An automatic oil and gas well production metering device and method

Abstract

The application discloses an oil and gas well yield automatic metering device and method, one end of a tubing is connected with an input end of an electric valve group, an output end of the electric valve group is connected with an input end of a computer through a liquid production metering system, an output end of the computer is connected with an input end of the electric valve group through a first programmable logic controller, and the output end of the computer is also connected with an input end of the liquid production metering system; a water content detection system is connected with the liquid production metering system and the computer respectively; an output end of a 220V alternating voltage source is connected with a power supply end of the first programmable logic controller, and the output end of the 220V alternating voltage source is also connected with a power supply end of a second programmable logic controller in the liquid production metering system and a power supply end of a liquid storage tank electric heat tracing belt; the liquid production metering system and the water content detection system are used to automatically obtain the liquid production, the gas production and the water content of produced liquid of the oil and gas well within a specified time, so that the daily oil production is obtained, and the detection efficiency and accuracy are improved.

Description

Technical Field

[0001] This invention belongs to the field of oil and gas field development and relates to oil and gas well production measurement technology, specifically to an automatic oil and gas well production metering device and method. Background Technology

[0002] In oil and gas field development, measuring well production is fundamental to understanding well operation and formulating injection-production development plans. With the gradual improvement of injection-production well networks, the workload of metering has increased, and the requirements for the automation level of metering technology are constantly rising. How to accurately and efficiently measure daily oil and gas production, and optimize development plans through production data analysis, has become a critical issue that urgently needs to be addressed. Currently, the commonly used metering method in China involves using a separator to separate the produced fluid, using glass tubes or tipping buckets to measure the fluid volume, and manually sampling to detect the water content of the produced fluid to calculate the daily oil production. However, this measurement technology has some problems in practical applications: 1. Glass tube metering requires manual reading of the water level rise in the glass tube, resulting in long detection times and low automation levels; 2. Tipping bucket metering is prone to crude oil adhering to the walls and wax deposition, which can lead to inaccurate metering results over long-term use. Furthermore, the changing patterns of fluid and gas production are important indicators of reservoir connectivity, but due to the lack of comprehensive data analysis and evaluation methods, it is difficult to quantify and utilize reservoir connectivity. Summary of the Invention

[0003] To address the problems of long detection time, low automation level, and inaccurate results in existing oil and gas well production measurement methods, this invention provides an automatic oil and gas well production measurement device and method. Through a production volume measurement system and a water cut detection system, the device automatically acquires the production volume, gas production volume, and water cut of the produced fluid within a specified time to obtain the daily oil production, thereby improving the efficiency and accuracy of detection.

[0004] The technical solution adopted by this invention to solve its technical problem is: an automatic metering device for oil and gas well production, comprising an oil pipe, an electric valve assembly, a production volume metering system, a water cut detection system, a computer, a first programmable logic controller (PLC), and a 220V AC power source; one end of the oil pipe is connected to the input end of the electric valve assembly, the output end of the electric valve assembly is connected to the input end of the computer via the production volume metering system, the output end of the computer is connected to the input end of the electric valve assembly via the first PLC, and the output end of the computer is also connected to the input end of the production volume metering system; the water cut detection system is connected to both the production volume metering system and the computer; the output end of the 220V AC power source is connected to both the power supply end of the first PLC and the production volume metering system.

[0005] As a further embodiment of the present invention, the liquid production metering system includes an inlet pipe, a second electric valve, an auxiliary outlet pipe, a third electric valve, an outlet pipe, a second programmable logic controller, a storage tank, a first electric valve, an outlet pipe, a gas flow meter, a 24V DC voltage source, an ultrasonic level gauge, a first data acquisition card, and a second data acquisition card.

[0006] One end of the inlet pipe is connected to the storage tank via the first electric valve. The storage tank is connected to one end of the auxiliary outlet pipe, and the other end of the auxiliary outlet pipe is connected to the outlet pipe via the third electric valve. One end of the inlet pipe is also connected to the outlet pipe via the second electric valve. The input terminal of the second programmable logic controller is connected to the output terminal of the computer. The output terminal of the second programmable logic controller is connected to the input terminals of the first electric valve, the second electric valve, and the third electric valve, respectively. The power supply terminal of the second programmable logic controller is connected to a 220V AC voltage source.

[0007] The storage tank is connected to one end of the gas outlet pipe, and the other end of the gas outlet pipe is connected to the input end of the gas flow meter. The output end of the gas flow meter is connected to the input end of the first data acquisition card, and the output end of the first data acquisition card is connected to the input end of the computer. The input end of the ultrasonic level gauge is connected to the storage tank, and the output end of the ultrasonic level gauge is connected to the input end of the second data acquisition card, and the output end of the second data acquisition card is connected to the input end of the computer.

[0008] The high-voltage terminals of the 24V DC voltage source are connected to the high-voltage terminals of the gas flow meter and the ultrasonic level gauge, respectively, and the ground terminal of the 24V DC voltage source is grounded.

[0009] As a further embodiment of the present invention, the liquid storage tank includes a first heating pipe, a tank body, a second heating pipe, an electric heating tape, and a heat insulation layer;

[0010] The first heating tube and the second heating tube are welded to both sides of the tank body, and electric heating tape is inserted inside the first heating tube and the second heating tube. The power supply end of the electric heating tape is connected to a 220V AC voltage source. The tank body, the first heating tube, and the second heating tube are all inserted into the insulation layer. The top surface of the tank body is provided with a level gauge socket, an air outlet, and a liquid inlet, and the bottom surface is provided with a liquid outlet. The liquid inlet is connected to one end of the liquid inlet pipe, the air outlet is connected to one end of the air outlet pipe, the level gauge socket is connected to the input end of the ultrasonic level gauge, and the liquid outlet is connected to one end of the auxiliary liquid outlet pipe.

[0011] As a further embodiment of the present invention, the moisture content detection system includes a detection tube, a receiving antenna, a filter, a low-noise amplifier, an amplitude and phase detection module, a detector, an A / D converter, a microwave signal generator, a radio frequency isolator, a power attenuator, and a transmitting antenna;

[0012] The detection tube is connected to the outlet tube of the liquid production metering system. The receiving antenna and the transmitting antenna are respectively located on both sides of the detection tube. The output end of the receiving antenna is connected to a filter and then to the input end of a low noise amplifier. The output end of the low noise amplifier is connected to the input end of the amplitude and phase detection module.

[0013] The output of the microwave signal generator is connected to the input of the power attenuator via an RF isolator. The output of the power attenuator is connected to the output of the transmitting antenna. The output of the power attenuator is also connected to the input of the amplitude and phase detection module. The output of the amplitude and phase detection module is connected to the A / D converter via a detector.

[0014] An automatic measurement method for oil and gas well production, using the above-mentioned apparatus, includes:

[0015] Step 1: Input initial parameters, including the initial and upper limit values ​​of the well number m of the oil and gas well, the initial and upper limit values ​​of the metering days F, the metering interval t1, the upper limit value of the metering time t2, the number of daily meters a, and the liquid level rise H;

[0016] Step 2: The electric valve group starts working, opening the electric valve controlling oil and gas well m and closing the electric valves controlling other oil and gas wells;

[0017] Step 3: Obtain the production volume and water cut data of oil and gas well m using the oil and gas well production volume metering system and water cut detection system, respectively;

[0018] Step 4: Calculate oil and gas well production;

[0019] Step 5: Determine whether F has reached the upper limit of the metering days. If not, when the metering time of the first programmable logic controller reaches 24 hours, increment the metering days F by 1, and repeat steps 3 to 4 until the upper limit of the metering days is reached.

[0020] Step 6: Determine if m has reached the upper limit of the well number for oil and gas wells. If not, increment the well number m by 1 and repeat steps 2 to 5 until the upper limit of the well number is reached.

[0021] As a further embodiment of the present invention, step 3 includes:

[0022] Step 3.1: The first programmable logic controller is initialized and timing begins;

[0023] Step 3.2: Start the liquid production metering system, initialize the second programmable logic controller and start timing, and use the ultrasonic level gauge to measure the initial value of the liquid level in the storage tank;

[0024] Step 3.3: The first electric valve opens and the second electric valve closes;

[0025] Step 3.4: The liquid from the m-th oil and gas well flows into the storage tank through the first electric valve, while the natural gas in the liquid is discharged through the gas outlet pipe, and the gas flow meter measures the amount of gas discharged.

[0026] Step 3.5: The ultrasonic level gauge detects the liquid level in the storage tank; if the liquid level rise H can reach the specified value within the upper limit of the measurement time t2, the second programmable logic controller stops timing and resets when the liquid level rise H reaches the specified value; if the liquid level rise H has not reached the specified value when the timing time reaches t2, the second programmable logic controller stops timing and measures the liquid level at this time;

[0027] Step 3.6: The first electric valve is closed, the second and third electric valves are opened, the liquid in the storage tank is discharged through the outlet pipe, the moisture content detection system starts working, the microwave signal generator is started to detect the moisture content of the liquid in the detection tube in real time, when the liquid level in the storage tank drops to the initial value, the third electric valve is closed, and the moisture content detection system stops working;

[0028] Step 3.7: Keep the liquid flowing into the outlet pipe through the second electric valve. The second programmable logic controller starts timing until the metering interval time t1 is reached. Then, the second programmable logic controller stops timing and resets.

[0029] Step 3.8: Determine whether the daily measurement frequency 'a' of the liquid production has been reached. If not, increment the measurement frequency by 1 and repeat steps 3.2 to 3.7 until the daily measurement frequency 'a' is reached. Then, the liquid production measurement system will stop working.

[0030] As a further embodiment of the present invention, step 4 includes:

[0031] Step 4.1: Take the average moisture content within the detection period as the result of each moisture content measurement;

[0032] Step 4.2: Take the average value of the moisture content measurements taken a times within a day as the daily moisture content;

[0033] Step 4.3: Determine the daily liquid production volume;

[0034] Step 4.4: Determine daily oil production;

[0035] Step 4.5: Determine the daily gas production.

[0036] As a further embodiment of the present invention, it also includes:

[0037] Step 7: Establish an evaluation model for the correlation between oil and gas well production. By analyzing the variation patterns of fluid production and gas production of different oil and gas wells, determine the reservoir connectivity evaluation score of each oil and gas well in the block.

[0038] As a further embodiment of the present invention, step 7 includes:

[0039] Step 7.1: Select well number i as the reference well, and set the initial value of i to 1;

[0040] Step 7.2: Select well j as the calculation well, and the initial value of j is i+1;

[0041] Step 7.3: Establish reference sequence X based on the product yield data. i And calculate sequence X j A reference sequence Y is established based on gas production data. i And calculate sequence Y j :

[0042] Step 7.4: Calculate sequence X i and X j displacement difference d ij1 Speed ​​difference d ij2 Acceleration difference d ij3 Calculate the reference sequence Y i And calculate sequence Y j displacement difference dd ij1 Speed ​​difference dd ij2 Acceleration difference dd ij3 :

[0043] Step 7.5: Calculate sequence X i and X j correlation coefficient γ ij Calculate sequence Y i and Y j correlation coefficient β ij :

[0044] Step 7.6: Determine if the upper limit of the calculated well number has been reached. If not, increment the well number j by 1 and repeat steps 7.3 to 7.5. If the upper limit has been reached, stop the loop.

[0045] Step 7.7: Determine if the upper limit of the reference hash number has been reached. If not, increment the reference hash number i by 1 and repeat steps 7.2 to 7.6. If the upper limit has been reached, stop the loop.

[0046] Step 7.8: Construct relevance matrices A and B, where element A in matrix A is... ij The correlation coefficient γ between oil and gas well number i and oil and gas well number j ij A ij =A ji The element B in matrix B ij The correlation coefficient between oil and gas well number i and oil and gas well number j β ij B ij =Bji The row numbers of the matrix are the well numbers of the oil and gas wells;

[0047] Step 7.9: Determine the evaluation score of oil and water connectivity in the reservoir based on the correlation coefficient of production volume of each oil and gas well;

[0048] Step 7.10: Determine the reservoir connectivity evaluation score based on the correlation coefficient of gas production of each oil and gas well;

[0049] Step 7.11: Determine the reservoir connectivity evaluation score based on the oil and water layer connectivity evaluation scores and the gas layer connectivity evaluation scores.

[0050] As a further embodiment of the present invention, step 7.9 includes:

[0051] Step 7.9.1: Calculate the expected value and variance of the correlation coefficient of production from each oil and gas well within the block:

[0052] Step 7.9.2: Use the expected value and variance of the correlation coefficient of production of each oil and gas well as the evaluation index. Determine the weight of the expected value and variance according to the needs of the scheme design, and evaluate them with a total score of 100 points.

[0053] As a further embodiment of the present invention, step 7.10 includes:

[0054] Step 7.10.1: Calculate the expected value and variance of the correlation coefficient of gas production of each oil and gas well within the block:

[0055] Step 7.10.2: Use the expected value and variance of the correlation coefficient of gas production of each oil and gas well as the evaluation index. Determine the weight of the expected value and variance according to the needs of the scheme design, and evaluate them with a total score of 100 points.

[0056] The beneficial effects of this invention include: By constructing an automatic oil and gas well production metering device comprising tubing, electric valve assembly, production volume metering system, water cut detection system, first programmable logic controller, 220V AC voltage source, and computer, this invention solves the problems of low automation and inaccurate metering results existing in current glass tube metering and tipping bucket metering methods, while achieving multi-well metering. Furthermore, by establishing an evaluation model that uses production data from each oil and gas well within a block as input and reservoir connectivity evaluation scores as output, reservoir connectivity is quantitatively scored, providing data support for the formulation of oilfield well network injection-production conversion schemes and gas storage and production development schemes. Attached Figure Description

[0057] Figure 1 This is a schematic diagram of the overall structure of the automatic metering device for oil and gas well production of the present invention;

[0058] Figure 2This is a schematic diagram of the liquid production metering system.

[0059] Figure 3 This is a schematic diagram of the liquid storage tank structure;

[0060] Figure 4 This is a schematic diagram of the moisture content detection system.

[0061] Figure labeling: 1-oil pipe; 2-electric valve assembly; 3-product liquid metering system; 4-water content detection system; 5-computer; 6-first programmable logic controller; 7-220V AC voltage source; 8-inlet pipe; 9-second electric valve; 10-auxiliary outlet pipe; 11-third electric valve; 12-outlet pipe; 13-second programmable logic controller; 14-storage tank; 15-first electric valve; 16-gas outlet pipe; 17-gas flow meter; 18-24V DC voltage source; 19-ultrasonic level gauge; 20-first... 21-Second data acquisition card; 23-First heating element; 24-Tank body; 25-Liquid outlet; 26-Second heating element; 27-Electric heating tape; 28-Insulation layer; 29-Level gauge socket; 30-Gas outlet; 31-Liquid inlet; 32-Filter; 33-Low noise amplifier; 34-Amplitude and phase detection module; 35-Detector; 36-A / D converter; 37-Microwave signal generator; 38-RF isolator; 39-Power attenuator; 40-Transmitting antenna; 41-Detection tube; 42-Receiving antenna. Detailed Implementation

[0062] The technical solution of the present invention will now be clearly and completely described with reference to the accompanying drawings. Obviously, the described embodiments are only some, not all, of the embodiments of the present invention. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0063] In the description of this invention, it should be noted that the terms "vertical," "horizontal," "inner," and "outer," etc., indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings. They are used only for the convenience of describing the invention and for simplifying the description, and do not indicate or imply that the device or component referred to must have a specific orientation, or be constructed and operated in a specific orientation. Therefore, they should not be construed as limitations on the invention. Furthermore, the terms "first," "second," and "third" are used only to distinguish components and should not be construed as indicating or implying relative importance.

[0064] Furthermore, the technical features involved in the different embodiments of the present invention described below can be combined with each other as long as they do not conflict with each other.

[0065] Example 1

[0066] An automatic metering device for oil and gas well production, such as Figure 1 As shown, it includes an oil pipe 1, an electric valve assembly 2, a liquid production metering system 3, a water content detection system 4, a computer 5, a first programmable logic controller 6, and a 220V AC voltage source 7;

[0067] One end of the oil pipe 1 is connected to the input end of the electric valve assembly 2. The output end of the electric valve assembly 2 is connected to the input end of the computer 5 via the liquid production metering system 3. The output end of the computer 5 is connected to the input end of the electric valve assembly 2 via the first programmable logic controller 6. The output end of the computer 5 is also connected to the input end of the liquid production metering system 3. The water content detection system 4 is connected to the liquid production metering system 3 and the computer 5 respectively. The output end of the 220V AC voltage source 7 is connected to the power supply end of the first programmable logic controller 6. The output end of the 220V AC voltage source 7 is also connected to the power supply end of the second programmable logic controller 13 in the liquid production metering system 3 and the power supply end of the electric heating tape 27 of the liquid storage tank 14.

[0068] Furthermore, such as Figure 2 As shown, the liquid production metering system 3 includes an inlet pipe 8, a second electric valve 9, an auxiliary outlet pipe 10, a third electric valve 11, an outlet pipe 12, a second programmable logic controller 13, a storage tank 14, a first electric valve 15, a gas outlet pipe 16, a gas flow meter 17, a 24V DC voltage source 18, an ultrasonic level gauge 19, a first data acquisition card 20, and a second data acquisition card 21.

[0069] One end of the inlet pipe 8 is connected to the storage tank 14 via the first electric valve 15. The storage tank 14 is connected to one end of the auxiliary outlet pipe 10, and the other end of the auxiliary outlet pipe 10 is connected to the outlet pipe 12 via the third electric valve 11. One end of the inlet pipe 8 is also connected to the outlet pipe 12 via the second electric valve 9. The input terminal of the second programmable logic controller 13 is connected to the output terminal of the computer 5, and the output terminal of the second programmable logic controller 13 is connected to the input terminal of the first electric valve 15, the input terminal of the second electric valve 9, and the input terminal of the third electric valve 11, respectively.

[0070] One end of the storage tank 14 is connected to the gas outlet pipe 16, and the other end of the gas outlet pipe 16 is connected to the input end of the gas flow meter 17. The output end of the gas flow meter 17 is connected to the input end of the first data acquisition card 20, and the output end of the first data acquisition card 20 is connected to the input end of the computer 5. The input end of the ultrasonic level gauge 19 is connected to the storage tank 14, and the output end of the ultrasonic level gauge 19 is connected to the input end of the second data acquisition card 21. The output end of the second data acquisition card 21 is connected to the input end of the computer 5.

[0071] The high-voltage terminal of the 24V DC voltage source 18 is connected to the high-voltage terminal of the gas flow meter 17 and the high-voltage terminal of the ultrasonic level gauge 19, respectively, and the ground terminal of the 24V DC voltage source 18 is grounded.

[0072] Furthermore, such as Figure 3 As shown, the liquid storage tank 14 includes a first heating tube 23, a tank body 24, a second heating tube 26, an electric heating tape 27, and a heat insulation layer 28;

[0073] The tank body 24 is a cylindrical barrel structure. The first heating tube 23 and the second heating tube 26 are welded to both sides of the tank body 24, and electric heating tape 27 is inserted into the first heating tube 23 and the second heating tube 26. The power supply end of the electric heating tape 27 is connected to a 220V AC voltage source 7. The tank body 24, the first heating tube 23, and the second heating tube 26 are all inserted into the insulation layer 28. The top surface of the tank body 24 is provided with a liquid level gauge socket 29, an air outlet 30, and a liquid inlet 31. The bottom surface is provided with a liquid outlet 25. The liquid inlet 31 is connected to one end of the liquid inlet pipe 8, the air outlet 30 is connected to one end of the air outlet pipe 16, the liquid level gauge socket 29 is connected to the input end of the ultrasonic liquid level gauge 19, and the liquid outlet 25 is connected to one end of the auxiliary liquid outlet pipe 10.

[0074] In the above implementation scheme, the oil pipe 1 is made of alloy, with an inner diameter of 64mm and an outer diameter of 76.2mm; the electric valve group 2 includes multiple electric valves, which are used to control the on / off state and flow rate of each oil pipe 1. The opening degree of the electric valve 2 is controlled by a 4-20mA current signal, and the electric valve model is ZDLP.

[0075] The first programmable logic controller 6 is used to control the operation of the electric valve group 2, to time the moisture content detection interval, to process the output data of the moisture content detection system 4, and to transmit it to the computer 5. The model of the first programmable logic controller 6 is FX3U-128MT / ES-A.

[0076] Computer 5 is used to send instructions to the first programmable logic controller 6 to control the operation of electric valve group 2, and to send instructions to the second programmable logic controller 13 to control the operation of the first electric valve 15, the second electric valve 9, and the third electric valve 11; it is used to receive the liquid level signal output by the ultrasonic level gauge 19; and it is used to calculate the daily oil production of oil and gas wells. The computer model is TG01-155ccn.

[0077] The 220V AC voltage source 7 is used to supply power to the first programmable logic controller 6, the second programmable logic controller 13, and the electric heating tape 27 at a frequency of 50Hz.

[0078] The inner diameter of the inlet pipe 8, the auxiliary outlet pipe 10, and the outlet pipe 12 are all 64 mm and the outer diameter is 76.2 mm. They are made of alloy. The first electric valve 15 is used to open and close the liquid flowing into the storage tank 14. The second electric valve 9 is used to open and close the liquid flowing directly into the outlet pipe 12. The third electric valve 11 is used to open and close the liquid flowing out of the storage tank 14. The first electric valve 15, the second electric valve 9, and the third electric valve 11 are all of model ZDLP.

[0079] The ultrasonic level gauge 19 is used to measure the liquid level of the storage tank 14 and converts the liquid level into a 4-20mA analog signal, which is then transmitted to the computer 5 for signal processing. The ultrasonic level gauge 19 is model SUX-L300N, with a measurement range of 0-20m and a measurement accuracy of 1mm. The first data acquisition card 20 and the second data acquisition card 21 are used to transmit the current signals output by the gas flow meter 17 and the ultrasonic level gauge 19 to the computer 5 for data communication. The first data acquisition card 20 is model TD-4071. The second programmable logic controller 13 controls the opening and closing of the first electric valve 15, the second electric valve 9, and the third electric valve 11 through logic operations. The second programmable logic controller 13 is model FX3U-128MT / ES-A. The gas flow meter 17 is used to measure the amount of gas flowing through the gas outlet pipe 16. The gas flow meter 17 is model LWQ-DN50, powered by a 24V DC voltage source 18, and outputs a 4-20mA current signal.

[0080] The tank 24 is a cylindrical barrel structure used for short-term storage of oil pipe inlet liquid and preliminary separation of natural gas in the oil pipe inlet liquid. It is made of stainless steel, with a bottom radius of 800mm and a height of 2000mm. The top surface has a level gauge socket, a gas outlet, and a liquid inlet, and the bottom surface has a liquid outlet. To reduce crude oil adhesion to the wall, the inner surface of the tank 24 is coated with an oleophobic coating, the coating type being TM2000. Based on the skin effect, the first heating tube 23 and the second heating tube 26 form an insulating structure, making the outer surfaces of the tank 24, the first heating tube 23, and the second heating tube 26 non-electrically charged. The first heating tube 23 and the second heating tube 26 are made of stainless steel, with a tube length of 800mm and a tube diameter of 40mm. The electric heating cable 27 has a wire specification of 7×0.5mm2, a maximum withstand temperature of 135℃, a minimum ambient temperature of -55℃, and an insulating sheath material of flame-retardant polyolefin. The insulation layer 28 is used to prevent heat dissipation from the first heating tube 23 and the second heating tube 26, and the material is nitrile rubber.

[0081] Furthermore, such as Figure 4 As shown, the moisture content detection system 4 includes a detection tube 41, a receiving antenna 42, a filter 32, a low-noise amplifier 33, an amplitude and phase detection module 34, a detector 35, an A / D converter 36, a microwave signal generator 37, a radio frequency isolator 38, a power attenuator 39, and a transmitting antenna 40.

[0082] The detection tube 41 is connected to the outlet tube 12 of the liquid production metering system 3. The receiving antenna 42 and the transmitting antenna 40 are respectively located on both sides of the detection tube 41. The output end of the receiving antenna 42 is connected to the filter 32 and then to the input end of the low noise amplifier 33. The output end of the low noise amplifier 33 is connected to the input end of the amplitude and phase detection module 34.

[0083] The output of the microwave signal generator 37 is connected to the input of the power attenuator 39 via the radio frequency isolator 38. The output of the power attenuator 39 is connected to the output of the transmitting antenna 40. The output of the power attenuator 39 is also connected to the input of the amplitude and phase detection module 34. The output of the amplitude and phase detection module 34 is connected to the A / D converter 36 via the detector 35.

[0084] In the above implementation scheme, the microwave signal generator 37 is model HK-SG12000, which can generate microwaves with a center frequency of 10GHz for moisture content detection; the radio frequency isolator 38 is used to ensure unidirectional microwave transmission. After passing through the radio frequency isolator 38, the forward microwave attenuation is very small and the reverse microwave attenuation is very large. The radio frequency isolator 38 is model UIYBD1716A, with a standing wave ratio of 1.3 and an isolation of 36dB.

[0085] The power attenuator 39, model RAXXA5, controls the attenuation of the microwave signal to achieve the desired level. The filter 32, model LFCN-3800+, filters the 10GHz frequency component in the transmitted wave received by the receiving antenna 42. The low-noise amplifier 33, model SPF5043, amplifies the filtered microwave signal. The amplitude and phase detection module 34, model AD8302, compares the incident wave signal emitted by the transmitting antenna 40 with the transmitted wave signal output by the low-noise amplifier 33 to obtain amplitude and phase difference signals. The detector 35, model AD831, is used for this purpose. 7. The bandwidth is 1M-10GHz, used to convert high-frequency signals into DC signals; the A / D converter 36 converts the analog signal output by the detector 35 into a digital signal that can be recognized by the programmable logic controller. The model is ADS1256, and the resolution bit is 24 bits; the transmitting antenna 40 and the receiving antenna 42 are used to transmit microwaves and receive transmitted waves, respectively. Both the transmitting antenna 40 and the receiving antenna 42 adopt rectangular waveguide horn antennas with a horn diameter of 69mm in length and 53mm in width, and a microwave gain of 15dB; the detection tube 41 is made of glass with an inner diameter of 64mm and an outer diameter of 76.2mm, and is sealed to the liquid outlet tube 12 by a rubber ring.

[0086] It should be noted that the limitations on the various equipment models in the above implementation schemes are preferred options and not the only standard. Other models with corresponding functions can be selected for this embodiment.

[0087] Example 2

[0088] The automatic oil and gas well production metering device described in Example 1 is used to measure the production volume of liquid, gas, and water cut. Daily oil production is obtained from the production volume and water cut. Based on the measured production data, the reservoir connectivity evaluation score for each oil and gas well in the block is obtained through an oil and gas well production correlation evaluation model. The optimal injection-production well conversion scheme is then determined, including:

[0089] Step 1: Input initial parameters, including the initial and upper limit values ​​of the well number m of the oil and gas well, the initial and upper limit values ​​of the metering days F, the metering interval t1, the upper limit value of the metering time t2, the number of daily meters a, and the liquid level rise H;

[0090] In this embodiment, the initial value of well number m of the oil and gas well to be measured is 1, the upper limit value is 8, and m is an integer from 1 to 8; the initial value of the number of measurement days F is 1, the upper limit value is 48, and F is an integer from 1 to 48; the measurement interval time t1 is 4h, the number of daily measurements a is 3 times / day, the upper limit value of the measurement time t2 is 2h, and the liquid level rise H is 1000mm.

[0091] Step 2: Electric valve group 2 starts working, opening the electric valve controlling oil and gas well m and closing the electric valves controlling other oil and gas wells;

[0092] Step 3: Obtain the production data and water cut data of the m-th oil and gas well through the oil and gas well production measurement system 3 and the water cut detection system 4, respectively;

[0093] Step 3.1: The first programmable logic controller 6 is initialized and timing begins;

[0094] Step 3.2: Start the liquid production metering system 3, initialize the second programmable logic controller 13 and start timing, and the ultrasonic level gauge 19 measures the initial value of the liquid level in the storage tank 14;

[0095] Step 3.3: The first electric valve 15 is opened and the second electric valve 9 is closed;

[0096] Step 3.4: The liquid from the m-th oil and gas well flows into the storage tank 14 through the first electric valve 15, while the natural gas in the liquid is discharged through the gas outlet pipe 16, and the gas flow meter 17 measures the amount of gas discharged.

[0097] Step 3.5: The ultrasonic level gauge 19 detects the liquid level in the storage tank 14; if the liquid level can rise to the specified value of 1000mm within the upper limit of the measurement time t2, i.e., 2 hours, the second programmable logic controller 13 stops timing and resets when the liquid level reaches the specified value; if the timing time reaches t2, i.e., 2 hours and the liquid level has not risen to the specified value of 1000mm, the second programmable logic controller 13 stops timing and measures the liquid level at this time;

[0098] Step 3.6: The first electric valve 15 is closed, the second electric valve 9 and the third electric valve 11 are opened, the liquid in the storage tank 14 is discharged through the outlet pipe 12, the moisture content detection system 4 starts working, the microwave signal generator 37 is started, and the moisture content of the liquid in the detection tube 41 is detected in real time. When the liquid level in the storage tank 14 drops to the initial value, the third electric valve 11 is closed, and the moisture content detection system 4 stops working.

[0099] Step 3.7: Keep the liquid flowing into the outlet pipe 12 through the second electric valve 9. The second programmable logic controller 13 starts timing until the metering interval time t1, i.e., 4h, is reached. Then the second programmable logic controller 13 stops timing and resets.

[0100] Step 3.8: Determine whether the daily measurement count 'a' of the liquid production has been reached. If not, increment the measurement count by 1 and repeat steps 3.2 to 3.7 until the daily measurement count 'a' is reached. Then, the liquid production measurement system 3 stops working.

[0101] Step 4: Calculate oil and gas well production;

[0102] Step 4.1: Take the average moisture content within the detection period as the result of each moisture content measurement:

[0103]

[0104] in, w ap , w bp They represent the number of days. p The maximum and minimum moisture content within the time period of the test. w p This represents the moisture content measured at the p-th time each day;

[0105] Step 4.2: Take the average of the three moisture content measurements taken within one day (a times) as the daily moisture content:

[0106]

[0107] in, w Daily moisture content w 1~ w 3 represents the moisture content measured for the first to third times each day;

[0108] Step 4.3: Determine the daily liquid production:

[0109]

[0110] Where Q1 is the daily liquid production volume, in liters (L). T 1~ T3 represents the liquid production measurement time output by the second programmable logic controller 13 for each measurement, in seconds. r The radius of the bottom surface of storage tank 14 is in mm. h 1~ h 3 represents the liquid level rise during each measurement, in mm; in this embodiment, r= 800mm. If the liquid level can reach 1000mm within 2 hours, the liquid level rise shall be taken as 1000mm. If it cannot reach 1000mm within 2 hours, the liquid level rise measured by the ultrasonic level gauge 19 shall be taken.

[0111] Step 4.4: Determine daily oil production:

[0112]

[0113] in, Q 1 represents the daily liquid production, in liters (L). Y Daily oil production, in liters (L).

[0114] Step 4.5: Determine the daily gas production:

[0115]

[0116] Where Q2 represents the daily gas production volume, in liters (L). T 1~ T 3 represents the liquid production measurement time output by the second programmable logic controller for each measurement, in seconds. q 1~ q 3 represents the gas production output of gas flow meter 17 during each measurement period, in L;

[0117] Step 5: Determine whether F has reached the upper limit of 48 days of metering. If not, when the metering time of the first programmable logic controller 6 reaches 24 hours, increment the metering days F by 1, and repeat steps 3 to 4 until the upper limit of 48 days of metering is reached.

[0118] Step 6: Determine whether m has reached the upper limit of well number 8 for oil and gas wells. If not, increment well number m by 1 and repeat steps 2 to 5 until the upper limit of well number 8 is reached.

[0119] Step 7: Establish an evaluation model for the correlation between oil and gas well production. By analyzing the variation patterns of fluid production and gas production of different oil and gas wells, determine the reservoir connectivity evaluation score of each oil and gas well in the block.

[0120] Step 7.1: Select well number i as the reference well, and set the initial value of i to 1; since the upper limit of well number is 8 in this embodiment, i is an integer from 1 to 8;

[0121] Step 7.2: Select well j as the calculation well, and the initial value of j is i+1; in this embodiment, j is an integer from 1 to 8;

[0122] Step 7.3: Establish reference sequence X based on the product yield data. i And calculate sequence X j A reference sequence Y is established based on gas production data. i And calculate sequence Y j :

[0123]

[0124]

[0125] Where, x i (1) x i (2), ... represent the production volume of oil and gas well i on the first day, the production volume on the second day, ..., x j (1) x j (2) ... represent the production volume of well j on the first day, the production volume on the second day, ... respectively; y i (1) y i (2), ... represent the gas production of well i on the first day, the gas production on the second day, ..., respectively. j (1) y j (2) ... represent the gas production of well j on the first day, the gas production of well j on the second day, ... respectively. In this embodiment, n is 48.

[0126] Step 7.4: Calculate sequence X i and X j displacement difference d ij1 Speed ​​difference d ij2 Acceleration difference d ij3 Calculate the reference sequence Y i And calculate sequence Y j displacement difference dd ij1 Speed ​​difference dd ij2 Acceleration difference dd ij3 :

[0127]

[0128]

[0129]

[0130]

[0131]

[0132] ;

[0133] Step 7.5: Calculate sequence X i and X j correlation coefficient γ ij Calculate sequence Y i and Y j correlation coefficient β ij :

[0134]

[0135] ;

[0136] Step 7.6: Determine whether the upper limit value of the calculated well number has been reached. If not, increment the well number j by 1 and repeat steps 7.3 to 7.5. If it has been reached, stop the loop. In this embodiment, the upper limit value of the calculated well number is 8.

[0137] Step 7.7: Determine whether the upper limit of the reference hash number has been reached. If not, increment the reference hash number i by 1 and repeat steps 7.2 to 7.6. If it has been reached, stop the loop. In this embodiment, the upper limit of the reference hash number is 8.

[0138] Step 7.8: Construct relevance matrices A and B, where element A in matrix A is... ij The correlation coefficient γ between oil and gas well number i and oil and gas well number j ij A ij =A ji The element B in matrix B ij The correlation coefficient between oil and gas well number i and oil and gas well number j β ij B ij =B ji The row numbers of the matrix represent the well numbers of the oil and gas wells; in this embodiment, both A and B are 8×48 matrices.

[0139]

[0140] ;

[0141] Step 7.9: Determine the evaluation score of oil and water connectivity in the reservoir based on the correlation coefficient of production volume of each oil and gas well;

[0142] Step 7.9.1: Calculate the expected value and variance of the correlation coefficient of production from each oil and gas well within the block:

[0143]

[0144]

[0145] Where n is the number of days being measured, E i Let E be the mathematical expectation of the correlation coefficient of the production volume of the i-th oil and gas well. i The larger the value of D, the greater the correlation between the production of oil and gas well i and the production of other oil and gas wells in the block. i D represents the variance of the correlation coefficient of product volume. i A smaller value indicates a more stable correlation between the production of well i and other wells in the block. In this embodiment, n is 48.

[0146] Step 7.9.2: Use the expected value and variance of the correlation coefficient of production of each oil and gas well as evaluation indicators. Determine the weight of the expected value and variance according to the needs of the scheme design, and evaluate according to a total score of 100 points; in this embodiment, the weights of the expected value and variance are set to 70% and 30%, respectively.

[0147] The scoring method for oil and gas well oil-water reservoir connectivity is as follows:

[0148]

[0149] Among them, P i The score for the connectivity between the oil and water layers in the i-th oil and gas well.

[0150] Step 7.10: Determine the reservoir connectivity evaluation score based on the correlation coefficient of gas production of each oil and gas well;

[0151] Step 7.10.1: Calculate the expected value and variance of the correlation coefficient of gas production of each oil and gas well within the block:

[0152]

[0153]

[0154] Where n is the number of days measured, EE i Let EE be the mathematical expectation of the correlation coefficient of gas production of oil and gas well i. i The larger the value, the greater the correlation between the gas production of well i and other wells in the block. i DD represents the variance of the correlation coefficient for gas production. i A smaller value indicates a more stable correlation between the gas production of well i and other wells in the block. In this embodiment, n is 48.

[0155] Step 7.10.2: Use the expected value and variance of the correlation coefficient of gas production of each oil and gas well as the evaluation index. Determine the weight of the expected value and variance according to the needs of the scheme design, and evaluate according to a total score of 100 points; in this embodiment, the weights of the expected value and variance are set to 70% and 30%, respectively.

[0156] The scoring method for oil and gas well reservoir connectivity is as follows:

[0157]

[0158] Among them, PP i The gas reservoir connectivity score for the i-th oil and gas well;

[0159] Step 7.11: Evaluate the oil-water layer connectivity score P. i and air layer connectivity evaluation score PP i Determine reservoir connectivity score M i ;P i and PP i The weights are determined based on the thickness ratios of oil, water, and gas layers within the reservoir. In this embodiment, P i The weight is 60%, PP i The proportion is 40%.

[0160]

[0161] Based on the oil and gas well production correlation evaluation model established in the above implementation plan, reservoir connectivity is analyzed to provide data support for the formulation of oilfield well network injection-production conversion schemes and gas storage and production development schemes.

[0162] Obviously, the above embodiments are merely illustrative examples for clear explanation and are not intended to limit the implementation. Those skilled in the art will recognize that other variations or modifications can be made based on the above description. It is neither necessary nor possible to exhaustively list all possible implementations here. However, obvious variations or modifications derived therefrom are still within the scope of protection of this invention.

Claims

1. An automatic metering device for oil and gas well production, characterized in that, The system includes an oil pipe (1), an electric valve assembly (2), a liquid production metering system (3), a water content detection system (4), a computer (5), a first programmable logic controller (6), and a 220V AC voltage source (7). One end of the oil pipe (1) is connected to the input end of the electric valve assembly (2), and the output end of the electric valve assembly (2) is connected to the input end of the computer (5) via the liquid production metering system (3). The output end of the computer (5) is connected to the input end of the electric valve assembly (2) via the first programmable logic controller (6), and the output end of the computer (5) is also connected to the input end of the liquid production metering system (3). The water content detection system (4) is connected to the liquid production metering system (3) and the computer (5) respectively. The output end of the 220V AC voltage source (7) is connected to the power supply end of the first programmable logic controller (6) and the liquid production metering system (3) respectively. The liquid production metering system (3) includes an inlet pipe (8), a second electric valve (9), an auxiliary outlet pipe (10), a third electric valve (11), an outlet pipe (12), a second programmable logic controller (13), a storage tank (14), a first electric valve (15), an outlet pipe (16), a gas flow meter (17), a 24V DC voltage source (18), an ultrasonic level gauge (19), a first data acquisition card (20), and a second data acquisition card (21). One end of the inlet pipe (8) is connected to the storage tank (14) via the first electric valve (15). The storage tank (14) is connected to one end of the auxiliary outlet pipe (10). The other end of the auxiliary outlet pipe (10) is connected to the outlet pipe (12) via the third electric valve (11). One end of the inlet pipe (8) is also connected to the outlet pipe (12) via the second electric valve (9). The input terminal of the second programmable logic controller (13) is connected to the output terminal of the computer (5). The output terminal of the second programmable logic controller (13) is connected to the input terminal of the first electric valve (15), the input terminal of the second electric valve (9), and the input terminal of the third electric valve (11). The power supply terminal of the second programmable logic controller (13) is connected to a 220V AC voltage source (7). One end of the storage tank (14) is connected to the gas outlet pipe (16), and the other end of the gas outlet pipe (16) is connected to the input end of the gas flow meter (17). The output end of the gas flow meter (17) is connected to the input end of the first data acquisition card (20), and the output end of the first data acquisition card (20) is connected to the input end of the computer (5). The input end of the ultrasonic level gauge (19) is connected to the storage tank (14), and the output end of the ultrasonic level gauge (19) is connected to the input end of the second data acquisition card (21). The output end of the second data acquisition card (21) is connected to the input end of the computer (5). The high-voltage terminal of the 24V DC voltage source (18) is connected to the high-voltage terminal of the gas flow meter (17) and the high-voltage terminal of the ultrasonic level gauge (19), respectively, and the ground terminal of the 24V DC voltage source (18) is grounded. The moisture content detection system (4) includes a detection tube (41), a receiving antenna (42), a filter (32), a low noise amplifier (33), an amplitude and phase detection module (34), a detector (35), an A / D converter (36), a microwave signal generator (37), a radio frequency isolator (38), a power attenuator (39), and a transmitting antenna (40). The detection tube (41) is connected to the outlet tube (12) of the liquid production metering system (3). The receiving antenna (42) and the transmitting antenna (40) are respectively located on both sides of the detection tube (41). The output end of the receiving antenna (42) is connected to the filter (32) and then connected to the input end of the low noise amplifier (33). The output end of the low noise amplifier (33) is connected to the input end of the amplitude and phase detection module (34). The output of the microwave signal generator (37) is connected to the input of the power attenuator (39) via the radio frequency isolator (38). The output of the power attenuator (39) is connected to the output of the transmitting antenna (40). The output of the power attenuator (39) is also connected to the input of the amplitude and phase detection module (34). The output of the amplitude and phase detection module (34) is connected to the A / D converter (36) via the detector (35).

2. The automatic metering device for oil and gas well production according to claim 1, characterized in that, The liquid storage tank (14) includes a first heating tube (23), a tank body (24), a second heating tube (26), an electric heating tape (27), and an insulation layer (28). The first heating tube (23) and the second heating tube (26) are welded to both sides of the tank body (24), and electric heating tape (27) is inserted into the first heating tube (23) and the second heating tube (26). The power supply end of the electric heating tape (27) is connected to a 220V AC voltage source (7). The tank body (24), the first heating tube (23), and the second heating tube (26) are all inserted into the insulation layer (28). The top surface of the tank body (24) is provided with a liquid level gauge socket (29), an air outlet (30), and a liquid inlet (31). The bottom surface is provided with a liquid outlet (25). The liquid inlet (31) is connected to one end of the liquid inlet pipe (8), the air outlet (30) is connected to one end of the air outlet pipe (16), the liquid level gauge socket (29) is connected to the input end of the ultrasonic liquid level gauge (19), and the liquid outlet (25) is connected to one end of the auxiliary liquid outlet pipe (10).

3. An automatic measurement method for oil and gas well production, using the apparatus described in any one of claims 1-2, characterized in that, include: Step 1: Input initial parameters, including the initial and upper limit values ​​of the well number m of the oil and gas well, the initial and upper limit values ​​of the metering days F, the metering interval t1, the upper limit value of the metering time t2, the number of daily meters a, and the liquid level rise H; Step 2: The electric valve group (2) starts working, opening the electric valve controlling the m-th oil and gas well and closing the electric valves controlling other oil and gas wells; Step 3: Obtain the production data and water cut data of the m-th oil and gas well through the oil and gas well production measurement system (3) and the water cut detection system (4); Step 4: Calculate oil and gas well production; Step 5: Determine whether F has reached the upper limit of the metering days. If not, when the metering time of the first programmable logic controller (6) reaches 24 hours, the metering days F is incremented by 1. Repeat steps 3 to 4 until the upper limit of the metering days is reached. Step 6: Determine if m has reached the upper limit of the well number for oil and gas wells. If not, increment the well number m by 1 and repeat steps 2 to 5 until the upper limit of the well number is reached.

4. The automatic measurement method for oil and gas well production according to claim 3, characterized in that, Step 3 includes: Step 3.1: The first programmable logic controller (6) is initialized and starts timing; Step 3.2: Start the liquid production metering system (3), the second programmable logic controller (13) initializes and starts timing, and the ultrasonic level gauge (19) measures the initial value of the liquid level in the storage tank (14); Step 3.3: The first electric valve (15) is opened and the second electric valve (9) is closed; Step 3.4: The liquid from the m-th oil and gas well flows into the storage tank (14) through the first electric valve (15), while the natural gas in the liquid is discharged through the gas outlet pipe (16), and the gas flow meter (17) measures the amount of gas discharged. Step 3.5: The ultrasonic level gauge (19) detects the liquid level in the storage tank (14); if the liquid level rise H can reach the specified value within the upper limit of the measurement time t2, the second programmable logic controller (13) stops timing and resets when the liquid level rise H reaches the specified value; if the liquid level rise H still has not reached the specified value when the timing time reaches t2, the second programmable logic controller (13) stops timing and measures the liquid level at this time; Step 3.6: The first electric valve (15) is closed, the second electric valve (9) and the third electric valve (11) are opened, the liquid in the storage tank (14) is discharged through the outlet pipe (12), the water content detection system (4) starts working, the microwave signal generator (37) is started, and the water content of the liquid in the detection tube (41) is detected in real time. When the liquid level in the storage tank (14) drops to the initial value, the third electric valve (11) is closed, and the water content detection system (4) stops working. Step 3.7: Keep the liquid flowing into the outlet pipe (12) through the second electric valve (9), and the second programmable logic controller (13) starts timing until the metering interval time t1 is reached. Then the second programmable logic controller (13) stops timing and resets. Step 3.8: Determine whether the daily measurement frequency a of the liquid production has been reached. If not, increase the measurement frequency by 1 and repeat steps 3.2 to 3.7 until the daily measurement frequency a is reached. Then the liquid production measurement system (3) stops working.

5. The automatic measurement method for oil and gas well production according to claim 3, characterized in that, Step 4 includes: Step 4.1: Take the average moisture content within the detection period as the result of each moisture content measurement; Step 4.2: Take the average value of the moisture content measurements taken a times within a day as the daily moisture content; Step 4.3: Determine the daily liquid production volume; Step 4.4: Determine daily oil production; Step 4.5: Determine the daily gas production.

6. The automatic measurement method for oil and gas well production according to claim 3, characterized in that, Also includes: Step 7: Establish an evaluation model for the correlation between oil and gas well production. By analyzing the variation patterns of fluid production and gas production in different oil and gas wells, determine the reservoir connectivity evaluation score for each oil and gas well.

7. The automatic measurement method for oil and gas well production according to claim 6, characterized in that, Step 7 includes: Step 7.1: Select well number i as the reference well, and set the initial value of i to 1; Step 7.2: Select well j as the calculation well, and the initial value of j is i+1; Step 7.3: Establish reference sequence X based on the product yield data. i And calculate sequence X j A reference sequence Y is established based on gas production data. i And calculate sequence Y j : Step 7.4: Calculate sequence X i and X j displacement difference d ij1 Speed ​​difference d ij2 Acceleration difference d ij3 Calculate the reference sequence Y i And calculate sequence Y j displacement difference dd ij1 Speed ​​difference dd ij2 Acceleration difference dd ij3 : Step 7.5: Calculate sequence X i and X j correlation coefficient γ ij Calculate sequence Y i and Y j correlation coefficient β ij : Step 7.6: Determine if the upper limit of the calculated well number has been reached. If not, increment the well number j by 1 and repeat steps 7.3 to 7.

5. If the upper limit has been reached, stop the loop. Step 7.7: Determine if the upper limit of the reference hash number has been reached. If not, increment the reference hash number i by 1 and repeat steps 7.2 to 7.

6. If the upper limit has been reached, stop the loop. Step 7.8: Construct relevance matrices A and B, where element A in matrix A is... ij The correlation coefficient γ between oil and gas well number i and oil and gas well number j ij A ij =A ji The element B in matrix B ij The correlation coefficient between oil and gas well number i and oil and gas well number j β ij B ij =B ji The row numbers of the matrix are the well numbers of the oil and gas wells; Step 7.9: Determine the evaluation score of oil and water connectivity in the reservoir based on the correlation coefficient of production volume of each oil and gas well; Step 7.10: Determine the reservoir connectivity evaluation score based on the correlation coefficient of gas production of each oil and gas well; Step 7.11: Determine the reservoir connectivity evaluation score based on the oil and water layer connectivity evaluation scores and the gas layer connectivity evaluation scores.

8. The automatic measurement method for oil and gas well production according to claim 6, characterized in that, Step 7.9 includes: Step 7.9.1: Calculate the expected value and variance of the correlation coefficient of production from each oil and gas well within the block: Step 7.9.2: Use the expected value and variance of the correlation coefficient of production of each oil and gas well as the evaluation index. Determine the weight of the expected value and variance according to the needs of the scheme design, and evaluate according to a total score of 100 points.

9. The automatic measurement method for oil and gas well production according to claim 6, characterized in that, Step 7.10 includes: Step 7.10.1: Calculate the expected value and variance of the correlation coefficient of gas production of each oil and gas well within the block: Step 7.10.2: Use the expected value and variance of the correlation coefficient of gas production of each oil and gas well as the evaluation index. Determine the weight of the expected value and variance according to the needs of the scheme design, and evaluate them with a total score of 100 points.

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