KR20230040097A - Test method for esp and tubing monitoring system reflecting production conditions and obstacle elements in oil and gas wells(tubing leakage) - Google Patents

Abstract

The present invention relates to a test method for an ESP and tubing monitoring system that reflects oil and gas well underground production conditions and obstacles. More specifically, the present invention relates to a test method for an ESP and tubing monitoring system that reflects oil and gas well underground production conditions and obstacles capable of deriving productivity improvement mechanisms and performance degradation influencing factors according to underground production conditions and obstacles for an oil and gas well production system including ESP and tubing. The test method for an ESP and tubing monitoring system according to the present invention comprises the steps of: setting test conditions to reflect underground production conditions and obstacles; operating an oil and gas supply simulation unit and an oil and gas production simulation unit; checking the status of the oil and gas production simulation unit through a monitoring unit; and detecting a leakage status of a transmission member while checking the status of the oil and gas production simulation unit.

Description

TUBING LEAKAGE of ESP and TUBING MONITORING SYSTEM REFLECTING PRODUCTION CONDITIONS AND OBSTACLE ELEMENTS IN OIL AND GAS WELLS (TUBING LEAKAGE)}

The present invention relates to a test method for an ESP and tubing monitoring system reflecting oil well production conditions and obstacles. More specifically, ESP and tubing reflecting oil well production conditions and obstacles that can derive productivity improvement mechanisms and performance degradation influencing factors according to underground production conditions and obstacles for oil well production systems including ESP and tubing It is about the test method of the monitoring system.

In general, the artificial oil extraction method to improve the productivity of reservoirs is applied to 95% of production wells around the world, and ESP (Electrical Submersible Pump) in particular is widely used not only in traditional oil and gas fields but also in non-traditional oil and gas fields.

ESP life expectancy is important because pump performance and lifespan are reduced due to overheating, abrasion, corrosion, etc., and additional costs and production stoppage occur due to replacement of old pumps.

In addition, in the case of tubing, if problems such as unexpected leakage due to deterioration occur, it is important to identify this in advance because production loss and additional costs and production stoppage due to tubing replacement occur. .

Therefore, it is necessary to analyze the failure occurrence mechanism of ESP and tubing and the factors affecting performance deterioration through investigation of various failure cases. In order to understand the normal state of ESP and tubing and performance degradation due to failure, a laboratory-scale flow loop experiment must be conducted, and also classify flow experimental variables necessary for performance analysis of ESP and tubing and design the experimental range it is necessary to do

However, since there is no facility capable of analyzing the performance of the ESP and tubing and a test method using the same, it is urgent to prepare for this.

The technical problem to be solved by the present invention is an oil well production condition and obstacles that can derive a productivity improvement mechanism and performance degradation influencing factors according to underground production conditions and obstacles for an oil well production system including ESP and tubing It is to provide a test method of the ESP and tubing monitoring system reflecting the

The technical problem to be solved in the present invention is not limited thereto, and other technical problems not mentioned will be clearly understood by those skilled in the art from the following description.

In order to solve the above technical problem, the test method of the ESP and tubing monitoring system according to the present invention includes an oil gas supply simulation unit that simulates the oil gas supply state, and production that produces oil gas supplied through the oil gas supply simulation unit. An oil gas production simulation unit equipped with a member and a transmission member for transmitting the produced oil gas, a detection unit for detecting the state of the oil gas production simulation unit when oil gas is produced, and a signal transmitted from the detection unit In the test method of the ESP and tubing monitoring system including a monitoring unit for checking the state of the oil gas production simulation unit, setting test conditions to reflect underground production conditions and obstacles, and the oil gas supply simulation unit and the Operating the gas production simulation unit, checking a state of the oil gas production simulation unit through the monitoring unit, and detecting a leakage state of the transfer member while checking the state of the oil gas production simulation unit.

At this time, the oil gas supply simulation unit includes a first fluid supply member for supplying a first fluid in a liquid state, a second fluid supply member for supplying a second fluid in a gaseous state, and a foreign material supply for supplying foreign substances in a solid state. A member is provided, and the production member produces the oil gas containing the first fluid, the second fluid, and the foreign matter supplied through the oil gas supply simulation unit, and reflects the underground production conditions and obstacles. Setting test conditions to be possible may include first setting basic operating conditions of the production member.

At this time, the oil gas supply simulation unit is provided with a supply pipe member through which the oil gas flows, and a supply port to which the supply pipe member is directly connected to the production member so that the oil gas supplied through the supply pipe member is directly supplied to the inside. And, a discharge port directly connected to a discharge pipe member to discharge the pressurized oil gas is provided, and the transmission member is provided with an inner tube communicating with the discharge pipe member and moving the oil gas, and provided outside the inner tube An outer tube for heating and pressurizing the inner tube is provided, and the step of setting the basic operating condition of the production member is to supply only the first fluid in a liquid state through the first fluid supply member to the supply port. and setting a basic operating condition of the production member through an increase pressure, which is a difference between a supply pressure of the oil gas passing through and a discharge pressure of the oil gas passing through the discharge port.

At this time, the step of setting the basic operating conditions of the production member may include checking a tendency of the rising pressure according to an increase in the supply flow rate of the first fluid supplied to the production member, and the first fluid that may be supplied to the production member. The method may further include setting a maximum flow rate of the fluid and a maximum value of the rising pressure as basic operating conditions of the production member.

At this time, the step of setting test conditions to reflect the underground production conditions and obstacles is a leak test provided with a communication hole communicating the inside and outside of the inner tube so that the oil gas moving through the inner tube flows out. A step of installing the member may be further included.

In this case, the step of installing the leak test member may be a step of screwing a leak test member having the through hole formed therein and having a thread formed thereon to a corresponding thread formed in the inner tube.

At this time, the step of setting test conditions to reflect the underground production conditions and obstacles may further include increasing a diameter of the communication hole to increase a leakage amount of the oil gas flowing out of the inner tube. .

At this time, the step of checking the state of the oil gas production simulation unit through the monitoring unit detects vibration and sound of the oil gas passing through the supply port and the discharge port in a state in which the oil gas flows out through the inner tube. and checking a state of the oil gas production simulation unit through a vibration sensing member and a sound sensing member.

At this time, the step of checking the state of the oil gas production simulation unit through the monitoring unit, in a state in which the oil gas flows out through the inner tube, the sound of the oil gas passing through one end of the inner tube and the sound of the inner tube The method may further include checking a state of the oil gas production simulation unit through a sound sensing member that senses a sound of the oil gas passing through the other end.

According to the test method of the ESP and tubing monitoring system of the present invention having the above configuration, liquid and gaseous fluids and solid foreign substances are supplied to the production member and then moved through the transmission member in the same way as in the actual production site It is possible to accurately derive the factors affecting performance degradation that may occur in , and to reflect them, it is possible to derive a mechanism for improving productivity.

In addition, it checks the signal when a production member is damaged due to foreign substances in a solid state such as sand, and compares the similarity of the signal found at the actual production site to predict the failure and replacement time of the production member, thereby improving the quality of the oil and gas production site. It is possible to maximize operation by minimizing time loss and cost loss at the same high unit price.

The effects of the present invention are not limited to the above effects, and should be understood to include all effects that can be inferred from the detailed description of the present invention or the configuration of the invention described in the claims.

1 is a flow chart illustrating a test method of an ESP and tubing monitoring system according to the present invention.
2 is a schematic diagram of an ESP and tubing monitoring system according to the present invention.
Figure 3 is a flow chart showing the steps of first setting the basic operating conditions of the production member according to the present invention.
4 is a sectional view showing a production member according to the present invention.
5 is a schematic diagram showing a second fluid supply member according to the present invention.
6 is a schematic diagram showing a foreign material supply member according to the present invention.
7 is a cross-sectional view showing a transmission member according to the present invention.
8 is a cross-sectional view showing a circulation unit according to the present invention.
9 is a flowchart illustrating the steps of setting test conditions for leakage of an inner tube while setting test conditions to reflect underground production conditions and obstacles according to the present invention.
10 is a flowchart illustrating the step of checking the state of the oil and gas production simulation unit through the monitoring unit according to the present invention.

Hereinafter, with reference to the accompanying drawings, embodiments of the present invention will be described in detail so that those skilled in the art can easily carry out the present invention. This invention may be embodied in many different forms and is not limited to the embodiments set forth herein. In order to clearly describe the present invention in the drawings, parts irrelevant to the description are omitted, and the same reference numerals are attached to the same or similar components throughout the specification.

In this specification, terms such as "include" or "have" are intended to designate that there is a feature, number, step, operation, component, part, or combination thereof described in the specification, but one or more other features It should be understood that it does not preclude the possibility of the presence or addition of numbers, steps, operations, components, parts, or combinations thereof. In addition, when a part such as a layer, film, region, plate, etc. is said to be “on” another part, this includes not only the case where it is “directly on” the other part, but also the case where there is another part in the middle. Conversely, when a part such as a layer, film, region, plate, etc. is said to be "under" another part, this includes not only the case where it is "directly below" the other part, but also the case where another part exists in the middle.

1 is a flow chart showing a test method of an ESP and tubing monitoring system according to the present invention, FIG. 2 is a schematic diagram of an ESP and tubing monitoring system according to the present invention, and FIG. 3 is a basic operating condition of a production member according to the present invention 4 is a cross-sectional view showing a production member according to the present invention, FIG. 5 is a schematic diagram showing a second fluid supply member according to the present invention, and FIG. Figure 7 is a cross-sectional view showing a transfer member according to the present invention, Figure 8 is a cross-sectional view showing a circulation unit according to the present invention.

As shown in FIG. 1, the test method of the ESP and tubing monitoring system according to the present invention includes setting test conditions to reflect underground production conditions and obstacles (S100), oil and gas supply simulation unit 100 and Operating the oil and gas production simulating unit 200 (S200), checking the state of the oil and gas production simulating unit 200 through the monitoring unit 300 (S300), and oil and gas production simulating unit 200 and detecting a leakage state of the transfer member 220 while checking the state of (S400). At this time, the ESP and tubing monitoring system includes a first fluid supply member 110 for supplying a first fluid in a liquid state, a second fluid supply member 120 for supplying a second fluid in a gaseous state, and foreign substances in a solid state The oil gas supply simulating unit 100 equipped with the foreign matter supply member 130 for supplying the oil gas supplied through the oil gas supply simulating unit 100, the first fluid, the second fluid, and the oil gas containing the foreign matter An oil gas production simulation unit 200 equipped with a production member 210 that produces oil and a transmission member 220 that transmits the oil gas produced through the production member 210, and the production member 210 during oil gas production ) and the detection unit 400 for detecting the state of the transmission member 220, and a monitoring unit for checking the state of the production member 210 and the transmission member 220 using signals transmitted from the detection unit 400 (300).

The aforementioned oil and gas supply simulating unit 100 may be configured to simulate non-traditional oil/gas fields such as shale gas as well as traditional oil/gas fields.

Shale gas is natural gas that is developed and produced in hydrocarbon-rich shale layers. Normal natural gas is generated in shale layers and then moved to the surface to be stored in one place, while shale gas is blocked by rock layers that are impervious to gas and moves. Since the gas is trapped in the shale layer without being able to do so, it is preferable that the oil gas supply simulating unit 100 is configured to simulate such an environment.

In a state where such an environment is simulated through the oil gas supply simulating unit 100, the oil gas production simulating unit 200 produces and transmits oil gas containing the first fluid, the second fluid, and foreign substances. The oil gas production simulation unit 200 includes a production member 210 that produces oil gas and a transmission member 220 that transmits the oil gas produced through the production member 210 . ESP (Electrical Submersible Pump) described above may be used as the production member 210, but if a configuration that can be produced in a mixture of a gaseous gas such as shale gas and a liquid state fluid is used, a different type of pump is used. It is also possible.

In addition, in order to derive factors that can affect performance in the process of producing shale gas, it is necessary to accurately simulate the actual shale gas production state. That is, since shale gas is characterized by being widely spread in the fine crevices of rocks, vertical drilling like conventional natural gas is impossible, and it can be produced in the same way as horizontal drilling. It is preferable to configure oil gas production through the oil gas production simulation unit 200 in a state where the horizontal drilling situation is accurately simulated.

In particular, by allowing the second fluid in the gaseous state and the foreign matter in the solid state to be supplied to the production member 210, the amount of foreign matter such as gas volume and sand corresponding to the obstacle in the ground is simulated It is possible to check how the effect affects the production member 210 and the transmission member 220 .

At this time, the production member 210 and the transmission member 210 and the transmission member using the detection unit 400 for detecting the state of the production member 210 and the transmission member 220 during oil gas production, and the signal transmitted from the detection unit 400 A monitoring unit 300 for checking the state of 220 is provided, and through this, oil gas can be produced and monitored while liquid and gaseous fluids and solid foreign substances are included in the same way as in the actual production site. Therefore, it is possible to accurately derive the factors affecting performance deterioration that may occur in actual production sites, and to reflect them, it is possible to derive a mechanism for improving productivity.

In addition, the above-described monitoring unit 300 may be configured to connect a transmitted signal to a computer, receive a data storage signal to a PCL (Programmable Logic Controller), and store data in the computer.

At this time, the step of setting test conditions to reflect the above-mentioned underground production conditions and obstacles (S100) may include first setting basic operating conditions of the production member 210 (S110).

Fig. 4 is a cross-sectional view showing a production member according to the present invention, Fig. 5 is a schematic view showing a second fluid supply member according to the present invention, and Fig. 6 is a schematic view showing a foreign matter supply member according to the present invention.

As shown in FIG. 4, the first fluid in liquid state, the second fluid in gaseous state, and the foreign matter in solid state are all supplied in a mixed state to the production member 210, as shown in FIG. 5 for this purpose. As described above, a second fluid supply member 120 for supplying a second fluid in a gaseous state and, as shown in FIG. 6 , a foreign substance supply member 130 for supplying a foreign substance in a solid state may be provided.

In this case, the foreign material supply member 130 may include a foreign material tank 131 in which sand and other foreign materials are accommodated. It is preferable that the foreign matter tank 131 is provided with a detachable cover so as to be able to open and close the inside, and it is possible to more accurately simulate underground production conditions while changing the type of foreign matter through the cover.

As shown in FIG. 4, the oil gas supply simulation unit 100 is provided with a supply pipe member 140 through which oil gas flows, and the oil gas supplied through the supply pipe member 140 is provided to the production member 210 described above. A supply port 211 to which the supply pipe member 140 is directly connected may be provided so as to be directly supplied to the inside.

That is, the supply pipe member 140 is provided to the supply port 211 provided in the production member 210 so that liquid and gaseous oil gas and solid foreign matter supplied through the oil gas supply simulation unit 100 are directly supplied. it will be directly connected. If the system is configured in such a way that oil gas and foreign substances are sucked through the production member 210 while being accommodated in a separate tank member, an error may occur due to a vortex phenomenon formed in the process of sucking oil gas. As described above, if the supplied liquid and gaseous oil gas and solid foreign matter are configured to be directly supplied to the production member 210 through the supply port 211, the occurrence of the above error can be minimized, thereby improving underground production conditions. It can be accurately copied, and the conditions of the production member 210 and the transmission member 220 according to underground production conditions can be more accurately confirmed and quantified.

As shown in FIG. 5 , the sensing unit 400 may include a flow rate sensing member 410 that senses a flow rate of the second fluid supplied through the second fluid supply member 120 . Through this, it is possible to more accurately control the amount of gas corresponding to the obstacle in the ground.

In addition, as shown in FIG. 6 , the first heating member 150 and the first pressure are supplied to the oil and gas supply simulation unit 100 so that foreign substances supplied through the foreign substance supply member 130 are supplied in a heated and pressurized state. A member 160 may be provided. That is, since the supplied foreign substances are supplied in a state of elevated temperature and pressurization in accordance with underground production conditions, it is possible to more accurately check and quantify the conditions of the production member 210 and the transmission member 220 according to these conditions.

7 is a cross-sectional view showing a transmission member according to the present invention.

As shown in FIG. 7 , the transmission member 220 is provided on the inner tube 221 through which the oil gas produced through the production member 210 moves, and on the outside of the inner tube 221, the inner tube 221 ) may include an outer tube 222 for raising and pressurizing the temperature.

This inner tube 221 is installed in direct communication with the production member 210 and is configured to move the produced oil gas.

At this time, in the case of shale gas, unlike general natural gas, it exists in a much deeper location. It is necessary to reflect the deep location where Edo shale gas is buried, and for this purpose, as described above, the inner tube 221 is heated and pressurized using the outer tube 222.

In addition, a plurality of divided regions may be formed in the outer tube 222, and by varying the degree of heating and pressurizing the inner tube 221 for each divided region, the situation during shale gas production can be more accurately simulated. do.

At this time, as shown in FIG. 4, the production member 210 has a discharge pipe communicating with the inner tube 221 so that liquid and gaseous oil gases and solid foreign substances discharged from the inside move to the inner tube 221. A discharge port 212 to which member 214 is directly connected may be provided. With this configuration, since the discharged liquid and gaseous oil gas and solid foreign matter are directly discharged to the discharge pipe member 214 through the discharge port 212, errors that may occur during the discharge process can be minimized. It is possible to more accurately check and quantify the conditions of the production member 210 and the transmission member 220 according to underground production conditions.

At this time, as shown in FIG. 4 , the sensing unit 400 includes a first temperature sensing member 420 and a first pressure sensing member that sense the temperature and pressure of the oil gas supplied through the supply pipe member 140 ( 430), and a second temperature sensing member 440 and a second pressure sensing member 450 that sense the temperature and pressure of the oil gas discharged through the discharge pipe member 214. In this configuration, the operating state of the production member 210 can be accurately confirmed through the rising pressure (ΔP) and the temperature difference (Differential Temperature), which means the differential pressure between the supply port 211 and the discharge port 212. be able to

At this time, as shown in FIG. 7, a working fluid for heating and pressurizing the inner tube 221 while wrapping the inner tube 221 is accommodated inside the outer tube 222, and the oil and gas production simulation unit 200 A second heating member 230 and a second pressing member 240 for raising and pressurizing the working fluid may be provided.

Water having a high specific heat may be used as a working fluid for raising the temperature of the inner tube 221 . As such, when water is used, the specific heat is large, so it may take some time to raise the temperature of the water to a certain temperature in accordance with the underground situation where shale gas is buried in the initial setting, but once the water is heated to a certain temperature, the range of temperature change Since it is not large, it is easy to maintain it for underground conditions.

In addition, nitrogen can be used as a working fluid for pressurizing the inner tube 221, and the degree of pressurization of the inner tube 221 can be adjusted by adjusting the amount of nitrogen accommodated in the outer tube 222. .

In this case, the second pressing member 240 may include an inlet 241 for pressurizing the inner tube 221 by additionally supplying a working fluid to the inside of the outer tube 222 .

As described above, the temperature of the working fluid accommodated inside the outer tube 222 can be adjusted using the second heating member 230, and the degree to which fluid such as nitrogen is additionally supplied using the inlet 241 can be controlled. By adjusting, the degree to which the inner tube 221 is pressurized can be adjusted. The second heating member 230 may be a heater surrounding the outer tube 222 .

In addition, when a plurality of divided regions are formed in the outer tube 222, the second heating member 230 and the inlet 241 may be respectively provided to correspond to each of these divided regions, through which underground burial of shale gas You can simulate the situation more accurately.

As shown in FIG. 7 , the sensing unit 400 includes a third temperature sensing member 480 and a third pressure sensing member 490 that sense the temperature and pressure of the oil gas moving through the inner tube 221. can include more.

As the third temperature sensing member 480 and the third pressure sensing member 490, a Fiber Bragg Grating (FBG) sensor may be used. An optical fiber pattern is formed inside the FBG sensor, and the temperature and pressure can be sensed by detecting the change in the distance between the fiber pattern due to the temperature and pressure of the oil gas and foreign matter moving along the inner tube 221. An optical fiber cable may be used to transmit these temperature and pressure signals to the monitoring unit 300.

In this way, it is necessary to replace the third temperature sensing member 480 and the third pressure sensing member 490 provided in the inner tube 221, or to measure other factors, the third temperature sensing member 480 and the third pressure sensing member 480 3 When it is necessary to replace the pressure sensing member 490 In order to separate the third temperature sensing member 480 and the third pressure sensing member 490 provided in the inner tube 221 as described above, the following procedure is used. it is possible to replace

First, fluids such as water and nitrogen provided inside the outer tube 222 must be discharged, and a separate outlet for this may be formed. When the fluid provided inside the outer tube 222 is discharged through the outlet, the outer tube 222 is separated when the fixed state of the outer tube 222 is released by loosening the bolts of the flange fixing the outer tube 222. You can do it. When the outer tube 222 is separated in this way, the inner tube 221 is exposed to the outside, so that the third temperature sensing member 480 and the third pressure sensing member 490 can be replaced.

In addition, as shown in FIG. 4 , the sensing unit 400 includes a vibration sensing member 460 for sensing vibration of the drive motor 213 provided in the production member 210, and a supply port 211 and a discharge port. It may further include a sound sensing member 470 for detecting the sound of oil gas passing through 212, and such a sound sensing member 470 is further provided at the front and rear ends of the inner tube 221, respectively. It may be configured to sense the sound of oil gas passing through (221).

For example, an acoustic emission (AE) sensor may be used as the acoustic sensing member 470 . This AE sensor detects the micro-unit sound generated while the oil gas is moving, and checks the sound pattern generated when the ratio of the second fluid in the gaseous state and the foreign matter in the solid state is changed in addition to the first fluid in the liquid state. Acoustic changes can be quantified according to the production conditions in the ground.

That is, the state of the production member 210 and the transmission member 220 can be more accurately confirmed by checking the vibration and sound signals obtained through the vibration sensing member 460 and the sound sensing member 470 .

As shown in FIG. 7 , the inner tube 221 is provided with a leak test member 250 so that the oil gas moving through the inner tube 221 flows out, and the leak test member 250 has the inner tube 221 ) May be provided with a communication hole 251 communicating the inside and outside.

The communication hole 251 may be configured to be directly opened and closed by a worker, and when the operator opens the communication hole 251, liquid and gaseous oil gases and solid foreign substances moving along the inner tube 221 It is possible to check the state of the transmission member 220 through a signal generated as a result of some leakage, and to quantify it.

For example, it is possible to form a tap penetrating the inner tube 221 and install the leakage test member 250 having a thread formed therein in a manner of screwing, and the communication hole 251 having a different diameter is formed. If the leak test member 250 is used, it is possible to simulate various leak situations.

8 is a cross-sectional view showing a circulation unit according to the present invention.

As shown in FIG. 8, when the first fluid and the second fluid are simultaneously transmitted through the oil and gas production simulation unit 200, recovering only the liquid first fluid back to the oil and gas supply simulation unit 100 It may further include a circulation unit 500 for

That is, in the process of repeating the test of the production member 210 and the transmission member 220, even if the second fluid in gaseous state is discharged to the outside, the first fluid in liquid state passes through the circulation unit 500 to the oil gas supply simulation unit. It is configured to be recovered as (100).

The circulation part 500 is in communication with the inner tube 221 and the upper circulation pipe 510 in which the first fluid and the second fluid move simultaneously, and communicates with the upper circulation pipe 510, but removes the second fluid , the buffer tank 520 that separates and transmits only the first fluid, and the buffer tank 520 and the first fluid supply member so that the first fluid transmitted from the buffer tank 520 is recovered to the oil gas supply simulation unit 100 It may include a lower circulation pipe 530 communicating with (110).

In the case of the upper circulation pipe 510, since it is formed to have the same diameter as the inner tube 221, it is possible to effectively prevent unnecessary resistance from being generated due to a decrease in diameter.

After the first fluid and the second fluid are transferred to the buffer tank 520 through the upper circulation pipe 510 as described above, the gaseous second fluid is removed, and only the liquid first fluid flows through the lower circulation pipe 530. It is configured to be recovered to the oil and gas supply simulation unit 100 through. At this time, the foreign matter in solid state may also be moved through the lower circulation pipe 530, but it is also possible to configure such that only the first fluid in liquid state is recovered while the foreign matter in solid state is removed.

At this time, a gas discharge member 521 for discharging the second fluid out of the first fluid and the second fluid transmitted through the upper circulation pipe 510 may be provided on the upper part of the buffer tank 520 . Since the gas discharge member 521 is provided at the upper part, the second fluid such as gas has a low specific gravity and is removed through the gas discharge member 521, and the first fluid such as liquid has a high specific gravity so that the lower circulation pipe 530 is removed. is recovered through

At this time, it is preferable that the diameter d2 of the lower circulation pipe 530 is relatively larger than the diameter d1 of the upper circulation pipe 510 . This is to ensure that the first fluid accommodated inside the buffer tank 520 does not stay in the buffer tank 520, but directly descends. In this configuration, overflow of the fluid in the buffer tank 520 can be effectively prevented. there will be

On the other hand, as shown in FIG. 3, in the step of setting the basic operating conditions of the production member 210 (S110), only the first fluid in a liquid state is supplied through the first fluid supply member 110. The base of the production member 210 through the rising pressure ΔP, which is the difference between the supply pressure PE1 of the oil gas passing through the supply port 211 and the discharge pressure PE2 of the oil gas passing through the discharge port 212. A step of setting operating conditions (S111) may be included.

In addition, as shown in FIG. 3, setting the basic operating conditions of the production member 210 (S110) is the increase in pressure ΔP according to the increase in the supply flow rate of the first fluid supplied to the production member 210. Further comprising the step of confirming the trend and setting the maximum flow rate of the first fluid that can be supplied to the production member 210 and the maximum value of the rising pressure ΔP as basic operating conditions of the production member 210 (S112). can do.

For example, water may be supplied as the first fluid in a state in which the production member 210 operates under a fixed RPM condition. The supply flow rate of the first fluid may be adjusted so that the opening of the choke valve increases by 1%/min. When the rising pressure (ΔP) is negative (less than 0), the test is terminated. That is, the first fluid, which is a single phase fluid, is supplied to the production member 210, the RPM of the production member 210 is 45 Hz, the temperature is 25 ° C, and the supply pressure PE1 is 10 bar (about 150 psi). ) to check the tendency of the discharge pressure (PE2) and the rising pressure of the production member 210 in a fixed state.

9 is a flowchart illustrating the steps of setting test conditions for leakage of an inner tube while setting test conditions to reflect underground production conditions and obstacles according to the present invention.

As shown in FIG. 9, in the step of setting test conditions to reflect the underground production conditions and obstacles (S100), the inside of the inner tube 221 and the oil gas moving through the inner tube 221 flow out. A step of installing the leak test member 250 having the communication hole 251 communicating with the outside may be further included (S120). In this way, the ESP and the tubing monitoring system are tested in a state where the leakage test member 250 is installed. For example, the production member 210 may supply water as oil gas while operating under a fixed RPM condition. In this way, water is supplied to the production member 210, and the RPM of the production member 210 is fixed at 45 Hz, the temperature is 25 ° C, and the supply pressure (PE1) is fixed at 10 bar (about 150 psi), and the inner tube 221 ), it is possible to check what trend is derived in case of leakage of oil gas moving, and when oil gas leakage occurs in the process of operating the ESP and tubing monitoring system in the field later, it is possible to quickly check.

In the step of installing the leak test member 250 (S120), the leak test member 250 having a communication hole 251 formed therein and a thread formed on the outside is screwed into the corresponding thread formed in the inner tube 221. It may be a bonding step. That is, since the leak state of the inner tube 221 can be simulated by a simple method of screwing the leak test member 250, workability is improved.

At this time, as shown in FIG. 9, in the step of setting test conditions to reflect the underground production conditions and obstacles (S100), the communication hole ( 251) may further include increasing the diameter (S130). For example, a leakage test member 250 having a communication hole 251 having a diameter of 0 mm, 1 mm, 3 mm, or 5 mm may be used. Through this, it is possible to check what trend is derived when the amount of leakage of oil and gas increases. Therefore, in the process of operating the ESP and tubing monitoring system in the field later, it is possible to quickly check if leakage of oil and gas occurs and this amount of leakage increases will do

10 is a flowchart illustrating the step of checking the state of the oil and gas production simulation unit through the monitoring unit according to the present invention.

As shown in FIG. 10, in the step of checking the state of the oil gas production simulation unit 200 through the monitoring unit 300 (S300), in a state where oil gas flows out through the inner tube 221, the supply port ( 211) and checking the state of the oil gas production simulation unit 200 through the vibration sensing member 460 and the sound sensing member 470 that detect vibration and sound of the oil gas passing through the discharge port 212 ( S310) may be included.

At this time, in the step of checking the state of the oil gas production simulation unit 200 through the monitoring unit 300 (S300), oil gas flows through the inner tube 221 via one end of the inner tube 221. The step of checking the state of the oil gas production simulation unit 200 through the sound sensing member 470 that senses the sound of oil gas passing through the other end of the inner tube 221 (S320). can include more. That is, when oil gas moving through the inner tube 221 leaks, it is possible to accurately check through the vibration sensing member 460 and the sound sensing member 470, and in the process of operating the ESP and tubing monitoring system in the future, When a gas leak occurs, it is possible to quickly check.

As described above, according to the test method of the ESP and tubing monitoring system of the present invention, liquid and gaseous fluids and solid foreign substances are supplied to the production member 210 as in the actual production site, and then the transmission member 220 ), it is possible to accurately derive the performance degradation influencing factors that may occur in the process of moving, and to reflect them, it is possible to derive a mechanism for improving productivity.

In addition, a signal when the production member 210 is damaged due to a foreign substance in a solid state such as sand is checked, and the failure and replacement time of the production member 210 is predicted by comparing the similarity of the signal found in the actual production site. By doing so, it is possible to maximize operation by minimizing time loss and cost loss at high unit prices such as oil and gas production sites.

Although one embodiment of the present invention has been described, the spirit of the present invention is not limited to the embodiments presented herein, and those skilled in the art who understand the spirit of the present invention may add or change elements within the scope of the same spirit. Other embodiments can be easily proposed by deleting, adding, etc., but this will also be said to be within the scope of the present invention.

100: oil and gas supply copy unit 110: first fluid supply member
120: second fluid supply member 130: foreign matter supply member
131: foreign matter tank 140: supply pipe member
150: first heating member 160: first pressing member
200: oil and gas production copy unit 210: production member
211: supply port 212: discharge port
213: drive motor 214: discharge pipe member
220: transmission member 221: inner tube
222: outer tube 230: second heating member
240: second pressing member 241: inlet
250: leak test member 251: communication hole
300: monitoring unit 400: sensing unit
410: flow rate sensing member 420: first temperature sensing member
430: first pressure sensing member 440: second temperature sensing member
450: second pressure sensing member 460: vibration sensing member
470: sound sensing member 480: third temperature sensing member
490: third pressure sensing member 500: circulation unit
510: upper circulation pipe 520: buffer tank
521: gas discharge member 530: lower circulation pipe
d1: diameter of upper circulation pipe d2: diameter of lower circulation pipe
ΔP: rising pressure

Claims (9)

An oil gas production simulation unit equipped with an oil gas supply simulation unit that simulates an oil gas supply state, a production member that produces oil gas supplied through the oil gas supply simulation unit, and a transmission member that transmits the produced oil gas; Test of ESP and tubing monitoring system including a sensing unit for detecting the state of the oil gas production simulation unit during oil gas production and a monitoring unit for checking the state of the oil gas production simulation unit using a signal transmitted from the detection unit in the method,
Setting test conditions to reflect geologic production conditions and obstacles;
operating the oil gas supply simulating unit and the oil and gas production simulating unit;
checking the state of the oil and gas production simulation unit through the monitoring unit; and
detecting a leakage state of the transmission member while checking a state of the oil and gas production simulation unit;
ESP and tubing monitoring system test method comprising a. According to claim 1,
The oil and gas supply simulation unit includes a first fluid supply member for supplying a first fluid in a liquid state, a second fluid supply member for supplying a second fluid in a gaseous state, and a foreign substance supply member for supplying foreign substances in a solid state. is provided,
The production member produces the oil gas containing the first fluid, the second fluid, and the foreign matter supplied through the oil gas supply simulation unit,
The step of setting test conditions to reflect the underground production conditions and obstacles,
A test method of an ESP and tubing monitoring system comprising the step of first setting basic operating conditions of the production member. According to claim 2,
The oil gas supply simulation unit is provided with a supply pipe member through which the oil gas flows,
The production member includes a supply port directly connected to the supply pipe member so that the oil gas supplied through the supply pipe member is directly supplied to the inside, and a discharge port directly connected to the discharge pipe member so that the pressurized oil gas is discharged. becomes,
The transmission member is provided with an inner tube communicating with the discharge pipe member and moving the oil gas, and an outer tube provided outside the inner tube to heat and pressurize the inner tube,
The step of setting the basic operating conditions of the production member,
The rising pressure, which is the difference between the supply pressure of the oil gas passing through the supply port and the discharge pressure of the oil gas passing through the discharge port in a state in which only the first fluid in a liquid state is supplied through the first fluid supply member ESP and tubing monitoring system test method comprising the step of setting the basic operating conditions of the production member through. According to claim 3,
The step of setting the basic operating conditions of the production member,
The maximum flow rate of the first fluid that can be supplied to the production member and the maximum value of the rising pressure are determined by checking the tendency of the rising pressure according to the increase in the supply flow rate of the first fluid supplied to the production member. A test method of an ESP and tubing monitoring system further comprising setting the basic operating condition of the member. According to claim 3,
The step of setting test conditions to reflect the underground production conditions and obstacles,
ESP and tubing monitoring system test method further comprising the step of installing a leak test member having a communication hole communicating the inside and outside of the inner tube so that the oil gas moving through the inner tube flows out. According to claim 5,
The step of installing the leak test member,
The test method of the ESP and tubing monitoring system, which is a step of screwing a leak test member having the communication hole formed therein and having a thread formed therein to a corresponding thread formed in the inner tube. According to claim 5,
The step of setting test conditions to reflect the underground production conditions and obstacles,
The test method of the ESP and tubing monitoring system further comprising increasing the diameter of the communication hole to increase the leakage amount of the oil gas flowing out of the inner tube. According to claim 5,
The step of checking the state of the oil gas production simulation unit through the monitoring unit,
In a state where the oil gas flows out through the inner tube, the state of the oil gas production simulation unit is checked through a vibration sensing member and a sound sensing member that sense vibration and sound of the oil gas passing through the supply port and the discharge port. A test method for an ESP and tubing monitoring system comprising the steps of: According to claim 8,
The step of checking the state of the oil gas production simulation unit through the monitoring unit,
In a state in which the oil gas flows out through the inner tube, a sound sensing member that senses the sound of the oil gas passing through one end of the inner tube and the sound of the oil gas passing through the other end of the inner tube A test method of the ESP and tubing monitoring system further comprising the step of checking the state of the gas production simulation unit.

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