Novel automatic crude oil sampling device

Abstract

The utility model relates to the technical field of automatic crude oil sampling devices, in particular to a novel automatic crude oil sampling device. The problems that in the prior art, manual testing is poor in real-time performance, and the testing result is not accurate are solved, and the practicability of the equipment is improved. The device structurally comprises a box body, a sampling cavity is formed in the box body, a first oil inlet pipe and an oil outlet pipe are arranged on the side wall of the sampling cavity, the oil outlet end of the first oil inlet pipe is sequentially connected with a power device, a first pressure transmitter, a water content meter, a density meter and a first temperature transmitter, and the other end of the temperature transmitter is connected with the oil outlet pipe; the oil inlet end of the first oil inlet pipe is sequentially connected with a filter, a second temperature transmitter, a second pressure transmitter and a flow metering device. According to the embodiment, the design of manual measurement in the prior art is replaced, the labor intensity of workers is reduced, the number of workers in a factory is reduced, and more scientific and reliable monitoring of crude oil data is achieved.

Description

Technical Field

[0001] The utility model relates to the technical field of crude oil automatic sampling devices, and in particular to a novel crude oil automatic sampling device. Background Art

[0002] The dynamic transfer of crude oil is a key task in calculating crude oil production. However, existing technologies have traditionally relied on manual sampling and testing at regular intervals, combined with manual calculations based on GB / T9109.5-2017, "Dynamic Measurement of Petroleum and Liquid Petroleum Products - Part 5: Calculation of Oil Volume."

[0003] This leads to the following problems: 1. The real-time performance of manual handover measurement is poor and the monitoring level is low, making it impossible to grasp the changes in oil products in real time; 2. Due to the influence of various factors such as personnel testing techniques, experience, equipment and sampling frequency, different personnel will produce different results when testing the same sample, which will affect production and operations. Utility Model Content

[0004] The utility model provides a novel automatic crude oil sampling device, which solves the problems of poor real-time performance and inaccurate test results of manual testing in the prior art, and improves the practicability of the device.

[0005] The technical solution of the utility model is as follows:

[0006] A new type of crude oil automatic sampling device, including a box body,

[0007] A sampling chamber is provided in the box body, and a first oil inlet pipe and an oil outlet pipe are provided on the side wall of the sampling chamber. The oil outlet end of the first oil inlet pipe is connected to a power device, a first pressure transmitter, a water content meter, a density meter and a first temperature transmitter in sequence. The other end of the temperature transmitter is connected to the oil outlet pipe. The oil inlet end of the first oil inlet pipe is connected to a filter, a second temperature transmitter, a second pressure transmitter and a flow metering device in sequence.

[0008] Furthermore, the power device includes a first sampling pump and a second sampling pump, the oil inlet end of the first sampling pump and the oil inlet end of the second sampling pump are both connected to the first oil inlet pipe, the oil outlet end of the first sampling pump is respectively connected to the water content meter and the first pressure transmitter, and the oil outlet end of the second sampling pump is connected to the first pressure transmitter.

[0009] Furthermore, the flow metering device includes a first flow meter and a second flow meter, the first flow meter and the second flow meter are both connected to a second pressure transmitter, and the other ends of the first flow meter and the second flow meter are both connected to a second oil inlet pipe.

[0010] Furthermore, the filter is a basket filter, the density meter is a Micro Motion density meter, the second temperature transmitter is a manifold temperature transmitter, and the second pressure transmitter is a manifold pressure transmitter.

[0011] Furthermore, a control chamber is provided in the box body, and a controller is provided in the control chamber. The controller is electrically connected to the power unit, the first pressure transmitter, the water content meter, the density meter, the first temperature transmitter, the filter, the second temperature transmitter, the second pressure transmitter and the flow metering device respectively.

[0012] Furthermore, a display screen is provided outside the box, and the display screen is electrically connected to the controller.

[0013] Furthermore, the sampling chamber is rotatably connected to a first sealing door, the control chamber is rotatably connected to a second sealing door, a buffer layer is fixed on the first sealing door, the buffer layer is made of rubber material, a first magnet is fixed in the buffer layer, a second magnet is provided near the end of the first magnet in the sampling chamber, the magnetic properties of the first magnet and the second magnet are opposite, and the connection structure of the first sealing door and the second sealing door is the same.

[0014] The working principle and beneficial effects of the utility model are as follows:

[0015] The working process of this embodiment is as follows: the crude oil to be tested passes through the second oil inlet pipe, in sequence, through the flow meter, the second pressure transmitter, the second temperature transmitter, the filter, the power unit, the first pressure transmitter, the water content meter, the density meter, and the first temperature transmitter, and finally through the oil outlet pipe back into the crude oil pipeline. This enables real-time monitoring of the crude oil pressure and temperature at inlet and outlet, the water content, and the density of the crude oil.

[0016] This embodiment provides a flow meter, a second pressure transmitter, a second temperature transmitter, a filter, a power unit, a first pressure transmitter, a water content meter, a density meter, and a first temperature transmitter on the tank body, thereby enabling real-time monitoring of the crude oil pressure and temperature at inlet and outlet, the water content, and the density of the crude oil. This replaces the manual measurement design used in the prior art, reduces employee labor intensity, reduces the number of factory workers, and achieves more scientific and reliable monitoring of crude oil data. BRIEF DESCRIPTION OF THE DRAWINGS

[0017] The present invention will be further described in detail below with reference to the accompanying drawings and specific implementation methods.

[0018] Figure 1 This is a schematic diagram of the overall structure of this embodiment Figure 1 ;

[0019] Figure 2This is a schematic diagram of the overall structure of this embodiment Figure 2 ;

[0020] Figure 3 This is a schematic diagram of the connection between the internal and external parts of the box in this embodiment;

[0021] Figure 4 Schematic diagram of the structure of the first sealing door in this embodiment.

[0022] In the picture:

[0023] 1. Box body; 11. Sampling chamber; 111. Second magnet; 12. Control chamber; 2. First sealing door; 21. Buffer layer; 211. First magnet; 3. Second sealing door; 41. First oil inlet pipe; 42. Oil outlet pipe; 43. Second oil inlet pipe; 51. First sampling pump; 52. Second sampling pump; 6. First pressure transmitter; 71. Moisture meter; 72. Density meter; 73. First temperature transmitter; 74. First flow meter; 75. Second flow meter; 76. Filter; 77. Second temperature transmitter; 78. Second pressure transmitter; 8. Controller; 9. Display screen. DETAILED DESCRIPTION

[0024] The following will be combined with the embodiments of the present invention to clearly and completely describe the technical solutions in the embodiments of the present invention. Obviously, the embodiments described are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without making creative efforts are within the scope of protection of the present invention.

[0025] like Figures 1 to 4 As shown, this embodiment provides a novel automatic crude oil sampling device, which includes a housing 1. In this embodiment, a sampling chamber 11 is disposed within the housing 1, and a first oil inlet pipe 41 and an oil outlet pipe 42 are disposed on the sidewalls of the sampling chamber 11. The outlet end of the first oil inlet pipe 41 is sequentially connected to a power unit, a first pressure transmitter 6, a water content meter 71, a density meter 72, and a first temperature transmitter 73. The other end of the temperature transmitter is connected to the oil outlet pipe 42. The oil inlet end of the first oil inlet pipe 41 is sequentially connected to a filter 76, a second temperature transmitter 77, a second pressure transmitter 78, and a flow meter.

[0026] The power unit in this embodiment includes a first sampling pump 51 and a second sampling pump 52. The first oil inlet pipe 41 is connected to both the oil inlet of the first sampling pump 51 and the oil inlet of the second sampling pump 52. The oil outlet of the first sampling pump 51 is connected to the water content meter 71 and the first pressure transmitter 6, respectively. The oil outlet of the second sampling pump 52 is connected to the first pressure transmitter 6. This embodiment employs a dual sampling pump design, which allows the second sampling pump to continue operating even if one sampling pump stops operating due to a malfunction or maintenance requirement, ensuring a continuous sampling process and preventing data loss or inaccuracy due to a single point of failure.

[0027] The flow metering device in this embodiment includes a first flowmeter 74 and a second flowmeter 75, both of which are connected to a second pressure transmitter 78. The second oil inlet pipe 43 is connected to the other ends of both the first and second flowmeters 74 and 75. Because crude oil flow rates vary significantly within the crude oil pipeline, the measurement range of a single flowmeter may be insufficient to cover these flow variations. Therefore, the first and second flowmeters 74 and 75 are connected in parallel to calculate the oil flow rate at the oil inlet through superposition. In this embodiment, the second oil inlet pipe 43 and the oil outlet pipe 42 are evenly connected to the oil pipeline to be tested, thus avoiding oil loss caused by testing.

[0028] The filter 76 in this embodiment is a basket filter 76. Using a wire mesh or other microporous structure, it can selectively block particles of a specific size, reducing the impact of impurities on the crude oil temperature, water content, and oil density after entering the tank 1. The densitometer 72 is a high-precision Coriolis densitometer 72. Since even small differences in crude oil water content can directly affect its quality, the use of a high-precision Coriolis densitometer 72 can provide highly accurate density measurements and ensure data accuracy and reliability. The second temperature transmitter 77 is a manifold temperature transmitter, and the second pressure transmitter 78 is a manifold pressure transmitter. Since both the second temperature transmitter 77 and the second pressure transmitter 78 are connected to the oil pipeline, there may be real-time changes in oil temperature and pressure within the pipeline. Using the manifold pressure transmitter and the manifold temperature transmitter allows for real-time monitoring of pressure changes within the pipeline.

[0029] In this embodiment, the control chamber 12 is arranged in the box body 1, and the controller 8 is arranged in the control chamber 12. The controller 8 is electrically connected to the power device, the first pressure transmitter 6, the water content meter 71, the density meter 72, the first temperature transmitter 73, the filter 76, the second temperature transmitter 77, the second pressure transmitter 78 and the flow metering device respectively.

[0030] This design enables real-time online collection of the oil product density, water content, flow rate, pressure, and temperature in this embodiment, and automatic calculation of the transfer oil volume in accordance with GB / T 9109.1-2016 "Dynamic Measurement of Petroleum and Liquid Petroleum Products Part 1: General Principles" and GB / T 9109.5-2017 "Dynamic Measurement of Petroleum and Liquid Petroleum Products Part 5: Oil Quantity Calculation" standards;

[0031] When the device's measurement sensor uncertainty reaches: better than ±0.1% for oil moisture content of 0-1%; better than ±0.15% for oil moisture content of 1-3%; better than ±0.5% for oil moisture content of 3%-10%; and better than ±1% for oil moisture content greater than 10%. Density uncertainty is better than ±0.5kg / m³; temperature uncertainty is better than ±0.2°C; and pressure uncertainty is better than 1% of the pressure range. Controller 8 can automatically generate production alarms based on the alarm limits set by the host computer.

[0032] The standard density (ρ20), density at 15°C (ρ15), compressibility (F), oil volume pressure correction factor (Cpl), and oil volume temperature correction factor (Ctl) used in this example were calculated using the formulas specified in "Dynamic Measurement of Petroleum and Liquid Petroleum Products - Part 5: Calculation of Oil Quantity" (GB / T 9109.5-2017) and the table in "Petroleum Metering Tables" (GB / T 1885-1998). The standard volume (V), mixed oil content, water content, and pure oil content were calculated using the formulas specified in "Dynamic Measurement of Petroleum and Liquid Petroleum Products - Part 5: Calculation of Oil Quantity" (GB / T 9109.5-2017).

[0033] Standard density (ρ20): Calculated based on the visual density and the temperature inside the skid. The calculation formula is as follows:

[0034] ρ20=ρ201+(ρ202-ρ201) / (ρ2-ρ1)x(ρ-ρ1) (1)

[0035] Where:

[0036] ρ: apparent density

[0037] ρ1, ρ2: front and back values ​​of the apparent density interval

[0038] ρ201, ρ202: Standard density before and after values ​​of apparent density range at corresponding temperature

[0039] Data lookup table: "Standard Density Table of Crude Oil"

[0040] Density at 15°C (ρ15): Calculated based on the standard density at 20°C. The calculation formula is as follows:

[0041] ρ15=ρ151+(ρ152-ρ151) / (ρ202-ρ201)x(ρ20-ρ201) (2)

[0042] Where:

[0043] ρ20: standard density

[0044] ρ201, ρ202: front and back values ​​of standard density interval

[0045] ρ151, ρ152: corresponding to the density value before and after 15℃ in the standard density range

[0046] Data lookup table: "Conversion table of crude oil density at 20℃ to density at 15℃"

[0047] Compression coefficient (F): Calculated based on the density at 15°C and the main pipe temperature. The calculation formula is as follows:

[0048] F=F1+(F2-F1) / (ρ152-ρ151)x(ρ15-ρ151) (3)

[0049] Where:

[0050] ρ15: density at 15°C

[0051] ρ151, ρ152: front and back values ​​of the 15℃ density range

[0052] F1, F2: F value before and after the density range of 15℃ at the corresponding temperature

[0053] Data table: "Compression coefficient of petroleum hydrocarbons"

[0054] Oil volume temperature correction coefficient (Ctl): Calculate based on the density at 20°C and the main pipe temperature. The calculation formula is as follows:

[0055] Ctl=Ctl1+(Ctl2-Ctl1) / (ρ202-ρ201)x(ρ20-ρ201) (4)

[0056] Where:

[0057] ρ20: standard density at 20℃

[0058] ρ201, ρ202: front and back values ​​of the standard density range at 20℃

[0059] Ctl1, Ctl2: Ctl value before and after the density range of 20℃ at the corresponding temperature

[0060] Data table: "Crude oil volume correction factor"

[0061] Oil volume pressure correction coefficient (Cpl)

[0062] Cpl=1 / [1-(P-Pe)xFx10-6] (5)

[0063] Where:

[0064] P: Main pipe pressure KPa

[0065] Pe: Oil vapor pressure, generally less than atmospheric pressure, so Pe = 0

[0066] F: Compression factor

[0067] Standard volume (V20)

[0068] V20=VxCtlxCpl (6)

[0069] Where:

[0070] V: volume m3

[0071] Ctl: Oil volume temperature correction coefficient

[0072] Cpl: Oil volume pressure correction coefficient

[0073] Mixed oil quantity (Q)

[0074] Q=V20x(ρ20-1.1) / 1000 (7)

[0075] Where:

[0076] V20: standard volume m3

[0077] ρ20: Standard density at 20℃ Kg / m3

[0078] Water quantity (QW)

[0079] Qw=QxSW / 100 (8)

[0080] Where:

[0081] Q: Mixed oil quantity t

[0082] SW: moisture content%

[0083] Pure oil volume (Q0)

[0084] QO=Q –QW (9)

[0085] Where:

[0086] Q: Mixed oil quantity t

[0087] QW: water volume t

[0088] Rounding method: The method of numerical rounding shall be implemented in accordance with the "Data Rounding Rules and Representation and Determination of Limit Values" (GB / T8170-2008).

[0089] Transfer volume calculation process: The incoming liquid first passes through the flow meter, and the volume flowing through the flow meter within a fixed time period is calculated based on the difference in the flow meter base data before and after the time period; the standard density ρ20 of the oil is calculated based on the temperature transmitter data inside the skid and the density meter 72; the oil volume temperature correction coefficient Ctl is calculated based on the manifold temperature transmitter data and the standard density ρ20; the density ρ15 is calculated based on the standard density ρ20; the compression coefficient F×10-6 is calculated based on the density ρ15 and the manifold temperature data; the oil volume pressure correction coefficient Cpl is calculated based on the manifold pressure data and the compression coefficient F×10-6; the standard volume of the transfer is calculated based on the volume, the oil volume temperature correction coefficient Ctl, and the oil volume pressure correction coefficient Cpl; the mixed oil amount is calculated based on the standard volume and standard density ρ20, and the transfer water amount is calculated based on the mixed oil amount and water content; the transfer pure oil amount is calculated based on the mixed oil amount and water amount.

[0090] In this embodiment, a display screen 9 is disposed outside the housing 1 and is electrically connected to the controller 8. This embodiment uses the display screen 9 to display the detected crude oil water content, crude oil temperature, crude oil flow rate, and crude oil density, facilitating real-time monitoring by the operator. In this embodiment, the controller 8 is controlled by a PLC or microcomputer. These PLCs and microcomputers are conventional technologies and will not be described in detail in this embodiment.

[0091] In this embodiment, the first sealing door 2 is rotatably mounted on the sampling chamber 11, and the second sealing door 3 is rotatably mounted on the control chamber 12. The buffer layer 21 is fixedly mounted on the first sealing door 2. The buffer layer 21 is made of rubber material and is used to reduce the collision damage of the first sealing door 2 on the housing 1 when it is closed. The first magnet 211 is fixedly mounted in the buffer layer 21, and the second magnet 111 is mounted on the end of the sampling chamber 11 close to the first magnet 211. The magnetic properties of the first magnet 211 and the second magnet 111 are opposite, and the connection structure of the first sealing door 2 and the second sealing door 3 is the same. This embodiment adopts the attraction of the first magnet 211 and the second magnet 111, which not only realizes the sealing and closure of the first sealing door 2 relative to the sampling chamber 11, but also makes the first sealing door 2 relatively easy to open, making it convenient to observe and maintain the working condition of the sampling chamber 11.

[0092] The working process of this embodiment is as follows: the crude oil to be tested passes through the second oil inlet pipe 43, in sequence, through the flow meter, the second pressure transmitter 78, the second temperature transmitter 77, the filter 76, the power unit, the first pressure transmitter 6, the water content meter 71, the density meter 72, and the first temperature transmitter 73, and finally returns to the crude oil pipeline through the oil outlet pipe 42. This enables real-time monitoring of the crude oil pressure and temperature at inlet and outlet, the water content, and the density of the crude oil.

[0093] The above are only preferred embodiments of the present invention and are not intended to limit the present invention. Any modifications, equivalent replacements, improvements, etc. made within the spirit and principles of the present invention should be included in the scope of protection of the present invention.

Claims

1. A novel automatic crude oil sampling device, comprising a housing (1), characterized in that: A sampling chamber (11) is provided in the box body (1), and a first oil inlet pipe (41) and an oil outlet pipe (42) are provided on the side wall of the sampling chamber (11). The oil outlet end of the first oil inlet pipe (41) is sequentially connected to a power device, a first pressure transmitter (6), a water content meter (71), a density meter (72) and a first temperature transmitter (73). The other end of the temperature transmitter is connected to the oil outlet pipe (42). The oil inlet end of the first oil inlet pipe (41) is sequentially connected to a filter (76), a second temperature transmitter (77), a second pressure transmitter (78) and a flow meter.

2. A novel automatic crude oil sampling device according to claim 1, characterized in that: The power device comprises a first sampling pump (51) and a second sampling pump (52), wherein the oil inlet end of the first sampling pump (51) and the oil inlet end of the second sampling pump (52) are both connected to a first oil inlet pipe (41), the oil outlet end of the first sampling pump (51) is respectively connected to a water content meter (71) and a first pressure transmitter (6), and the oil outlet end of the second sampling pump (52) is connected to the first pressure transmitter (6).

3. A novel automatic crude oil sampling device according to claim 1, characterized in that: The flow metering device comprises a first flow meter (74) and a second flow meter (75), wherein the first flow meter (74) and the second flow meter (75) are both connected to a second pressure transmitter (78), and the other ends of the first flow meter (74) and the second flow meter (75) are both connected to a second oil inlet pipe (43).

4. A novel automatic crude oil sampling device according to claim 1, characterized in that: The filter (76) is a basket filter (76), the density meter (72) is a high-precision density meter (72), the second temperature transmitter (77) is a manifold temperature transmitter, and the second pressure transmitter (78) is a manifold pressure transmitter.

5. A novel automatic crude oil sampling device according to claim 1, characterized in that: A control chamber (12) is further provided in the box (1), and a controller (8) is provided in the control chamber (12). The controller (8) is electrically connected to the power device, the first pressure transmitter (6), the water content meter (71), the density meter (72), the first temperature transmitter (73), the filter (76), the second temperature transmitter (77), the second pressure transmitter (78), and the flow meter.

6. A novel automatic crude oil sampling device according to claim 5, characterized in that: A display screen (9) is also provided outside the box (1), and the display screen (9) is electrically connected to the controller (8).

7. A novel automatic crude oil sampling device according to claim 5, characterized in that: The sampling chamber (11) is also rotatably connected to a first sealing door (2), and the control chamber (12) is rotatably connected to a second sealing door (3). A buffer layer (21) is fixed to the first sealing door (2), and the buffer layer (21) is made of a rubber material. A first magnet (211) is fixed in the buffer layer (21). A second magnet (111) is provided at an end of the sampling chamber (11) close to the first magnet (211). The magnetic properties of the first magnet (211) and the second magnet (111) are opposite. The connection structure of the first sealing door (2) and the second sealing door (3) is the same.

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