What does ecn consist of? Installation of an electric centrifugal pump (uetsn)

ESP scheme

ESP - installation of an electric submersible pump, in the English version - ESP (electric submersible pump). In terms of the number of wells in which such pumps operate, they are inferior to SRP units, but in terms of the volume of oil produced with their help, ESPs are unrivaled. About 80% of all oil in Russia is produced with the help of ESPs.

In general, the ESP is an ordinary pumping unit, only thin and long. And he knows how to work in an environment that is distinguished by its aggressiveness to the mechanisms present in it. It consists of a submersible pump unit (electric motor with hydraulic protection + pump), cable line, tubing string, wellhead equipment and surface equipment (transformer and control station).

The main components of the ESP:

ESP (electric centrifugal pump)- a key element of the installation, which actually lifts the liquid from the well to the surface. It consists of sections, which in turn consist of steps (guides) and a large number of impellers assembled on a shaft and enclosed in a steel casing (pipe). The main characteristics of the ESP are flow rate and head, so these parameters are present in the name of each pump. For example, ESP-60-1200 pumps 60 m 3 /day of liquid with a head of 1200 meters.

SEM (submersible electric motor) is the second most important element. It is an asynchronous electric motor filled with special oil.

Protector (or waterproofing)- an element located between the electric motor and the pump. Separates the electric motor filled with oil from the pump filled with reservoir fluid and at the same time transfers rotation from the motor to the pump.

Cable, through which electricity is supplied to the submersible motor. The cable is armored. On the surface and to the depth of the descent of the pump, it is of circular cross section (KRBK), and in the area of ​​the submersible unit along the pump and hydraulic protection it is flat (KPBK).

Optional equipment:

gas separator- used to reduce the amount of gas at the pump inlet. If there is no need to reduce the amount of gas, then a simple input module is used, through which the well fluid enters the pump.

TMS– thermomanometric system. Thermometer and pressure gauge rolled into one. Gives us data on the temperature and pressure of the medium in which the ESP running down into the well operates.

This entire installation is assembled directly when it is lowered into the well. It is assembled sequentially from the bottom up, not forgetting about the cable, which is fastened to the installation itself and to the tubing, on which it all hangs, with special metal belts. On the surface, the cable is fed to a step-up transformer (TMPN) and a control station installed near the cluster.

In addition to the already listed units, check and drain valves are installed in the tubing string above the electric centrifugal pump.

check valve(KOSH - check ball valve) is used to fill the tubing with liquid before starting the pump. It does not allow the liquid to drain down when the pump stops. During pump operation, the check valve is in the open position due to the pressure from below.

Mounted above the check valve drain valve (KS), which is used to drain fluid from the tubing before pulling the pump out of the well.

Electric centrifugal submersible pumps have significant advantages over deep rod pumps:

• Ease of ground equipment;
• Possibility of fluid extraction from wells up to 15000 m 3 /day;
• The ability to use them in wells with a depth of more than 3000 meters;
• High (from 500 days to 2-3 years or more) ESP operation overhaul period;
• Possibility of conducting research in wells without lifting pumping equipment;
• Less time-consuming methods for removing wax from tubing walls.

Electric centrifugal submersible pumps can be used in deep and inclined oil wells (and even in horizontal ones), in heavily watered wells, in wells with iodine-bromide waters, with high salinity of formation waters, for lifting salt and acid solutions. In addition, electric centrifugal pumps have been developed and are being produced for the simultaneous-separate operation of several horizons in one well with 146 mm and 168 mm casing strings. Sometimes electric centrifugal pumps are also used to pump saline formation water into an oil reservoir in order to maintain reservoir pressure.

The scope of ESP is high-rate flooded, deep and inclined wells with a flow rate of 10 ¸ 1300 m3/day and a lift height of 500 ¸ 2000 m. The overhaul period of the ESP is up to 320 days or more.

Units of modular submersible centrifugal pumps of the UETsNM and UETsNMK types are designed for pumping oil well products containing oil, water, gas and mechanical impurities. Units of the UETsNM type have a conventional design, while those of the UETsNMK type are corrosion-resistant.

The installation (Figure 24) consists of a submersible pumping unit, a cable line lowered into the well on tubing, and ground electrical equipment (transformer substation).

The submersible pumping unit includes an engine (an electric motor with hydraulic protection) and a pump, above which a check and drain valve is installed.

Depending on the maximum transverse dimension of the submersible unit, the installations are divided into three conditional groups - 5; 5A and 6:

· installations of group 5 with a transverse dimension of 112 mm are used in wells with a casing string with an internal diameter of at least 121.7 mm;

· installations of group 5A with a transverse dimension of 124 mm - in wells with an internal diameter of at least 130 mm;

· installations of group 6 with a transverse dimension of 140.5 mm - in wells with an internal diameter of at least 148.3 mm.

ESP applicability conditions for pumped media: liquid with a content of mechanical impurities not more than 0.5 g/l, free gas at the pump intake not more than 25%; hydrogen sulfide not more than 1.25 g/l; water not more than 99%; the pH value (pH) of formation water is within 6 ¸ 8.5. The temperature in the electric motor location area is not more than + 90 ˚С (special heat-resistant version up to + 140 ˚С).

An example of a code for installations - UETsNMK5-125-1300 means: UETsNMK - installation of an electric centrifugal pump of a modular and corrosion-resistant design; 5 - pump group; 125 - supply, m3/day; 1300 - developed pressure, m of water. Art.

Figure 24 - Installation of a submersible centrifugal pump

1 - wellhead equipment; 2 - remote connection point; 3 - transformer complex substation; 4 - drain valve; 5 - Check Valve; 6 - head module; 7 - cable; 8 - module-section; 9 - pump gas separator module; 10 - initial module; 11 - protector; 12 - electric motor; 13 - thermomanometric system.

Figure 24 shows a diagram of the installation of submersible centrifugal pumps in a modular design, representing a new generation of equipment of this type, which allows you to individually select the optimal layout of the installation for wells in accordance with their parameters from a small number of interchangeable modules. ”, Moscow) provide optimal selection of the pump to the well, which is achieved by the presence of a large number of heads for each supply. The head spacing of the units ranges from 50 ¸ 100 to 200 ¸ 250 m, depending on the supply, in the intervals indicated in table 6 of the basic data of the installations.

Commercially produced ESPs have a length of 15.5 to 39.2 m and a weight of 626 to 2541 kg, depending on the number of modules (sections) and their parameters.

In modern installations, from 2 to 4 modules-sections can be included. A package of steps is inserted into the section housing, which is impellers and guide vanes assembled on the shaft. The number of stages ranges from 152 ¸ 393. The inlet module represents the base of the pump with intake holes and a mesh filter through which the fluid from the well enters the pump. At the top of the pump is a fishing head with a check valve, to which the tubing is attached.

Table 6

Name of installations	Minimum (internal) diameter of the production string, mm	Transverse dimension of the installation, mm	Supply m3/day		Engine power, kW	Gas separator type
UETsNMK5-80
UETsNMK5-125
UETsNM5A-160
UETsNM5A-250
UETsNMK5-250
UETsNM5A-400
UETsNMK5A-400
	144.3 or 148.3	137 or 140.5
UETsNM6-1000

Pump (ETsNM) - submersible centrifugal modular multistage vertical execution.

Pumps are also divided into three conditional groups - 5; 5A and 6. Case diameters of group 5 ¸ 92 mm, group 5A - 103 mm, group 6 - 114 mm.

The pump section module (Figure 25) consists of a housing 1 , shaft 2 , packages of steps (impellers - 3 and guide vanes - 4 ), upper bearing 5 , lower bearing 6 , top axial support 7 , heads 8 , grounds 9 , two edges 10 (serve to protect the cable from mechanical damage) and rubber rings 11 , 12 , 13 .

The impellers move freely along the shaft in the axial direction and are limited in movement by the lower and upper guide vanes. The axial force from the impeller is transmitted to the lower textolite ring and then to the shoulder of the guide vane. Partially, the axial force is transferred to the shaft due to friction of the wheel on the shaft or sticking of the wheel to the shaft due to the deposition of salts in the gap or corrosion of metals. The torque is transmitted from the shaft to the wheels by a brass (L62) key, which is included in the groove of the impeller. The key is located along the entire length of the wheel assembly and consists of segments 400 - 1000 mm long.

Figure 25 - Module-section pump

1 - frame; 2 - shaft; 3 - working wheel; 4 - guiding apparatus; 5 - upper bearing; 6 - lower bearing; 7 - axial upper support; 8 - head; 9 - base; 10 - edge; 11 , 12 , 13 - rubber rings.

The guide vanes are articulated with each other along the peripheral parts, in the lower part of the housing they all rest on the lower bearing 6 (picture 25) and base 9 , and from above through the housing of the upper bearing are clamped in the housing.

Impellers and guide vanes of standard pumps are made of modified gray cast iron and radiation-modified polyamide, corrosion-resistant pumps are made of modified cast iron TsN16D71KhSh of the "niresist" type.

Shafts of section modules and input modules for conventional pumps are made of combined corrosion-resistant high-strength steel OZKh14N7V and are marked “NZh” at the end. "M".

Shafts of modules-sections of all groups of pumps, having the same casing lengths of 3, 4 and 5 m, are unified.

Shafts of section modules are connected to each other, a section module with the input module shaft (or gas separator shaft), the input module shaft with the engine hydroprotection shaft is connected using splined couplings.

The connection of the modules to each other and the input module with the motor is flanged. Sealing of connections (except for the connection of the input module with the engine and the input module with the gas separator) is carried out with rubber rings.

To pump out formation fluid containing more than 25% (up to 55%) of free gas at the grid of the pump inlet module, a pump module - gas separator is connected to the pump (Figure 26).

Figure 26 - Gas separator

1 - head; 2 - translator; 3 - separator; 4 - frame; 5 - shaft; 6 - lattice; 7 - guide apparatus; 8 - Working wheel; 9 - auger; 10 - bearing; 11 - base.

The gas separator is installed between the input module and the section module. The most efficient gas separators are of the centrifugal type, in which the phases are separated in the field of centrifugal forces. In this case, the liquid is concentrated in the peripheral part, and the gas is concentrated in the central part of the gas separator and is ejected into the annulus. Gas separators of the MNG series have a limit flow of 250 ¸ 500 m3/day, a separation factor of 90%, and a weight of 26 to 42 kg.

The engine of the submersible pumping unit consists of an electric motor and hydraulic protection. Electric motors (Figure 27) submersible three-phase squirrel-cage bipolar oil-filled conventional and corrosion-resistant version of the unified series of PEDU and in the usual version of the series of retrofit PED L. Hydrostatic pressure in the operating area is not more than 20 MPa. Rated power from 16 to 360 kW, rated voltage 530 ¸ 2300 V, rated current 26 ¸ 122.5 A.

Figure 27 - PEDU series electric motor

1 - coupling; 2 - lid; 3 - head; 4 - heel; 5 - thrust bearing; 6 - cable entry cover; 7 - cork; 8 - cable entry block; 9 - rotor; 10 - stator; 11 - filter; 12 - base.

Hydroprotection (Figure 28) of SEM motors is designed to prevent the penetration of formation fluid into the internal cavity of the electric motor, to compensate for changes in the volume of oil in the internal cavity due to the temperature of the electric motor and to transfer torque from the electric motor shaft to the pump shaft.

Figure 28 - Hydroprotection

a- open type; b- closed type

BUT- upper chamber; B- down Cam; 1 - head; 2 - mechanical seal; 3 - top nipple; 4 - frame; 5 - middle nipple; 6 - shaft; 7 - lower nipple; 8 - base; 9 - connecting tube; 10 - aperture.

Hydroprotection consists either of one protector, or of a protector and a compensator. There are three versions of the hydroprotection.

The first one consists of protectors P92, PK92 and P114 (open type) from two chambers. The upper chamber is filled with a heavy barrier fluid (density up to 2 g/cm3, not miscible with formation fluid and oil), the lower chamber is filled with MA‑SED oil, which is the same as the cavity of the electric motor. The chambers are communicated by a tube. Changes in the volumes of the liquid dielectric in the engine are compensated by the transfer of the barrier liquid in the hydraulic protection from one chamber to another.

The second one consists of protectors P92D, PK92D and P114D (closed type), in which rubber diaphragms are used, their elasticity compensates for the change in the volume of the liquid dielectric in the engine.

The third - hydraulic protection 1G51M and 1G62 consists of a protector placed above the electric motor and a compensator attached to the bottom of the electric motor. The mechanical seal system provides protection against ingress of formation fluid along the shaft into the electric motor. Transmitted power of hydraulic protection 125 ¸ 250 kW, weight 53 ¸ 59 kg.

The thermomanometric system TMS-3 is designed for automatic control of the operation of a submersible centrifugal pump and its protection against abnormal operating modes (at reduced pressure at the pump intake and elevated temperature of the submersible motor) during well operation. There are underground and ground parts. Controlled pressure range from 0 to 20 MPa. Operating temperature range from 25 to 105 ˚С.

The total weight is 10.2 kg (see figure 24).

The cable line is a cable assembly wound on a cable drum.

The cable assembly consists of the main cable - a round PKBK (cable, polyethylene insulation, armored, round) or flat - KPBP (Figure 29), a flat cable attached to it with a cable entry sleeve (extension cable with a sleeve).

Figure 29 - Cables

a- round; b- flat; 1 - lived; 2 - isolation; 3 - shell; 4 - pillow; 5 - armor.

The cable consists of three cores, each of which has an insulation layer and a sheath; cushions made of rubberized fabric and armor. Three insulated conductors of a round cable are twisted along a helical line, and the conductors of a flat cable are laid in parallel in one row.

The KFSB cable with PTFE insulation is designed for operation at ambient temperatures up to + 160 ˚С.

The cable assembly has a unified cable gland K38 (K46) of round type. In the metal case of the coupling, the insulated cores of the flat cable are hermetically sealed with a rubber seal.

Plug-in lugs are attached to the conductive wires.

The round cable has a diameter of 25 to 44 mm. Flat cable size from 10.1x25.7 to 19.7x52.3 mm. Nominal construction length 850, 1000 ¸ 1800 m.

Complete devices of the ShGS5805 type provide switching on and off of submersible motors, remote control from the control room and program control, operation in manual and automatic modes, shutdown in case of overload and deviation of the mains voltage above 10% or below 15% of the nominal, current and voltage control, as well as an external light signaling of an emergency shutdown (including with a built-in thermometric system).

Integrated transformer substation for submersible pumps - KTPPN is designed to supply electricity and protect electric motors of submersible pumps from single wells with a capacity of 16 ¸ 125 kW inclusive. Rated high voltage 6 or 10 kV, medium voltage regulation limits from 1208 to 444 V (TMPN100 transformer) and from 2406 to 1652 V (TMPN160). Weight with transformer 2705 kg.

The complete transformer substation KTPPNKS is designed for power supply, control and protection of four centrifugal electric pumps with electric motors 16 ¸ 125 kW for oil production in well clusters, power supply for up to four electric motors of pumping units and mobile pantographs during repair work. KTPPNKS is designed for use in the conditions of the Far North and Western Siberia.

The delivery set of the installation includes: a pump, a cable assembly, a motor, a transformer, a complete transformer substation, a complete device, a gas separator and a set of tools.

The ESP plant is a complex technical system and, despite the well-known principle of operation of a centrifugal pump, it is a combination of elements that are original in design. The schematic diagram of the ESP is shown in fig. 6.1. The installation consists of two parts: ground and submersible. The ground part includes an autotransformer 1; control station 2; sometimes a cable drum 3 and wellhead equipment 4. The submersible part includes a tubing string 5, on which the submersible unit is lowered into the well; armored three-core electric cable 6, through which the supply voltage is supplied to the submersible electric motor and which is attached to the tubing string with special clamps 7.

The submersible unit consists of a multistage centrifugal pump 8 equipped with a suction screen 9 and a check valve 10. The submersible unit includes a drain valve 11 through which liquid is drained from the tubing when the unit is lifted. In the lower part, the pump is articulated with a hydraulic protection unit (protector) 12, which, in turn, is articulated with a submersible motor 13. In the lower part, the motor 13 has a compensator 14.

The liquid enters the pump through a mesh located in its lower part. The mesh provides formation fluid filtration. The pump supplies fluid from the well to the tubing.

ESP units in Russia are designed for wells with casing strings with a diameter of 127, 140, 146 and 168 mm. Two sizes of submersible units are available for 146 and 168 mm casing strings. One is designed for wells with the smallest internal diameter (according to GOST) of the casing string. In this case, the ESP unit also has a smaller diameter, and, consequently, lower limit values ​​for the operating characteristic (pressure, flow, efficiency).

Rice. 6.1. Schematic diagram of the ESP:

1 - autotransformer; 2 - control station; 3 - cable drum; 4 - wellhead equipment; 5 - tubing string; 6 - armored electrical cable; 7 - cable clamps; 8 - submersible multistage centrifugal pump; 9 - receiving grid of the pump; 10 - check valve; 11 - drain valve; 12 - hydraulic protection unit (protector); 13 - submersible motor; 14 - compensator

Each installation has its own code, for example, UETsN5A-500-800, in which the following designations are accepted: a number (or a number and a letter) after the ESP indicates the smallest permissible inner diameter of the casing string into which it can be lowered, the number "4" corresponds to a diameter of 112 mm , the number "5" corresponds to 122 mm, "5A" - 130 mm, "6" - 144 mm and "6A" - 148 mm; the second number of the code indicates the nominal flow of the pump (in m 3 / sU t) and the third - the approximate head in m. The values ​​​​of flow and head are given for operation on water.

In recent years, the range of manufactured centrifugal pump installations has expanded significantly, which is also reflected in the codes of the manufactured equipment. Thus, ESP units manufactured by ALNAS (Almetyevsk, Tatarstan) have a capital letter “A” in the cipher after the inscription “ESP”, and units of the Lebedyansky Mechanical Plant (JSC Lemaz, Lebedyan, Kursk Region) have a capital letter the letter "L" before the inscription "UESP". Units of centrifugal pumps with a two-bearing design of the impeller, intended for the selection of reservoir fluid with a large amount of mechanical impurities, have in their code "2" after the letter "L" and before the inscription ESP (for Lemaz pumps), the letter "D" after the inscription "UETsN" (for pumps "JSC "Borets"), the letter "A" before the figure of the installation size (for pumps ALNAS). The corrosion-resistant version of the ESP is indicated by the letter "K" at the end of the installation code, the heat-resistant version is indicated by the letter "T". The design of the impeller with additional vortex blades on the rear disk (Novomet, Perm) has the letter VNNP in the pump code.

6.3. The main components of the ESP installation, their purpose and characteristics

Downhole centrifugal pumps

Borehole centrifugal pumps are multistage machines. This is primarily due to the low pressure values ​​created by one stage (impeller and guide vane). In turn, small values ​​of the pressure of one stage (from 3 to 6-7 m of water column) are determined by the small values ​​of the outer diameter of the impeller, limited by the inner diameter of the casing string and the dimensions of the downhole equipment used - cable, submersible motor, etc.

The design of a borehole centrifugal pump can be conventional and wear-resistant, as well as increased corrosion resistance. The diameters and composition of the pump units are basically the same for all pump versions.

Downhole centrifugal pump of conventional design is designed to extract liquid from a well with a water content of up to 99%. Mechanical impurities in the pumped liquid should be no more than 0.01 mass% (or 0.1 g / l), while the hardness of mechanical impurities should not exceed 5 points according to Mohs; hydrogen sulfide - not more than 0.001%. According to the requirements of the technical conditions of manufacturers, the content of free gas at the pump intake should not exceed 25%.

The corrosion-resistant centrifugal pump is designed to operate when the content of hydrogen sulfide in the pumped formation fluid is up to 0.125% (up to 1.25 g/l). The wear-resistant design allows pumping out liquids with mechanical impurities up to 0.5 g/l.

The steps are placed in the bore of the cylindrical body of each section. One section of the pump can accommodate from 39 to 200 steps, depending on their mounting height. The maximum number of stages in the pumps reaches 550 pieces.

Rice. 6.2. Scheme of a borehole centrifugal pump:

1 - ring with segments; 2,3- smooth washers; 4,5- shock absorber washers; 6 - top support; 7 - lower support; 8 - shaft support spring ring; 9 - remote bushing; 10 -base; 11 - slotted coupling.

Modular ESPs

To create high-pressure borehole centrifugal pumps, many stages (up to 550) have to be installed in the pump. At the same time, they cannot be accommodated in one housing, since the length of such a pump (15–20 m) makes it difficult to transport, install on a well, and manufacture the housing.

High-pressure pumps are made up of several sections. The body length in each section is no more than 6 m. The body parts of individual sections are connected by flanges with bolts or studs, and the shafts are connected by spline couplings. Each section of the pump has an upper axial shaft bearing, a shaft, radial shaft bearings, steps. Only the lower section has a receiving grid. Fishing head - only the upper section of the pump. Sections of high-pressure pumps can be shorter than 6 m (typically 3.4 and 5 m pump casing length), depending on the number of stages to be placed in them.

The pump consists of an inlet module (Fig. 6.4), a section module (modules-sections) (Fig. 6.3), a head module (Fig. 6.3), a check valve and a bleed valve.

It is allowed to reduce the number of modules-sections in the pump, respectively, completing the submersible unit with an engine of the required power.

The connections of the modules between each other and the input module with the motor are flanged. Connections (except for the connection of the input module with the engine and the input module with the gas separator) are sealed with rubber rings. Shafts of modules-sections are connected to each other, module-sections are connected to the shaft of the input module, the shaft of the input module is connected to the shaft of the hydraulic protection of the engine using splined couplings.

Shafts of modules-sections of all groups of pumps, having the same casing lengths of 3.4 and 5 m, are unified. To protect the cable from damage during round-trip operations, removable steel ribs are located on the bases of the module-section and module-head. The design of the pump allows the use of the pump gas separator module, which is installed between the inlet module and the section module, without additional disassembly.

Technical characteristics of some standard sizes of ESP for oil production, manufactured by Russian companies according to specifications, are presented in Table 6.1 and fig. 6.6.

The scope of centrifugal pumps in oil production is quite large: at a flow rate of 40-1000 m 3 /day; for heads 740-1800 and (for domestic pumps). These pumps are most effective when working in wells with high flow rates. However, there are limitations for ESPs due to well conditions, such as high GOR, high viscosity, high content of mechanical impurities, etc.

The creation of pumps and electric motors in a modular design makes it possible to more accurately select the ESP to the characteristics of the well in terms of flow rates and pressures. All these factors, taking into account economic feasibility, should be taken into account when choosing methods for operating wells.

Submersible pump units are lowered into the well on tubing of the following diameters: 60 mm at liquid flow rate Q No. up to 150 m 3 /day, 73 mm at 150< Q» < 300 м 3 , - сут. 89 мм при Q e >> 300 m 3 /day The design characteristics of the ESP are given for water, and for specific liquids (oil) they are refined using correlation coefficients. It is advisable to select a pump according to flow rates and pressures in the area of ​​​​the highest efficiency of the minimum required power. ESP units can operate with liquids containing up to 1.25 g/l H, S, while conventional units can handle liquids containing up to 0.01 g/l H:S.

Conventional pumps are recommended for wells with a content of mechanical impurities in the pumped liquid up to 0.1 g/l; pumps of increased wear resistance - for wells with a content in the pumped liquid of more than 0.1 g/l, but not more than 0.5 g/l of mechanical impurities; pumps of increased corrosion resistance - for wells with a hydrogen sulfide content of up to 1.25 g l and a pH of 6.0-8.5.

Diaphragm borehole pumping units are used to select aggressive reservoir fluids or fluids with a significant content of mechanical impurities (sand). They are electrically driven positive displacement pumps.

The ESP unit includes a submersible electric pump unit, which combines an electric motor with hydraulic protection and a pump; cable line lowered into the well on lifting tubing; mouth equipment type OUEN 140-65 or Christmas trees. AFK1E-65x14; control station and transformer, which are installed at a distance of 20-30 and from the wellhead. Power is supplied to the motor through a cable line. The cable is attached to the pump and tubing with metal belts. Check and drain valves are installed above the pump. The pumped liquid from the well comes to the surface through the tubing string. The submersible electric pump, electric motor and hydraulic protection are interconnected by flanges and studs. The shafts of the pump, motor and protector have splines at the ends and are connected by spline couplings.

ESP applicability criterion:

• 1 The industry produces pumps for fluid extraction of 1000 m3 per day at a head of 900 m
• 2 The content of hydrogen sulfide in the extracted products - up to 0.01
• 3 Minimum produced water content up to 99%
• 4 The content of mechanical impurities up to 0.5
• 5 Free gas content no more than 25%

The interpretation of the symbols of the installations is given on the example of U2ETsNI6-350-1100.

U - installation; 2 (1) - modification number;

E - driven by a submersible motor;

C - centrifugal;

H - pump;

And - increased wear resistance (K - increased corrosion resistance);

• 6 (5; 5A) - installation group;
• 350 - pump supply in the optimal mode for water in m 3 / day;
• 1100 - pressure developed by the pump in meters of water column.

The installation of a submersible centrifugal pump includes submersible and surface equipment. The submersible equipment includes: an electric pump unit, which is lowered into the well under the liquid level on the tubing string (tubing). The electric pump unit consists of: an electric motor with hydraulic protection, a gas separator, a centrifugal pump, as well as a check and drain valves. Surface equipment includes: electrical equipment of the installation and wellhead equipment (string head and wellhead fittings connected with a flow line). Electrical equipment, depending on the current supply scheme, includes either a complete transformer substation for submersible pumps (KTPPN), or a transformer substation (TP), a control station and a transformer. Electricity is supplied from the transformer to the submersible motor via a cable line, which consists of a ground supply cable and a main cable with an extension. The connection of the ground cable with the main cable of the cable line is carried out in a terminal box, which is installed at a distance of 3-5 meters from the wellhead.

Abstract (Russian) Abstract (English) INTRODUCTION 1. ANALYSIS OF EXISTING SCHEMES AND DESIGNS. 1.1. Purpose and technical data of the ESP. 1.1.1. Historical background on the development of the mining method. 1.1.2. Composition and completeness of the ESP. 1.1.3 Technical characteristics of the SEM. 1.1.4. Main technical data of the cable. 1.2. Brief review of domestic schemes and installations. 1.2.1. General information. 1.2.2. Submersible centrifugal pump. 1.2.3. Submersible motors. 1.2.4. Hydroprotection of the electric motor. 1.3. Brief review of foreign schemes and installations. 1.4. Analysis of ESP operation. 1.4.1. Analysis of the well stock. 1.4.2. Analysis of the ESP fund. 1.4.3. Upon submission. 1.4.4. By pressure. 1.5. Brief description of wells. 1.6. ESP malfunction analysis. 1.7.Analysis of the accident rate of the ESP fund.2.PATENT STUDY. 2.1 Patent study. 2.2. Justification of the selected prototype. 2.3. The essence of modernization. 3. CALCULATION PART. 3.1. Calculation of the ESP stage. 3.1.1. Calculation of the impeller. 3.1.2. Calculation of the guide apparatus. 3.2. Verification calculation of the key connection. 3.3. Verification calculation of spline connection. 3.4 Calculation of the ESP shaft. 3.5. Strength calculation 3.5.1. Strength calculation of the pump housing. 3.5.2. Strength calculation of the screws of the safety clutch. 3.5.3. Strength calculation of the half-coupling body. 4. ECONOMIC EFFECT FROM 5. SAFETY AND ENVIRONMENTAL FRIENDLY OF THE PROJECT. Appendix 18. Appendix 29. Appendix 310. Appendix 411. Appendix 5.

INTRODUCTION

ESPs are designed to pump formation fluid from oil wells and are used to boost fluid withdrawal. The units belong to product group II, type I according to GOST 27.003-83.

Climatic version of submersible equipment - 5, ground electrical equipment - I GOST 15150-69.

For reliable operation of the pump, its correct selection for a given well is required. During the operation of the well, the parameters of the board, the bottomhole formation zone, the properties of the withdrawn fluid are constantly changing: water content, the amount of associated gas, the amount of mechanical impurities, and as a result, there is no additional withdrawal of the fluid or the pump runs idle, which reduces the overhaul period of the pump. At the moment, emphasis is being placed on more reliable equipment to increase the overhaul period, and as a result of this, reducing the cost of lifting the liquid. This can be achieved by using centrifugal ESPs instead of SCHs, since centrifugal pumps have a long overhaul period.

The ESP unit can be used for pumping out liquids containing gas, sand, and corrosive elements.

1. ANALYSIS OF EXISTING SCHEMES AND DESIGNS.

1.1. Purpose and technical data of the ESP.

Installations of submersible centrifugal pumps are designed for pumping out of oil wells, including inclined reservoir fluid containing oil, water and gas, and mechanical impurities. Depending on the number of different components contained in the pumped liquid, the pumps of the installations are of standard and increased corrosion and wear resistance. During the operation of the ESP, where the concentration of mechanical impurities in the pumped liquid exceeds the allowable 0.1 gram liter, clogging of the pumps occurs, intensive wear of the working units. As a result, vibration increases, water gets into the SEM through the mechanical seals, the engine overheats, which leads to the failure of the ESP.

Conventional designation of installations:

ESP K 5-180-1200, U 2 ESP I 6-350-1100,

Where U - installation, 2 - second modification, E - driven by a submersible electric motor, C - centrifugal, N - pump, K - increased corrosion resistance, I - increased wear resistance, M - modular design, 6 - groups of pumps, 180, 350 - supply msut, 1200, 1100 - head, m.w.st.

Depending on the diameter of the production string, the maximum transverse dimension of the submersible unit, ESPs of various groups are used - 5.5, and 6. Installation of group 5 with a transverse diameter of at least 121.7 mm. Installations of group 5 a with a transverse dimension of 124 mm - in wells with an internal diameter of at least 148.3 mm. Pumps are also divided into three conditional groups - 5.5 a, 6. The diameters of the cases of group 5 are 92 mm, groups 5 a are 103 mm, groups 6 are 114 mm. Technical characteristics of ETsNM and ETsNMK pumps are given in Appendix 1.

1.1.1.Historical information aboutdevelopment of the extraction method.

The development of rodless pumps in our country began even before the revolution. When A.S. Artyunov together with V.K. Domov developed a downhole unit in which a centrifugal pump was driven by a submersible electric motor. Soviet engineers, starting in the 1920s, proposed the development of piston pumps with a piston pneumatic engine. One of the first such pumps was developed by M.I. Martsishevsky.

The development of a borehole pump with an air motor was continued in Azinmash by V.I. Dokumentov. downhole centrifugal pumps with an electric drive were developed in the prewar period by A.A. Bogdanov, A.V. Krylov, L.I. Navigator. Industrial samples of centrifugal pumps with electric drive were developed in a special design office for rodless pumps. This organization carries out all work on borehole rodless pumps, including screw, diaphragm, etc.

The oil and gas industry, with the discovery of new deposits, needed pumps to extract large amounts of liquid from the well. Naturally, the most rational vane pump, adapted for high flows. Of the vane pumps, pumps with centrifugal impellers have become widespread, since they gave a large head for given liquid flows and pump dimensions. The widespread use of electrically driven downhole centrifugal pumps is due to many factors. With large fluid withdrawals from the well, ESP units are the most economical and least labor-intensive for maintenance, compared with compressor production and liquid lifting by other types of pumps. At high flows, the energy costs of the installation are relatively small. Maintenance of ESP units is simple, since only a control station and a transformer are located on the surface, which do not require constant maintenance.

Installation of ESP equipment is simple, since the control station and transformer do not need foundations. These two units of the ESP installation are usually placed in a light booth.

1.1.2. Composition and completeness of the ESP

The ESP unit consists of a submersible pump unit (an electric motor with hydraulic protection and a pump), a cable line (a round flat cable with a cable entry sleeve), a tubing string, wellhead equipment and ground electrical equipment: a transformer and a control station (complete device) (see Figure 1.1 .). The transformer substation converts the voltage of the field network of a suboptimal value at the terminals of the electric motor, taking into account the voltage losses in the cable. The control station provides control of the operation of pumping units and its protection under optimal conditions.

A submersible pumping unit, consisting of a pump and an electric motor with hydraulic protection and a compensator, is lowered into the well along the tubing. The cable line provides power supply to the electric motor. The cable is attached to the tubing with metal wheels. The cable is flat along the length of the pump and protector, attached to them by metal wheels and protected from damage by casings and clamps. Check and drain valves are installed above the pump sections. The pump pumps fluid out of the well and delivers it to the surface through the tubing string (see Figure 1.2.)

The wellhead equipment provides suspension on the casing flange of the tubing string with an electric pump and cable, sealing of pipes and cable, as well as removal of the produced fluid to the outlet pipeline.

A submersible, centrifugal, sectional, multistage pump does not differ in principle from conventional centrifugal pumps.

Its difference is that it is sectional, multi-stage, with a small diameter of working steps - impellers and guide vanes. Submersible pumps produced for the oil industry contain from 1300 to 415 stages.

The sections of the pump connected by flange connections are a metal casing. Made from steel pipe 5500 mm long. The length of the pump is determined by the number of operating stages, the number of which, in turn, is determined by the main parameters of the pump. - delivery and pressure. The flow and head of the stages depend on the cross section and design of the flow path (blades), as well as on the rotational speed. In the casing of the pump sections, a package of stages is inserted, which is an assembly of impellers and guide vanes on the shaft.

The impellers are mounted on a shaft on a feather key in a running fit and can move in the axial direction. The guide vanes are secured against rotation in the nipple housing located at the top of the pump. From below, the pump base is screwed into the housing with inlet holes and a filter through which the liquid from the well enters the first stage of the pump.

The upper end of the pump shaft rotates in the stuffing box bearings and ends with a special heel that takes the load on the shaft and its weight through the spring ring. Radial forces in the pump are perceived by plain bearings installed at the base of the nipple and on the pump shaft.