The order of acceptance of wells after PRS, workover. Information project for employees of the oil and gas industry and students of oil and gas educational institutions

Underground repair is designed to maintain in working condition underground equipment lowered into an oil well, as a rule, with its extraction to the surface for repair or replacement.

It is very laborious and stressful, as it requires a lot of power of special equipment to extract lowered devices from the well and physical effort. It should be noted that PRS is performed outdoors under any climatic conditions.

Currently, more than 70% of all repairs are performed on wells with SRP and less than 30% - on ESP.

When repairing wells, the following operations are carried out (see Figures 81, 82): a) transport - delivery of equipment to the well (t 1); b) preparatory - preparation for repair (t 2); c) lowering - lifting - lifting and lowering oil equipment from the well (t 3); d) operations to clean up the well, replace equipment, eliminate minor accidents (t 4); e) final - dismantling of equipment and preparing it for transportation (t 5).

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

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

Considering the graphs depicting the relative time spent on cycles of operations, we can say that the main efforts of designers should be directed to reducing the time: a) transport operations (it takes up to 50%) by creating high-speed, high-passing units; b) preparatory operations by creating assembleable 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 complexity of the cycle

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

Operations performed during underground well workover (WRS):

1. Cleaning of bottomhole, lifting string from paraffin, hydrate deposits, salts and sand plugs.

2. Conservation and reactivation of wells.

3. Elimination of tubing leaks.

4. Repair of a well with the help of wire rope equipment.

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

Operations performed during well workover (WOC):

1. Extraction from the wells of the equipment remaining in it (tubing, pumps, cable, rod, rope, etc.).

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

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

4. Insulation work.

5. Return to the overlying or underlying horizons.

6. Kick-off and drilling of the swine.

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

8. Repair of injection wells.

9. Increasing and restoring flow rates and injectivity of wells - acid treatment, hydraulic fracturing, hydrosand. perforation, washing with solvents and surfactants.

The oil and gas industry involves the use of a large number of various equipment that is used for the extraction, storage and transportation of petroleum products, as well as well maintenance. To automatically measure 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 health of wells, repair work is carried out, including a major overhaul of wells for 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

The oil and gas industry involves the use of a large number of various equipment that is used for the extraction, storage and transportation of petroleum products, as well as well maintenance. The complex, which combines all the equipment used in the mining industry, is commonly called "oil and gas field 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, mechanization tools and tools for all purposes can be classified by dividing them into eight main groups, each of which consists of several subgroups, which include specific technical means of this group.

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

To automatically measure 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 health of wells, repair work is carried out, including a major overhaul of wells, for which it is necessary to involve sophisticated equipment, up to the use of drilling rigs.

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

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
• determine the equipment used in the workover of wells

1. Equipment installations of sucker rod pump (UShGN)

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

Concrete pumps have the following advantages over other mechanized methods of oil production: high efficiency; repair is possible directly at the fields; different drives can be used for prime movers; SRP units can be used in complicated operating conditions - in sand-producing wells, in the presence of paraffin in the produced oil, with a high GOR, when pumping out a corrosive liquid.

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

Structurally, USHGN equipment includes ground and underground parts.

Ground equipment includes:

• drive (pumping machine) - is an individual drive of a sucker-rod pump, lowered into the well and connected to the drive by a flexible mechanical connection - a string of rods;
• wellhead fittings with polished rod glands are designed for rod sealing and wellhead sealing.

Underground equipment includes:

• tubing (tubing), which is a channel through which the produced fluid flows from the pump to the daylight surface.
• submersible pump intended for pumping out from a well of liquid watered up to 99% with a temperature not exceeding 130°C of plug-in or non-plug type
• rods - designed to transfer reciprocating motion to the plunger of the deep pump from the machine - rocking chair and is a kind of piston pump rod.

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

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

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

The installation works as follows. The plunger pump is driven by a pumping unit, where the rotational motion received from the engine using a gearbox, a crank mechanism and a balancer is converted into a reciprocating motion transmitted to the rod pump plunger through the rod string. When the plunger moves upwards, the pressure in the pump cylinder decreases and the lower (suction) valve rises, opening up fluid access (suction process). At the same time, the liquid column located above the plunger presses the upper (discharge) valve to the seat, rises up and is ejected from 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 fluid 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. Pumping unit type SKD.

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

The pumping unit informs the rods of a reciprocating motion close to sinusoidal. The SC has a flexible rope suspension of the wellhead rod and a folding or swivel head of the balancer for unimpeded passage of tripping mechanisms (travel block, hook, elevator) during underground repairs.

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

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

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

Since the gearbox has a constant gear ratio, a change in the oscillation 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 rod pumps are positive displacement hydraulic machines, where the seal between the plunger and the cylinder is achieved due to the high accuracy of their working surfaces and regulated clearances.

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

Pumps are used in the following types:

• non-insertable
• plug-in.

Non-insert pumps are lowered semi-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-insert pump is simple in design. The cylinder of a non-inserted pump is mounted directly on the tubing string, usually in its lower part. Below the cylinder there is a lock support in which the suction valve is locked. After the cylinder and the lock support are lowered 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 locking support, the plunger suspension height is finally adjusted. The suction valve is lowered into the well, fixed at the lower end of the plunger with a gripping rod. When the suction valve actuates the lock support, the latter locks it with a mechanical lock or friction collars. The plunger is then released from the suction valve by rotating the rod string counterclockwise. After that, the plunger assembly is lifted from the suction valve to the height necessary for the free movement of the plunger down.

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

Plug-in rod pumps are lowered into the well in assembled form. The tool is first lowered into the well at or near the last tubing.

Depending on the conditions in the well, a mechanical lower lock or lower collar type lock is lowered into it, if the pump is with a lock at the bottom, or a mechanical upper lock or upper collar type lock, if the pump is with a lock at the top. Then the entire pumping unit is lowered into the well on a string of rods with a landing unit on the lock support. After fixing the pump on the locking support, adjust the height of the plunger suspension so that it is as close as possible to the lower base of the cylinder. In wells with a high gas content, it is desirable to hang the pump so that the movable pump assembly almost touches the lower base of the cylinder, i.e. Minimize the distance between the suction and discharge valve on the downward stroke of the plunger. Accordingly, to change such a pump, it is not necessary to once again lower and raise the pipes. The plug-in pump works on the same principle as the plug-in pump.

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

NN - non-inserted without catcher;

HH1 - non-inserted with a gripping rod;

HH2S - non-inserted with a catcher.

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

Figure 3—Types of downhole rod pumps.

The use of HH pumps is preferable in wells with a large flow rate, a small depth of descent and a long overhaul period, and HB pumps in wells with a small flow rate, at large depths of descent. The higher the viscosity of the liquid, the higher the landing group is taken. For pumping liquid with high temperature or high content of sand and paraffin, it is recommended to use pumps of the third landing group. With a large depth of descent, it is recommended to use pumps with a smaller clearance.

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

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

1. Basic equipment, main memory scheme and principle of operation.

Group metering installations are built for deep-pumping and fountain-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 tasks, planning of geological and technical measures and systematic control of the oil field development mode. Information is transmitted via telemechanical channels to the control point.

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

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

At the same time, the liquid flow rate is measured in turn for each well. At the outlet of the AGZU, the production of all wells enters one pipeline - a "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).

BT hosts:

• main technological 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 shut-off and control valves;
• engineering life support systems: lighting, heating, ventilation systems; instrumentation - primary instrumentation and control;
• emergency interlock and alarm systems: gas pollution, fire, unauthorized access alarms.

The BA has:

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

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

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

The production of wells GZhS (gas-liquid mixture consisting of crude oil, formation water and associated petroleum gas) through pipelines 1 connected to the installation, sequentially passing the check valve KO and valve ZD, enters the well switch made on the PSM (multi-way well switch) or on PSM with hydraulic drive GP-1, or on three-way ball valves with electric drives with hydraulic drive GP-1, or on three-way ball valves with electric drives, after which it enters the collection manifold 3 connected to the collection system through a common manifold 2 through the cut-off device OKG-4. The well switching unit directs the flow of HCL from the well selected for measurement through the metering branch 4 with the cutter OKG-3 to the double-capacity metering hydrocyclone separator of the HW, where it is separated into liquid and gaseous phases by the centrifugal-gravitational method.

When using a lever-float mechanical system for switching the separator operation modes, the gas passes through pipeline 5 through the butterfly valve of the SP, mixes with the measured liquid and enters the common collection manifold 3 through pipeline 6. The liquid phase separated in the upper part of the HS gas separator accumulates in the lower storage part separator. As the oil level rises, the float P rises and, upon reaching the upper specified level, acts on the rotary valve, blocking the gas line 5. The pressure in the separator rises and the liquid from the separator begins to be displaced through the flow meter TOR-1. When the liquid reaches the lower level, the SG 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 TOR-1 counter.

In the case of equipping the AGZU with instrumentation and control devices, the gaseous phase (associated petroleum gas) from the upper part of the separator enters through a gas line equipped with shut-off and control valves through a gas flow meter to the outlet manifold. In this case, the gas flow 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 operation mode to the liquid drain 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. In this case, the flow rate of the liquid is measured. When the lower liquid level is reached in the separator, the instrumentation means give a signal to change the separator operation mode. In this case, the liquid line closes, and the gas line opens, the separator again switches to the liquid accumulation mode with gas flow measurement.

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

The well switching unit allows you to direct the flow of GLS from 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 candle through the SPPK (spring relief valve). To remove contaminants when cleaning the separator by washing and steaming, there are drainage pipes with shutoff valves and an inspection hatch.

When operating low-rate wells with a low gas factor, AGPUs are used that do not use separators. In this case, the flow of GZhM of the measured well after the well switching unit is sent to the flow meter-liquid counter of the SKZH type, 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 BIUS 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, GLS is fed through the inlet valves to the separator, then to the liquid measuring and gas lines, and the outlet manifold. Bypass line provided. Liquid flow measurement is carried out by mechanical meters with local indication. Accounting for gas consumption is carried out by the calculation method. CICS, as a rule, is not equipped with BA.

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

1. Equipment used forwell workover (WOC)

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

Well workovers include repair work, for which more sophisticated equipment has to be involved, up to the use of drilling rigs. Overhaul is carried out by teams of a specialized service, which has powerful and diverse technical means and relevant specialists.

Well workover equipment consists of:

• Non-aggregate combinable equipment (towers, pumps, rotors, travel systems, hoists).
• Aggregated equipment (installation);
• Downhole tools (chisels, pipes, fishing tools);
• Tools for SPO (elevators, keys).

The main difference between the well workover technique and the current technique lies in the widespread use of a complex of drilling equipment.

All work on the overhaul is accompanied by the descent into the well and the rise of pipes, rods and various tools from it. Therefore, a lifting structure is installed above the wellhead - a tower, a mast with equipment for tripping operations (SPO). 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 during underground repairs. Their transport base is tractors and cars.

Workover units are designed to eliminate violations of the tightness or shape of the wellbore (violation of the tightness of the casing string and cement ring or collapse of the casing string), the elimination of complex downhole accidents and to repair the filter part of the well. The unit - unlike the lift, 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 drive is carried out from the traction engine of the tractor, cars, in the rest from an independent internal combustion engine 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 operations related to this process (descent and retrieval of drill pipes, flushing wells, etc.);
• lowering and lifting tubing;
• installation of operational 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 - tackle 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 was produced with increased reliability and load capacity.

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

Lifting units of this type are subdivided into AzINmash-37A, AzINmash-37A1, AzINmash-37B, mounted on the basis of off-road vehicles KrAZ-255B and KrAZ-260. Lifting installations AzINmash-37A and AzINmash-37A1 are equipped with APR automatic machines for screwing and unscrewing tubing and an automatic key of the KSHE type with an electric drive for screwing pump rods.

Lifting units are equipped with a hook block lifting limiter, a sound and light signaling system for the installation of a tower, control and measuring instruments for the operation of the engine and pneumatic system, as well as other locking systems that ensure the safety of work when installing the unit near the well and tripping operations.

Figure 6. Lifting unit AzINmash-37.

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

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

For the production of tripping operations during the repair of wells not equipped with derrick structures, lifting units APRS-32 and APRS-40 are intended for the production of tethering operations, for cleaning sand plugs with a bailer and for excitation of wells by pistoning (swabbing).

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

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

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

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

Figure 7. Lifting unit UPT1-50. 1 - gearbox; 2 - single-drum winch; 3 air compressor; 4 - front support of the tower; 5 - headlight; 6 - tower with 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, injection of process fluids into the well, well cementing in the bottomhole zone, geophysical surveys, a mobile unit UPD-5M is used. UPD-5M is a self-propelled oilfield machine together with an installation base, including a drum with a stacker for winding long pipes, a pipe feeder into the well, mounted 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 load capacity of 300 kg.

Pipe elevators - several sizes are used to capture casing, drilling and tubing:

• elevators EZN - single-link (SPO with the help of two elevators) with a carrying capacity of 15, 25 and 50 tons. The kit includes: two elevators, a gripping device and a link.
• elevators EG - single-bar 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 a nominal diameter of 48 to 114 mm, a load capacity of 10 - 40 tons.

Rod elevators ESHN (Figure 8) - for capturing a column of rods and holding it in a suspended state during a trip, with a carrying 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 - for rods Zh25.

Figure 8. ESP rod elevator.

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

Lifting hooks intended for suspension of elevators, swivels and other equipment during tripping are produced in two types: single-horned (version I) and three-horned (version II).

Links are used to hang the elevator on a hook. Structurally, this is a closed oval-shaped steel loop, strongly elongated along one axis. They are made solid-rolled or butt-welded by contact welding with subsequent heat treatment. For the overhaul of wells, ShE-28-P-B and ShE-50-B slings are produced with a lifting capacity of 28 and 50 tons.

For mechanization of screwing and unscrewing operations, as well as for automation of gripping, holding on weight, release and centering of the tubing string, automatic machines of the APR type are designed.

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

Spiders are designed to automate the operations of capturing, holding on weight, releasing and centering a string of tubing or drill pipes in the process of lowering them into the well.

For screwing and unscrewing tubing and drill pipes in the process of tripping operations during current and major repairs of wells, a mechanical hydraulic key KPR-12 is used.

It consists of the following main units: a pipe tong that makes up and unscrews with the estimated torque; a hydraulic pumping station that creates the required oil flow and pressure in the hydraulic system, and a tong suspension with a hydraulic lift and a shock absorber.

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

For screwing and unscrewing tubing pipes (tubing pipes) and drill pipe locks by mechanized, as well as manually, during the current and major repairs of wells, a pipe wrench of the KTL type is used. It provides a reliable grip of the tubing, the safety of the tubing from deformation.

To unscrew the rods with a fixed plunger of a deep-well pump with adjustable clamping rams, a circular rod wrench KSHK is used.

During underground workover of wells, when the plunger of the deep pump is stuck, it is necessary to lift the pipes together with the rods. Since the coupling connections of the pipes do not coincide with the connections of the rods, after unscrewing the next pipe, a smooth body of the rod will be located above the coupling installed on the elevator, which cannot be gripped with a rod wrench. In a circular key, the rods are captured by dies with angular cutouts with teeth. One of the dies is fixed, attached with two pins to the inside of the key, and the second is movable, attached to the inner end of the clamping rod.

When manually screwing and unscrewing pipes of various diameters, chain wrenches are used. The key consists of a handle, two hinged cheeks with teeth with flat hinged links. To give strength, the cheeks are thermally processed.

To seal the mouth during repair work in the well, sealers GU-48, GU-60, GU-73 are designed.

Conclusion

The production process for the development and operation of oil fields is a set of all the actions of people and production equipment necessary to extract oil from the bowels to the surface, count the products produced from wells, and further transport them to obtain marketable products.

Violation of the integrity of oilfield equipment leads to the cessation of well operation, to the inevitable decrease in oil or gas production, which makes it necessary to perform the so-called workover of the well - a long, laborious and very expensive process; the cost of repairing a well 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, the measurement of products and the possibility of carrying out the necessary technological operations, taking into account the protection of the subsoil, the environment and the prevention of emergency situations.Measuring units alsoare a source of information about the state of wells, for planning geological and technical measures and systematic monitoring of the oil field development mode.

In connection with the development of the oil and gas industry, the Russian market for oil and gas 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: textbook for universities / M: Nedra / Chicherov L.G., Molchanov G.V., Rabinovich A.M., 1987
2. Development and operation of oil fields: a textbook for universities / M.: Nedra / Boyko V.S., 1990.
3. Development of oil and gas fields / textbook / Pokrepin B.V.
4. Reference guide to the design of the development and operation of oil and gas fields. /M.: Nedra/ Gimatudinov Sh.K., Borisov Yu.P., Rlzenberg M.D./ 1983.
5. Reference book on the current and overhaul of oil and gas wells / M: Nedra / Amirov A.D., Karapetov K.A., Lemberansky F.D. / 1979.
6. The system of maintenance and scheduled repairs of drilling and oilfield equipment in the oil industry. / M., VNIIOENG, / Usacheva G.N., Kuznetsova E.A., Koroleva L.M., 1982.
7. Technique and technology for drilling rising wells. /M.: Nedra/ Kolosov D.P., Glukhov I.F., 1988.
8. Technological foundations 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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GENERAL PROVISIONS

All work on commissioning wells is associated with lowering equipment into them: tubing, downhole pumps, sucker rods, etc.

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

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

A change in the technological mode of well operation necessitates changing the length of the lifting pipe string, replacing tubing lowered into the well with pipes of a different diameter, ESP, USP, eliminating rod breaks, replacing wellhead equipment, etc. All these works are related to underground (current) workover of wells and are carried out by special teams for underground workover.

More complex works related to the liquidation of an accident with a casing string (breakage, collapse), with the isolation of water that appeared in the well, the transition to another productive horizon, catching broken pipes, cable, bail rope or any tool, belong to the category of overhaul.

Works on the overhaul of wells are carried out by special teams. The task of field workers, including workers of underground workover of wells, is to reduce the time of underground workover, to maximize the overhaul period of well operation.

High-quality underground repair is the main condition for increasing oil and gas production. The higher the repair quality, the longer the overhaul period and the more efficient the well operation.

Under the overhaul period of well operation is understood the duration of the actual operation of the well from repair to repair, i.e. the time between two successive 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 (six months) by the number of underground repairs for the same working time in a given well.

To lengthen the period between overhauls, a comprehensive repair is of great importance - repair of surface equipment and underground well repair. In order to maintain the warranty period of the well, the repair of surface equipment must be combined with underground repair. Therefore, in the field, complex schedules for underground repairs and for the repair of surface equipment should be drawn up in advance.

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

The operating factor is always less than 1 and the average for oil and gas companies is 0.94 - 0.98, i.е. from 2 to 6% of the total time falls on repair work in wells.

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

Overhauls are carried out by overhaul teams that are part of the service enterprises of oil companies.

Units of repair work for various purposes are:

 overhaul of the well;

 current workover of the well;

 well-operation to enhance oil recovery.

• A well workover (WOC) is a set of works related to the restoration of the performance of casing strings, cement ring, bottomhole zone, elimination of accidents, lowering and lifting of equipment during separate operation and injection.

  o Well workover (TRS) is a set of works aimed at restoring the performance of well and wellhead equipment, and works to change the operating mode of the well, as well as to clean the lifting string and bottomhole from paraffin-resinous deposits, salts and sand plugs by the TRS team.

  o A well intervention to improve oil recovery is a set of works in a well to introduce agents into the reservoir that initiate the flow of physical, chemical or biochemical processes in the depths of the reservoir, aimed at increasing the ultimate oil displacement factor in this area of ​​the deposit.

The unit of repair work in the above areas (repair, well-operation) is a set of preparatory, main and final works carried out by the team for the current, major workover of wells or the intensification unit, from the transfer of the well by the customer to the completion of the work provided for by the plan and accepted by the act.

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

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

o with the help of a specially lowered pipe string;

o by pumping through tubing or annulus;

o on a cable or on a rope.

ORGANIZATION OF WORK WITH THE MECHANIZED FUND

The procedure for determining the causes of repeated and premature repairs of SRP, ESP.

1. Work carried out by GTS TsDNG before putting the well into repair. In the event of a decrease or lack of supply, the technological service studies the history of the work being done on the well (measurements, reasons for previous repairs, well treatment, etc.), a dynamometer chart is taken, the tubing is pressure tested, and the well is flushed. After that, a drilling team is placed on the well.

2. After lifting the GNO, a preliminary investigation is carried out at the wellhead. The chairman of the ITR commission of the CDNG determines the remaining members of the commission of the CDNG independently. The results of the investigation are documented in an act and attached to the warranty passport. If obvious reasons for the failure of the GNO are found, measures are taken to prevent them. The equipment is not dismantled during the initial investigation, with a wedge it is allowed to unscrew the suction valve.

3. After that, the equipment is sent for commission analysis (to 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 GNO repair, proceeds to determine the cause of the failure and the guilty organization.

5. If the parties did not come to a consensus at 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 in the lapels of the rods.

1. In case of detection of breakage, lapel of the rods in the case of workover or workover, the brigade submits an application to the CDNG.

2. The commission of investigation headed by the technologist (or TsDNG engineer) goes to the bush, where it is checked whether the lapel is broken (weight indicator readings are taken into account), the layout of the rods, and a sample of the broken element 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 of the rods with centralizers, etc.)

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

The procedure for repairing wells equipped with NSV.

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

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

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

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

2.3. With an operating time of more than 365 days and the presence of a conical Z.O.

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

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

5. At the end of the repair, the GNO is pressure tested with a pressure drop of more than 5 atm in 5 minutes, the TsDNG technologist determines the reason for the lack of pressure testing using a dynamometer chart, fills out a warranty certificate, which indicates the reason for the rise. It is forbidden for the crews of the PRS, KRS to re-lift the SRP without a guarantee passport.

The order of acceptance of wells after PRS, workover.

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

2. After signing the act for pressure testing, the well is considered accepted after repair.

3. If the pressure drops more than 5 atm in 5 minutes, the technologist of the TsDNG determines the reason for the lack of pressure testing using a dynamometer chart, fills out a warranty certificate, in which it indicates the reason for the rise. It is forbidden for the crews of the PRS, KRS to re-lift the SRP without a guarantee passport.

4. If necessary, the crew of the workover worker, determined by the CDNG, is obliged to flush the GNO and pressure test the tubing within 2 days after the completion of the repair.

5. With optimal operation of GNO, after 2 days from the moment of launch, for SRP N - 44,N - 57 ESP, for SRP N-32, N-29 an act is signed for underground workover of wells.

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

ADB— aerated drilling fluid.

AHRP— abnormally high reservoir pressure.

ANPD— abnormally low reservoir pressure.

ACC- acoustic cement meter.

ATC- motor transport shop.

BGS- quick mix.

BKZ— lateral logging sounding.

BKPS- block cluster pumping stations.

BSV— drilling wastewater.

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

BOO- drilling rig.

VGK— water-gas contact.

VZBT- Volgograd plant of drilling equipment.

HDM- screw downhole motor.

WRC- high-calcium solution.

VKG— internal gas-bearing contour.

VNKG— external contour of gas-bearing.

WPC— internal oil-bearing contour.

VNKN- the outer contour of the oil-bearing.

VIC- assembly shop.

VNK— oil-water contact.

ERW— impact of pneumatic explosion.

RRP- viscoplastic (Bingham) fluid.

GRP- water distribution point.

GGK— gamma gamma logging.

GGRP— deep-penetrating hydraulic fracturing.

GDI— hydrodynamic studies. Study of the state of the well.

GZhS- gas-liquid mixture.

GIV- hydraulic weight indicator.

GIS— geophysical survey of wells.

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

GZU— group metering installation. Measurement of the flow rate of liquid coming from the mustache.

GC— gamma ray logging.

GKO- clay treatment.

GNO— deep pumping equipment. Equipment submerged into the well (pump, rods, tubing).

STS- main oil pumping station.

GSP- hydro-sandblasting perforation.

YPL— gas-flushing liquid.

GPZ- Gas Processing Plant.

GPS- head pumping station.

hydraulic fracturing— hydraulic fracturing.

fuel and lubricants- fuels and lubricants.

GSP- group collection point.

GTM— geological and technical measures. Measures to increase the productivity of wells.

GTN- geological and technological outfit.

GTU— geological and technological conditions.

GER- hydrophobic emulsion solution.

CSN- booster pumping station. The flow of oil from wells through the GZU along the mustache to the BPS for booster to the commodity park. It can only be boosted by liquid pumps or with partial processing (separation of water and oil).

DU- acceptable level.

ESG- unified gas supply system.

JBR- reinforced concrete tank.

ZSO- zone of sanitary protection.

ZCN- downhole centrifugal pump.

KVD— pressure recovery curve. Characteristics when the well is put into operation. Change in pressure in the annulus over time.

HLC is the level recovery curve. Characteristics when the well is put into operation. Change in the level in the annulus over time.

CIN— oil recovery factor.

KIP- control and measuring devices.

CMC- carboxymethyl cellulose.

KNS- cluster pumping station.

To- overhaul.

KO- acid treatment.

CRBC— cable rubber armored round.

cattle — . Repair after "flights of equipment", violations of the casing, costs an order of magnitude more expensive than the PRS.

KSSB— condensed sulfite-alcohol stillage.

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

LBT- light-alloy drill pipes.

LBTM— light-alloy drill pipes of coupling connection.

LBTN— light-alloy drill pipes of nipple connection.

IGR- low clay solutions.

WMC- modified methylcellulose.

MNP- main oil pipeline.

MNPP— main oil product pipeline.

MCI- overhaul period.

MRS- the mechanism for arranging candles.

EOR- 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.

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

NPP- oil pipeline.

NPS- oil pumping station.

OA- cleaning agents.

OBR— treated drilling fluid.

OGM- Department of the chief mechanic.

OGE- department of the chief power engineer.

OOS— environmental protection.

WOC- waiting for the cement to harden.

FROM— treatment of the bottomhole zone.

OTB- safety department.

OPRS— waiting for underground workover of the well. The state of the well in which it is transferred from the moment a malfunction is detected and shut down until the repair begins. Wells from the pilot well to the pilot well are selected by priority (usually - well flow rate).

OPS- pre-discharge sump.

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

OTRS— waiting for the current workover of the well.

surfactant- surface-active substance.

PAA- polyacrylamide.

surfactant- surfactants.

PBR— polymer-bentonite solutions.

MPE— maximum allowable emission.

MPC- maximum permissible concentration.

PDS- maximum allowable discharge.

pancreas- washing liquid.

PZP— bottomhole formation zone.

PNP— enhanced oil recovery.

PNS— intermediate oil pumping station.

RPL— pseudoplastic (power-law) liquid.

PPR- planning and preventive work. Works on the prevention of faults in wells.

teaching staff- intermediate pumping station.

PPU- steam plant.

AT- rock cutting tool.

PRS- underground well repair. Repair of underground well equipment in case of malfunctions.

PRTSBO— rental and repair shop of drilling equipment.

PSD- design and estimate documentation.

RVS— vertical steel cylindrical tank.

RVSP- a vertical steel cylindrical tank with a pontoon.

RVSPK— vertical steel cylindrical tank with a floating roof.

RIR- repair and insulation works.

RITS— repair engineering and technical service.

RNPP- branched oil pipeline.

RPAP— electric bit feed regulator.

RTB— jet-turbine drilling.

RC- repair cycle.

SBT- steel drill pipes.

SBTN— steel drill pipes of nipple connection.

SG- a mixture of tars.

FROM TO— solar-distillate processing. Well treatment.

Maintenance and PR system— system of maintenance and scheduled repair of drilling equipment.

SQOL- liquid counter. Meters for liquid measurements directly on the wells to control measurements at the GZU.

SNA— static shear stress.

LNG- liquefied natural gas.

SPO- lowering and lifting operations.

PRS- sulfite-alcohol stillage.

SSC- a projectile with a removable core receiver.

T- Maintenance.

MSW- municipal solid waste.

TGHV— thermogas-chemical effect.

TDSH— torpedo with a detonating cord.

TC- backfill composition.

MSW— torpedo cumulative axial action.

THEN- Maintenance.

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

TP- technological process.

TRS— current workover of the well.

TEP— technical and economic indicators.

EEDN— group of Techniques and Technologies of Oil Production.

UBT— hot-rolled or shaped drill collars.

UBR— management of drilling operations.

ultrasound— ultrasonic flaw detection.

UKB— installation of core drilling.

UKPN— installation of complex oil treatment.

USP- precinct collection point.

UCG- weighted oil well cement.

USC- weighted slag cement.

USHR- carbon alkali reagent.

UPG— gas treatment plant.

UPNP— management of enhanced oil recovery.

UPTO and CO— 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.

HKR- calcium chloride solution.

CA- cementing unit.

CDNG- oil and gas production shop. Fishing within the framework of NGDU.

CITS— central engineering and technical service.

CKPRS— workshop for overhaul and underground workover of wells. A workshop within the framework of the OGPD that performs workover and workover.

CKS— well casing shop.

TsNIPR— shop of research and production works. Workshop within the framework of NGDU.

CPPD— reservoir pressure maintenance shop.

CA- circulation system.

DSP- central collection point.

SHGN— sucker rod pump. With rocking chair, for low-rate wells.

SHPM- tire-pneumatic clutch.

SPCA- slag-sand cement of joint grinding.

ESU- electro-hydraulic shock.

ERA- electro-hydraulic repair unit.

ECP— electrochemical protection.

ESP- electric centrifugal pump. For high yield wells.