROCATING PUMP IS LOCATED BELOW THE FLUID LEVEL OF THE WELL AND HAS A PISTON THEREIN WITH A SUCKER ROD STRING EXTENDING UPWARD TO A POLISHED ROD WHICH IS CONNECTED TO A RECIPROCATING PRIME MOVER MEANS AT THE TOP OF THE WELL, SAID METHOD COMPRISING: (A) MEASURING THE AREA OF EACH ROD SIZE IN THE SUCKER ROD STRING, THE COMBINED LENGTH OF THE RODS IN THE SUCKER ROD STRING, THE WEIGHT OF THE SUCKER RODS AND THE PUMP, AND THE WEIGHT OF THAT PORTION OF THE SUCKER ROD HANGING IN SAID FLUID; (B) ACTUATING SAID SUCKER ROD STRING TO RECIPROCATE THE PUMP, WHEREBY SAID PUMP PISTON GENERATES ACOUSTIC WAVES WHICH MOVE ALONG THE SUCKER ROD; (C) MEASURING AND RECORDING THE LOAD AND DISPLACEMENT OF THE POLISHED ROD AS FUNCTIONS OF TIME; (D) SELECTING A DEPTH WITHIN THE WELL TO BE INVESTIGATED AND COMBINING THE CORRESPONDING COMPONENTS OF THE SIZE AND WEIGHT DATA MEASURED IN STEP (A) WITH THE LOAD AND DISPLACEMENT VERSUS TIME DATA MEASURED IN
US3343409A 1966-10-21 1966-10-21 Method of determining sucker rod pump performance Expired - Lifetime US3343409A (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US3343409A US3343409A (en) 1966-10-21 1966-10-21 Method of determining sucker rod pump performance

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US3343409A US3343409A (en) 1966-10-21 1966-10-21 Method of determining sucker rod pump performance

Publications (1)

Publication Number Publication Date
US3343409A true US3343409A (en) 1967-09-26

Family

ID=24387043

Family Applications (1)

Application Number Title Priority Date Filing Date
US3343409A Expired - Lifetime US3343409A (en) 1966-10-21 1966-10-21 Method of determining sucker rod pump performance

Country Status (1)

Country Link
US (1) US3343409A (en)

Cited By (39)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3457781A (en) * 1966-08-29 1969-07-29 Phillips Petroleum Co Modified dynamometer
US3527094A (en) * 1967-08-04 1970-09-08 Shell Oil Co Apparatus for analyzing sucker-rod wave motion
DE2136670A1 (en) * 1970-07-27 1972-02-17
US3765234A (en) * 1970-07-09 1973-10-16 J Sievert Method for determining the net torque and the instantaneous horsepower of a pumping unit
US3951209A (en) * 1975-06-09 1976-04-20 Shell Oil Company Method for determining the pump-off of a well
US4034808A (en) * 1976-09-20 1977-07-12 Shell Oil Company Method for pump-off detection
US4406122A (en) * 1980-11-04 1983-09-27 Mcduffie Thomas F Hydraulic oil well pumping apparatus
US4509901A (en) * 1983-04-18 1985-04-09 Fmc Corporation Method and apparatus for detecting problems in sucker-rod well pumps
US4583915A (en) * 1983-08-01 1986-04-22 End Devices, Inc. Pump-off controller
US4599046A (en) * 1983-04-07 1986-07-08 Armco Inc. Control improvements in deep well pumps
US4694390A (en) * 1985-06-28 1987-09-15 Electric Power Research Institute, Inc. Microprocessor-based control and diagnostic system for motor operated valves
US4816987A (en) * 1985-06-28 1989-03-28 Electric Power Research Institute, Inc. Microprocessor-based control and diagnostic system for motor operated valves
US4947936A (en) * 1989-06-14 1990-08-14 Marathon Oil Company Well unit dynamometer installation means and method
US5159832A (en) * 1990-11-28 1992-11-03 Wada Ventures Indicating device
US5182946A (en) * 1991-11-08 1993-02-02 Amerada Hess Corporation Portable well analyzer
WO1993002289A1 (en) * 1991-07-22 1993-02-04 Westerman G Wayne Pump control using calculated downhole dynagraph information
US5184507A (en) * 1990-12-21 1993-02-09 Union Oil Company Of California Surface hydraulic pump/well performance analysis method
US5252031A (en) * 1992-04-21 1993-10-12 Gibbs Sam G Monitoring and pump-off control with downhole pump cards
US5464058A (en) * 1993-01-25 1995-11-07 James N. McCoy Method of using a polished rod transducer
US20040062658A1 (en) * 2002-09-27 2004-04-01 Beck Thomas L. Control system for progressing cavity pumps
US20070020110A1 (en) * 2005-06-29 2007-01-25 Weatherford/Lamb, Inc. Method for estimating pump efficiency
US20080067116A1 (en) * 2002-11-26 2008-03-20 Unico, Inc. Determination And Control Of Wellbore Fluid Level, Output Flow, And Desired Pump Operating Speed, Using A Control System For A Centrifugal Pump Disposed Within The Wellbore
US20080240930A1 (en) * 2005-10-13 2008-10-02 Pumpwell Solution Ltd Method and System for Optimizing Downhole Fluid Production
US20100111716A1 (en) * 2008-10-31 2010-05-06 Lufkin Industries, Inc. Apparatus for analysis and control of a reciprocating pump system by determination of a pump card
CN101498296B (en) 2008-01-31 2010-11-10 淄博亚华电子有限公司 Measuring means for oilfield oil pump indicating diagram without load transducer
US20110185825A1 (en) * 2010-01-29 2011-08-04 Dan Mackie Horseshoe load cell
US8083499B1 (en) 2003-12-01 2011-12-27 QuaLift Corporation Regenerative hydraulic lift system
WO2012082081A2 (en) 2010-12-16 2012-06-21 Naftamatika, S.R.O. A method for obtaining diagnostics and control of the pumping process of rod pumped oil and gas wells and devices for the method execution.
CN102877832A (en) * 2012-09-14 2013-01-16 中国石油天然气股份有限公司 Method and system for measuring movable liquid surface of oil well
CN102926743A (en) * 2012-10-31 2013-02-13 黄山华讯电子科技有限公司 Load and displacement integral wireless indicator of belt type pumping unit and detection system of load and displacement integral wireless indicator
WO2013063591A2 (en) 2011-10-28 2013-05-02 Weatherford/Lamb, Inc. Calculating downhole cards in deviated wells
CN103806893A (en) * 2012-11-14 2014-05-21 中国石油天然气股份有限公司 Intelligent detection method, intelligent detection device and intelligent detection system
US8892372B2 (en) 2011-07-14 2014-11-18 Unico, Inc. Estimating fluid levels in a progressing cavity pump system
WO2015042257A1 (en) * 2013-09-18 2015-03-26 Group Four Transducers Inc Improved load cell for measuring load on a rod
US9080438B1 (en) 2012-04-02 2015-07-14 James N. McCoy Wireless well fluid extraction monitoring system
US9574435B2 (en) 2011-12-22 2017-02-21 James N. McCoy Hydrocarbon well performance monitoring system
EP3176361A2 (en) 2015-11-30 2017-06-07 Weatherford Technology Holdings, LLC Calculating downhole card in deviated wellbore using parameterized segment calculations
WO2017100669A1 (en) * 2015-12-10 2017-06-15 General Electric Company Controller for a rod pumping unit and method of operation
US9689251B2 (en) 2014-05-08 2017-06-27 Unico, Inc. Subterranean pump with pump cleaning mode

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2107151A (en) * 1934-10-17 1938-02-01 George M Higginson Load compensation in oil well pumps
US2596361A (en) * 1950-01-23 1952-05-13 Bendix Aviat Corp Displacement indicating apparatus
US2741915A (en) * 1952-10-24 1956-04-17 Harry J Renken Apparatus for pumping and weighing wells

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2107151A (en) * 1934-10-17 1938-02-01 George M Higginson Load compensation in oil well pumps
US2596361A (en) * 1950-01-23 1952-05-13 Bendix Aviat Corp Displacement indicating apparatus
US2741915A (en) * 1952-10-24 1956-04-17 Harry J Renken Apparatus for pumping and weighing wells

Cited By (75)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3457781A (en) * 1966-08-29 1969-07-29 Phillips Petroleum Co Modified dynamometer
US3527094A (en) * 1967-08-04 1970-09-08 Shell Oil Co Apparatus for analyzing sucker-rod wave motion
US3765234A (en) * 1970-07-09 1973-10-16 J Sievert Method for determining the net torque and the instantaneous horsepower of a pumping unit
DE2136670A1 (en) * 1970-07-27 1972-02-17
US3817094A (en) * 1970-07-27 1974-06-18 Mobil Oil Corp Well monitoring apparatus
US3951209A (en) * 1975-06-09 1976-04-20 Shell Oil Company Method for determining the pump-off of a well
US4034808A (en) * 1976-09-20 1977-07-12 Shell Oil Company Method for pump-off detection
US4406122A (en) * 1980-11-04 1983-09-27 Mcduffie Thomas F Hydraulic oil well pumping apparatus
US4599046A (en) * 1983-04-07 1986-07-08 Armco Inc. Control improvements in deep well pumps
US4509901A (en) * 1983-04-18 1985-04-09 Fmc Corporation Method and apparatus for detecting problems in sucker-rod well pumps
US4583915A (en) * 1983-08-01 1986-04-22 End Devices, Inc. Pump-off controller
US4694390A (en) * 1985-06-28 1987-09-15 Electric Power Research Institute, Inc. Microprocessor-based control and diagnostic system for motor operated valves
US4816987A (en) * 1985-06-28 1989-03-28 Electric Power Research Institute, Inc. Microprocessor-based control and diagnostic system for motor operated valves
US4947936A (en) * 1989-06-14 1990-08-14 Marathon Oil Company Well unit dynamometer installation means and method
US5159832A (en) * 1990-11-28 1992-11-03 Wada Ventures Indicating device
US5184507A (en) * 1990-12-21 1993-02-09 Union Oil Company Of California Surface hydraulic pump/well performance analysis method
WO1993002289A1 (en) * 1991-07-22 1993-02-04 Westerman G Wayne Pump control using calculated downhole dynagraph information
US5182946A (en) * 1991-11-08 1993-02-02 Amerada Hess Corporation Portable well analyzer
US5252031A (en) * 1992-04-21 1993-10-12 Gibbs Sam G Monitoring and pump-off control with downhole pump cards
US5464058A (en) * 1993-01-25 1995-11-07 James N. McCoy Method of using a polished rod transducer
US7168924B2 (en) 2002-09-27 2007-01-30 Unico, Inc. Rod pump control system including parameter estimator
US20040062657A1 (en) * 2002-09-27 2004-04-01 Beck Thomas L. Rod pump control system including parameter estimator
US20040064292A1 (en) * 2002-09-27 2004-04-01 Beck Thomas L. Control system for centrifugal pumps
US7117120B2 (en) 2002-09-27 2006-10-03 Unico, Inc. Control system for centrifugal pumps
US20060251525A1 (en) * 2002-09-27 2006-11-09 Beck Thomas L Rod pump control system including parameter estimator
US20060276999A1 (en) * 2002-09-27 2006-12-07 Beck Thomas L Control system for centrifugal pumps
US8444393B2 (en) * 2002-09-27 2013-05-21 Unico, Inc. Rod pump control system including parameter estimator
US20040062658A1 (en) * 2002-09-27 2004-04-01 Beck Thomas L. Control system for progressing cavity pumps
US8249826B1 (en) 2002-09-27 2012-08-21 Unico, Inc. Determination and control of wellbore fluid level, output flow, and desired pump operating speed, using a control system for a centrifugal pump disposed within the wellbore
US8417483B2 (en) 2002-09-27 2013-04-09 Unico, Inc. Determination and control of wellbore fluid level, output flow, and desired pump operating speed, using a control system for a centrifugal pump disposed within the wellbore
US8180593B2 (en) 2002-09-27 2012-05-15 Unico, Inc. Determination and control of wellbore fluid level, output flow, and desired pump operating speed, using a control system for a centrifugal pump disposed within the wellbore
US7558699B2 (en) 2002-09-27 2009-07-07 Unico, Inc. Control system for centrifugal pumps
US20110106452A1 (en) * 2002-09-27 2011-05-05 Unico, Inc. Determination and Control of Wellbore Fluid Level, Output Flow, and Desired Pump Operating Speed, Using a Control System for a Centrifugal Pump Disposed Within the Wellbore
US7869978B2 (en) 2002-09-27 2011-01-11 Unico, Inc. Determination and control of wellbore fluid level, output flow, and desired pump operating speed, using a control system for a centrifugal pump disposed within the wellbore
US20100150737A1 (en) * 2002-09-27 2010-06-17 Unico, Inc. Determination and Control of Wellbore Fluid Level, Output Flow, and Desired Pump Operating Speed, Using a Control System for a Centrifugal Pump Disposed within the Wellbore
US7668694B2 (en) 2002-11-26 2010-02-23 Unico, Inc. Determination and control of wellbore fluid level, output flow, and desired pump operating speed, using a control system for a centrifugal pump disposed within the wellbore
US20080067116A1 (en) * 2002-11-26 2008-03-20 Unico, Inc. Determination And Control Of Wellbore Fluid Level, Output Flow, And Desired Pump Operating Speed, Using A Control System For A Centrifugal Pump Disposed Within The Wellbore
US8083499B1 (en) 2003-12-01 2011-12-27 QuaLift Corporation Regenerative hydraulic lift system
US8562308B1 (en) 2003-12-01 2013-10-22 Rodmax Oil & Gas, Inc. Regenerative hydraulic lift system
US7891237B2 (en) 2005-06-29 2011-02-22 Weatherford/Lamb, Inc. Method for estimating pump efficiency
US20090232662A1 (en) * 2005-06-29 2009-09-17 Mills Thomas M Method for estimating pump efficiency
US20070020110A1 (en) * 2005-06-29 2007-01-25 Weatherford/Lamb, Inc. Method for estimating pump efficiency
US7500390B2 (en) 2005-06-29 2009-03-10 Weatherford/Lamb, Inc. Method for estimating pump efficiency
US20080240930A1 (en) * 2005-10-13 2008-10-02 Pumpwell Solution Ltd Method and System for Optimizing Downhole Fluid Production
US9033676B2 (en) 2005-10-13 2015-05-19 Pumpwell Solutions Ltd. Method and system for optimizing downhole fluid production
CN101498296B (en) 2008-01-31 2010-11-10 淄博亚华电子有限公司 Measuring means for oilfield oil pump indicating diagram without load transducer
RU2556781C2 (en) * 2008-10-31 2015-07-20 ЛАФКИН ИНДАСТРИЗ, ЭлЭлСи Device for analysis and control over reciprocating pump system by determination of pump map
US20100111716A1 (en) * 2008-10-31 2010-05-06 Lufkin Industries, Inc. Apparatus for analysis and control of a reciprocating pump system by determination of a pump card
WO2010051270A1 (en) * 2008-10-31 2010-05-06 Lufkin Industries, Inc. Apparatus for analysis and control of a reciprocating pump system by determination of a pump card
US8036829B2 (en) * 2008-10-31 2011-10-11 Lufkin Industries, Inc. Apparatus for analysis and control of a reciprocating pump system by determination of a pump card
US8433516B1 (en) 2008-10-31 2013-04-30 Lufkin Industries, Inc. Apparatus for analysis and control of a reciprocating pump system by determination of a pump card
US20110185825A1 (en) * 2010-01-29 2011-08-04 Dan Mackie Horseshoe load cell
WO2012082081A2 (en) 2010-12-16 2012-06-21 Naftamatika, S.R.O. A method for obtaining diagnostics and control of the pumping process of rod pumped oil and gas wells and devices for the method execution.
US8892372B2 (en) 2011-07-14 2014-11-18 Unico, Inc. Estimating fluid levels in a progressing cavity pump system
US20130115107A1 (en) * 2011-10-28 2013-05-09 Victoria M. Pons Calculating Downhole Pump Card With Iterations on Dual Damping Factors
WO2013063591A2 (en) 2011-10-28 2013-05-02 Weatherford/Lamb, Inc. Calculating downhole cards in deviated wells
WO2013085637A1 (en) 2011-10-28 2013-06-13 Weatherford/Lamb, Inc. Fluid load line calculation, concavity test, and iterations on damping factor for downhole pump card
US9810212B2 (en) 2011-10-28 2017-11-07 Weatherford Technology Holdings, Llc Fluid load line calculation and concavity test for downhole pump card
US9810214B2 (en) * 2011-10-28 2017-11-07 Weatherford Technology Holdings, Llc Calculating downhole pump card with iterations on dual damping factors
US9810213B2 (en) * 2011-10-28 2017-11-07 Weatherford Technology Holdings, Llc Calculating downhole pump card with iterations on single damping factor
US20130115104A1 (en) * 2011-10-28 2013-05-09 Victoria M. Pons Calculating Downhole Pump Card With Iterations on Single Damping Factor
US9897083B2 (en) 2011-10-28 2018-02-20 Weatherford Technology Holdings, Llc Calculating downhole cards in deviated wells
US9574442B1 (en) 2011-12-22 2017-02-21 James N. McCoy Hydrocarbon well performance monitoring system
US9574435B2 (en) 2011-12-22 2017-02-21 James N. McCoy Hydrocarbon well performance monitoring system
US9587481B2 (en) 2011-12-22 2017-03-07 James N. McCoy Hydrocarbon well performance monitoring system
US9080438B1 (en) 2012-04-02 2015-07-14 James N. McCoy Wireless well fluid extraction monitoring system
CN102877832A (en) * 2012-09-14 2013-01-16 中国石油天然气股份有限公司 Method and system for measuring movable liquid surface of oil well
CN102877832B (en) * 2012-09-14 2015-11-18 中国石油天然气股份有限公司 In a hydrocarbon well fluid level measurement method and system for
CN102926743A (en) * 2012-10-31 2013-02-13 黄山华讯电子科技有限公司 Load and displacement integral wireless indicator of belt type pumping unit and detection system of load and displacement integral wireless indicator
CN103806893A (en) * 2012-11-14 2014-05-21 中国石油天然气股份有限公司 Intelligent detection method, intelligent detection device and intelligent detection system
CN103806893B (en) * 2012-11-14 2016-07-06 中国石油天然气股份有限公司 Intelligent detecting method, apparatus, and the detection system
WO2015042257A1 (en) * 2013-09-18 2015-03-26 Group Four Transducers Inc Improved load cell for measuring load on a rod
US9689251B2 (en) 2014-05-08 2017-06-27 Unico, Inc. Subterranean pump with pump cleaning mode
EP3176361A2 (en) 2015-11-30 2017-06-07 Weatherford Technology Holdings, LLC Calculating downhole card in deviated wellbore using parameterized segment calculations
WO2017100669A1 (en) * 2015-12-10 2017-06-15 General Electric Company Controller for a rod pumping unit and method of operation

Similar Documents

Publication Publication Date Title
US3374341A (en) Method for controlling pressure differential resulting from fluid friction forces in well-drilling operations
Geertsma The effect of fluid pressure decline on volumetric changes of porous rocks
US7168924B2 (en) Rod pump control system including parameter estimator
US8214188B2 (en) Methods and systems for modeling, designing, and conducting drilling operations that consider vibrations
Shibuya et al. Elastic shear modulus of soft clays from shear wave velocity measurement
Rummel FRACTURE MECHANICS APPROACH TO HYDRAUL| C FRACTURING STRESS MEASUREMENTS
US4597290A (en) Method for determining the characteristics of a fluid-producing underground formation
US4848461A (en) Method of evaluating fracturing fluid performance in subsurface fracturing operations
Collins et al. Seismic wave attenuation characteristics from pulse experiments
Wu et al. Simultaneous multifracture treatments: fully coupled fluid flow and fracture mechanics for horizontal wells
US20040139791A1 (en) Non-intrusive multiphase flow meter
Skempton et al. A contribution to the settlement analysis of foundations on clay.
Brennan et al. Evaluation of shear modulus and damping in dynamic centrifuge tests
US7031841B2 (en) Method for determining pressure of earth formations
US7369979B1 (en) Method for characterizing and forecasting performance of wells in multilayer reservoirs having commingled production
US5960369A (en) Method and apparatus for predicting the fluid characteristics in a well hole
US6834233B2 (en) System and method for stress and stability related measurements in boreholes
Houlsby et al. Analysis of the cone pressuremeter test in clay
Housner Spectrum intensities of strong-motion earthquakes
US4328705A (en) Method of determining characteristics of a fluid producing underground formation
Park et al. Soil damping formulation in nonlinear time domain site response analysis
US20060117842A1 (en) Single probe downhole sampling apparatus and method
Lacasse et al. State-of-the-art paper: triaxial testing methods for soils
US3817094A (en) Well monitoring apparatus
US5261267A (en) Method and apparatus for rock property determination using pressure transient techniques and variable volume vessels