High-viscosity crude oil gathering and transportation process method and device and storage medium

Abstract

The invention relates to a high-viscosity crude oil gathering and transportation process method and device and a storage medium. The method comprises the steps that the water mixing pressure of an oil well is determined; adjusting the watering pressure of the high-viscosity crude oil; establishing a low-pressure area for unpowered recovery of casing gas; and throttling parameters are optimized. According to the gathering and transportation process method and device for the high-viscosity crude oil and the storage medium, the problems that in the gathering and transportation process of the high-viscosity crude oil with a well mouth only matched with a water injection pipeline, the viscosity is high, the gathering and transportation resistance is large, and residual natural gas in a sleeve is wasted are effectively solved, and construction of high-viscosity crude oil field surface engineering can be guided.

Description

Technical Field

[0001] This application relates to the field of passive optical network systems, and particularly to a high-viscosity crude oil gathering and transportation process method, device, and storage medium. Background Art

[0002] During the gathering and transportation of high-viscosity crude oil, due to its high viscosity and poor physical properties such as pour point, it is difficult to smoothly pipeline the crude oil using the common single-pipe normal-temperature gathering and transportation process. Therefore, in the gathering and transportation process, a double-pipe water blending gathering and transportation method is mostly adopted, and water is blended to reduce viscosity to ensure production. When oil wells in high-viscosity crude oil oilfields produce, most oil wells do not have water blending pipelines, only wellhead water injection pipelines. Due to the high water injection pressure and low water blending pressure (the water injection pressure is higher than 16 MPa, and the water blending pressure is lower than 1.5 MPa), the water injection pipeline cannot be directly applied to water blending. At the same time, since the oil well pressure is higher than the casing pressure, it is difficult to discharge the natural gas existing in the annulus between the bottom and wellhead of the high-viscosity crude oil, resulting in waste of natural gas resources. Currently, a constant pressure valve is mainly used to build up pressure greater than or equal to the oil well pressure and then discharge it. However, the increase in casing pressure will affect the height of the downhole dynamic liquid level, resulting in insufficient release of the oil well production capacity. Therefore, improvement is needed. Summary of the Invention

[0003] In order to solve the above technical problems or at least partially solve the above technical problems, this application provides a high-viscosity crude oil gathering and transportation process method, device, and storage medium.

[0004] In a first aspect, this application provides a high-viscosity crude oil gathering and transportation process method, and the method includes the steps of:

[0005] Determine the water blending pressure of the oil well;

[0006] Adjust the water blending pressure of the high-viscosity crude oil;

[0007] Establish a low-pressure area for non-powered recovery of casing gas;

[0008] Optimize the throttling parameters.

[0009] Preferably, the step of determining the water blending pressure of the oil well includes the steps of:

[0010] Obtain the back pressure at the wellhead of the high-viscosity oil well;

[0011] Obtain the calculation formula for the water blending pressure of the oil well;

[0012] Calculate the water blending pressure of the oil well according to the back pressure at the wellhead of the high-viscosity oil well and the calculation formula for the water blending pressure of the oil well.

[0013] Preferably, the step of calculating the water blending pressure of the oil well according to the back pressure at the wellhead of the high-viscosity oil well and the calculation formula for the water blending pressure of the oil well includes the steps of:

[0014] Obtain the parameters of the calculation formula for the water blending pressure of the oil well;

[0015] Substitute the wellhead backpressure of the high-viscosity oil well and the parameters into the calculation formula for the water injection pressure of the oil well.

[0016] Preferably, the expression of the calculation formula for the water injection pressure of the oil well is:

[0017] P 掺 ≥P 回 +k×0.1;

[0018] Wherein, P 掺 represents the water injection pressure, P 回 represents the wellhead backpressure of the high-viscosity oil well, and k represents the safety factor.

[0019] Preferably, the adjustment of the water injection pressure of the high-viscosity crude oil includes the steps of:

[0020] Obtain a high-pressure water injection system;

[0021] Configure a throttle valve in the high-pressure water injection system;

[0022] Adjust the opening degree of the throttle valve.

[0023] Preferably, the establishment of the non-powered recovered casing gas in the low-pressure area includes the steps of:

[0024] Obtain a water injection pipeline;

[0025] Install a check valve at the inlet of the water injection pipeline.

[0026] Preferably, the optimization of the throttle parameters includes the steps of:

[0027] Obtain the value of the oil pressure change;

[0028] Obtain the value of the dynamic liquid level change;

[0029] Adjust the throttle pressure according to the value of the oil pressure change and the value of the dynamic liquid level change.

[0030] In a second aspect, the present application provides a high-viscosity crude oil gathering and transportation process device, including:

[0031] A pressure determination module for determining the water injection pressure of the oil well;

[0032] A pressure adjustment module for adjusting the water injection pressure of the high-viscosity crude oil;

[0033] A casing gas establishment module for establishing non-powered recovered casing gas in the low-pressure area;

[0034] A parameter optimization module for optimizing the throttle parameters.

[0035] In a third aspect, an electronic device is provided, and the electronic device includes:

[0036] At least one processor; and,

[0037] A memory communicatively connected to the at least one processor; wherein,

[0038] The memory stores instructions executable by the at least one processor, and the instructions are executed by the at least one processor to enable the at least one processor to execute any one of the foregoing high-viscosity crude oil gathering and transportation process methods.

[0039] In a fourth aspect, a non-transitory computer-readable storage medium is provided, and the non-transitory computer-readable storage medium stores computer instructions for causing the computer to execute any one of the foregoing high-viscosity crude oil gathering and transportation process methods.

[0040] The above technical solutions provided by the embodiments of the present application have the following advantages compared with the prior art:

[0041] A high-viscosity crude oil gathering and transportation process method, device and storage medium provided by the embodiments of the present application effectively solve the problems of high viscosity, large gathering and transportation resistance and waste of residual natural gas in the casing during the gathering and transportation of high-viscosity crude oil with only water injection pipelines equipped at the wellhead, and can guide the construction of surface engineering for high-viscosity crude oil oilfields. BRIEF DESCRIPTION OF THE DRAWINGS

[0042] The accompanying drawings herein are incorporated into the specification and constitute a part of the specification, showing embodiments consistent with the present invention and used together with the specification to explain the principles of the present invention.

[0043] In order to more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the following will briefly introduce the accompanying drawings required for use in the description of the embodiments or the prior art. Obviously, for those of ordinary skill in the art, other drawings can also be obtained based on these drawings without creative efforts.

[0044] Figure 1 is a schematic flowchart of a high-viscosity crude oil gathering and transportation process method provided by an embodiment of the present invention;

[0045] Figure 2 is a schematic structural diagram of a high-viscosity crude oil gathering and transportation process device provided by an embodiment of the present invention;

[0046] Figure 3 is a schematic structural diagram of an electronic device provided by the present invention;

[0047] Figure 4 is a schematic structural diagram of a non-transitory computer-readable storage medium provided by the present invention;

[0048] Figure 5It is a schematic diagram of the process of reducing the pressure of the water injection pipeline and converting it to the water mixing process in a high-viscosity crude oil gathering and transportation process method provided by an embodiment of the present invention;

[0049] Figure 6 It is a schematic diagram of a casing gas recovery device in a high-viscosity crude oil gathering and transportation process method provided by an embodiment of the present invention. Specific embodiments

[0050] To make the objectives, technical solutions, and advantages of the embodiments of the present application clearer, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the accompanying drawings in the embodiments of the present application. Obviously, the described embodiments are some, but not all, of the embodiments of the present application. All other embodiments obtained by those of ordinary skill in the art based on the embodiments of the present application without creative efforts shall fall within the protection scope of the present application.

[0051] Figure 1 It is a schematic flow diagram of a high-viscosity crude oil gathering and transportation process method provided by an embodiment of the present application.

[0052] The present application provides a high-viscosity crude oil gathering and transportation process method, and the method includes the steps:

[0053] S1: Determine the water mixing pressure of the oil well;

[0054] In the embodiment of the present application, the determining the water mixing pressure of the oil well includes the steps:

[0055] Obtain the wellhead back pressure of the high-viscosity oil well;

[0056] Obtain the calculation formula for the water mixing pressure of the oil well;

[0057] Calculate the water mixing pressure of the oil well according to the wellhead back pressure of the high-viscosity oil well and the calculation formula for the water mixing pressure of the oil well.

[0058] Specifically, calculate the minimum pressure required for water mixing of heavy oil according to the wellhead oil pressure of different high-viscosity oil wells and the calculation formula for the water mixing pressure of the oil well.

[0059] In the embodiment of the present application, the calculating the water mixing pressure of the oil well according to the wellhead back pressure of the high-viscosity oil well and the calculation formula for the water mixing pressure of the oil well includes the steps:

[0060] Obtain the parameters of the calculation formula for the water mixing pressure of the oil well;

[0061] Substitute the wellhead back pressure of the high-viscosity oil well and the parameters into the calculation formula for the water mixing pressure of the oil well.

[0062] Specifically, substitute the wellhead back pressure of the high-viscosity oil well and each parameter in the calculation formula for the water mixing pressure of the oil well into the calculation formula for the water mixing pressure of the oil well. The water mixing pressure of the oil well can be calculated.

[0063] In the embodiment of the present application, the expression of the water blending pressure calculation formula for the oil well is as follows:

[0064] P 掺 ≥P 回 +k×0.1;

[0065] Wherein, P 掺 represents the water blending pressure, P 回 represents the back pressure at the wellhead of the high-viscosity oil well, and k represents the safety factor.

[0066] S2: Adjust the water blending pressure of the high-viscosity crude oil;

[0067] In the embodiment of the present application, the adjustment of the water blending pressure of the high-viscosity crude oil includes the following steps:

[0068] Obtain a high-pressure water injection system;

[0069] Configure a throttle valve in the high-pressure water injection system;

[0070] Adjust the opening degree of the throttle valve.

[0071] Specifically, adjust the structural process of the existing high-pressure water injection system. By adjusting the opening degree of the throttle valve, reduce the water injection pressure to the required water blending pressure.

[0072] Such as Figure 5 , according to the current production operation status of the high-viscosity crude oil wells in the oil field, the water blending pressure needs to be higher than the wellhead pressure of the oil well. Generally, it is 1.2 - 1.5 MPa, and the water injection pressure is 16 - 35 MPa. By modifying the pipeline to add a throttle valve, the main process is enabled to have the function of reducing the high-pressure water injection to low-pressure water blending (the main process is in the open state of pneumatic valves A, C, and E, and the closed state of pneumatic valves B, C, and F). If it is found in the remote transmission of the pressure monitoring before and after the throttle valve in the main process that the pressure difference before and after the throttle valve is less than 0.1 MPa, it indicates that the throttle valve fails. At this time, close the main process. Switch to the standby process (the standby process is in the closed state of pneumatic valves A, D, and E, and the open state of pneumatic valves B, C, and F), switch to the standby pressure reduction process, and at the same time, an alarm appears at the system control end to remind the main process to be repaired.

[0073] The standby process and the main process have the same throttle pressure reduction function, and there is a remote transmission function for pressure monitoring before and after the throttle valve. If the pressure difference before and after the throttle valve is less than 0.1 MPa, it indicates that the throttle valve of the standby process fails, then stop the water blending work and switch back to the water injection process. Repair the entire process. At this time, pneumatic valve D is opened, and the rest of the pneumatic valves are in the closed state.

[0074] S3: Establish a non-powered recovery casing gas in the low-pressure area;

[0075] In the embodiment of the present application, the establishment of the non-powered recovery casing gas in the low-pressure area includes the following steps:

[0076] Obtain the water injection pipeline;

[0077] Install a check valve at the inlet of the water injection pipeline.

[0078] Specifically, as Figure 6 , when the high-pressure water in the water injection pipeline c passes through the conical throttle valve, the liquid flow before and after the valve changes from thick to thin. At the narrowest part of the conical nozzle head, the dynamic pressure reaches the maximum value and the static pressure reaches the minimum value. The velocity of the gas (liquid) increases because the cross-sectional area of the flow passage decreases. The entire surge flow has to experience the process of pipeline narrowing at the same time, so the pressure also decreases at the same time. Furthermore, a pressure difference is generated, forming a low-pressure (negative pressure) area in the a1 area behind the nozzle. The lower end of the a pipe is connected to the casing. To prevent the mixing water from flowing back due to pressure fluctuations, a check valve is installed on the a pipe. Utilizing the pressure difference between the casing pressure and the low pressure area behind the nozzle, the casing gas stored in the casing below the oil pressure is recovered into the low-pressure mixing water pipeline, mixed with the low-pressure mixing water and then enters the b pipe to reduce the viscosity of the high-viscosity crude oil by mixing water.

[0079] S4: Optimize the throttling parameters.

[0080] In the embodiment of the present application, the optimization of the throttling parameters includes the steps of:

[0081] Obtain the change value of the oil pressure;

[0082] Obtain the change value of the dynamic liquid level;

[0083] Adjust the throttling pressure according to the change value of the oil pressure and the change value of the dynamic liquid level.

[0084] Specifically, according to the changes in the oil pressure and the dynamic liquid level during the production process, through throttling pressure adjustment, the mixing water pressure and the casing gas recovery amount most suitable for the production of high-viscosity oil wells are adjusted.

[0085] Embodiment

[0086] For a certain heavy oilfield, the viscosity of the surrounding crude oil at 50 °C is 13000 mPa·s, the freezing point is 25 °C, the wellhead production liquid temperature is 35 °C, the daily oil production is 25 t / d, the daily liquid production is 38 m3 / d, the water cut is 34.2%, the wellhead oil pressure is 0.8 MPa, there is a certain amount of casing gas in the casing, and it is produced by pulling oil. Due to the high viscosity of the crude oil, it cannot be directly transported, and there is no mixing water pipeline in the surrounding area, so the produced liquid enters the elevated tank for pulling oil production. However, there is a production injection well 100 m away, and the injection water pressure is 13.8 MPa. Therefore, the process is reformed according to a high-viscosity crude oil gathering and transportation process method provided by the present invention.

[0087] (1) Determine the mixing water pressure of the oil well. According to the production situation of the surrounding wells, k is taken as 4. Therefore, the determined mixing water pressure should be greater than or equal to 1.2 MPa.

[0088] (2) After the transformation of the water injection pipeline, during normal production, it is the main process. Pneumatic valves A, C, and E are in the open state, and pneumatic valves B, C, and F are in the closed state. The high-pressure water in the water injection pipeline c enters the throttle valve through pneumatic valves C and A, passes through the nozzle head, and the flow rate becomes faster, resulting in a decrease in pressure around the nozzle head, forming a negative pressure area, which is lower than the pressure in the casing a. Therefore, the casing gas stored in the casing a begins to migrate towards the a1 area, mixes with the low-pressure water behind the nozzle, enters the b pipe, and is used for water blending in the gathering and transportation system through the check valve.

[0089] When the throttle valve fails (the pressure difference before and after the throttle valve is 0.1 MPa), pneumatic valves A, D, and E close, and pneumatic valves B, C, and F open. The process switches to the right-side standby process, and the standby process has the same technology as the main process. When switching to the standby process, the remote central control alarm system will be triggered to remind the staff to repair the main process immediately.

[0090] When the pressure difference before and after the throttle valve in both the main process and the standby process is less than 0.1 MPa, it is considered that the water blending system is paralyzed. Pneumatic valve D opens, and the rest of the pneumatic valves close, and an alarm is sent to the central control to remind the staff to repair in time. The high-pressure water in pipe C returns to the water injection system, the water blending system stops operating, and the oil well switches back to the production process of pulling oil with an elevated tank.

[0091] Through the method described in the present invention, the gathering and transportation of high-viscosity crude oil wells without surrounding water blending pipelines and the non-powered collection of associated gas are solved, reducing the annual hauling cost by 680,000 yuan.

[0092] Such as Figure 2 , this application provides a high-viscosity crude oil gathering and transportation process device, including:

[0093] A pressure determination module 10 for determining the water blending pressure of the oil well;

[0094] A pressure adjustment module 20 for adjusting the water blending pressure of high-viscosity crude oil;

[0095] A casing gas establishment module 30 for establishing a non-powered recovery of casing gas in the low-pressure area;

[0096] A parameter optimization module 40 for optimizing the throttle parameters.

[0097] The high-viscosity crude oil gathering and transportation process device provided by this application can execute the high-viscosity crude oil gathering and transportation process method provided in the above steps.

[0098] It should be understood that the above specific embodiments of the present invention are only used for exemplary illustration or explanation of the principles of the present invention, and do not constitute a limitation on the present invention. Therefore, any modifications, equivalent substitutions, improvements, etc. made without departing from the spirit and scope of the present invention shall be included within the protection scope of the present invention. In addition, the appended claims of the present invention are intended to cover all variations and modifications that fall within the scope and boundaries of the appended claims, or equivalent forms of such scope and boundaries.

[0099] Reference is made below to Figure 3 , which shows a schematic structural diagram of an electronic device 100 suitable for implementing the embodiments of the present disclosure. The electronic device in the embodiments of the present disclosure may include, but is not limited to, mobile terminals such as mobile phones, laptop computers, digital broadcast receivers, PDAs (Personal Digital Assistants), PADs (Tablet Computers), PMPs (Portable Multimedia Players), in-vehicle terminals (such as in-vehicle navigation terminals), etc., and fixed terminals such as digital TVs, desktop computers, etc. Figure 3 The electronic device shown is only an example and should not impose any limitations on the functions and usage scope of the embodiments of the present disclosure.

[0100] As Figure 3 shown, the electronic device 100 may include a processing device (such as a central processing unit, a graphics processing unit, etc.) 101, which may perform various appropriate actions and processes according to a program stored in a read-only memory (ROM) 102 or a program loaded from a storage device 108 into a random access memory (RAM) 103. In the RAM 103, various programs and data required for the operation of the electronic device 100 are also stored. The processing device 101, the ROM 102, and the RAM 103 are connected to each other through a bus 104. An input / output (I / O) interface 105 is also connected to the bus 104.

[0101] Generally, the following devices may be connected to the I / O interface 105: an input device 106 including, for example, a touch screen, a touchpad, a keyboard, a mouse, an image sensor, a microphone, an accelerometer, a gyroscope, etc.; an output device 107 including, for example, a liquid crystal display (LCD), a speaker, a vibrator, etc.; a storage device 108 including, for example, a magnetic tape, a hard disk, etc.; and a communication device 109. The communication device 109 may allow the electronic device 100 to communicate with other devices wirelessly or wiredly to exchange data. Although the figure shows an electronic device 100 having various devices, it should be understood that it is not required to implement or have all the shown devices. More or fewer devices may be alternatively implemented or had.

[0102] In particular, according to an embodiment of the present disclosure, the processes described above with reference to the flowcharts can be implemented as computer software programs. For example, an embodiment of the present disclosure includes a computer program product that includes a computer program carried on a computer-readable medium, and the computer program includes program code for performing the method shown in the flowchart. In such an embodiment, the computer program can be downloaded and installed from a network via the communication device 109, or installed from the storage device 108, or installed from the ROM 102. When the computer program is executed by the processing device 101, the above-described functions defined in the method of the embodiment of the present disclosure are performed.

[0103] Reference is made below to Figure 4 , which shows a schematic structural diagram of a computer-readable storage medium suitable for implementing an embodiment of the present disclosure. The computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, it can implement the high-viscosity crude oil gathering and transportation process method as described in any one of the above.

[0104] A high-viscosity crude oil gathering and transportation process method, device, and storage medium provided by an embodiment of the present application effectively solve the problems of high viscosity, large gathering and transportation resistance, and waste of residual natural gas in the casing during the high-viscosity crude oil gathering and transportation process where only a water injection pipeline is provided at the wellhead, and can guide the construction of the surface engineering of high-viscosity crude oil oilfields.

[0105] It should be noted that in this article, relational terms such as "first" and "second" are only used to distinguish one entity or operation from another entity or operation, and do not necessarily require or imply any actual relationship or order between these entities or operations; moreover, the terms "include", "comprise" or any other variation thereof are intended to cover non-exclusive inclusion, so that a process, method, article or device including a series of elements not only includes those elements, but also includes other elements not expressly listed, or also includes elements inherent to such process, method, article or device. Without further limitation, an element defined by the statement "including one..." does not exclude the existence of additional identical elements in the process, method, article or device including the element.

[0106] The above are only specific embodiments of the present invention, enabling those skilled in the art to understand or implement the present invention. Various modifications to these embodiments will be obvious to those skilled in the art, and the general principles defined herein can be implemented in other embodiments without departing from the spirit or scope of the present invention. Therefore, the present invention will not be limited to these embodiments shown herein, but rather to the broadest scope consistent with the principles and novel features claimed herein.

Claims

1. A process method for gathering and transporting high-viscosity crude oil, characterized in that, the method includes the steps of: Determine the water injection pressure of the oil well; Adjust the water injection pressure of the high-viscosity crude oil; Establish a non-powered recovery casing gas in the low-pressure area; Optimize the throttling parameters.

2. The process method for gathering and transporting high-viscosity crude oil according to claim 1, characterized in that, the determination of the water injection pressure of the oil well includes the steps of: Obtain the back pressure at the wellhead of the high-viscosity oil well; Obtain the calculation formula for the water injection pressure of the oil well; Calculate the water injection pressure of the oil well according to the back pressure at the wellhead of the high-viscosity oil well and the calculation formula for the water injection pressure of the oil well.

3. The process method for gathering and transporting high-viscosity crude oil according to claim 2, characterized in that, calculating the water injection pressure of the oil well according to the back pressure at the wellhead of the high-viscosity oil well and the calculation formula for the water injection pressure of the oil well includes the steps of: Obtain the parameters of the calculation formula for the water injection pressure of the oil well; Substitute the back pressure at the wellhead of the high-viscosity oil well and the parameters into the calculation formula for the water injection pressure of the oil well.

4. The process method for gathering and transporting high-viscosity crude oil according to claim 2 or 3, characterized in that, the expression of the calculation formula for the water injection pressure of the oil well is: P 掺 ≥P 回 +k×0.1; Among them, P 掺 represents the water injection pressure, and P 回 represents the back pressure at the wellhead of the high-viscosity oil well, and k represents the safety factor.

5. The process method for gathering and transporting high-viscosity crude oil according to claim 1, characterized in that, the adjustment of the water injection pressure of the high-viscosity crude oil includes the steps of: Obtain a high-pressure water injection system; Configure a throttle valve in the high-pressure water injection system; Adjust the opening of the throttle valve.

6. The process method for gathering and transporting high-viscosity crude oil according to claim 1, characterized in that, the establishment of a non-powered recovery casing gas in the low-pressure area includes the steps of: Obtain a water injection pipeline; Install a check valve at the inlet of the water injection pipeline.

7. The process method for gathering and transporting high-viscosity crude oil according to claim 1, characterized in that, the optimization of the throttling parameters includes the steps of: Obtain the change value of the oil pressure; Obtain the change value of the dynamic liquid level; Adjust the throttling pressure according to the change value of the oil pressure and the change value of the dynamic liquid level.

8. A process device for gathering and transporting high-viscosity crude oil, characterized in that, including: A pressure determination module for determining the water injection pressure of the oil well; A pressure adjustment module for adjusting the water injection pressure of the high-viscosity crude oil; A casing gas establishment module for establishing a non-powered recovery casing gas in the low-pressure area; A parameter optimization module for optimizing the throttling parameters.

9. An electronic device, characterized in that, the electronic device includes: At least one processor; and, A memory communicatively connected to the at least one processor; wherein, the memory stores instructions executable by the at least one processor, and the instructions are executed by the at least one processor to enable the at least one processor to execute the process method for gathering and transporting high-viscosity crude oil according to any one of the preceding claims 1-7.

10. A non-transitory computer-readable storage medium, characterized in that, the non-transitory computer-readable storage medium stores computer instructions for causing the computer to execute the process method for gathering and transporting high-viscosity crude oil according to any one of the preceding claims 1-7.

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