Well acceptance procedure after well workover, workover. Information project for employees of the oil and gas industry and students of oil and gas educational institutions Prs Neft

Underground repairs are designed to maintain operational condition of underground equipment, lowered into an oil well, as a rule, with its retrieval to the surface for repair or replacement.

It has a high labor intensity and tension, as it requires a lot of power consumption of special equipment for the extraction of lowered devices from the well and physical efforts. It should be noted that PRS is performed on outdoors under any climatic conditions.

Currently, more than 70% of all workovers are performed at wells with sucker rod pumping units and less than 30% at ESPs.

During well workover, the following operations are carried out (see Figures 81, 82): a) transportation - equipment delivery to the well (t 1); b) preparatory - preparation for repair (t 2); c) tripping - lifting - lifting and lowering of oil equipment from the well (t 3); d) well cleaning operations, equipment replacement, elimination of minor accidents (t 4); e) final - dismantling the equipment and preparing it for transportation (t 5).

Figure 81-Diagram of the time distribution at the PRS in the Bashneft association

Figure 82- Diagram of the time distribution at the PRS in the Bashneft association

Considering the graphs depicting the relative time spent on cycles of operations, we can say that the main efforts of designers should be aimed at reducing the time: a) transport operations (it takes up to 50%) due to the creation of high-speed, high-passing units; b) preparatory operations due to the creation of erection-capable machines and units; c) lowering and lifting operations due to the creation of reliable automatic machines and mechanized keys.

The characteristic of the labor intensity of the cycle of operations for lifting one pipe is shown in Figure 83.

1-transfer of corkscrews; 2-charging corkscrews; 3-column lifting; 4-removal, transfer, charging of elevators; 5-key charging; 6-unscrewing;

Figure 83-Characteristic of the cycle labor intensity

Figure 83 shows that the most difficult operation is the unscrewing of pipes and this is where the main efforts of the designers should be directed.

Operations performed during underground workover (ORS):

1. Cleaning the bottom hole, lifting string from paraffin, hydrate deposits, salts and sand plugs.

2. Conservation and re-entry of wells.

3. Elimination of tubing leaks.

4. Well workover using wire rope equipment.

5. Experienced work on the use of new downhole equipment and other geological and technical measures.

Well workover operations (workover):

1. Removing the remaining equipment from the wells (tubing, pumps, cable, rod, rope, etc.).

2. Corrections of columns in case of breaking, crushing.

3. Fastening of bottomhole zone rocks with various binders (cement, resin).

4. Insulation works.

5. Return to higher or lower horizons.

6. Sidecutting and drilling of the svola.

7. Repair of wells equipped with cut-off packers.

8. Repair of injection wells.

9. Increase and recovery of flow rates and well injectivity - acidizing, hydraulic fracturing, hydropesko. perforation, washing with solvents and surfactants.

GENERAL PROVISIONS

All work on putting wells into operation is associated with lowering equipment into them: tubing, deep pumps, sucker rods, etc.

During the operation of wells by a flowing, compressor or pumping method, their work is disrupted, which is expressed in a gradual or sharp decrease in flow rate, sometimes even in a complete cessation of fluid supply.

Work on restoring a given technological mode of well operation is associated with lifting underground equipment for its replacement or repair, cleaning the well from a sand plug with a thief or flushing, eliminating a break or unscrewing sucker rods and other operations.

A change in the technological mode of wells operation necessitates a change in the length of the tubing string, replacement of tubing, run into the well, with pipes of a different diameter, ESP, USSN, elimination of rod breakage, replacement of wellhead equipment, etc. All these works are related to underground (current) well workover and are performed by special underground workover teams.

More complex work related to the elimination of an accident with a casing string (scrapping, crushing), with isolation of water that appeared in a well, transition to another productive horizon, catching broken pipes, cables, tartar rope or any tool, are categorized as capital repairs.

Works on overhaul wells are performed by special teams. The task of the field workers, including the workers of underground repair of wells, is to reduce the time of underground repairs, to maximize the turnaround time of wells.

High-quality underground repairs are the main condition for increasing oil and gas production. The higher the quality of the workover, the longer the turnaround time and the more efficient the well operation.

The overhaul period of wells is understood as the duration of actual well operation from workover to workover, i.e. time between two consecutive repairs.

The duration of the overhaul period of a well is usually determined once a quarter (or half a year) by dividing the number of well days worked during a quarter (half year) by the number of underground repairs for the same work time in this well.

For lengthening the overhaul period, it is of great importance complex repair- repair of ground equipment and underground well workover. In order to maintain the warranty period of the well operation, the repair of the surface equipment must be combined with the underground repair. Therefore, in the field, comprehensive schedules for underground repairs and for repairs of surface equipment should be drawn up in advance.

Well operation factor is the ratio of the actual operation time of the wells to their total calendar time for a month, quarter, year.

The operating factor is always less than 1 and on average for oil and gas producing enterprises is 0.94 - 0.98, i.e. from 2 to 6% of the total time is spent on workover operations in wells.

The underground repair team carries out the current repairs. Rotational organization - 3 people: an operator with an assistant at the mouth and a tractor driver-driver on a winch.

Overhaul is performed by overhaul teams that are part of the service enterprises of oil companies.

Units of repair work for various purposes are:

Well overhaul;

 routine well workover;

 well-operation to enhance oil recovery.

• Overhaul of wells (workover) is a set of works related to the restoration of the operability of casing strings, cement rings, bottomhole zone, emergency response, lowering and lifting of equipment during separate operation and injection.

  o Routine well workover (RWS) is a set of works aimed at restoring the operability of downhole and wellhead equipment, and work on changing the well operation mode, as well as cleaning the lifting string and bottomhole from paraffin-resinous deposits, salts and sand plugs by the workover team.

  o Well-workover operation to increase oil recovery is a set of works in a well to introduce agents into the formation that initiate physical, chemical or biochemical processes in the depths of the formation, aimed at increasing the final oil displacement coefficient in a given area of ​​the reservoir.

The unit of repair work in the above areas (repair, well-operation) is a complex of preparatory, main and final work carried out by a team of current, workover, wells or a stimulation unit, from the transfer of a well to them by the customer until the end of the work stipulated by the plan and accepted under the act.

 If, after the completion of the work, the well has not worked for 48 hours of the guaranteed period or has not reached the established mode due to poor performance of the planned complex due to the fault of the workover crew or the stimulation unit, then regardless of which crew will carry out additional work on the well, consider them to be a continuation of the work performed without registering a second repair or well operation on them.

o Workover operations in wells in the industry are carried out in three main ways of delivering tools, technological materials (reagents) or devices to a given area of ​​the wellbore:

o using a specially lowered pipe string;

o by injection through tubing or annulus;

o on a cable or rope.

ORGANIZATION OF WORK WITH A MECHANIZED FUND

The procedure for determining the causes of repeated and premature repairs of sucker rod pumps, electric submersible pumps.

1. Work carried out by the GTS TsDNG before putting the well for repair. With a decrease or no supply, the technological service studies the history of the work carried out in the well (measurements, the reasons for previous repairs, well treatment, etc.), a dynamo chart is taken, the tubing is pressurized, and the well is flushed. After that, a workover team is placed on the well.

2. After lifting the wellhead, a preliminary investigation is carried out at the wellhead. The chairman of the CDNG engineering and technical work commission shall determine the remaining members of the CDNG commission independently. The results of the investigation are documented in an act and attached to the warranty certificate. If obvious reasons for the failure of the GSP are detected, measures are taken to prevent them. The equipment during the initial investigation is not disassembled; with a wedge, it is allowed to unscrew the suction valve.

3. After that, the equipment is sent to the commission analysis (at KTsTB).

4. After the commission analysis, the commission appointed by the order of the chief engineer, as well as representatives of organizations carrying out well workover and well maintenance work, proceeds to determine the reason for the refusal and the guilty organization.

5. If the parties do not agree on the commission, then a central commission is appointed. The results of the work of the central commission are documented in a protocol and communicated to all interested parties.

The procedure for investigating breaks of the lapels of the rods.

1. In the event of a breakage detection, a breakaway of the rods during a workover or workover, the brigade submits an application to the CDNG.

2. The Investigation Commission headed by the technologist (or ITR TsDNG) travels to the bush, where it is checked whether a lapel break is present (the readings of the weight indicator are taken into account), the arrangement of the rods, a sample of the breaking rod of the rod.

3. After that, an act of the established form is drawn up.

4. After determining the reason for the breakage of the rods, the commission plans to carry out appropriate measures (change of layout, lowering rods with centralizers, etc.)

6. A sample of the breaking rod element is sent for investigation to the KTsTB.

The order of repair of wells equipped with LWS.

1. When repairing wells with PSV after killing, the tubing is pressurized. Based on the data on pressure testing, operating parameters, a decision is made to lift the tubing and change the locking support.

2. Lifting of tubing and locking support is carried out in the following cases:

2.1. In the absence of pressure testing of tubing (pressure drop more than 5 atm in 5 minutes)

2.2. If the lock support does not match, prepared for the descent of the GSP.

2.3. If the operating time is more than 365 days and the presence of a cone Z.O.

3. Descent of the NSV only if there is a filter installed at the pump inlet with a hole diameter of 3 mm.

4. When running the tubing, they are gauged with a template with a diameter of 60 mm.

5. At the end of the repair, pressure testing of the gas pumping unit is carried out when the pressure drops more than 5 atm in 5 minutes, the technologist of the TsDNG, using the dynamogram, determines the reason for the lack of pressure testing, fills out the warranty certificate, in which he indicates the reason for the rise. It is forbidden for the crews of PRS, workover to re-lift the sucker rod pump without a guarantee passport.

Well acceptance procedure after well workover, workover.

1. When starting a well after repair, an act is drawn up for pressure testing of the tubing string.

2. After signing the pressure test certificate, the well is considered accepted after repair.

3. When the pressure drops more than 5 atm in 5 minutes, the TsDNG technologist uses a dynamogram to determine the reason for the lack of pressure testing, fills out the warranty certificate, in which he indicates the reason for the rise. It is forbidden for the crews of PRS, workover to re-lift the sucker rod pump without a guarantee passport.

4. If necessary, a workover and workover team determined by the CSDNG is obliged to flush the HSP and pressure the tubing within 2 days after the completion of the repair.

5. With the optimal operation of the gas pumping unit, 2 days after the start-up, for the sucker rod pump N - 44, N - 57 ESP, for the sucker rod pump Н-32, Н-29, an act for underground well repair is signed.

6. The certificate for underground repairs must contain 3 signatures: the production foreman responsible for the condition of the well pad, the completeness of the equipment, etc., the CDNG technologist responsible for the operational efficiency of the OGP and the deputy head of the CDNG. The repair act is considered signed, regardless of the presence of any notes.

The oil and gas industry involves the use of a large variety of equipment that serves for the production, storage and transportation of oil products, as well as for well maintenance. For automatic measurement of the flow rate of oil, gas and water produced from wells, group metering units are used that are installed directly at the field. To restore the operability of the wells, repair work is carried out, including the overhaul of wells for the performance of which ...

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MINISTRY OF EDUCATION AND SCIENCE OF THE RUSSIAN FEDERATION

abstract

by discipline:

"Oil and gas field equipment"

2015

Plan

Introduction …………………………………………………………………….… .3

1. Equipment of the sucker rod pumping unit ………………………………………………….… ... 4

2. The main equipment, the scheme of the GZU and the principle of operation ... …… .. …………… 10

3. Equipment used for workover .. ………………… ... ……………… ... 14

Conclusion…. ……………………………………………………………… ... 20

List of used literature… .. ……………………………………… .21

Introduction

The oil and gas industry involves the use of a large variety of equipment that is used for the extraction, storage and transportation of petroleum products, as well as for well servicing. The complex, which combines all the equipment used in the extractive industry, is commonly called "oil and gas equipment".

The range of equipment included in the complexes is hundreds of items, and the high rates of development of the oil and gas industry lead to its rapid renewal, the creation of completely new types, sizes and designs. The study of this variety of technical means makes it necessary to systematize them, the basis of which is the classification. All machines, equipment, mechanisms, structures, means of mechanization and tools of all purposes can be classified by dividing them into eight main groups, each of which consists of several subgroups, to which the specific technical means of this group belong.

The most common way to artificially lift oil is to extract oil using sucker rod pumps, which is explained by their simplicity, efficiency and reliability. At least two-thirds of the existing producing wells are operated by sucker-rod pumps.

For automatic measurement of the flow rate of oil, gas and water produced from wells, group metering units are used, which are installed directly at the field.

To restore the working capacity of the wells, repair work is carried out, including the overhaul of wells, for which it is necessary to involve sophisticated equipment, up to the use of drilling rigs.

The purpose of this work is to study oilfield equipment used for oil production; for measuring the flow rate of oil, gas and water; for workover of wells.

Research objectives:

• to study the installation of a sucker rod pump used for oil production
• consider the main equipment, scheme and principle of operation of the AGZU
• to determine the equipment used for workover of wells

1. Equipment at sucker rod pump installations

Sucker rod pumping is the most common method for artificially lifting oil. A distinctive feature of the sucker rod pumping unit is that a plunger (piston) pump is installed in the well, which is driven by a surface drive by means of a rod string.

Before others mechanized methods oil production sucker rod pumping units have the following advantages: high efficiency; repairs are possible directly at the fields; various drives can be used for prime movers; Sucker rod pump units can be used in difficult operating conditions - in sand-producing wells, in the presence of paraffin in the oil produced, with a high gas-oil ratio, when pumping out a corrosive liquid.

There are sucker rod pumps and disadvantages. The main disadvantages include: limitation on the depth of the pump lowering (the deeper, the higher the probability of the rods breaking); low pump flow; restriction on the inclination of the wellbore and the intensity of its deviation (not applicable in deviated and horizontal wells, as well as in highly deviated vertical wells)

Structurally, the equipment of the sucker rod pumping unit includes the surface and underground parts.

Ground equipment includes:

• drive (rocker) - is an individual drive of a sucker rod pump, lowered into the well and connected to the drive by a flexible mechanical link - a rod string;
• 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 day surface.
• submersible pump designed for pumping out of a well liquid watered up to 99% with a temperature of no more than 130 ° С plug-in or non-plug-in types
• rods - designed to transfer the reciprocating motion to the plunger of the deep pump from the pumping unit and is a kind of piston pump rod.

Figure 1 shows a diagram of a sucker rod pumping unit (SRP).

Figure 1. Diagram of a sucker rod pumping unit (USHGN).

1 - production casing; 2 - suction valve; 3 - pump cylinder; 4 - plunger; 5 - discharge valve; 6 - tubing; 7 - sucker rods; 8 - crosspiece; 9 - wellhead branch pipe; 10 - check valve for gas bypass; 11 - tee; 12 - wellhead stuffing box; 13 - wellhead stock; 14 - rope suspension; 15 - balancer head; 16 - balancer; 17 - rack; 18 - balance weight; 19 - connecting rod; 20 - crank weight; 21 - crank; 22 - reducer; 23 - driven pulley; 24 - V-belt transmission; 25 - electric motor on a rotary slide; 26 - driving pulley; 27 - frame; 28 - control unit.

The installation works as follows. The plunger pump is driven by a pumping unit, where the rotary motion received from the engine by means of a gearbox, crank mechanism and balancer is converted into reciprocating motion, transmitted to the plunger of the sucker rod pump through the rod string. When the plunger moves up, the pressure in the pump cylinder decreases and the lower (suction) valve rises, opening the access of liquid (suction process). At the same time, the liquid column above the plunger presses the upper (delivery) valve to the seat, rises up and is thrown out of the tubing into the working manifold (injection process).

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

The pumping unit (Figure 2) is an individual drive of the borehole pump.

Figure 2. SKD-type rocking machine.

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

The rocking machine imparts to the rods a reciprocating movement close to sinusoidal. The SK has a flexible rope suspension of the wellhead rod and a folding or swivel head of the balancer for unimpeded passage of the triggering mechanisms (traveling block, hook, elevator) during underground repairs.

The balancer oscillates on a transverse axle fixed in bearings and is articulated with two massive cranks by means of 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 shaft of the gearbox at a certain distance along the cranks. Counterweights are needed to balance the rocker.

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

In addition, all SKs are equipped with a braking device necessary to hold the balance bar 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 rearranging the crank pin to a particular hole. This achieves a step change in the swinging amplitude of the balance bar, 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 motor shaft to a larger or smaller diameter.

Downhole sucker rod pumps are a positive displacement hydraulic machine, where the seal between the plunger and the cylinder is achieved due to the high accuracy of their working surfaces and controlled clearances.

Structurally, all borehole pumps consist of a cylinder, a plunger, valves, a lock (for plug-in pumps), connecting and installation parts. The design of the pumps adheres to the principle of the maximum possible unification of the specified units and parts for the convenience of replacing worn-out parts and reducing the range of required spare parts.

Pumps are used in the following types:

• non-removable
• plug-in.

Non-removable pumps run half-disassembled. First, the pump cylinder is lowered onto the tubing. And then a plunger with a check valve is lowered on the rods. The non-insertable pump is simple in design. The cylinder of a non-plug-in pump is attached directly to the tubing string, usually at the bottom of it. Below the cylinder there is a lock support in which the suction valve is locked. After lowering the cylinder and the key support into the well, the plunger is lowered on the rod string. When the number of rods is lowered into the well, which is necessary for the plunger to enter the cylinder and the suction valve to land on the lock support, the final adjustment of the plunger suspension height is performed. The suction valve is lowered into the borehole, secured to the lower end of the plunger by means of a gripping rod. When the suction valve actuates the lock support, the latter locks it with a mechanical lock or friction cups. The plunger is then released from the suction valve by rotating the rod string counterclockwise. The plunger assembly is then lifted from the suction valve to the height required for the plunger to move freely downward.

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

Plug-in sucker rod pumps are run into the well in assembled form. Previously, a key support is 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, if the pump is with a lock at the bottom, or a mechanical upper lock or an upper lip-type lock, if the pump is with a lock at the top, is lowered into it. Then the entire pumping unit with the landing unit on the lock support is lowered into the well on the rod string. After fixing the pump on the lock support, adjust the height of the plunger suspension so that it is as close to the bottom of the cylinder as possible. In wells with a high gas content, it is desirable to make the suspension so that the movable pump assembly almost touches the bottom of the cylinder, i. E. keep the distance between the suction and discharge valve to a minimum on the downstroke of the plunger. Accordingly, to change such a pump, it is not required to run the pipes down and out again. A plug-in pump works on the same principle as a non-plug-in pump.

Both types of pump have both advantages and disadvantages. The most suitable type is used for each specific condition. For example, if the oil contains a large amount of paraffin, it is preferable to use a non-slip pump. Paraffin deposited on the tubing walls can block the possibility of lifting the plunger of the plug-in pump. For deep wells, it is preferable to use a plug-in pump to reduce the time required to run tubing when changing a pump.

There are the following types of borehole pumps (Figure 3):

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

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

НН - non-insertable without a catcher;

НН1 - non-removable with a gripping rod;

НН2С - non-insertable with a safety catch.

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

Figure 3. Types of downhole sucker rod pumps.

The use of NN pumps is preferable in wells with a large flow rate, a shallow running depth and a long turnaround time, and HB pumps in wells with a small flow rate, at large running depths. The higher the viscosity of the liquid, the higher the landing group is taken. For pumping liquids with a high temperature or a high content of sand and paraffin, it is recommended to use pumps of the third landing group. It is recommended to use pumps with a smaller clearance for large lowering depths.

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

The principle of operation of the pumps is as follows. During the upward stroke of the plunger, a vacuum is created in the inter-valve 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 inter-valve 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 made by the plunger ensure the pumping of the formation fluid and pumping it onto the surface into the pipe cavity. 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.

1. The main equipment, the scheme of the GZU and the principle of operation

Group metering installations are constructed for deep-well pumping and flow-compressor wells.

Group metering units are a source of information on the state of wells used for operational control over the implementation of current production assignments, planning geological and technical measures and systematic control of the oil field development mode. Information is transmitted via telemechanical channels to the control center.

Group metering units are used to automatically measure the flow rate of oil, gas and water produced from wells, and to connect flow lines from wells to collecting collectors for further transportation of the produced products to the collection point, as well as blocking wells in case of emergency technological process or by command from the control room.

In the oil and gas gathering system, AGZU is installed directly at the field. The AGZU receives products from several production wells via flow lines. Up to 14 wells can be connected to one unit, depending on its design.

In this case, the fluid flow rate is measured in turn for each well. At the exit from the AGSU, the production of all wells enters one pipeline - the “collecting collector” and is transported to a booster pumping station (BPS) or directly to oil and gas treatment facilities.

AGZU structurally consists of a technological unit (BT) and an automation unit (BA).

The BT contains:

• main process equipment: well switching unit, bypass line, separation tank with control devices for its operation modes, liquid line with liquid flow meter, gas line with gas flow meter, outlet manifold, pipeline system with shutoff and control valves;
• engineering life support systems: lighting, heating, ventilation systems; instrumentation - primary instrumentation and automation;
• emergency blocking and alarm systems: gas contamination, fire, unauthorized access alarms.

The BA contains:

• power supply device for AGZU equipment: power cabinet (AL) with control of actuator drives;
• device for collecting, processing and local indication of signals: secondary instrumentation and automation devices, instrumentation cabinet for collecting and processing signals from primary instrumentation;
• device for issuing information: cabinet for telemetry and radio channel equipment, communication with the upper level of the automated process control system of the oil field;
• engineering life support systems and emergency systems alarms: lighting, heating, ventilation, fire alarm, unauthorized access equipment.

A schematic diagram of a group metering unit is shown in Figure 4.

Figure 4. Schematic diagram of an automated group metering installation.

The production of GZhS wells (gas-liquid mixture, consisting of crude oil, formation water and associated petroleum gas) through pipelines 1 connected to the installation, sequentially passing the KO check valve and the ZD gate valve, enters the well switch made on the PSM (multi-way well switch) or PSM with a hydraulic drive GP-1, or on three-way ball valves with electric drives with a hydraulic drive GP-1, or on three-way ball valves with electric drives, after which it enters the collecting manifold 3, connected to the collection system, through the common manifold 2 through the OCG-4 cut-off device. The well switching unit directs the flow of the wells selected for measurement through metering tap 4 with an OCG-3 cut-off into a two-volume metering hydrocyclone separator GS, where it is centrifugally-gravitationally separated into liquid and gaseous phases.

When using a lever-float mechanical system for switching the operating modes of the separator, the gas through pipeline 5 passes through rotary shutter ZP, is mixed with the measured liquid and through the pipeline 6 enters the common collector 3. The liquid phase separated in the upper part of the gas separator ГС accumulates in the lower storage part of the separator. As the oil level rises, the float P rises and upon reaching the upper preset level acts on the butterfly valve, shutting off the gas line 5. The pressure in the separator rises and the liquid from the separator begins to be displaced through the TOP-1 flow meter. When the liquid reaches the lower level, the ZP opens the gas line, the pressure in the separator drops, and a new cycle of liquid accumulation in the lower tank begins. The measured flow rate of the well (in m3) is recorded by the electromagnetic counter of the control unit. Signals to this block come from the TOP-1 counter.

If the AGZU is equipped with instrumentation and control devices, the gaseous phase (associated petroleum gas) from the upper part of the separator enters through the gas line equipped with shut-off and control valves through the gas flow meter into the outlet manifold. In this case, the gas flow rate is measured. When the set upper liquid level (crude oil, including formation water) is reached in the separator, the instrumentation and control means give a signal to change the separator's operating mode to the liquid draining mode. As a result, the liquid line is opened and the gas line is closed to create excess pressure in the separator, which ensures the flow of liquid into the liquid line, equipped with shut-off and control valves and a liquid flow meter, and then into the outlet manifold. This measures the flow rate of the liquid. When the lower liquid level is reached in the separator, the instrumentation and control means give a signal to change the operating mode of the separator. In this case, the liquid line is closed, and the gas line is opened, the separator again switches to the mode of liquid accumulation with measurement of the gas flow rate.

Switching of wells for measurement is carried out by the control unit periodically. The duration of the measurement is determined by the setting of the time relay.

When the time relay is triggered, the GP-1 hydraulic drive motor turns on, and the pressure in the hydraulic control system rises. The hydraulic cylinder of the PSM-1 switch, under the influence of the pressure of the GP-1 hydraulic drive, moves the rotary branch pipe of the switch, and the next well is connected for measurement.

The wells switching unit allows directing the flow of gas liquids of all wells connected to the installation "to the bypass" and then to the outlet manifold. This mode allows you to perform service and repair work on the AGZU equipment.

The separator is equipped with an emergency pressure relief line, gas discharge to the spark plug through the SPPK (relief safety spring valve). To remove contaminants when cleaning the separator by flushing and steaming, there are drainage pipes with shut-off valves and an inspection hatch.

When operating marginal wells with a low gas ratio, AGZU are used, in which separators are not used. In this case, the flow of the well-liquid mixture of the measured well after the well switching unit is directed to the SKZh-type liquid flow meter, which measures the liquid flow rate, and the gas flow rate is taken into account by calculation.

If it is necessary to measure remote marginal wells, measuring installations called CIUS are used, designed to measure the flow rate of one well with a liquid flow rate of up to 100 m3 / day and a gas factor of up to 60 m3 / m3. They do not have a well switching unit, the GWM is fed through the inlet valves to the separator, then to the liquid metering and gas lines, the outlet manifold. A bypass line is provided. Liquid flow rate measurement is carried out by mechanical meters with local indication. Gas consumption is accounted for by the calculation method. CIUS, as a rule, is not equipped with BA.

The duration of the measurement is set depending on specific conditions - well flow rate, production methods, the state of field development.

1. Equipment used forrepair of wells (workover)

Well workover (workover) is a set of works related to the restoration of the casing, cement ring, bottomhole zone, installation and extraction of underground equipment, elimination of accidents, complications and conservation and abandonment of wells, as well as work requiring preliminary killing of productive formations ( for gas wells), installation of blowout equipment.

Well workover includes repair work, for which it is necessary to attract more sophisticated equipment, up to the use of drilling rigs. Overhaul is carried out by teams specialized service with powerful and varied technical means and appropriate specialists.

Well workover equipment consists of:

• Non-aggregate companion equipment (towers, pumps, rotors, tackle systems, lifts).
• Aggregated equipment (installation);
• Downhole tools (bits, pipes, fishing tools);
• Tools for open source software (elevators, keys).

The main difference between the well workover technique and the current technique is the widespread use of a set of drilling equipment.

All workover operations are accompanied by running in and out of the well of pipes, rods and various tools. Therefore, a lifting structure is installed above the wellhead - a tower, a mast with equipment for tripping operations (TRO). Stationary towers and masts are used extremely irrationally, because repair work on each well is carried out only a few days a year, the rest of the time these facilities are inactive. Therefore, it is advisable to use lifts carrying their own masts for underground repairs. Tractors and cars serve as their transport base.

The workover units are designed to eliminate leaks or breaches in the shape of the wellbore (leakage of the casing and cement ring or collapse of the casing), to eliminate complex downhole accidents and to repair the filter section of the well. The unit - unlike a hoist, is equipped with a tower and a mechanism for raising and lowering it.

The hoist is a mechanical winch mounted on a tractor, car or a separate frame. In the first case, the winch is driven from the traction engine of the tractor, cars, in the rest from an independent engine internal combustion or an electric motor.

For the development and repair of wells, a self-propelled unit A-50U is used, mounted on the chassis of a KrAZ-257 vehicle, with a lifting force of 500 kN (Figure 5). This unit is designed for:

• drilling out a cement plug in pipes with a diameter of 146 and 168 mm and related operations (running and retrieving drill pipes, flushing wells, etc.);
• lowering and lifting of tubing pipes;
• installation of production equipment at the wellhead;
• carrying out repair work and work to eliminate the accident;
• drilling operations.

Figure 5. A-50U unit for well workover.

1 - front support; 2 - intermediate support; 3 - compressor; 4 - transmission; 5 - intermediate shaft; 6 - hydraulic jack for lifting the tower; 7 - hoist system; 8 - travel block lifting limiter; 9 - winch; 10 - tower; 11 - control panel; 12 - support jacks; 13 - rotor.

Instead of the A-50U unit, a modernized A-50M unit with increased reliability and carrying capacity was produced.

For tripping operations with laying pipes and rods on the walkways during the overhaul of oil and gas wells not equipped with tower structures, lifting units of the AzINmash-37 type are used (Figure 6).

Hoisting installations of this type are subdivided into AzINmash-37A, AzINmash-37A1, AzINmash-37B, mounted on the basis of KrAZ-255B and KrAZ-260 off-road vehicles. Hoisting units AzINmash-37A and AzINmash-37A1 are equipped with automatic devices APR for making up and unscrewing tubing and an automatic key of the KShE type with an electric drive for making up sucker rods.

The lifting units are equipped with a hook block lifting limiter, a sound and light alarm system for the rig installation, control and measuring devices for the engine and pneumatic system operation, as well as other blocking systems that ensure the safety of work during installation of the unit near the well and round trip operations.

Figure 6. Lifting installation AzINmash-37.

1 - hoist system; 2 - tower; 3 - power transmission; 4 - front support; 5 - operator's cabin; 6 - winch; 7 - hydraulic cylinder for lifting the tower; 8 - back support.

Tractor lifts LPT-8, units AzINmash-43A, Bakinets-3M, A50U, UPT, AzINmash-37, etc. are widely used.

For the production of round-trip operations during the workover of wells that are not equipped with tower structures, lifting units APRS-32 and APRS-40 are intended for the production of tarting works, for cleaning sand plugs with a bailer and for stimulating wells by pistoning (swabbing).

The unit is a self-propelled oilfield machine mounted on the chassis of a three-axle all-terrain vehicle URAL4320 or KrAZ-260, and consists of a single-drum winch and a two-section telescopic tower with a traveling system. The tower of the unit has increased strength and is made of low-alloy frost-resistant steel.

For underground workover of wells equipped with lifting equipment, it is designedtractor lift AzINmash-43P. The hoist is a self-propelled mechanized winch mounted on a tracked swamp tractor T-100MZBGS or a conventional T-100MZ.

For round-trip operations in the process of overhaul of oil and gas wells, lifting units of the UPT type are intended. These include: UPT-32, UPT1-50, UPT1-50B. Self-propelled units mounted on tracked tractors. They consist of the following main units: a single-drum winch installed on a special base for equipment, a tower with a traveling system, rear and front tower supports, a driver's cab. Installations are equipped with mechanisms for screwing - unscrewing pipes; equipped with a hook block anti-pulling device and an explosion-proof lighting system for the working platform at the wellhead and the hook block movement path.

Unlike UPT-32, UPT1-50 and UPT-50V units are equipped with a rotor drive unit and are also equipped with a hydraulic breaker.

Figure 7. Lifting unit UPT1-50. 1 - gearbox; 2 - single-drum winch; 3 air compressor; 4 - the front support of the tower; 5 - headlight; 6 - a tower with a traveling system; 7 - management; 8 - driver's cab; 9 - hydraulic jack; 10 - rear support of the tower.

For the destruction of hydrate and paraffin plugs, pumping process fluids into the well, cementing wells in the bottomhole zone, geophysical studies, a mobile unit UPD-5M is used. UPD-5M is a self-propelled oilfield machine together with an assembly base, which includes a drum with a stacker for winding long pipes, a pipe feed mechanism into the well, fixed on the chassis of a KaAZ-65101/100 vehicle, or any other type of chassis, if desired customer. The drive of all mechanisms of the installation is carried out by hydraulic motors, for carrying out auxiliary work there is a hydraulic manipulator with a lifting capacity of 300 kg.

Pipe elevators - for gripping casing, drilling and tubing, several standard sizes are used:

• EZN elevators are single-line (SPO with the help of two elevators) with a lifting capacity of 15, 25 and 50 tons. The set includes: two elevators, a gripper and a link.
• EG elevators - single-line are designed to work with automatic machines APR-2VB and spiders, with a carrying capacity of 16, 50 and 80 tons.
• ECL elevators for tubing with nominal diameter from 48 to 114 mm, carrying capacity 10 - 40 tons.

Rod elevators ESHN (Figure 8) - to grip the rod string and keep it suspended during tripping, with a lifting capacity of 5 and 10 tons. Their design provides for the use of two pairs of liners for bushings, one is designed for rods Zh12, 16, 19 and 22 mm, the second is for the Zh25 rods.

Figure 8. Rod elevator ESHN.

1 - washer; 2 - cotter pin; 3 - link; 4 - screw; 5 - insert; 6 - bushing; 7 - case.

Lifting hooks designed for hanging elevators, swivels and other equipment during tripping are made of two types: one-horned (version I) and three-horned (version II).

The slings are used to suspend the elevator on the hook. Structurally, it is a closed oval steel loop, strongly elongated along one axis. They are made solid-rolled or welded at the joint by resistance welding followed by heat treatment. For well workovers, links ShE-28-P-B and ShE-50-B with a lifting capacity of 28 and 50 tons are produced.

Automatic machines of the APR type are intended for mechanization of screwing and unscrewing operations, as well as for automation of gripping, holding on weight, releasing and centering the tubing string.

To mechanize the process of screwing and unscrewing the sucker rods, rod wrenches ASHKTM, KMSHE, KARS (automatic and mechanical keys) are used, the principle is similar to the APR.

Spiders are designed to automate the operations of gripping, holding on to the weight, releasing and centering the tubing string or drill pipes during their lowering into the well.

For screwing and unscrewing tubing and drill pipes in the process of round-trip operations during routine and overhaul of wells, a mechanical hydraulic key KPR-12 is used.

Consists of the following main units: a pipe wrench, which produces make-up and unscrewing with a calculated torque; a hydraulic pumping station, which creates the required oil flow and pressure in the hydraulic system, and a key suspension with a hydraulic lift and shock absorber.

The key is a two-speed spur gearbox with a split working gear, in which replaceable grippers are installed. It is completed with a volumetric locking device.

For screwing and unscrewing tubing (tubing) and drill pipe joints by mechanized, as well as by hand for routine and major well repairs, a pipe wrench of the KTL type is intended. It provides reliable grip of tubing, safety of tubing from deformations.

To unscrew the rods with a fixed plunger of a submersible pump with adjustable clamping dies, a circular rod wrench KSHK is used.

During the workover of wells, when the plunger of the deep-well pump is seized, it is necessary to lift the pipes together with the rods. Since the couplings of the pipes do not coincide with the couplings of the rods, after unscrewing the next pipe, there will be a smooth body of the rod above the coupling installed on the elevator, which cannot be gripped with a rod wrench. In a circular key, the rods are gripped by dies that have angled notches with teeth. One of the dies is fixed, attached by two pins to the inner part of the key, and the second is movable, attached to the inner end of the clamping rod.

For manual screwing and unscrewing of pipes of various diameters, chain wrenches are used. The wrench consists of a handle, two pivotally connected cheeks with teeth with flat hinged links. To give strength, the cheeks are thermally processed.

To seal the wellhead during repair work in the well, the GU-48, GU-60, GU-73 dock seals are designed.

Conclusion

Manufacturing process the development and operation of oil fields is the totality of all the actions of people and production equipment necessary for extracting oil from the bowels to the surface, calculating the produced products from wells, and further transporting them to obtain marketable products.

Violation of the integrity of oilfield equipment leads to the termination of wells operation, to an inevitable decrease in oil or gas production, which makes it necessary to perform the so-called workover of a well - a long, laborious and very expensive process; the cost of well workover is often commensurate, and sometimes the same, with the cost of its construction. Hence, the main requirement for the quality of equipment is its reliability.

The equipment of any well must ensure the selection of products in a given mode, measurement of products and the ability to carry out the necessary technological operations taking into account the protection of the subsoil, the environment and prevention of emergencies.Metering installations alsoare a source of information about the condition of wells, for planning geological and technical measures and systematic monitoring of the mode of development of an oil field.

Due to the development of the oil and gas industry Russian market oil and gas field equipment is actively developing, which leads to a rapid upgrade of equipment, the creation of completely new types, sizes and designs.

List of used literature

1. Calculation and design of oilfield equipment: tutorial for universities / M: Nedra / Chicherov L.G., Molchanov G.V., Rabinovich A.M., 1987
2. Development and operation of oil fields: textbook for universities / M .: Nedra / Boyko V.S., 1990.
3. Development of oil and gas fields / tutorial / B.V. Pokrepin
4. Reference guide for the design, development and operation of oil and gas fields. / M .: Nedra / Gimatudinov Sh.K., Borisov Yu.P., Rlzenberg M.D. / 1983.
5. Reference book on current and capital repairs of oil and gas wells / M: Nedra / Amirov A.D., Karapetov K.A., Lemberansky F.D. / 1979.
6. System Maintenance and scheduled repair of drilling and oilfield equipment in the oil industry. / M., VNIIOENG, / Usacheva G.N., Kuznetsova E.A., Koroleva L.M., 1982.
7. Technique and Technoblogy of Raising Wells Drilling. / M .: Nedra / Kolosov D.P., Glukhov I.F., 1988.
8. Technological bases of technology / M.: Metallurgy / I.M. Glushchenko. GI. 1990.
9. Operation of oil and gas wells. / M: Nedra / Muravyov V.M. 1978.

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ADB- aerated drilling mud.

AHPA- abnormally high reservoir pressure.

ANPD- abnormally low reservoir pressure.

OCC- acoustic cement meter.

ATC- motor transport workshop.

BGS- fast-thickening mixture.

BKZ- lateral logging sounding.

BCPS- modular cluster pumping stations.

BSV- drilling waste water.

BPO- production service base. Auxiliary service shops (repairs, etc.)

BOO- drilling rig.

VGK- water-gas contact.

VZBT- Volgograd Drilling Equipment Plant.

PDM- downhole screw motor.

WRC- high-calcium solution.

VKG- internal contour of gas content.

VNKG- outer contour of gas content.

VKN- the inner contour of oil-bearing capacity.

VNKN- outer contour of oil-bearing capacity.

VIC- rig assembly shop.

VNK- oil-water contact.

ERW- the influence of pneumatic explosion.

VPZh- viscoplastic (Bingham) liquid.

GRP- water distribution point.

GGK- gamma-gamma logging.

Hydraulic fracturing- deep-penetrating hydraulic fracturing.

GDI- hydrodynamic research. Well condition survey.

GZhS- gas-liquid mixture.

GIV- hydraulic weight indicator.

GIS — geophysical survey wells.

GZNU- group metering pumping unit. Same as GZU + DNS. Now they are moving away from this, only the old ones have survived.

MSU- group measuring installation. Measurement of the flow rate of the liquid coming from the mustache.

GK- gamma-ray logging.

GKO- clay-acid treatment.

GNO- downhole pumping equipment. Equipment submerged in a well (pump, rods, tubing).

GNS- head oil pumping station.

GPP- hydrosand-blasting perforation.

Gpw- gas flushing liquid.

GPP- Gas Processing Plant.

GPS- head pumping station.

Hydraulic fracturing- hydraulic fracturing.

Fuels and lubricants- fuels and lubricants.

SHG- group collection point.

GTM- geological and technical measures. Measures to increase well productivity.

GTN- geological and technological outfit.

GTU- geological and technological conditions.

ER- hydrophobic emulsion solution.

CSN- booster pumping station. Oil inflow from wells through the GZU along the mustache to the booster pump station for boostering to the commodity park. It can be only booster pumps of liquid or with partial treatment (separation of water and oil).

DU- permissible level.

UGSS — one system gas supply.

ZhBR- reinforced concrete tank.

ZSO- sanitary protection zone.

ZTsN- downhole centrifugal pump.

KVD- pressure recovery curve. Characteristic when bringing the well into operation. Change in pressure in the annular space over time.

KVU- level recovery curve. Characteristic when bringing the well into operation. Change in the level in the annular space over time.

KIN Is the oil recovery factor.

Instrumentation- instrumentation.

CMC- carboxymethyl cellulose.

CNS- cluster pumping station.

TO- major overhaul.

NS- acid treatment.

KRBC- rubber armored round cable.

Cattle — . Repair after "equipment flights", casing violations, is much more expensive than PRS.

CSSC- condensed sulfite-alcohol stillage.

KSSK- a set of shells with a removable core receiver.

LBT- light alloy drill pipes.

LBTM- light-alloy drill pipes for coupling joints.

LBTN- light alloy nipple drill pipes.

MGR- low-clay solutions.

MMC- modified methylcellulose.

MNP- main oil pipeline.

MNPP- main oil product pipeline.

MCI- overhaul period.

MRS- a mechanism for placing candles.

MOON- a method of increasing oil recovery.

NB- drilling pump.

NBT- three-piston drilling pump.

NGDU- oil and gas production department.

NGK- neutron gamma-ray logging.

Tubing- tubing pipes. Pipes through which oil is pumped out at production wells, and water is injected at injection wells.

NPP- oil product pipeline.

NPC- oil pumping station.

OA- cleaning agents.

OBR- treated drilling mud.

OGM- department of the chief mechanic.

OGE- Department of the Chief Power Engineer.

OOS- environmental protection.

OZTS- waiting for the cement to harden.

FROM- treatment of the bottomhole zone.

OTB- safety department.

ODS- Waiting for underground workover of the well. The state of the well, into which it is transferred from the moment of detection of a malfunction and shutdown until the start of repairs. Wells from OPRS to PRS are selected according to their priorities (usually well production rate).

OPS- preliminary discharge settling tank.

ORZ (E)- equipment for separate injection (operation).

OTRS- waiting for the current workover of the well.

Surfactant- surface-active substance.

PAA- polyacrylamide.

Surfactant- surfactants.

FGP- polymer-bentonite solutions.

MPE Is the maximum permissible emission.

MPC- maximum permissible concentration.

PDS- maximum permissible discharge.

Pancreas- flushing liquid.

PPP- bottomhole formation zone.

Tnp- enhanced oil recovery.

PNS- intermediate oil pumping station.

PPZh- pseudoplastic (power-law) fluid.

PPR- scheduled preventive work. Work on the prevention of malfunctions in the wells.

PPP- intermediate pumping station.

PPU- steam mobile installation.

AT- rock cutting tool.

PRS- underground workover of a well. Repair of underground well equipment upon detection of malfunctions.

PRTSBO- rolling and repair shop of drilling equipment.

PSD- design and estimate documentation.

RVS- vertical steel cylindrical tank.

RVSP- vertical steel cylindrical tank with a pontoon.

RVSPK- a vertical steel cylindrical tank with a floating roof.

RIR- repair and insulation works.

RITS- repair engineering service.

RNPP- branched oil product pipeline.

RPDE- bit feed regulator is electric.

RTB- jet-turbine drilling.

RC- repair cycle.

SBT- steel drill pipes.

SBTN- steel nipple drill pipes.

SG- a mixture of tar.

FROM TO- solar-distillate treatment. Well treatment.

Maintenance and repair system- system of maintenance and scheduled repair of drilling equipment.

SKZH- counter of the amount of liquid. Meters for measuring liquid directly on the wells to control measurements on the gas wells.

SNS- static shear stress.

LNG- liquefied natural gas.

SPO- round-trip operations.

PRS- sulfite-alcohol stillage.

SSK- a projectile with a removable core receiver.

T — Maintenance.

MSW- municipal solid waste.

THCV- thermogasochemical impact.

TDH- a torpedo with a detonating cord.

TC- grouting composition.

MSW- cumulative axial torpedo.

THEN- Maintenance.

TP- commodity park. Place of collection and processing of oil (the same as the UKPN).

TP- technological process.

TRS- routine maintenance of the well.

TEP- technical and economic indicators.

EEDN- Group of Oil Production Techniques and Technologies.

UBT- heavy-duty drill pipes, hot-rolled or shaped.

UBR- management of drilling operations.

Ultrasound- ultrasonic flaw detection.

UKB- installation of core drilling.

UKPN- complex oil treatment unit.

USP- a local collection point.

UCH- weighted oil well cement.

UShTS- weighted slag cement.

USHR- carbon-alkali reagent.

UPG- gas treatment unit.

UPNP- management of enhanced oil recovery.

UPTO and KO- management of production and technical support and equipment configuration.

UTT- management of technological transport.

USHGN- installation of a sucker rod pump.

ESP- installation of an electric centrifugal pump.

XKR- calcium chloride solution.

CA- cementing unit.

CDNG- workshop for oil and gas production. Fishing within the NGDU.

CITS- central engineering and technical service.

TsKPRS- workshop for overhaul and underground repair of wells. A workshop within the NGDU, performing workover and workover.

CFB- well casing workshop.

TsNIPR- workshop for research and production works. Workshop within the NGDU.

CPPD- workshop for maintaining reservoir pressure.

CA- circulation system.

DSP- the central collection point.

SHGN- sucker rod pump. With a rocking chair for low production wells.

Winders- tire-pneumatic clutch.

ShPCS- slag-sand cement of joint grinding.

EGU- electrohydraulic shock.

ERA- electro-hydraulic repair unit.

ECP- electrochemical protection.

ESP- electric centrifugal pump. For high production wells.