Oil production using rod pumps is the most common method of artificially lifting oil, which is explained by their simplicity, efficiency and reliability. At least two thirds of the existing production wells are operated by sucker rod pumping units.

In front of others by mechanized means oil production, USPs have the following advantages:

• have a high coefficient useful action;
• repairs can be carried out directly at the fields;
• Various drives can be used for prime movers;
• SRP units can be used in difficult operating conditions - in sand-producing wells, in the presence of paraffin in the produced oil, at a high gas factor, when pumping out corrosive liquids.

Rod pumps also have disadvantages. The main disadvantages include:

• limitation on the depth of pump descent (the deeper, the higher the probability of rod breakage);
• low pump flow;
• limitation on the inclination of the wellbore and the intensity of its curvature (not applicable in inclined and horizontal wells, as well as in highly curved vertical ones)

A deep well pump in its simplest form (see picture to the right) consists of a plunger moving up and down a well-fitted cylinder. The plunger has a check valve that allows fluid to flow up but not down. The check valve, also called a check valve, in modern pumps is usually a ball-and-seat valve. The second suction valve is a ball valve located at the bottom of the cylinder which also allows fluid to flow upward but not downward.

A rod pump is a positive displacement type of pump, the operation of which is ensured by the reciprocating movement of a plunger using a ground drive through a connecting member (a string of rods). The topmost rod is called polished stem, it passes through the stuffing box at the wellhead and is connected to the head of the pumping machine's balancer using a traverse and a flexible rope suspension.

The main components of the USHGN (pumping machine) drive are: frame, stand in the form of a truncated tetrahedral pyramid, a beam with a rotating head, a traverse with connecting rods hinged to the balance beam, a gearbox with cranks and counterweights, equipped with a set of replaceable pulleys for changing the number of swings. To quickly change and tension belts, the electric motor is mounted on a rotating slide.

Rod pumps are plug-in (NSV) And non-insertable (NSN).

Insert rod pumps are lowered into the well at assembled form. A special locking device is first lowered into the well onto the tubing, and the pump on the rods is lowered into the already lowered tubing. Accordingly, to change such a pump, it is not necessary to carry out the lowering and lifting of pipes once again.

Non-insert pumps are launched in a semi-assembled form. First, the pump cylinder is lowered onto the tubing. And then a plunger with a check valve is lowered on the rods. Therefore, if it is necessary to replace such a pump, it is necessary to lift from the well first the plunger on rods, and then the tubing with the cylinder.

Both types of pumps have both their advantages and disadvantages. For each specific condition, the most suitable suitable type. For example, provided that the oil contains large quantity for paraffin, it is preferable to use non-insert pumps. Paraffin, deposited on the walls of the tubing, can block the ability to lift the plunger of the insert pump. For deep wells, it is preferable to use an insert pump to reduce the time spent on lowering and lifting the tubing when changing the pump.

Rod borehole pumping units (SHPU) are designed to lift formation fluid from a well to the surface.

Over 70% of the existing well stock are equipped with deep well pumps. With their help, about 30% of the country's oil is produced.

Currently, SSNUs are usually used in wells with a flow rate of up to 30...40 m 3 of liquid per day, less often up to 50 m 3 at average suspension depths of 1000... 1500 m. In shallow wells, the installation ensures a liquid lift of up to 200 m 3 /day

In some cases, pump suspension can be used to depths of up to 3000 m.

The drive is designed to convert engine energy into reciprocating motion of the sucker rod string.

The rod borehole pumping unit includes:

a) ground equipment - pumping machine (SK), wellhead equipment, control unit;

b) underground equipment - tubing, pumping rods, sucker rod pumps and various protective devices that improve the operation of the installation in difficult conditions.

Rice. 1. Rod borehole pumping unit:

1 - foundation; 2 - frame; 3 - electric motor; 4 - cylinder; 5 - crank; b - load; 7 - connecting rod; 8 - load; 9 - stand; 10 - balancer; 11 - mechanism for fixing the balancer head; 12 - balancer head; 13 - rope suspension; 14 - polished rod;

15 - wellhead equipment; 16 - casing; 17 - pump and compressor pipes; 18 - rod column; 19 - deep pump; 20 - gas anchor; 21 - polished rod seal; 22 - pipe coupling; 23 - rod coupling; 24 - deep-well pump cylinder; 25 - pump plunger; 26 - discharge valve; 27 - suction valve.

A pump cylinder is lowered into the well on the tubing string under the liquid level. Then, a piston (plunger) is lowered into the tubing on the sucker rods and installed in the pump cylinder. The plunger has one or two valves that open only upward, called butterfly valves. The upper end of the rods is attached to the head of the rocker's balancer. To direct fluid from the tubing into the oil pipeline and prevent its spillage, a tee is installed at the wellhead and a gland above it, through which a gland rod is passed.

Upper rod, called a polished rod, is passed through the stuffing box and connected to the head of the rocker's balancer by means of a rope suspension and crossbar.

plunger pump is driven by a pumping machine, where the rotational motion received from the engine using a gearbox, crank mechanism and balancer is converted into reciprocating motion transmitted to the plunger of a sucker rod pump through a string of rods.

When the plunger moves upward the pressure below it decreases, and liquid from the intertubular space enters the pump cylinder through the open suction valve.

When the plunger moves down The suction valve closes and the discharge valve opens, and the liquid from the cylinder passes into the rise pipes. With continuous operation of the pump, the liquid level in the tubing rises, the liquid reaches the wellhead and flows through the tee into the flow line.

Drives PA "Uraltransmash"

Designation of drives using the example of PShGNT4-1.5-1400:

PSHGN – drive of sucker rod pumps;

T – the gearbox is installed on the stand;

1,5 – greatest length wellhead rod stroke 1.5 m;

1400 – maximum permissible torque on the driven shaft of the gearbox;

Lecture No. 2. Underground equipment of the power steering unit

Purpose, types, design and marking of wells

Rod pumps.

Downhole rod pumps are designed for pumping liquids from oil wells with a water content of up to 99%, a temperature of up to 130°C, a hydrogen sulfide content of no more than 50 mg/l, and a water salinity of no more than 10 g/l.

Well pumps have a vertical, single-acting design with a fixed cylinder, movable metal plunger and ball valves. Pumps are manufactured in the following types:

1) HB1 - plug-in with a lock at the top;

2) HB2 - plug-in with a lock at the bottom;

3) NN - non-plug-in without catcher;

4) НН1 - non-insertable with a gripping rod;

5) НН2 - non-insertable with catcher

Rice. 2. Non-insert well pumps

The cylinder of a non-insert (pipe) well pump (see Fig. 2) is attached to the tubing string and, together with it, is lowered into the well. The NSN plunger is inserted through the tubing into the cylinder along with the suction valve suspended from it on the sucker rods. In order not to damage the plunger when lowering, its diameter is taken to be approximately 6 mm smaller than the internal diameter of the tubing. The use of NSN is advisable in wells with a large flow rate, shallow descent depth and a long turnaround period. To change the pump (cylinder), it is necessary to remove the rods and pipes.

The HH1 pump consists of a cylinder, a plunger, discharge and suction valves. In the upper part of the plunger there is a discharge valve and a rod with an adapter for rods.

The suction valve is freely suspended from the lower end of the plunger using a tip on the gripping rod. During operation, the valve is seated in the housing seat. It is necessary to hang the suction valve from the plunger to drain fluid from the tubing before lifting it, as well as to replace the valve without lifting the tubing. The presence of a gripping rod inside the plunger limits its stroke length, which in NH1 pumps does not exceed 0.9 m.

In the НН2С pump, unlike the НН1 pump, the discharge valve is installed at the lower end of the plunger. To remove the suction valve without lifting the tubing, a catcher (bayonet lock) is used, which is attached to the discharge valve seat. The catcher has two shaped grooves for engagement. A spindle (short rod) with two thickened pins is screwed into the suction valve cage. After the suction valve is seated in the body seat, turn the rod column 1-2 turns counterclockwise to ensure that the spindle pins slide along the grooves of the catcher and the suction valve is disconnected from the plunger. The capture is carried out after the plunger lands on the spindle when turning the rod column clockwise.

The NNBA pump allows for forced withdrawal of fluid from wells through tubing whose diameter is less than the diameter of the plunger.

This is achieved by its special design - the presence of an automatic coupler, including a coupling and gripper, and drain device. The assembled pump, without a coupling, is lowered into the well onto the tubing. Then a coupling with a measuring rod is lowered on the rods. The clutch pushes the drain valve down and engages with a grip attached to the plunger, thereby closing the drain hole. When lifting the pump, the rod string must be raised. In this case, the gripper pushes the spool upward, opening the drain hole. After this, the coupling is separated from the gripper and the rod column rises freely.

Insert pump cylinder(see Fig. 3) is lowered inside the pipes on a column of rods and mounted on them using a special locking connection. This allows you to change the insert pump without lowering and lifting pipes. But with the same diameters of the plungers, the inserted pump requires the use of tubing of a larger diameter.

Downhole pumps of design НВ1С are designed for pumping low-viscosity liquid from oil wells.

The pump consists of a composite cylinder on the lower end of which a double suction valve is screwed, and on the upper end there is a plunger lock, movably located inside the cylinder, onto the threaded ends of which are screwed: a double discharge valve at the bottom, and a plunger cage at the top. To connect the plunger to the sucker rod string, the pump is equipped with a rod screwed onto the plunger cage and secured with a lock nut. In the bore of the upper sub of the cylinder there is a stop, resting on which, the plunger ensures that the well pump is pulled off the support.

Borehole pumps, version NV1B. These pumps are similar in purpose, design, and operating principle to pumps of the NV1C design and differ from them only in that solid cylinders of the CB design are used as the cylinder, which are characterized by increased strength, wear resistance and transportability compared to cylinders of the CS design.

Downhole pumps of the HB2 design have a field of application similar to that of the downhole pumps of the HB1 design, however, they can be lowered into wells to greater depths.

Rice. 3. Insertable well pumps

Structurally, well pumps consist of a cylinder with a suction valve screwed onto the lower end.

A thrust nipple with a cone is screwed onto the suction valve. A safety valve is located at the upper end of the cylinder to prevent sand from settling in the cylinder when the pump is stopped.

A plunger with a discharge valve at the lower end and a plunger cage at the upper end is movably installed inside the cylinder. To connect the pump plunger to the sucker rod string, the pump is equipped with a rod screwed onto the plunger cage and locked with a lock nut.

There is a stop in the bore of the upper end of the cylinder.

The pump is lowered into the tubing string on a string of sucker rods and secured in a support bottom using a thrust nipple with a cone. Such fastening of the pump allows it to be unloaded from pulsating loads.

This circumstance ensures its use at great depths of wells.

Cylindersborehole pumps Available in two versions:

® Central Bank - solid (sleeveless), thick-walled;

® TsS - composite (sleeve).

The bushing pump cylinder consists of a casing in which the bushings are located. Fixation of the bushings in the casing is ensured by nuts.

The bushings are exposed to variable internal hydraulic pressure caused by the column of pumped out liquid, and constant force resulting from the end compression of the working bushings. The bushings of all pumps with different internal diameters have the same length - 300 mm.

Bushings for all pumps are made of three types: alloyed from steel grade 38ХМУА, steel from steel grades 45 and 40Х, cast iron grade SCh26-48.

Alloy bushings are made only thin-walled, steel - thin-walled, with increased wall thickness and thick-walled, cast iron - thick-walled.

To increase durability, the inner surface of the bushings is strengthened using physico-thermal methods: cast iron bushings are hardened with high-frequency currents, steel bushings are nitrided, cemented, and nitrated. As a result of this treatment, the hardness of the surface layer is up to 80 HRc.

Mechanical processing of bushings consists of grinding and honing. The main requirements for machining are a high class of accuracy and cleanliness of the internal surface, as well as perpendicularity of the ends to the axis of the bushings.

Macrogeometric deviations of the inner diameter of the bushing should be no more than 0.03 mm. The flatness of the end surfaces should provide a uniform continuous paint spot of at least 2/3 of the thickness of the bushing walls.

Seamless cylinders are a long steel tube, the inner surface of which is working. In this case, the pipe plays the role of both the cylinder and the casing at the same time. This design is free of such disadvantages as leakage between the ends of the working bushings and bending of the cylinder axis. This increases the rigidity of the pump and makes it possible to use a large diameter plunger with the same outer diameter compared to a bushing pump.

Plunger deep well pump is steel pipe with internal thread at the ends. For all pumps, the length of the plunger is constant and is 1200 mm. They are made from steel 45, 40Х or 38ХМУА. Based on the method of sealing the gap between the cylinder and the plunger, a distinction is made between fully metallic and rubberized plungers. In a pair of metal plunger - cylinder, the seal is created by a normalized gap of large length, in rubberized ones - due to cuffs or rings made of elastomer or plastic.

Currently, plungers are used (Fig. 4):

a) with a smooth surface;

b) with annular grooves;

c) with a helical groove;

d) with annular grooves, a cylindrical bore and a beveled end in the upper part (“sandbreaker”);

e) lip plungers;

e) rubberized plungers.

a - smooth (version G); b - with annular grooves (version K); in - with a screw groove (version B); g - sandbray type (version P); d - cuff, rubberized plunger; 1 - plunger body; 2 - self-sealing rubber ring; 3 - swelling rubber rings.

Sucker rods

Sucker rods are designed to transmit reciprocating motion to the pump plunger (Fig. 5). Made mainly from alloy steels round section with a diameter of 16, 19, 22, 25 mm, a length of 8000 mm and shortened ones - 1000, 1200, 1500, 2000 and 3000 mm for both normal and corrosive operating conditions.

Rice. 5 – Sucker rod

Rod code – ШН-22 means: pump rod with a diameter of 22 mm. Steel grade - steel 40, 20N2M, 30KhMA, 15NZMA and 15Kh2NMF with a yield strength from 320 to 630 MPa. Sucker rods are used in the form of columns made up of individual rods connected by couplings.

Rod couplings are produced: connecting type MSh (Fig. 6) - for connecting rods of the same size and transfer type MShP - for connecting rods of different diameters.

To connect the rods, couplings are used - MSh16, MSh19, MSh22, MSh25; the number indicates the diameter of the connected rod along the body (mm). Ochersky Machine-Building Plant JSC manufactures pump rods from uniaxially oriented fiberglass with a tensile strength of at least 800 MPa. The ends (nipples) of the rods are made of steel. Rod diameters are 19, 22, 25 mm, length 8000 – 11000 mm.

Rice. 6 – Sucker rod coupling:

a – version I; b – version II

Advantages: reducing the weight of the rods by 3 times, reducing energy consumption by 18 - 20%, increasing corrosion resistance with an increased content of hydrogen sulfide, etc. Continuous rods “Korod” are used.

Equipment for installing a sucker rod pump (SSRP)

Oil production using sucker rod pumps is the most common method of artificially lifting oil. A distinctive feature of the SHPU is that a plunger (piston) pump is installed in the well, which is driven by a surface drive through a rod string.

Compared to other mechanized methods of oil production, USPs have the following advantages:

having a high efficiency;

repairs can be carried out directly at the fields;

Various drives can be used for prime movers;

SRP units can be used in difficult operating conditions - in sand-producing wells, in the presence of paraffin in the produced oil, at a high gas factor, when pumping out corrosive liquids.

Rod pumps also have disadvantages. The main disadvantages include: limitation on the depth of pump descent (the deeper, the higher the probability of rod breakage); low pump flow; limitation on the inclination of the wellbore and the intensity of its curvature (not applicable in inclined and horizontal wells, as well as in highly curved vertical ones)

Structurally, the USP pump equipment includes a surface and an underground part.

Ground equipment includes:

· drive (pumping machine) - is an individual drive of a deep-well sucker rod pump, lowered into the well and connected to the drive by a flexible mechanical connection - a string of rods;

· wellhead fittings with polished rod seals are designed to seal the rod and seal the wellhead.

Underground equipment includes:

· tubing (tubing), which is a channel through which the produced fluid flows from the pump to the surface.

· deep pump, designed for pumping out from a well liquid watered up to 99% with a temperature of no more than 130°C, plug-in or non-plug-in types

· rods - designed to transmit reciprocating motion to the plunger of a deep-well pump from a pumping machine and is a kind of rod of a piston pump.

Figure 1 shows a diagram of a rod well pumping unit (SHPU).

Figure 1. Diagram of a rod well pumping unit (USHPU)

1 - production string; 2 - suction valve; 3 - pump cylinder; 4 - plunger; 5 - discharge valve; 6 - pump and compressor pipes; 7 - sucker rods; 8 - cross; 9 - wellhead pipe; 10 - check valve for gas bypass; 11 - tee; 12 - wellhead seal; 13 - wellhead rod; 14 - rope suspension; 15 - balancer head; 16 - balancer; 17 - stand; 18 - balancing weight; 19 - connecting rod; 20 - crank weight; 21 - crank; 22 - gearbox; 23 - driven pulley; 24 - V-belt drive; 25 - electric motor on a rotary slide; 26 - drive pulley; 27 - frame; 28 - control unit.

Installation works in the following way. The plunger pump is driven by a pumping machine, where the rotational motion received from the engine using a gearbox, crank mechanism and balancer is converted into reciprocating motion transmitted to the plunger of the sucker rod pump through a string of rods. As the plunger moves upward, the pressure in the pump cylinder decreases and the lower (suction) valve rises, opening the access of liquid (suction process). At the same time, a column of liquid located above the plunger presses the upper (discharge) valve to the seat, rises up and is thrown out of the tubing into the working manifold (discharge process).

As the plunger moves downwards, the upper valve opens, the lower valve is closed by liquid pressure, and the liquid in the cylinder flows through the hollow plunger into the tubing.

Figure 2. Pumping machine type SKD

1 - wellhead rod suspension; 2 - balancer with support; 3 - stand (pyramid); 4 - connecting rod; 5 - crank; 6 - gearbox; 7 - driven pulley; 8 - belt; 9 - electric motor; 10 - drive pulley; 11 - fence; 12 - rotary plate; 13 - frame; 14 - counterweight; 15 - traverse; 16 - brake; 17 - rope suspension.

The pumping machine (Figure 2) is an individual drive for a well pump.

The pumping machine imparts to the rods a reciprocating motion that is close to sinusoidal. The SK has a flexible rope suspension of the wellhead rod and a folding or rotating head of the balancer for the unhindered passage of hoisting mechanisms (travel block, hook, elevator) during underground repairs.

The balancer swings on a transverse axis mounted in bearings and is articulated with two massive cranks using two connecting rods located on either side of the gearbox. Cranks with movable counterweights can move relative to the axis of rotation of the main gearbox shaft to a certain distance along the cranks. Counterweights are necessary to balance the pumping machine.

All elements of the pumping machine: stand, gearbox, electric motor are attached to a single frame, which is fixed to a concrete foundation.

In addition, all SCs are equipped with a braking device necessary to hold the balancer and cranks in any given position. The point of articulation of the connecting rod with the crank can change its distance relative to the center of rotation by moving the crank pin to one or another hole. This achieves a stepwise change in the swing amplitude of the balancer, i.e. plunger stroke length.

Since the gearbox has a constant gear ratio, a change in the swing frequency is achieved only by changing the gear ratio of the V-belt transmission and changing the pulley on the electric motor shaft to a larger or smaller diameter.

Downhole rod pumps are positive displacement hydraulic machines where the seal between the plunger and the cylinder is achieved by high precision their working surfaces and regulated clearances.

Structurally, all well pumps consist of a cylinder, a plunger, valves, a lock (for plug-in pumps), connecting and installation parts. When designing pumps, the principle of maximum possible unification of the specified components and parts is observed for the convenience of replacing worn parts and reducing the range of required spare parts.

The following types of pumps are used:

· non-insertable

· plug-in.

Non-insert pumps are launched in a semi-assembled form. First, the pump cylinder is lowered onto the tubing. And then a plunger with a check valve is lowered on the rods. The non-insert pump is simple in design. The cylinder of a non-insert pump is mounted directly on the tubing string, usually in its lower part. Below the cylinder there is a locking support in which the suction valve is locked. After the cylinder and lock support are lowered into the well, the plunger begins lowering on the rod string. When the number of rods necessary for the plunger to enter the cylinder and seat the suction valve on the lock support has been lowered into the well, the final adjustment of the height of the plunger suspension is made. The suction valve is lowered into the well, secured to the lower end of the plunger using a gripping rod. When the suction valve operates the locking support, the latter locks it using a mechanical lock or friction collars. The plunger is then released from the suction valve by rotating the rod string counterclockwise. After this, the plunger assembly is raised from the suction valve to the height necessary for the plunger to move freely downwards.

Therefore, if it is necessary to replace such a pump, it is necessary to lift from the well first the plunger on rods, and then the tubing with the cylinder.

Inserted rod pumps are lowered into the well in assembled form. A locking support is first lowered into the well on or next to the last tubing.

Depending on the conditions in the well, a mechanical lower lock or a lower cuff-type lock is lowered into it if the pump has a lock at the bottom, or a mechanical top lock or an upper cuff-type lock if the pump has a lock at the top. Then the entire pumping unit with a landing unit on a locking support is lowered into the well on a rod string. After fixing the pump on the lock support, adjust the height of the plunger suspension so that it is as close as possible to the lower base of the cylinder. In wells with a high gas content, it is advisable to hang it so that the movable pump assembly almost touches the lower base of the cylinder, i.e. Minimize the distance between the suction and discharge valves during the downward stroke of the plunger. Accordingly, to change such a pump, it is not necessary to carry out the lowering and lifting of pipes once again. An insert pump works on the same principle as a non-insert pump.

Both types of pumps have both their advantages and disadvantages. For each specific condition, the most suitable type is used. For example, if the oil contains a large amount of paraffin, it is preferable to use non-insert pumps. Paraffin, deposited on the walls of the tubing, can block the ability to lift the plunger of the insert pump. For deep wells, it is preferable to use an insert pump to reduce the time spent on lowering and lifting the tubing when changing the pump.

The following types of well pumps are distinguished (Figure 3):

HB-1 - plug-in with a lock at the top;

HB-2 - plug-in with a lock at the bottom;

NN - non-plug-in without catcher;

NN-1 - non-plug-in with a gripping rod;

NN-2S - non-insertable with a catcher.

In the designation of a pump, for example, NN2BA-44-18-15-2, the first two letters and a number indicate the type of pump, the next letters indicate the design of the cylinder and pump, the first two numbers indicate the diameter of the pump (mm), the subsequent stroke length of the plunger (mm ) and pressure (m), reduced by 100 times and the last digit is the landing group.

Figure 3. Types of downhole sucker rod pumps

The use of LV pumps is preferable in wells with high flow rates, shallow descent depths and long overhaul periods, and NV type pumps in wells with low flow rates, at large descent depths. The higher the viscosity of the liquid, the higher the landing group is accepted. For pumping liquid from high temperature or high content of sand and paraffin, it is recommended to use pumps of the third landing group. For large drainage depths, it is recommended to use pumps with less clearance.

The pump is selected taking into account the composition of the pumped liquid (presence of sand, gas and water), its properties, flow rate and depth of its descent, and the diameter of the tubing depends on the type and nominal size of the pump.

The operating principle of the pumps is as follows. As the plunger moves upward, a vacuum is created in the intervalve space of the cylinder, due to which the suction valve opens and the cylinder is filled. With the subsequent downward stroke of the plunger, the intervalve volume is compressed, due to which the discharge valve opens and the liquid entering the cylinder flows into the area above the plunger. Periodic up and down movements of the plunger ensure pumping of the formation fluid and its injection to the surface into the cavity of the pipes. With each subsequent stroke of the plunger, almost the same amount of liquid enters the cylinder, which then passes into the pipes and gradually rises to the wellhead.

Most of the production wells of oil producing enterprises are equipped with sucker rod pumping units. Control of the operation of sucker rod pumps is carried out, as is known, by means of dynamometer testing. That is, by recording a diagram of the change in load on the wellhead rod as it moves up and down.

The skill of reading dynamograms and the ability to interpret them correctly is necessary for both specialists of the technological service of an oil production enterprise and specialists of the geological service.

Dynamograms help process engineers make decisions about the need for routine well repair (TRS) or, for example, the need for hot treatment of a well to remove paraffin deposits without involving a TRS team.

Geological survey specialists need the skill of reading dynamograms as the very first step in analyzing the reasons for a decrease in the flow rate of a producing well. If the dynamogram is “working”, then the problem is not with the pump. This means we can move on to searching for “geological” reasons for the decrease in flow rate.

Theoretical dynamogram

Before moving on to the analysis of real dynamograms, it is necessary to understand the theoretical dynamogram.

As is known, dynamogram is a diagram of the change in load on the wellhead rod depending on its stroke. Theoretical dynamogram- this is an idealized dynamogram that does not take into account friction forces, inertial and dynamic effects that arise in real conditions. Because of such effects, the straight lines of the theoretical dynamogram turn into wavy lines characteristic of the real one. Also, in the theoretical dynamogram, it is assumed that the cylinder of the rod pump is completely filled, that is, the pump’s flow coefficient is equal to 1, which never happens in real conditions (the pump’s flow coefficient is usually less than one).

The theoretical dynamogram has the shape of a parallelogram (Figure 1).

Figure 1. Theoretical dynamogram

Figure 2. Shroud pump diagram

Dot A on the dynamogram this is the lowest position of the pump plunger. Line segment AB- upward stroke of the polished rod. In this case, the rods are deformed (stretched), but the pump plunger is still in the lowest position. Line segment B.C.- upward stroke of the polished rod and plunger of the pump.

Dot C- extreme upper position of the pump plunger. Line segment CD- down stroke of the polished rod. In this case, the rods are deformed (compressed), but the pump plunger is still in the uppermost position. Line segment D.A.- downward stroke of the polished pump rod and plunger

In general, nothing complicated. The left part of the dynamogram characterizes the operation of the pump when the plunger is in the lower position and, accordingly, the operation of the pump suction valve. The right side of the dynamogram shows the operation of the pump when the plunger is in the upper position and, accordingly, the operation of the pump discharge valve.

Having a dynamogram of pump operation in hand, you can calculate the fluid flow rate of the well. The dynamograph, which is used to take dynamograms, also provides information about the number of swings (per minute) of the pumping machine and the stroke length of the plunger. Knowing which pump is lowered into the well, calculating the flow rate is not difficult. Formula for calculation theoretical liquid flow rate:

Q t = 1440 · π /4 · D² · L · N

Where
Q t– liquid flow rate (theoretical), m 3 /day
D– plunger diameter, m
L– stroke length, m
N– number of swings, swings/min.

The stroke length and number of swings, as I already said, are given to us by a dynamograph along with a dynamogram. The plunger diameter is usually indicated in the pump name. For example, the NGN-2-44 pump has a plunger diameter of 44 mm, and the NGN-2-57 pump has a plunger diameter of 57 mm, respectively.

In order to receive actual well fluid flow rate, it is necessary to multiply the result obtained from the formula by the pump flow rate ( η ), which, as we already know, is always less than one.

Examples of real dynamograms

Actual dynamograms come in a huge number of shapes and varieties. I won’t be able to look at all of them here, I’ll just give a few. typical examples:

Gas influence, incomplete filling of the plunger

Both valves do not work

Broken or broken rods

Plunger exit from pump cylinder

Paraffin deposits

Before finishing the article, let's consider one more question:

How often are dynamograms taken?

The policies of different oil production companies regarding the frequency of dynamograms may vary. But, as a rule, dynamograms are taken once a month on a normal, uncomplicated well stock.

If necessary, dynamograms are taken more often (for example, once a week) on a stock of wells complicated by frequent paraffin deposits. Dynamograms are also taken if there are appropriate indications (as medical professionals say). For example, when the flow rate of a well fluid decreases, when the dynamic level increases, after changing the operating parameters of a rod pump (stroke length, number of swings) and others.

If geological and technical measures (GTM) were carried out at the well, then after the well is launched until it reaches operating mode, dynamograms are usually taken daily. The same can be said about new wells launched from drilling.

General information

The most common method of oil production is the use of rod wells. pumping units(Fig.1). The flow rate of wells equipped with sucker rod pumps ranges from several hundred kilograms to several tens of tons. Pumps are lowered to depths ranging from several hundred meters to 2000 meters (in some cases up to 3000 m).

Shsnu equipment includes:

Ground equipment.

Fountain fittings.

Wellhead piping.

Rocking machine.

Underground equipment.

Pumping and compressor pipes.

Sucker rods.

Rod borehole pump.

Various safety devices (gas or sand anchor, filter, etc.)

In a well equipped with a pumping unit, fluid is supplied by a deep plunger pump, which is driven by a special drive (pumping machine) through a rod string. The pumping machine converts the rotational movement of the electric motor into the reciprocating movement of the rod suspension.

Rocking machines - individual mechanical drive ShSN (Table 19).

Table 19

Rocking machine	Number of moves balancer in min.	Weight, kg	Gearbox
SKD4-2.1-1400
SKD6-2.5-2800
SKD8-3.0-4000
SKD10-3.5-5600
SKD12-3.0-5600

The code for a rocking machine of the SKD type, for example SKD78-3-4000, indicates: letters - deaxial rocking machine, 8 - the maximum permissible load P max on the head of the balancer at the point of suspension of the rods in tons (1t = 10 kN); 3 - maximum stroke length of the wellhead rod in m; 4000 - the maximum permissible torque M cr max on the driven shaft of the gearbox in kgf/m (1 kgf/m = 10 -2 kN·m).

The pumping machine (Fig. 20) is an individual drive for a well pump.

Table 20

Rocking machine	Wellhead rod length, m	Number of swings of the balancer, min	Electric motor power, kW	Weight, kg
SKS8-3.0-4000
PNSh 60-2.1-25

The main elements of the SC are a frame (21), a stand (8) with a balancer (13), two cranks (15) with two connecting rods (14), a gearbox (16), a V-belt drive (18), an electric motor (19) and a control unit, which is connected to the field power transmission line.

The frame is made of profiled steel in the form of two runners connected to each other by crossbars. All the main components of the SC are mounted on the frame.

The stand is made of profiled rolled steel of a four-legged design with cross braces.

The balancer consists of an arc head (10) and a balancer body (13) of a single-block design.

The balancer support creates a hinged connection between the balancer and the yoke and connecting rods.

The traverse is designed to connect the balancer with two parallel connecting rods.

The connecting rod is a steel pipe blank, which is pressed against the pin at one end, and pivotally against the traverse at the other.

The crank converts the rotational motion of the driven shaft of the gearbox into the vertical reciprocating motion of the rod column.

The gearbox is designed to reduce the rotation speed transmitted from the electric motor to the cranks of the pumping machine. The gearbox is two-stage, with a cylindrical chevron gear transmission.

The brake (22) is made in the form of two pads attached to the gearbox.

The V-belt drive connects the electric motor and the gearbox and consists of V-belts, a gearbox pulley and a set of quick-change pulleys.

The electric motor is asynchronous, three-phase with increased starting torque, short-circuited, in a closed design.

The rotating slide (23) under the electric motor is used for quickly changing and tensioning V-belts.

The wellhead rod hanger is designed to connect the wellhead rod (7) to the valve body. It consists of a rope suspension (12) and upper and lower cross beams (9).

To seal the wellhead rod, the christmas tree is equipped with a stuffing box device. The wellhead rod is connected via a rod string to the plunger of a deep-well sucker rod pump.

Downhole rod pumps (OST 26-26-06-86) are reliable and economical operating equipment for oil wells, widely used for withdrawing formation fluid (a mixture of oil, water and gas).

Indicators for normal operation sucker rod pumps:

· temperature of the pumped liquid - no more than 130 C

· water cut of the pumped liquid - no more than 99%

liquid viscosity - no more than 0.025 Pa_s

water mineralization - up to 10 mg/l

· maximum concentration of mechanical impurities - up to 1.3 g/l

· hydrogen sulfide concentration - no more than 50 mg/l

· hydrogen index of produced water (pH) 4.2-8

The pump works as follows. As the plunger moves upward, a vacuum is created in the intervalve space of the cylinder, due to which the suction valve opens (the ball rises from the seat) and the cylinder is filled with the discharge valve closed. With the subsequent downward stroke of the plunger, the intervalve volume is compressed, the discharge valve opens, and the liquid entering the cylinder flows into the area above the plunger with the suction valve closed. Periodic upward and downward movements of the plunger ensure pumping of the formation fluid and its injection onto the earth's surface.

Downhole rod pumps are a vertical, single-stage, single-plunger, single-acting design with a solid fixed cylinder, movable metal plunger, discharge and suction valves.

· Pump parts are made of high-alloy and special steels and alloys;

· Thick-walled pump cylinder with chrome plating and nitriding 70 HRC, cylinder length 4200 mm;

· Plunger made of carbon steel with chrome plating and nitriding 67-71 HRC of the outer surface;

· Pump straightness 0.08mm over a length of 1000mm;

· Surface roughness of the cylinder and plunger is 0.2 microns;

· Valve pairs made of stellite or tungsten carbide material;

· On the bottom (outer) side of the pump there is a thread pipe thread for hanging a “shank” or additional equipment(filter, GPU, etc.)

· In the upper part of the pump (not plug-in), a 0.5 m long pipe with a coupling is screwed in for working with keys and an elevator when lowering it into the well.

SRP are available in two types:

· Plug-in

HB1 is a plug-in well pump with a solid cylinder and an upper locking support.

· Non-insertable (pipe)

NN2B is a non-insert well pump with a solid cylinder and a drain valve.

Currently mainly used

· non-insert pumps type NN-2B with a nominal size (plunger diameter) of 32, 44, 57 and 68 mm, as well as

· insert pumps NV1B -28, NV1B - 32, NV1B - 44 and NV1B - 57 mm with an upper locking support.

The symbol includes:

pump type;

cylinder design;

nominal size (plunger diameter) of the pump;

plunger stroke in mm reduced by 100 times;

pump pressure in m reduced by 100 times;

boarding group;

performance in terms of resistance to the environment;

design features;

Examples symbols pump:

NV1BP - 44-18-12-2-I OST26-16-06-86 - plug-in pump, cylinder design B (thick-walled, sleeveless, solid), for operation with a high sand content (more than 1.3 g/l.) , nominal size (diameter) 44 mm, plunger stroke 1800 mm, head 1200 m, 2 landing groups and wear-resistant to aggressive environments - I.

1 - lock; 2 - rod; 3 - emphasis; 4 - lock nut; 5 - plunger cage; 6 - cylinder; 7 - plunger; 8 - discharge valve; 9 - suction valve

NN2B-57-30-12-1 OST 26-16-06-86 - non-insert pump, cylinder design B (thick-walled, sleeveless, solid), nominal size (diameter) 57mm, plunger stroke 3000mm, head 1200m, 1 group fit, normal design in terms of resistance to the pumped out medium.

1 - cylinder; 2 - rod; 3 - plunger cage; 4 - plunger; 5 - discharge valve; 6 - catcher rod; 7 - suction valve; 8 - cone saddle;

Rod pumps according to OST 26-16-06-86 correspond to ST - SEV 4355-83, GOST 6444-86.

Table No. 21.

Pump version	Conditional dimensions (mm)	Rod thread (mm)	Plunger stroke length (mm)
	44/28,57/32,70/44

Pump type:

HB1 - plug-in with a lock at the top

HB2 - plug-in with a lock at the bottom

NN - non-plug-in without catcher

НН1 - non-insertable with gripping rod

НН2 - non-plug-in with catcher

B - sleeveless pump cylinder

C - pump cylinder with bushings

Classification of pumps by design features- Areas of use.

T - with a hollow (tubular) rod, ensuring the rise of liquid along the channel of the column of hollow rods

A - with a coupling device (automatic coupler) (only for low voltage) ensuring coupling of the rod string with the pump plunger.

D1 - single-stage, double-plunger - ensuring the creation of a hydraulic heavy bottom.

D2 - two-stage, two-plunger - providing two-stage compression of the pumped out liquid

U - with an unloaded cylinder (only for НН2) ensuring removal from the cylinder cyclic load at work.

In the assembled pump, the plunger, lubricated with spindle oil, should move smoothly and without jamming along the entire length of the cylinder, depending on the fit group indicated in table No. 22.

Force of movement of the plunger in the pump cylinder (maximum)

Table No. 22.

The fit of the plunger in the pump cylinder is characterized by the maximum clearance values ​​(per diameter) between the plunger and the cylinder. Depending on the maximum clearance values, pumps are produced in the following fit groups:

“0” group - up to 0.045mm.

“1” group - from 0.020 to 0.070mm

“2” group - from 0.070 to 0.120 mm

“3” group - from 0.120 to 0.170mm

Groups for seating the plunger in the pump cylinder according to the API (American Petroleum Institute) standard.

Table No. 23.

Boarding group	Gap range (mm).

Incoming control of sucker rod pumps

When the sucker rod pumps arrive at the oil and gas production department, the pumps undergo incoming inspection. Incoming inspection is carried out by the chief mechanic service.

Checking quality and completeness

· Quality and completeness checks are carried out in the repair shop of sucker rod pumps after they are transferred from the oil and gas production department to Neftepromremont LLC in accordance with the transfer certificate.

· Checking the quality and completeness of pumps is carried out by competent specialists of NPR LLC, if necessary, in the presence of a representative of the NGDU (owner of the pumping unit) and a representative of the manufacturer (if serious defects are detected) with the drawing up of an appropriate bilateral report.

· It is allowed to accept pumps for quality unilaterally with the consent of the manufacturer.

· On the day of completion of pump acceptance, a report is drawn up and signed by all persons involved in the quality control. A copy of the invoice is attached to the act. The act is approved by the chief engineer of NPR LLC.

· When monitoring the quality of a sucker rod pump for external defects, the number indicated in the passport is checked against the actual number stamped on the sub of the sleeve cylinder and on the bore of a solid - sleeveless cylinder. In the absence of a factory passport, the actual number of the pump is recorded.

Pumps are rejected in the following cases:

· in case of failure of the plunger to pass into the cylinder (for non-insert-in pumps) connected to a tubing nozzle with a length of at least 1200 mm;

· in case of a discrepancy between the number of the plunger and its size indicated in the passport with the actual one, if the number does not match, but the size of the plunger matches, the actual data is entered into the operational passport;

· if the integrity of the chrome plating coating is damaged (delamination, risks, cracks, etc.);

· if at least one used part is found in the pump;

· if the pump cylinder is bent or bent;

· if traces of rough processing of the surfaces of the cylinder and plunger after chrome plating are detected;

· Before sending the sucker rod pump to the well, the main components of the pump and the smooth movement of the plunger in the cylinder are checked by external inspection.

· If there is sticking, jerking, knocking or the impossibility of the plunger passing along the entire length of the cylinder, the pump is rejected.

· In inserted pumps, the condition of the support cone, the quality of assembly, and fastening are additionally checked threaded connections and the quality of the seating surface of the lock support. The plunger of the insert pump is removed for inspection after unscrewing the thrust nipple.

· The tightness of the cylinder assembled with a suction valve and the plunger with a discharge valve, for plug-in pumps assembled with a lock support, is checked by testing with spindle oil at a temperature of 20 C to a pressure P = 150 atm.

· After checking the completeness and quality of the pump pump, NPR LLC issues an operational certificate for the pump, which contains data on the date of inspection, results of pressure testing and configuration.

Transportation of sucker rod pumps to the well

· Rod pumps are delivered to the well on a PS-0.5 field self-loader equipped with a rotating hydraulic crane with a lifting capacity of 5 tons or on any other vehicle that provides loading, unloading and transportation of rod pumps without bending them. To protect pumps from clogging, special threaded plugs (caps) must be installed in the end couplings; plug-in pumps must have a locking support protected from damage.

· During transportation, SRP are installed on the vehicle platform in an inclined position, secured against possible movement with special clamps with screw clamps.

· At the well, the pump is unloaded using universal slings and grips using a crane and placed in a clean horizontal place on 3-4 wooden pads or on a walkway. Rolling the pump from the platform to the ground, placing it on pipes, rods, wellhead fittings, or installing it in an inclined position is strictly prohibited.

· Pumps lifted from the well are delivered to NPR LLC also at vehicles intended for transportation of rigidly secured sucker rod pumps. Disassembling the pump at the well is prohibited.

Organization of work during the repair of wells equipped with ultrasonic pumping units

Wells equipped with ultrasonic pumping units are submitted for repair based on the conclusion of the oil field technological service and on the basis of measures on the need for underground repairs.

The basis for raising the CPRP is a reduction or cessation of supply. The cause of the malfunction must be determined in advance based on the dynamogram data taken before lifting and noted in the operational passport signed by the oil field technologist.

In the reason for refusal column, the general entry “no submission” is not allowed. The final decision on changing the pump rod is made by the TsDNG technologist and a note in the operational passport. The PRS team goes to the well to lift the sucker rod pump if they have a fully completed operational passport.

The necessary order and scope of work on wells equipped with USGDU is formed when drawing up a schedule for the movement of underground well repair teams from the NGDU, which is attended by representatives of the services and workshops of the NGDU (CITS, PTO, TsDNG, TsNIPR, CPRS).

The movement schedule of the workover crews is approved by the chief engineer of the NGDU.

For wells from the frequently repaired stock (3 or more failures of the pumping unit in a rolling year), a separate work plan is drawn up, which is agreed upon by the oil field, CPRS, LTTND, and when considering the schedule, these wells are included in the movement of the crews.

The scope of work is determined based on

· studying the operating mode of a failed USP,

reasons for failures of previous installations,

· well characteristics,

· type of work (change of sucker rod pump, commissioning after drilling, transfer to sucker rod pump)

· templating of the production string (in the presence of tightenings, landings during the process of tripping of the UGP equipment), it is recommended to lower the template to a depth of 150 m above the perforation interval, the diameter of the template is 120 mm and the length is 9 m;

· scraping of the production string (in case of tightening and failure to pass the template during tripping, with a hydraulic or mechanical scraper to the depth of the template, followed by flushing of the wellbore (carried out at least once every three years or when commissioning from inactivity - more than 3 years);

Determination of the current bottom of the well is carried out according to the application of the oil field:

· after cleaning the face with a bailer and washing;

· after an accident, “flights” of the USGN to the bottom of the well;

· in case of frequent failures of the pumping unit associated with the ingress of sand, solid impurities, and paraffin into the pump;

· after work on development of the formation or work on cleaning the bottomhole zone of the formation;

Borehole cleaning, well flushing:

· after carrying out hydrochloric acid treatments and other treatments of the bottomhole zone;

· based on the results of measuring the current bottom of the well;

Repair technology for wells equipped with ultrasonic pumping units

· Repair of wells equipped with sucker rod pumps is carried out by specialized repair teams according to the work plan and in accordance with the Maintenance Rules repair work and other regulations.

· Before killing the well, the static level H st and formation pressure P pl are measured. Based on the measurement results, the oil field makes a decision on killing or repair without killing (in accordance with the list of wells agreed with the UZSO GGTN).

· Well killing is carried out in accordance with the instructions in force at JSC Tomskneft VNK for killing wells equipped with ultrasonic pumping units.

The oil field is responsible for the reliability of information about the well’s readiness for killing.

· The killing results are documented in a report indicating the type of killing fluid, its volume, density, pressure and cycles during killing. The report is signed by the jamming master, transferred to the PRS team and stored together with launch documentation for well repair.

· The team begins to repair the well only if there is a work plan (work order) approved and agreed upon by the Central Distribution Center and the Central Power Plant, as well as a fully completed operational passport for the USGN. The oil field technologist is responsible for the quality of filling out the passport.

Before repairing a well, the following must be carried out: preparatory work:

§ secure the polished rod with a special clamp;

§ dismantle the rope suspension;

§ tilt the balancer head.

After carrying out repair work on the well, the TRS team, in the presence of a representative of the CDNG, must call the supply and pressurize the tubing with a pump and draw up a report on the acceptance of the well from repair. When the tubing is tight and the pump is operating stable, the pumping machine is put into operation.

§ The foreman of the pumping station (workover) team fills out the operational passport of the sucker rod pump indicating all the parameters of the layout of the lowered underground equipment (tubing diameter, rods and quantity, presence and number of centralizers, filter, gas pressure pump, etc.)

The act of handing over the well from repair is signed after 72 hours of trouble-free operation of the sucker rod pump by a representative of the oil field. The basis for signing the act of handing over the well from repair is the measurement of the well's flow rate and a dynamogram taken after the well was launched. The well repair report is accompanied by an operational certificate for the sucker rod pump, which must be stored together with the report and, during subsequent repairs, be transferred to the CPRS with data on the operation of the pump filled in.

Launch of wells equipped with USGN

2 hours before the launch of the well, the TRS team confirms the request to call a representative of the oil field. The application is submitted to the dispatcher or oil field technologist.

Reception of wells equipped with ultrasonic pumping units from repairs is carried out around the clock. On the first shift, as a CPRS (workover) foreman and an oil field foreman (or their substitutes), on the second shift, as a senior oil field operator and a senior oil field operator.

Before starting a well with an ultrasonic pumping unit, check the serviceability of the surface equipment:

o on the wellhead fittings - a check valve and valves, an echo sounding pipe with free access to it, a sampling valve on the flow line, etc.;

o operability of the Sputnik group measuring installation;

o tightness of pump-compressor pipes and LPG;

The launch and commissioning of a well equipped with a pumping unit is carried out by the oil and gas production operator.

Oil production operator does everything necessary operations with wellhead fittings, manifold, AGZU “Sputnik”, provides control over the amount of flow from the well and transfer of data to the oil field dispatcher (technologist).

Monitoring of changes in the fluid level in the annulus and dynamometer testing of wells is carried out by a research operator or oil production operator (at least once a day, measurement of Ndin, Pz, and dynamometer testing).

Responsibility for bringing wells into operation, timely shutdown of the pumping unit in abnormal conditions, or startup when the equipment is not ready (failure of the Sputnik gas pumping unit, leakage of valves, check valve at the annulus, etc.) is carried out by the oil field technological service and the production team foreman. The decision on how to bring the pump into operation or stop it to eliminate identified problems is made by the leading oil field technologist.

· Before pressure testing the well, determine the flow rate, assemble the wellhead seal (SUSG) with a polished rod, install a pressure gauge (scale no more than 100 atm.) on the manifold line.

· By reciprocating the rods with the help of a lifting unit, raise the pressure on the manifold line according to the pressure gauge - 30 atm.

· Observe the pressure drop on the pressure gauge when the annular valve is open.

The USP is considered suitable for operation if, during pressure testing, the pump raises the pressure to 30 atm. and when the swing stops, the pressure drop does not exceed 5 atm. in 15 minutes. At the same time, there should be no gas or liquid leaks in the lower oil seal and connections of the Christmas tree equipment.

· After crimping, the polished rod is connected to the suspended traverse and the machine - the rocking chair is put into operation.

· Within 2 hours after startup, the survey operator or the d/n operator needs to measure the well flow rate, the fluid level in the annulus and perform dynamometer testing. In the event of a low (high) plunger fit, or the upper coupling of the rods hitting the SUSG, the PRS team re-adjusts the plunger fit.

· All documents on the well are signed by the oil field foreman and technologist after 72 hours of trouble-free operation of underground equipment, provided that all the oil field's comments indicated when accepting the well from repair have been corrected.

When accepting a well from repair, the following requirements are imposed on the equipment of the pumping unit and the well area:

When the balancer head is in the lowest position, the distance between the gland rod suspension traverse or the rod holder and the wellhead gland should be no more than 200 mm.

Flange connections of the Christmas tree and wellhead piping must be sealed and have full set fasteners

The wellhead and well area and sucker rod equipment must be cleared of oil contamination, and the well cluster area must be cleared of pipes, rods and equipment used in well repair.

Bringing wells equipped with coal pumping units to operating mode

The purpose of the operation to bring a well with a USP pump into operation is to ensure the pump’s operability in initial period putting the well into operation after repair.

Before launching a well equipped with a USP

· check the readiness of ground equipment,

· measure the static level and

· start the installation.

In the operational passport, note the time of appearance of the feed.

Measure the well flow (Qzh) using the Sputnik AGZU, compare it with the theoretical productivity of the deflated pump; then a dynamogram is taken and a fluid sample is taken.

In the initial period after the launch of the USP, regular monitoring of the feed rate and the rate of decrease in the dynamic level is carried out. It is not allowed to pump out a level lower than 200m above the pump inlet.

When the well is brought into operation, the frequency of measurements is H dyn. and Qf should be determined by the technological service for each well individually.

The magnitude of the dynamic level in the well and the performance of the pumping unit are determined using an echo sounder and a dynamograph.

IN winter time, in cases of long-term shutdown of the well for inflow, measures must be taken to prevent freezing of the reservoir.

The ramp-up time is determined for each well individually.

A well is considered to be brought into operation if the results of 3 dynamic level measurements taken at intervals of at least 1 hour are close in value at constant productivity.

The person performing the work to bring a well with a pressure-pulling pump into operation (the production operator or the exploration operator) must transmit information to the oil field dispatcher on a shift basis.

After bringing the well to operating mode with an ultrasonic pumping unit, 1 day later, perform

· measurement of the dynamic level H dyn.,

· well productivity Qw,

· sampling of liquid for water content of products and fur content. impurities,

· remove the dynamogram.

Fill in the appropriate columns of the operational passport for the USP for bringing it into operation, if necessary, attaching supporting documents (dynamograms, measurement results, etc.).

Operation of wells with ultrasonic pumping units

· After bringing the well to a steady state, the oil field submits an application for work on additional balancing of the pumping machine.

· Within two days from the moment of launching the USP, the oil field monitors its operation. In the future, the well's operation is monitored by dynamometers, measurements of fluid flow rate, wellhead pressure and dynamic level.

· During the first two weeks of operation of the pumping unit, the oil field conducts a set of studies at the well in order to determine the optimal operating mode of the deflated pump.

· Any change in the operating modes of a well equipped with a pumping unit must be justified by calculations. The oil field technologist is responsible for timely calculations and systematic changes to the operating mode of the CP pump.

A permanent commission to investigate premature failures of pressure pumping units investigates the causes of failures of pumps with operating hours of up to 100 days.

Frequency of monitoring the operation of wells with ultrasonic pumping units

Table No. 24

Controlled parameter	Control method	Frequency of control
1. Rod loads and feed	Dynamometry	After starting the well and entering the mode When changing the operating mode Before PRS Current control at least 2 times a month.
Measurement of liquid flow rate from one temporary level offset.	According to AGZU counters and wave meters.	After starting and entering the well mode. When changing the operating mode. Before PRS.
Sampling liquids at water cut (%)	After the well was withdrawn. to mode. When changing the operating mode. Current control at least once a month.
4. Sampling for EHF	After starting and putting the well into mode. 4.2. Current control at least once a month.

Operational data must be promptly entered into the operational passport of the USGP; the oil field technologist is responsible for filling out the passport.