Super-heavy oil circulation tandem production method and device in SAGD production mode

Abstract

The invention relates to the technical field of oilfield exploitation and production, in particular to a super-heavy oil circulating tandem production method and device in an SAGD (steam assisted gravity drainage) production mode. The super-heavy oil circulating tandem production method is carried out according to the following steps: superheated steam from a boiler is injected into a well group A and a well group P through a boiler steam incoming main pipeline and a well group A main steam injection pipeline, and heavy oil in the well group A and the well group P is heated; high-temperature produced liquid of a well A group P is injected into a well B group P through a first liquid outlet pipeline, a well B group main steam injection pipeline and a third steam injection pipeline, thick oil in the well B group P is heated, produced liquid of the well B group P is discharged and then conveyed to a treatment station to be treated, and the treatment station comprises the well A group P, the well A group I, the well B group P, the well B group I and a boiler steam incoming main pipeline. According to the method, the well opening number, the crude oil yield and the boiler steam utilization rate can be effectively increased, the steam injection cost is reduced, meanwhile, the output liquid temperature of the SAGD well in the circulation stage is reduced, and the cooling heat exchange load cost of a tail end treatment station is reduced.

Description

Technical Field

[0001] The invention relates to the technical field of oilfield exploitation and production, and is a super-heavy oil circulation series production method and device in a SAGD production mode. Background Art

[0002] SAGD is an oil production method used to exploit heavy oil reservoirs, especially the development of extra-heavy oil reservoirs. SAGD production wells usually adopt a double horizontal well layout. The horizontal sections of the double horizontal wells are spaced 5 to 8 meters apart in the vertical direction. The upper horizontal well is used for steam injection, which heats the heavy oil in the reservoir near the horizontal section to reduce its viscosity, and then flows to the lower horizontal well under the action of gravity. The lower horizontal well extracts crude oil from the ground by means of self-flowing or mechanical production.

[0003] The SAGD production mode will be in the circulation preheating stage for a period of time in the early stage of exploitation. Its function is to connect the channels between the two horizontal wells to the greatest extent, so as to maximize the output in the normal production stage. In the circulation preheating stage, since the oil flow channel has not yet been formed, the output of the lower horizontal well contains steam injected from the well and a large number of upper horizontal wells. Since the injected steam is usually superheated steam, this steam has a high temperature and high enthalpy value. About 90% of the injected superheated steam is produced out of the ground with the oil production fluid after circulation. The temperature of the produced fluid is above 200°C, and the residual enthalpy value is high. This kind of output brings great problems to the terminal oil and gas processing. Not only does it require a large amount of water to heat exchange and cool the produced fluid, but it is also difficult to separate the oil and water emulsification under high saturation conditions. Therefore, it is necessary to develop a new production process to improve the production capacity and speed of oilfields. Summary of the invention

[0004] The present invention provides a super-heavy oil circulation series production method and device under the SAGD production mode, which overcomes the shortcomings of the above-mentioned prior art and can effectively solve the problems of high output fluid temperature in the circulation preheating stage, difficulty in oil-water separation at the end of the produced fluid, and high steam consumption cost in the existing SAGD production of super-heavy oil fields.

[0005] One of the technical solutions of the present invention is achieved through the following measures: a super-heavy oil circulation series production method under a SAGD production mode, which is carried out according to the following steps: in the first step, superheated steam from the boiler is injected into the well P and the well I of the well group A through the boiler steam main pipeline and the well group A main steam injection pipeline to heat the heavy oil in the well P of the well group A; in the second step, the high-temperature produced liquid of the well P of the well group A is injected into the well P and the well I of the well group B through the first liquid outlet pipeline, the well group B main steam injection pipeline and the third steam injection pipeline to heat the heavy oil in the well P of the well group B; in the third step, the produced liquid of the well P of the well group B is discharged and sent to a processing station for processing.

[0006] The following is a further optimization and / or improvement of one of the above-mentioned technical solutions: In the above two steps, the temperature of the high-temperature produced fluid from well P of well group A is 200°C to 300°C.

[0007] The second technical solution of the present invention is achieved by the following measures: a device for implementing the super-heavy oil circulation series production method under the SAGD production mode, comprising A well group P well, A well group I well, B well group P well, B well group I well, and a boiler steam main pipeline, the boiler steam main pipeline is fixedly connected with the A well group total steam injection pipeline and the B well group total steam injection pipeline from top to bottom, the A well group total steam injection pipeline outlet and the A well group P well inlet are fixedly connected with a first steam injection pipeline, the A well group P well outlet and the B well group total steam injection pipeline are fixedly connected with a first liquid outlet pipeline, the first steam injection pipeline and the boiler steam main pipeline are fixedly connected with each other. A second steam injection pipeline is fixedly connected between the total steam injection line of the A well group and the inlet of well I of the A well group between the main steam pipelines, a second liquid outlet pipeline is fixedly connected between the outlet of well I of the A well group and the first liquid outlet pipeline, a third steam injection pipeline is fixedly connected between the outlet of the total steam injection line of the B well group and the inlet of well P of the B well group, a third liquid outlet pipeline is fixedly connected to the outlet of well P of the B well group, a fourth steam injection pipeline is fixedly connected between the total steam injection pipeline of the B well group and the inlet of well I of the B well group between the third steam injection pipeline and the first liquid outlet pipeline, and a fourth liquid outlet pipeline is fixedly connected between the outlet of well I of the B well group and the third liquid outlet pipeline.

[0008] The following is a further optimization and / or improvement of the second technical solution of the above invention: The first steam injection pipeline is fixedly connected with the second liquid outlet pipeline and the first liquid outlet pipeline between the P well of the A well group, and the second connecting pipeline is fixedly connected with the third liquid outlet pipeline between the fourth liquid outlet pipeline and the P well of the B well group and the third steam injection pipeline.

[0009] A first bypass pipeline is fixedly connected between the first connecting pipeline and the total steam injection pipeline of the A well group and the first steam injection pipeline between the first connecting pipeline and the P well of the A well group, a second bypass pipeline is fixedly connected between the second steam injection pipeline and the second liquid outlet pipeline, a third bypass pipeline is fixedly connected between the third steam injection pipeline between the second connecting pipeline and the total steam injection pipeline of the B well group and the third steam injection pipeline between the second connecting pipeline and the P well of the B well group, and a fourth bypass pipeline is fixedly connected between the fourth steam injection pipeline and the fourth liquid outlet pipeline.

[0010] A first two-well connecting pipeline is fixedly connected between the second steam injection pipeline between the second bypass pipeline and well I of the A well group and the first steam injection pipeline between the first bypass pipeline and well P of the A well group. A second two-well connecting pipeline is fixedly connected between the fourth bypass pipeline and well I of the B well group and the third steam injection pipeline between the third bypass pipeline and well P of the B well group.

[0011] A third connecting pipeline is fixedly connected between the first two-well connecting pipeline and the first steam injection pipeline between the P well of the A well group and the first liquid outlet pipeline between the first connecting pipeline and the second liquid outlet pipeline, a fourth connecting pipeline is fixedly connected between the second two-well connecting pipeline and the third steam injection pipeline between the P well of the B well group and the third liquid outlet pipeline between the second connecting pipeline and the fourth liquid outlet pipeline, a fifth connecting pipeline is fixedly connected between the first two-well connecting pipeline and the second steam injection pipeline between the I well of the A well group and the first liquid outlet pipeline between the second liquid outlet pipeline and the total steam injection pipeline of the B well group, and a sixth connecting pipeline is fixedly connected between the second two-well connecting pipeline and the I well of the B well group and the fourth liquid outlet pipeline and the third liquid outlet pipeline between the outlet of the third liquid outlet pipeline.

[0012] The A well group main steam injection valve is fixedly installed on the A well group main steam injection pipeline, and the B well group main steam injection valve is fixedly installed on the B well group main steam injection pipeline.

[0013] The first steam injection pipeline between the first bypass pipeline and the P well of the A well group, the third steam injection pipeline between the third bypass pipeline and the P well of the B well group are fixedly installed with the P well flow meter inlet valve, the P well flow meter, the P well flow meter outlet valve, the P well auxiliary pipe steam injection valve, the pressure monitor and the temperature monitor from left to right, the first connecting pipeline and the second connecting pipeline are fixedly installed with the P well main pipe steam injection valve, the first bypass pipeline and the third bypass pipeline are fixedly installed with the P well flow meter bypass valve, the second bypass pipeline and the fourth bypass pipeline are fixedly installed with the I well flow meter bypass valve and the I well main pipe steam injection valve from left to right, the second steam injection pipeline between the second bypass pipeline and the I well of the A well group, the fourth bypass pipeline and the fourth steam injection pipeline between the I well of the B well group are fixedly installed from left to right The I-well flowmeter inlet valve, the I-well flowmeter, the I-well flowmeter outlet valve, the I-well auxiliary pipe steam injection valve, the pressure monitor and the temperature monitor are fixedly installed; the first two-well connecting pipeline and the second two-well connecting pipeline are fixedly installed with the two-well connecting valve; the first liquid outlet pipeline between the first connecting pipeline and the second liquid outlet pipeline and the third liquid outlet pipeline are fixedly installed with the temperature monitor, the pressure monitor and the P-well main pipe back pressure valve from right to left in sequence; the third connecting pipeline and the fourth connecting pipeline are fixedly installed with the P-well auxiliary pipe back pressure valve; the second liquid outlet pipeline and the fourth liquid outlet pipeline between the second bypass pipeline and the first liquid outlet pipeline are fixedly installed with the temperature monitor, the pressure monitor and the I-well main pipe back pressure valve from right to left in sequence; the fifth connecting pipeline and the sixth connecting pipeline are fixedly installed with the I-well auxiliary pipe back pressure valve.

[0014] An atmospheric venting pipeline is fixedly connected to the A well group main steam injection pipeline between the A well group steam injection main valve and the boiler steam main pipeline, and a venting valve is fixedly installed on the atmospheric venting pipeline. A first valve is fixedly installed on the boiler steam main pipeline between the boiler steam main pipeline inlet and the A well group main steam injection pipeline. A second valve and a third valve are fixedly installed in sequence from top to bottom on the boiler steam main pipeline between the A well group main steam injection pipeline and the B well group main steam injection pipeline. A fourth valve is fixedly installed on the A well group main steam injection pipeline between the atmospheric venting pipeline and the boiler steam main pipeline. A fifth valve is fixedly installed on the B well group main steam injection pipeline between the first liquid outlet pipeline and the boiler steam main pipeline. A sixth valve and a seventh valve are fixedly installed in sequence from top to bottom on the first liquid outlet pipeline between the fifth connecting pipeline and the B well group main steam injection pipeline.

[0015] The present invention can effectively increase the number of wells opened, crude oil production and boiler steam utilization, reduce the cost of steam injection, and simultaneously reduce the temperature of the output fluid of the SAGD well in the circulation stage, thereby reducing the cost of cooling and heat exchange load of the terminal processing station. BRIEF DESCRIPTION OF THE DRAWINGS

[0016] Attached Figure 1 This is a schematic diagram of the process flow of Example 3 of the present invention.

[0017] Attached Figure 2 It is a downhole schematic diagram of the SAGD well group in the present invention.

[0018] Attached Figure 1The codes in are: 1 is P well of A well group, 2 is I well of A well group, 3 is P well of B well group, 4 is I well of B well group, 5 is the main steam pipeline of boiler, 6 is the main steam injection pipeline of A well group, 7 is the main steam injection pipeline of B well group, 8 is the first steam injection pipeline, 9 is the first liquid outlet pipeline, 10 is the second steam injection pipeline, 11 is the second liquid outlet pipeline, 12 is the third steam injection pipeline, 13 is the third liquid outlet pipeline, 14 is the fourth steam injection pipeline, 15 is the first steam outlet pipeline, 16 is the second steam outlet pipeline, 17 is the third steam outlet pipeline, 18 is the fourth steam outlet pipeline, 19 is the fourth steam outlet pipeline, 20 is the fourth steam outlet pipeline, 21 is the fourth steam outlet pipeline, 22 is the third steam outlet pipeline, 23 is the third steam outlet pipeline, 24 is the fourth steam outlet pipeline, 25 is the fourth steam outlet pipeline, 26 is the fourth steam outlet pipeline, 27 is the fourth steam outlet pipeline, 28 is the fourth steam outlet pipeline, 29 is the fourth steam outlet pipeline, 30 is the fourth steam outlet pipeline, 31 is the fourth steam outlet pipeline, 32 is the fourth steam outlet pipeline, 33 is the third steam outlet pipeline, 34 is the fourth steam outlet pipeline, 35 is the fourth steam outlet pipeline, 36 is the fourth steam outlet pipeline, 37 is the fourth steam outlet pipeline, 38 is the fourth steam outlet pipeline, 39 is the fourth steam outlet pipeline, 40 is the fourth steam outlet pipeline, 41 is the fourth steam outlet pipeline, 42 is the fourth steam outlet pipeline, 43 is the fourth steam outlet pipeline, 44 is the fourth steam outlet pipeline, 45 is the fourth steam outlet pipeline, 46 is the fourth steam outlet pipeline, 47 is the fourth steam outlet pipeline, 48 is the fourth steam outlet pipeline, 49 is the fourth steam outlet pipeline, 50 is the first steam outlet pipeline, 5 There are four liquid outlet pipelines, 16 is the first connecting pipeline, 17 is the second connecting pipeline, 18 is the first bypass pipeline, 19 is the second bypass pipeline, 20 is the third bypass pipeline, 21 is the fourth bypass pipeline, 22 is the first two-well connecting pipeline, 23 is the second two-well connecting pipeline, 24 is the third connecting pipeline, 25 is the fourth connecting pipeline, 26 is the fifth connecting pipeline, 27 is the sixth connecting pipeline, 28 is the steam injection main valve of the A well group, 29 is the injection valve of the B well group The steam main valve, 30 is the inlet valve of the P well flowmeter, 31 is the P well flowmeter, 32 is the outlet valve of the P well flowmeter, 33 is the steam injection valve of the P well auxiliary pipe, 34 is the pressure monitor, 35 is the temperature monitor, 36 is the steam injection valve of the P well main pipe, 37 is the bypass valve of the P well flowmeter, 38 is the bypass valve of the I well flowmeter, 39 is the inlet valve of the I well flowmeter, 40 is the I well flowmeter, 41 is the outlet valve of the I well flowmeter, 42 is the I well auxiliary pipe Steam injection valve, 43 is the two-well connecting valve, 44 is the P well main pipe back pressure valve, 45 is the P well auxiliary pipe back pressure valve, 46 is the I well main pipe back pressure valve, 47 is the I well auxiliary pipe back pressure valve, 48 is the atmospheric venting pipeline, 49 is the venting valve, 50 is the first valve, 51 is the second valve, 52 is the third valve, 53 is the fourth valve, 54 is the fifth valve, 55 is the sixth valve, 56 is the seventh valve, and 57 is the I well main pipe steam injection valve. DETAILED DESCRIPTION

[0019] The present invention is not limited by the following embodiments, and specific implementation methods can be determined based on the technical solution of the present invention and actual conditions.

[0020] The present invention will be further described below in conjunction with embodiments: Embodiment 1: As attached Figure 1 As shown, the super-heavy oil circulation series production method under the SAGD production mode is carried out according to the following steps: in the first step, the superheated steam from the boiler is injected into the A well group P well 1 and the A well group I well 2 through the boiler steam main pipeline 5 and the A well group main steam injection pipeline 6 to heat the heavy oil in the A well group P well 1; in the second step, the high-temperature produced liquid of the A well group P well 1 is injected into the B well group P well 3 and the B well group I well 4 through the first liquid outlet pipeline 9, the B well group main steam injection pipeline 7 and the third steam injection pipeline 12 to heat the heavy oil in the B well group P well 3; in the third step, the produced liquid of the B well group P well 3 is discharged and sent to the processing station for processing.

[0021] Embodiment 2: As an optimization of the above embodiment, as shown in the attached Figure 1 As shown, in the second step, the temperature of the high-temperature produced fluid from well P1 of well group A is 200°C to 300°C.

[0022] The present invention utilizes the characteristics of high temperature, high pressure and high residual heat enthalpy of the output fluid in the SAGD circulation preheating stage, and injects the output fluid into other wells for circulation preheating, thereby achieving the goal of improving the production progress and production speed of the newly built production capacity without adding new production capacity investment.

[0023] Embodiment 3: The device for implementing the super-heavy oil circulation series production method under the SAGD production mode comprises A well group P well 1, A well group I well 2, B well group P well 3, B well group I well 4, and a boiler steam main pipeline 5, the boiler steam main pipeline 5 is fixedly connected with the A well group total steam injection pipeline 6 and the B well group total steam injection pipeline 7 from top to bottom, the A well group total steam injection pipeline 6 is fixedly connected with the A well group total steam injection pipeline 7, the A well group total steam injection pipeline 8 is fixedly connected between the outlet of the A well group total steam injection pipeline 6 and the inlet of the A well group P well 1, the A well group P well 1 outlet is fixedly connected with the B well group total steam injection pipeline 7, and the A well group total steam injection pipeline 8 between the first steam injection pipeline 8 and the boiler steam main pipeline 5 is fixedly connected with the A well group total steam injection pipeline 8. A second steam injection pipeline 10 is fixedly connected between line 6 and the inlet of well I 2 of well group A, a second liquid outlet pipeline 11 is fixedly connected between the outlet of well I 2 of well group A and the first liquid outlet pipeline 9, a third steam injection pipeline 12 is fixedly connected between the outlet of the total steam injection pipeline 7 of well group B and the inlet of well P 3 of well group B, a third liquid outlet pipeline 13 is fixedly connected to the outlet of well P 3 of well group B, a fourth steam injection pipeline 14 is fixedly connected between the total steam injection pipeline 7 of well group B and the inlet of well I 4 of well group B between the third steam injection pipeline 12 and the first liquid outlet pipeline 9, and a fourth liquid outlet pipeline 15 is fixedly connected between the outlet of well I 4 of well group B and the third liquid outlet pipeline 13.

[0024] Embodiment 4: As an optimization of the above embodiment 3, as shown in the attached Figure 1 As shown, a first connecting pipeline 16 is fixedly connected between the first steam injection pipeline 8 and the second liquid outlet pipeline 11 and the first liquid outlet pipeline 9 between the A well group P well, and a second connecting pipeline 17 is fixedly connected between the fourth liquid outlet pipeline 15 and the third liquid outlet pipeline 13 between the B well group P well and the third steam injection pipeline 12.

[0025] Embodiment 5: As an optimization of the above embodiment, as shown in the attached Figure 1As shown, a first bypass pipeline 18 is fixedly connected between the first connecting pipeline 16 and the first steam injection pipeline 8 between the first connecting pipeline 16 and the P well 1 of the A well group, a second bypass pipeline 19 is fixedly connected between the second steam injection pipeline 10 and the second liquid outlet pipeline 11, a third bypass pipeline 20 is fixedly connected between the third steam injection pipeline 12 between the second connecting pipeline 17 and the total steam injection pipeline 7 of the B well group and the third steam injection pipeline 12 between the second connecting pipeline 17 and the P well 3 of the B well group, and a fourth bypass pipeline 21 is fixedly connected between the fourth steam injection pipeline 14 and the fourth liquid outlet pipeline 15.

[0026] According to the actual needs of the production site, whether well group A and well group B need additional steam injection and the amount of additional steam injection can be checked, and the valves on the first bypass line 18, the second bypass line 19, the third bypass line 20 and the fourth bypass line 21 can be flexibly adjusted to ensure the circulation effect of the SAGD well.

[0027] Embodiment 6: As an optimization of the above embodiment, as shown in the attached Figure 1 As shown, a first two-well connecting pipeline 22 is fixedly connected between the second bypass line 19 and the second steam injection pipeline 10 between well I 2 of well group A and the first bypass line 18 and the first steam injection pipeline 8 between well P 1 of well group A, and a second two-well connecting pipeline 23 is fixedly connected between the fourth bypass line 21 and the fourth steam injection pipeline 14 between well I 4 of well group B and the third bypass line 20 and the third steam injection pipeline 12 between well P 3 of well group B.

[0028] Embodiment 7: As an optimization of the above embodiment, as shown in the attached Figure 1 As shown, a third connecting pipeline 24 is fixedly connected between the first two-well connecting pipeline 22 and the first steam injection pipeline 8 between P well 1 of the A well group and the first connecting pipeline 16 and the first liquid outlet pipeline 9 between the second liquid outlet pipeline 11; a fourth connecting pipeline 25 is fixedly connected between the second two-well connecting pipeline 23 and the third steam injection pipeline 12 between P well 3 of the B well group and the second connecting pipeline 17 and the third liquid outlet pipeline 13 between the fourth liquid outlet pipeline 15; a fifth connecting pipeline 26 is fixedly connected between the first two-well connecting pipeline 22 and the second steam injection pipeline 10 between I well 2 of the A well group and the second liquid outlet pipeline 11 and the first liquid outlet pipeline 9 between the total steam injection pipeline 7 of the B well group; a sixth connecting pipeline 27 is fixedly connected between the second two-well connecting pipeline 23 and the fourth steam injection pipeline 14 between I well 4 of the B well group and the fourth liquid outlet pipeline 15 and the third liquid outlet pipeline 13 between the outlet of the third liquid outlet pipeline 13.

[0029] Embodiment 8: As an optimization of the above embodiment, as shown in the attached Figure 1As shown, a main steam injection valve 28 of the A well group is fixedly installed on the main steam injection pipeline 6 of the A well group, and a main steam injection valve 29 of the B well group is fixedly installed on the main steam injection pipeline 7 of the B well group.

[0030] Embodiment 9: As an optimization of the above embodiment, as shown in the attached Figure 1 As shown, the first steam injection pipeline 8 between the first bypass pipeline 18 and the well P1 of the A well group, the third steam injection pipeline 12 between the third bypass pipeline 20 and the well P3 of the well B group are fixedly installed with the well P flow meter inlet valve 30, the well P flow meter 31, the well P flow meter outlet valve 32, the well P auxiliary pipe steam injection valve 33, the pressure monitor 34 and the temperature monitor 35 from left to right, and the first connecting pipeline 16 and the second connecting pipeline 17 are fixedly installed with the well P main pipe steam injection valve 33. The first bypass pipeline 18 and the third bypass pipeline 20 are both fixedly installed with a P well flow meter bypass valve 37, the second bypass pipeline 19 and the fourth bypass pipeline 21 are both fixedly installed with an I well flow meter bypass valve 38 and an I well main steam injection valve 57 from left to right, the second bypass pipeline 19 and the second steam injection pipeline 10 between the A well group I well 2, the fourth bypass pipeline 21 and the fourth steam injection pipeline 14 between the B well group I well 4 are both fixedly installed from left to right. The inlet valve 39 of the well flowmeter, the well flowmeter 40, the outlet valve 41 of the well flowmeter, the steam injection valve 42 of the well auxiliary pipe, the pressure monitor 34 and the temperature monitor 35 are installed. The first two-well connecting pipeline 22 and the second two-well connecting pipeline 23 are both fixedly installed with the two-well connecting valve 43. The first liquid outlet pipeline 9 and the third liquid outlet pipeline 13 between the first connecting pipeline 16 and the second liquid outlet pipeline 11 are fixedly installed with the temperature monitor 35 and the pressure monitor 35 in sequence from right to left. 34 and the P well main pipe back pressure valve 44, the third connecting pipeline 24 and the fourth connecting pipeline 25 are fixedly installed with the P well auxiliary pipe back pressure valve 45, the second liquid outlet pipeline 11 and the fourth liquid outlet pipeline 15 between the second bypass pipeline 19 and the first liquid outlet pipeline 9 are fixedly installed with a temperature monitor 35, a pressure monitor 34 and the I well main pipe back pressure valve 46, the fifth connecting pipeline 26 and the sixth connecting pipeline 27 are fixedly installed with the I well auxiliary pipe back pressure valve 47.

[0031] Embodiment 10: As an optimization of the above embodiment, as shown in the attached Figure 1As shown, an atmospheric venting pipeline 48 is fixedly connected to the A well group main steam injection pipeline 6 between the A well group steam injection main valve 28 and the boiler steam main pipeline 5, a venting valve 49 is fixedly installed on the atmospheric venting pipeline 48, a first valve 50 is fixedly installed on the boiler steam main pipeline 5 between the inlet of the boiler steam main pipeline 5 and the A well group main steam injection pipeline 6, and a first valve 50 is fixedly installed on the boiler steam main pipeline 5 between the A well group main steam injection pipeline 6 and the B well group main steam injection pipeline 7 from top to bottom. A second valve 51 and a third valve 52 are fixedly installed, a fourth valve 53 is fixed on the A well group total steam injection pipeline 6 between the atmospheric venting pipeline 48 and the boiler steam main pipeline 5, a fifth valve 54 is fixed on the B well group total steam injection pipeline 7 between the first liquid outlet pipeline 9 and the boiler steam main pipeline 5, and a sixth valve 55 and a seventh valve 56 are fixedly installed in sequence from top to bottom on the first liquid outlet pipeline 9 between the fifth connecting pipeline 26 and the B well group total steam injection pipeline 7.

[0032] In the present invention, unless otherwise specified, the equipment and devices used are all the equipment and devices known and used in the art.

[0033] As required, conventional valves, thermometers and pressure gauges known in the art may be provided on the pipelines and equipment of the device for implementing the super-heavy oil circulation series production method under the SAGD production mode according to production needs.

[0034] In the present invention, the method of using the device for implementing the super-heavy oil circulation series production method under the SAGD production mode is as follows: First, close the second valve 51, the third valve 52 on the boiler steam main pipeline 5 and the fifth valve 54 on the B well group main steam injection pipeline 7, close the P well main steam injection valve 36 on the first connecting pipeline 16, close the P well flow meter bypass valve 37 on the first bypass pipeline 18, close the I well flow meter bypass valve 38 and the I well main steam injection valve 57 on the second bypass pipeline 19, close the P well auxiliary pipe back pressure valve 45 on the third connecting pipeline 24 and the fourth connecting pipeline 25, close the I well auxiliary pipe back pressure valve 47 on the fifth connecting pipeline 26 and the sixth connecting pipeline 27, and close the steam from the boiler. A part of the superheated steam from the boiler steam main pipeline 5 is injected into the well I 2 of the well group A through the well group A main steam injection pipeline 6 and the second steam injection pipeline 10, and the other part is injected into the well P 1 of the well group A through the well group A main steam injection pipeline 6 and the first steam injection pipeline 8 (i.e., through the well group A steam injection main valve 28, the well P flow meter inlet valve 30, the well P flow meter 31, the well P flow meter outlet valve 32 and the well P auxiliary pipe steam injection valve 33 in sequence); then, the well P main pipe steam injection valve 36 on the second connecting pipeline 17 is closed, the well P flow meter bypass valve 37 on the third bypass pipeline 20 is closed, and the well P bypass pipeline 2 is closed. 1, the output liquid of well I 2 in group A is sent to the first output pipeline 9 through the second output pipeline 11 (i.e., it passes through the temperature monitor 35, the pressure monitor 34 and the back pressure valve 46 of the main pipe of well I in sequence), and then merges with the output liquid of well P 1 in group A (i.e., it passes through the temperature monitor 35, the pressure monitor 34 and the back pressure valve 44 of the main pipe of well P in sequence) and enters the main steam injection pipeline 7 of group B; then, part of the output liquid in the main steam injection pipeline 7 of group B is injected into well I 4 in group B through the fourth steam injection pipeline 14, and the other part is injected into well I 4 in group B through the third steam injection pipeline 15. The steam pipeline 12 (i.e., sequentially through the B well group steam injection main valve 29, the P well flow meter inlet valve 30, the P well flow meter 31, the P well flow meter outlet valve 32 and the P well auxiliary pipe steam injection valve 33) is injected into the B well group P well 3; finally, the output liquid of the B well group I well 4 is sent to the third liquid output pipeline 13 through the fourth liquid output pipeline 15 (i.e., sequentially through the temperature monitor 35, the pressure monitor 34 and the I well main pipe back pressure valve 46), and is combined with the output liquid of the B well group P well 3 (i.e., sequentially through the temperature monitor 35, the pressure monitor 34 and the P well main pipe back pressure valve 44) and then sent to the processing station for processing.

[0035] Embodiment 11: As attached Figure 1 As shown, the super-heavy oil circulation series production method under the SAGD production mode is carried out according to the following steps: Step 1: After the SAGD block is well-planned, two adjacent well groups are selected as a group of wells, and the design numbers are well group A and well group B (the downhole schematic diagram of SAGD well group A and well group B is shown in the figure below) Figure 2 As shown, the upper one is the steam injection well, i.e., Well I, and the lower one is the oil production well, i.e., Well P); Step 2: Connect the serial connection process (the process needs to have inlet and outlet valves that control the A and B well groups respectively). Through the serial connection process, the circulating produced liquid of the A well group is connected to the inlet of the third steam injection pipeline 12 of the B well group through the first liquid outlet pipeline 9 and the B well group total steam injection pipeline 7; Step 3: Well group A is first injected with steam for circulation. After the circulation system of well group A is established and the outlet liquid temperature reaches the injection requirement, the constructed series connection process is opened, and the first outlet liquid pipeline 9 of well group A is connected with the third steam injection pipeline 12 of well group B. The high-temperature output liquid of well A enters the horizontal section of well group B, is mixed with the output liquid of well group B, and is transported to the processing station through the third outlet liquid pipeline 13 of well group B for processing; Step 4: After the circulation system of well group B is established, the circulation quality of well groups A and B is continuously monitored, and the downhole connectivity of SAGD in the circulation stage is timely determined by downhole temperature; Step 5: After the A and B wells are confirmed to be connected, they will enter the next machine mining stage respectively, and the established series connection process can be dismantled at any time and retained until the next time the series connection process is needed.

[0036] In the super-heavy oil circulation serial production method and device under the SAGD production mode of the present invention, it is necessary to ensure that the injected steam from the boiler is superheated steam, and the superheat is maintained at a certain level. After the superheated steam enters the A well group for circulation, the enthalpy value carried by the produced liquid is relatively high, so that it still has a very high temperature after being injected into the B well group, so as to achieve the circulation preheating effect of the B well. If the heat of the produced liquid of the A well group does not meet the demand of the B well circulation, the second valve 51 and the third valve 52 on the boiler steam main pipeline 5 can be opened as needed, and the fifth valve 54 on the B well group main steam injection pipeline 7 can be opened, and a small amount of injected steam can be supplemented through the flow meter to ensure the circulation effect of the B well.

[0037] In summary, the present invention can effectively increase the number of wells opened, crude oil production and boiler steam utilization, reduce the cost of steam injection, and at the same time reduce the temperature of the produced fluid in the circulation stage of the SAGD well, thereby reducing the cost of cooling and heat exchange loads at the terminal processing station.

[0038] The above technical features constitute the embodiments of the present invention, which have strong adaptability and implementation effect. Non-essential technical features can be added or reduced according to actual needs to meet the requirements of different situations.

Claims

1. A super heavy oil circulation series production method under SAGD production mode, characterized in that In the first step, the superheated steam from the boiler is injected into the well P and the well I of the well group A through the boiler steam main pipeline and the well group A main steam injection pipeline to heat the heavy oil in the well P of the well group A; In the second step, the high-temperature produced fluid from the P well of the A well group is injected into the P well of the B well group and the I well of the B well group through the first liquid outlet pipeline, the total steam injection pipeline of the B well group and the third steam injection pipeline to heat the heavy oil in the P well of the B well group; In the third step, the produced fluid from well P in group B is discharged and sent to the processing station for treatment.

2. The method for producing super heavy oil in series under the SAGD production mode according to claim 1, characterized in that In the second step, the temperature of the high-temperature produced fluid from well P of well group A is 200°C to 300°C.

3. A device for implementing the super heavy oil circulation series production method under the SAGD production mode according to claim 1 or 2, characterized in that It includes A well group P well, A well group I well, B well group P well, B well group I well, and boiler steam main pipeline. The boiler steam main pipeline is fixedly connected with the A well group total steam injection pipeline and the B well group total steam injection pipeline from top to bottom. The outlet of the A well group total steam injection pipeline is fixedly connected with the inlet of the A well group P well. The first liquid outlet pipeline is fixedly connected between the outlet of the A well group P well and the B well group total steam injection pipeline. The A well group total steam injection pipeline between the first steam injection pipeline and the boiler steam main pipeline and the inlet of the A well group I well are connected. A second steam injection pipeline is fixedly connected, a second liquid outlet pipeline is fixedly connected between the outlet of well I of group A wells and the first liquid outlet pipeline, a third steam injection pipeline is fixedly connected between the outlet of the total steam injection pipeline of group B wells and the inlet of well P of group B wells, the outlet of well P of group B wells is fixedly connected to the third liquid outlet pipeline, a fourth steam injection pipeline is fixedly connected between the total steam injection pipeline of group B wells and the inlet of well I of group B wells between the third steam injection pipeline and the first liquid outlet pipeline, and a fourth liquid outlet pipeline is fixedly connected between the outlet of well I of group B wells and the third liquid outlet pipeline.

4. The device according to claim 3, characterized in that A first connecting pipeline is fixedly connected between the first steam injection pipeline and the second liquid outlet pipeline and the first liquid outlet pipeline between the P well of the A well group, and a second connecting pipeline is fixedly connected between the fourth liquid outlet pipeline and the third liquid outlet pipeline between the P well of the B well group and the third steam injection pipeline.

5. The device according to claim 4, characterized in that A first bypass pipeline is fixedly connected between the first connecting pipeline and the total steam injection pipeline of the A well group and the first steam injection pipeline between the first connecting pipeline and the P well of the A well group, a second bypass pipeline is fixedly connected between the second steam injection pipeline and the second liquid outlet pipeline, a third bypass pipeline is fixedly connected between the third steam injection pipeline between the second connecting pipeline and the total steam injection pipeline of the B well group and the third steam injection pipeline between the second connecting pipeline and the P well of the B well group, and a fourth bypass pipeline is fixedly connected between the fourth steam injection pipeline and the fourth liquid outlet pipeline.

6. The device according to claim 5, characterized in that A first two-well connecting pipeline is fixedly connected between the second bypass pipeline and the second steam injection pipeline between well I of group A wells and the first bypass pipeline and the first steam injection pipeline between well P of group A wells; a second two-well connecting pipeline is fixedly connected between the fourth bypass pipeline and well I of group B wells and the third bypass pipeline and the third steam injection pipeline between well P of group B wells.

7. The device according to claim 6, characterized in that A third connecting pipeline is fixedly connected between the first two-well connecting pipeline and the first steam injection pipeline between well P of group A wells and the first liquid outlet pipeline between the first connecting pipeline and the second liquid outlet pipeline, a fourth connecting pipeline is fixedly connected between the second two-well connecting pipeline and the third steam injection pipeline between well P of group B wells and the third liquid outlet pipeline between the second connecting pipeline and the fourth liquid outlet pipeline, a fifth connecting pipeline is fixedly connected between the first two-well connecting pipeline and the second steam injection pipeline between well I of group A wells and the first liquid outlet pipeline between the second liquid outlet pipeline and the total steam injection pipeline of group B wells, a sixth connecting pipeline is fixedly connected between the second two-well connecting pipeline and well I of group B wells and the fourth liquid outlet pipeline and the third liquid outlet pipeline between the outlet of the third liquid outlet pipeline.

8. The device according to any one of claims 2 to 7, characterized in that The A well group's main steam injection valve is fixedly installed on the A well group's main steam injection pipeline, and the B well group's main steam injection valve is fixedly installed on the B well group's main steam injection pipeline.

9. The device according to claim 7 or 8, characterized in that The first steam injection pipeline between the first bypass pipeline and the P well of the A well group, the third steam injection pipeline between the third bypass pipeline and the P well of the B well group are fixedly installed with the P well flow meter inlet valve, the P well flow meter, the P well flow meter outlet valve, the P well auxiliary pipe steam injection valve, the pressure monitor and the temperature monitor from left to right, the first connecting pipeline and the second connecting pipeline are fixedly installed with the P well main pipe steam injection valve, the first bypass pipeline and the third bypass pipeline are fixedly installed with the P well flow meter bypass valve, the second bypass pipeline and the fourth bypass pipeline are fixedly installed with the I well flow meter bypass valve and the I well main pipe steam injection valve from left to right, the second steam injection pipeline between the second bypass pipeline and the I well of the A well group, the fourth bypass pipeline and the fourth steam injection pipeline between the I well of the B well group are fixedly installed from left to right It is equipped with an I-well flowmeter inlet valve, an I-well flowmeter, an I-well flowmeter outlet valve, an I-well auxiliary pipe steam injection valve, a pressure monitor and a temperature monitor; the first two-well connecting pipeline and the second two-well connecting pipeline are both fixedly installed with two-well connecting valves; the first liquid outlet pipeline and the third liquid outlet pipeline between the first connecting pipeline and the second liquid outlet pipeline are both fixedly installed with a temperature monitor, a pressure monitor and a P-well main pipe back-pressure valve from right to left; the third connecting pipeline and the fourth connecting pipeline are both fixedly installed with a P-well auxiliary pipe back-pressure valve; the second liquid outlet pipeline and the fourth liquid outlet pipeline between the second bypass pipeline and the first liquid outlet pipeline are both fixedly installed with a temperature monitor, a pressure monitor and an I-well main pipe back-pressure valve from right to left; the fifth connecting pipeline and the sixth connecting pipeline are both fixedly installed with an I-well auxiliary pipe back-pressure valve.

10. The device according to claim 7, 8 or 9, characterized in that An atmospheric venting pipeline is fixedly connected to the A well group main steam injection pipeline between the A well group steam injection main valve and the boiler steam main pipeline, and a venting valve is fixedly installed on the atmospheric venting pipeline. A first valve is fixedly installed on the boiler steam main pipeline between the boiler steam main pipeline inlet and the A well group main steam injection pipeline. A second valve and a third valve are fixedly installed in sequence from top to bottom on the boiler steam main pipeline between the A well group main steam injection pipeline and the B well group main steam injection pipeline. A fourth valve is fixed on the A well group main steam injection pipeline between the atmospheric venting pipeline and the boiler steam main pipeline. A fifth valve is fixed on the B well group main steam injection pipeline between the first liquid outlet pipeline and the boiler steam main pipeline. A sixth valve and a seventh valve are fixedly installed in sequence from top to bottom on the first liquid outlet pipeline between the fifth connecting pipeline and the B well group main steam injection pipeline.

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