A star management method and system for deployment and implementation of gas field development well

Abstract

This invention relates to a star-rating management method and system for the deployment and implementation of gas field development wells, belonging to the field of gas field development technology. The invention first establishes an initial production estimation expression and dimensionless production curves for gas wells using dynamic production data from existing similar gas wells. Then, it uses these results to determine the production rate of newly deployed gas wells and, based on production and cost, determines the internal rate of return (IRR) for these wells. If the required IRR is not met, the deployment location and construction process of the new wells are re-optimized until the required IRR is achieved. Simultaneously, the star rating of the gas well's economic benefit is determined based on the IRR. Drilling is then carried out at the new well deployment location that meets the economic development requirements. After drilling, a more detailed fracturing design is conducted, and the IRR and star rating of the gas well are re-determined according to the new design. This invention effectively improves the targeting of single-well geological design and fracturing construction design, thereby improving development results and quality.

Description

Technical Field

[0001] This invention relates to a star-rating management method and system for the deployment and implementation of gas field development wells, belonging to the field of gas field development technology. Background Technology

[0002] Gas wells are the most fundamental management object for the efficient development of gas fields. The development benefits of a gas field are based on the development benefits of each gas well. Therefore, establishing the development concept that "every well is a source of benefits" helps to ensure the overall efficiency of gas field development. The "star-rating management" concept for the deployment and implementation of gas field development wells proposed in this invention has not been reported in similar literature, filling a gap in the field of refined gas well management. Summary of the Invention

[0003] The purpose of this invention is to provide a star-rating management method and system for the deployment and implementation of gas field development wells, so as to improve the development effect of gas field development wells.

[0004] To address the aforementioned technical problems, this invention provides a star-rating management method for the deployment and implementation of gas field development wells, comprising the following steps:

[0005] 1) Obtain dynamic production data of existing similar gas wells implemented in the previous period, normalize the dynamic production data to obtain dimensionless production curves, predict the dimensionless production curves, extend the production time of the dimensionless production curves to the end of the evaluation period, so as to obtain the dimensionless production curves within the evaluation period.

[0006] 2) Based on the production status and geological characteristics of existing similar gas wells implemented in the previous stage, establish the relationship between the initial production of gas wells and the key geological characteristic parameters of the gas reservoir and the key fracturing parameters, and use it as the expression for estimating the initial production of gas wells.

[0007] 3) Based on the drilling footage, fracturing design, and surface conditions of the gas well, calculate the development investment required to achieve normal production of the gas well, including drilling and production costs; the fracturing design includes the number of fracturing layers, the number of fracturing stages, the scale of sand addition, the amount of liquid used, the sand ratio, and the materials used in the well.

[0008] 4) Based on the key geological characteristic parameters and key fracturing design parameters of the newly deployed gas well, the initial production of the new gas well is estimated using the initial production estimation expression obtained in step 2). Then, combined with the dimensionless production curve obtained in step 1), the annual production of the new well during the evaluation period is predicted.

[0009] 5) Based on the new well input costs obtained in step 3), the new well production forecast during the evaluation period obtained in step 4), gas prices, and the development and operation cost data of similar gas wells, the internal rate of return of the new well is calculated using the cash flow method.

[0010] 6) If the internal rate of return of the newly deployed gas well does not meet the requirements for profitable development, optimize the deployment location, drilling and fracturing process of the newly deployed gas well, and repeat steps 3) to 5) until the internal rate of return of the newly deployed gas well meets the requirements for profitable development.

[0011] 7) After the internal rate of return meets the requirements for profitable development, drilling is carried out according to the corresponding deployment location. After the newly deployed gas well is completed, fracturing optimization design is carried out again based on the geological characteristic parameters obtained from actual drilling.

[0012] 8) Based on the redesigned fracturing system, repeat steps 3)-5) to redetermine the internal rate of return for the newly deployed gas wells.

[0013] The present invention also provides a star-rating management system for the deployment and implementation of gas field development wells. The system includes a processor and a memory, wherein the processor executes a computer program stored in the memory to implement the star-rating management method for the deployment and implementation of gas field development wells as described in the present invention.

[0014] This invention first establishes an initial production estimation expression and dimensionless production curves for gas wells using dynamic production data from existing similar gas wells. Then, it uses these results to determine the annual production of newly deployed gas wells during the evaluation period. Based on production and cost, and employing a cash flow method, it determines the internal rate of return (IRR) of the newly deployed gas wells. If the IRR does not meet the requirements, the deployment location and construction process of the new well are re-optimized until the IRR of the newly deployed gas well meets the requirements for profitable development. Simultaneously, the star level of the gas well's economic benefit is determined based on the level of the IRR. Drilling is carried out at the new well deployment location that meets the requirements for profitable development. After drilling, a more detailed fracturing design is conducted, and the star level of the gas well's IRR and development benefit is re-determined according to the new design. Through this process, this invention effectively improves the targeting of single-well geological design and fracturing construction design, thereby improving development results and ensuring development quality.

[0015] Furthermore, to achieve better construction results, the method also includes optimizing and adjusting the construction parameters such as fracturing displacement, sand ratio, sand addition scale, and liquid volume scale in a timely manner based on the actual on-site construction conditions during the fracturing implementation phase of newly deployed gas wells.

[0016] Furthermore, the method also includes redetermining the internal rate of return (IRR) of the newly deployed gas well based on the actual initial production of the newly deployed gas well after fracturing.

[0017] Furthermore, to achieve refined management, the method also includes classifying and evaluating the development benefits of gas wells according to their internal rate of return (IRR), dividing the IRR into several star levels from small to large, and determining the corresponding star level based on the IRR of the gas well.

[0018] Furthermore, to ensure the benefits of newly deployed gas wells, the benefit development requirement in step 6) refers to the lower limit of the internal rate of return that needs to be achieved for benefit development.

[0019] Furthermore, the starting point of the internal rate of return for two adjacent gas well benefit ratings differs by 2 percentage points.

[0020] Furthermore, in order to predict the gas well production during the evaluation period, step 1) uses the ARPS method to predict the dimensionless production curve.

[0021] Furthermore, to obtain the dimensionless production curve, the process of determining the dimensionless production curve in step 1) is as follows:

[0022] A. Obtain dynamic production data of gas wells of the same type as the newly deployed gas wells implemented in the early stage. Starting from the production date of each gas well, using the same time unit, give the output of the gas well at different time points according to the actual production situation, and use the shortest gas well production time among all gas wells as the target cutoff time for normalization.

[0023] B. The average production of each gas well at different time points is taken as the normalized gas well production at the corresponding time point.

[0024] C. Divide the normalized production of the gas well at different time points by the normalized initial production of the gas well to obtain the dimensionless production curve of the gas well with the initial production as the comparison object.

[0025] Furthermore, the expression for estimating the initial production of the gas well in step 2) is:

[0026]

[0027]

[0028]

[0029] Where 0.1728 is the dimension conversion coefficient, Q sc This represents the initial production estimate of the gas well, in meters (m³). 3 ; Nsec R represents the number of hydraulic fracture segments, dimensionless; di L represents the gas layer encounter rate at the i-th fracturing stage, dimensionless; fi H represents the length of the i-th pressure crack, in meters (m); fi The height of the i-th pressure crack is represented in meters (m); k i u represents the reservoir permeability at the i-th fracture, in mD; g P represents gas viscosity, with units of mPa·s; r P represents formation pressure, with units of MPa;wf G represents the bottom hole flowing pressure, in MPa; g This represents the gas seepage resistance gradient, with units of MPa / m; d fi is the distance between the i-th fracture and the fractures on both sides, in meters; represents the fracturing displacement at the i-th fracture, in meters. 3 / min; represents the amount of sand added at the i-th fracturing fracture, in meters. 3 b, c, d, n, t, and w are all fitting parameters. Attached Figure Description

[0030] Figure 1 This is a flowchart of the management method for the deployment and implementation of gas field development wells according to the present invention;

[0031] Figure 2 This is a dimensionless production curve established in the embodiments of the method of the present invention;

[0032] Figure 3 This is a graph showing the annual production change of a gas well during the evaluation period, as predicted in an embodiment of the method of the present invention. Detailed Implementation

[0033] The specific embodiments of the present invention will be further described below with reference to the accompanying drawings.

[0034] Method Implementation Examples

[0035] This invention first establishes an initial production estimation expression and a dimensionless production curve for gas wells based on dynamic production data from existing similar gas wells. Then, using these results, it determines the annual production of newly deployed gas wells during the evaluation period. Based on production and cost, and employing the cash flow method, it determines the internal rate of return (IRR) of the newly deployed gas wells. If the IRR does not meet the requirements, the deployment location and construction process of the new well are re-optimized until the IRR of the newly deployed gas well meets the requirements for profitable development. Simultaneously, the star level of the gas well's economic benefit is determined based on the level of the IRR. Drilling is carried out at the new well deployment location that meets the requirements for profitable development. After drilling, a more detailed fracturing design is conducted, and the star level of the gas well's IRR and development benefit is re-determined according to the new design. During the fracturing construction phase, construction parameters are optimized and adjusted in real time. Finally, based on the actual initial production after fracturing, the star level of the gas well's IRR and development benefit is evaluated again. The specific implementation process of this method is as follows: Figure 1 As shown, the specific implementation process is as follows.

[0036] 1. Obtain dimensionless production data from similar gas wells and make predictions to obtain dimensionless production curves that extend the production time to the end of the evaluation period.

[0037] Based on the dynamic production data of existing similar gas wells implemented in the previous period, this invention obtains a dimensionless production curve that reflects the stable production and declining characteristics of gas wells and takes the initial production as the comparison object through normalization processing. Based on the normalized dimensionless production data, the ARPS method is used to predict and obtain a dimensionless production curve that extends the production time to the end of the evaluation period.

[0038] When obtaining dimensionless production curves for existing gas wells of the same type, the production date of each gas well is taken as the starting point, and the same time unit is used (usually days or months). The production of the gas well at different time points is given according to the actual production situation. That is, the production of the gas well on the first day (or month) after production, the production on the second day (or month), the production on the third day (or month), and so on, up to the target deadline. The shortest production time of the gas well analyzed is used as the target deadline for normalization. The average production of each gas well at different time points is used as the normalized gas well production value at the corresponding time point. The normalized gas well production at different time points is divided by the normalized initial production of the gas well (usually the average daily production within the first 30 days after the gas well is put into production or the monthly production of the first month is used as the initial production of the gas well). This gives the dimensionless production curve of the existing gas well with the initial production as the comparison object.

[0039] 2. Establish an expression for estimating the initial production of gas wells.

[0040] Based on the production status and geological characteristics of existing similar gas wells, a quantitative relationship expression is established between the initial production of a gas well and key geological parameters of the gas reservoir, as well as key fracturing parameters. This expression is simply referred to as the initial production estimation expression for gas wells. The initial production estimation expression for gas wells determined by the fitting method in this invention is as follows:

[0041]

[0042]

[0043]

[0044] Where 0.1728 is the dimension conversion coefficient, Q sc This represents the initial production estimate of the gas well, in meters (m³). 3 ; Nsec R represents the number of hydraulic fracture segments, dimensionless; di L represents the gas layer encounter rate at the i-th fracturing stage, dimensionless; fi H represents the length of the i-th pressure crack, in meters (m); fi The height of the i-th pressure crack is represented in meters (m); k i u represents the reservoir permeability at the i-th fracture, in mD; gP represents gas viscosity, with units of mPa·s; r P represents formation pressure, with units of MPa; wf G represents the bottom hole flowing pressure, in MPa; g This represents the gas seepage resistance gradient, with units of MPa / m; d fi is the distance between the i-th fracture and the fractures on both sides, in meters; represents the fracturing displacement at the i-th fracture, in meters. 3 / min; represents the amount of sand added at the i-th fracturing fracture, in meters. 3 b, c, d, n, t, and w are all fitting parameters.

[0045] 3. Determine the drilling and production investment and operating costs for newly deployed gas wells.

[0046] This invention calculates the development costs required to achieve normal production of a gas well, including drilling and production costs, based on the drilling footage, fracturing design (including the number of fracturing layers, fracturing stages, sand addition scale, fluid usage, sand ratio, and well feed materials, etc.) and surface conditions of the newly deployed gas well. It also estimates the development costs by combining data such as the development and operation costs of similar gas wells.

[0047] 4. Predict the production of newly deployed gas wells.

[0048] Based on the key geological characteristic parameters and key fracturing design parameters of the newly deployed gas well, the initial production of the new gas well is estimated using the initial production estimation expression obtained in step 2. Then, combined with the dimensionless production curve obtained in step 1, the annual production of the newly deployed gas well during the evaluation period is predicted.

[0049] 5. Estimate the rate of return for newly deployed gas wells.

[0050] Based on the development and operation costs of the newly deployed gas wells obtained in step 3, the annual production of the newly deployed gas wells during the evaluation period obtained in step 4, and the gas price, the internal rate of return of the newly deployed gas wells is determined using the cash flow method.

[0051] Multiplying the annual output of each year during the evaluation period by the gas price yields the cash inflow for each year. Subtracting the annual cost from the cash inflow for each year gives the net cash flow for each year. Based on the net cash flow for each year during the evaluation period, the internal rate of return (IRR) can be calculated.

[0052] 6. Determine the star level of the development benefits of newly deployed gas wells based on the magnitude of the internal rate of return.

[0053] To achieve more refined management of gas wells, this invention will classify and evaluate the internal rate of return (IRR) into different levels based on the magnitude of the IRR. To more vividly illustrate the different levels, this embodiment adopts a star-level classification method, dividing development benefits into different star ratings. For example, the IRR is divided into five stars from lowest to highest, with one star corresponding to the lowest IRR and five stars corresponding to the highest IRR. The IRR of a three-star gas well must be greater than or equal to the industry-specified lower limit for IRR (generally 8%), the starting point for the IRR of a four-star gas well must be higher than that of a three-star gas well, and the starting point for the IRR of a five-star gas well must be higher than that of a four-star gas well. The specific values ​​can be determined according to the actual situation. It is generally recommended that the starting point for the IRR corresponding to the star rating of two adjacent gas wells differs by more than 2 percentage points (including 2 percentage points). This invention uses the above-mentioned star rating classification criteria to determine the star rating of newly deployed gas wells.

[0054] 7. Determine whether the newly deployed gas wells meet the requirements for profitable development. If they do not meet the requirements, then re-optimize the well location and engineering construction processes such as drilling and fracturing.

[0055] If the star rating of a newly deployed gas well does not meet expectations, the well location and drilling and fracturing processes must be optimized again. Steps 3 to 6 must be repeated iteratively until the gas well's profitability reaches the expected star rating. In this embodiment, gas wells that meet the profitability development requirements (internal rate of return greater than or equal to 8%) are defined as three-star gas wells.

[0056] 8. After the newly deployed gas wells are completed, further fracturing optimization will be carried out on the gas wells.

[0057] After the gas well is completed, in order to improve the pertinence of fracturing design, based on the geological characteristic parameters obtained from the actual drilling, the geological engineering integration is used to carry out fracturing optimization design with one plan for each layer and one plan for each section.

[0058] 9. The star level of the gas well after further fracturing optimization will be reassessed.

[0059] Based on the new fracturing optimization design in step 8, repeat steps 3 to 6 to re-analyze and determine the star level of the gas well's economic benefits.

[0060] 10. Adjust construction parameters in real time during the fracturing construction phase.

[0061] During the fracturing implementation phase in the mine, this invention optimizes and adjusts construction parameters such as fracturing displacement, sand ratio, sand addition scale, and liquid volume scale in a timely manner based on the actual on-site construction conditions, in order to achieve better implementation results.

[0062] 11. Based on the actual initial production after fracturing, the star level of the gas well is reassessed.

[0063] Based on the actual initial production after fracturing, the dimensionless production curve in step 1, and the actual drilling and production costs of the gas well, as well as the production and operating costs, repeat steps 5 and 6 to re-analyze and determine the star level of the gas well's economic benefits.

[0064] To demonstrate the feasibility of this invention, the method described above is applied to an actual gas field, and a horizontal development well from the Upper Paleozoic S2 gas reservoir in a certain gas field in 2021 is selected as an example of this invention. Taking this well as an example, the specific implementation process is as follows:

[0065] 1) Based on the dynamic production data of four similar gas wells (DPH-58, DPS-74, and DPH-124) in the adjacent S2 gas reservoir of this gas field, through normalization and Arps decline fitting, dimensionless production curves of existing similar gas wells with initial production as the comparison object were obtained, which can reflect the stable production and decline characteristics of gas wells (see...). Figure 2 (and dimensionless production data tables (see Table 1 and Table 2, Table 1 shows the monthly production and dimensionless monthly production data after normalization, and Table 2 shows the dimensionless monthly production data with production time predicted to the end of the evaluation period).

[0066] Table 1

[0067]

[0068]

[0069] Table 2

[0070]

[0071] 2) Based on the production status and geological characteristics of four similar gas wells (DPH-58, DPS-74, and DPH-124) implemented previously, the initial production estimation expression for the gas wells was obtained by fitting the following formula:

[0072]

[0073]

[0074]

[0075] Where Nsec: number of hydraulic fracture segments, dimensionless; R di : Gas layer encounter rate at each fracturing stage i, decimal; L fi : Length of the i-th pressure crack, in meters; H fi : Crack height, m; k i: Reservoir permeability at the i-th fracture, mD; u g Gas viscosity, mPa·s; P r Formation pressure, MPa; P wf Bottom hole flowing pressure, MPa; G g Gas flow resistance gradient, MPa / m, can be determined based on the reservoir permeability k at the i-th fracture. i Based on experimental data, the relationship between permeability and seepage resistance gradient is established as follows: d fi Q: The distance between the i-th crack and the cracks on both sides, in meters; pi : Fracturing displacement at the i-th fracture, m 3 / min;V si The amount of sand added at the i-th fracturing fracture, m 3 .

[0076] 3) Based on the drilling footage of the gas well, the fracturing design based on the geological characteristics of the gas layer at the well's location (including the number of fracturing layers, number of fracturing stages, scale of sand addition, fluid usage, sand ratio, and well feed materials), and the surface conditions, the estimated development cost, including drilling and production costs, to achieve normal production of the gas well is RMB 18 million.

[0077] 4) Based on key geological parameters such as the newly deployed gas well's horizontal section length of 1000m, the predicted average gas layer thickness of 6.5m, average sand thickness of 13m, and average permeability of 0.2mD, along with 7 fracturing stages and a fracturing flow rate of 4m³ / h, 3 / min, single seam sand addition scale 35m 3 Key fracturing design parameters, such as a fracture half-length of 183.73m and a fracture height of 9.52m, were used. The initial production estimate for the new gas well, obtained in step 2), was calculated to be 24,800 cubic meters per day (744,000 cubic meters per month). Then, combined with the dimensionless production curve obtained in step 1), the annual production variation curve of the gas well during the evaluation period was predicted (see...). Figure 3 (As shown).

[0078] 5) Based on the new well input cost obtained in step 3), the annual production forecast of the gas well during the evaluation period obtained in step 4), and combined with the gas price of RMB 1,119 / thousand cubic meters used in the scheme demonstration at that time and the natural gas operating cost of RMB 135 / thousand cubic meters for similar gas wells, the internal rate of return of the well was calculated to be -5.1%.

[0079] 6) The lower limit of the internal rate of return in the current natural gas development industry is generally 8%. Therefore, it is agreed that the internal rate of return of a three-star gas well should be greater than or equal to 8% and less than 10%; the internal rate of return of a four-star gas well should be greater than or equal to 10% and less than 12%; and the internal rate of return of a five-star gas well should be greater than or equal to 12%. According to the above well location star rating discrimination rule, this well is an unprofitable gas well and its star rating is lower than three stars.

[0080] 7) Since the star rating of the gas well's benefits did not meet expectations, the deployment location and fracturing construction process parameters were re-optimized. The horizontal section of the newly deployed gas well is about 1300m long, with an average gas layer thickness of 8m, an average sand thickness of 15m, and an average permeability of 0.11mD. The optimized fracturing section has 15 sections, a fracturing flow rate of 7.5m3 / min, a single fracture sand addition scale of 60m3, a fracture half length of 230.1m, and a fracture height of 16.97m. The total investment is about RMB 24.5 million. The initial production of the new gas well is estimated to be 47,800 cubic meters / day (1,434,000 cubic meters / month) using the initial production estimation expression obtained in step (2). After the above optimization work, steps (3) to (6) were repeated. The evaluation showed that the gas well's pre-tax internal rate of return was 15.4%, and its post-tax internal rate of return was 10.5%, making it a four-star gas well, which meets the requirements for profitable development.

[0081] 8) After the gas well is completed, in order to improve the pertinence of the fracturing design, based on the geological characteristic parameters obtained from the actual drilling, the geological engineering integration carries out the fracturing optimization design with one layer and one section. The specific fracturing design parameters are shown in Table 3. The total investment is about RMB 24.6 million. The initial production of the new gas well is estimated to be 48,000 cubic meters / day (1.44 million cubic meters / month) using the gas well initial production estimation expression obtained in step 2).

[0082] Table 3

[0083]

[0084] 9) Based on the new fracturing design in step 8), repeat steps 3) to 6), and evaluate that the pre-tax internal rate of return of the gas well is 15.7%, the post-tax internal rate of return is 10.7%, and the gas well star level is 4 stars.

[0085] 10) During the fracturing implementation phase at the mine, in order to ensure the implementation effect, the construction parameters such as fracturing displacement, sand ratio, and sand addition scale were optimized and adjusted in a timely manner based on the actual construction conditions on site. The comparison between the actual construction parameters and the design parameters is shown in Table 4.

[0086] Table 4

[0087]

[0088] 11) The actual initial production of the well after pressure control was 49,700 cubic meters / day (1,491,000 cubic meters / month). Based on the dimensionless production curve in step 1) and the actual input costs of drilling, pressure control and production of RMB 24.8 million, repeat steps 5) and 6) to re-analyze and determine that the pre-tax internal rate of return of the gas well is 17.7%, the after-tax internal rate of return is 12.0%, and the gas well star level is five stars.

[0089] The above examples demonstrate that adopting a star-rating management approach during gas well deployment and implementation helps to iteratively optimize and improve well location assessment and mine construction design, thereby ensuring the development benefits of gas wells.

[0090] System Implementation Examples

[0091] The star-rating management system for gas field development well deployment and implementation of the present invention includes a processor and a memory. The processor executes a computer program stored in the memory to implement the star-rating management method for gas field development well deployment and implementation described in the above-described method embodiments. In other words, the methods in the above embodiments should be understood as a flow of management methods for gas field development well deployment and implementation that can be implemented by computer program instructions. These computer program instructions can be provided to the processor, causing the processor to execute these instructions to produce the functions specified for implementing the above-described method flow.

[0092] In this embodiment, the processor refers to a processing device such as a microprocessor (MCU) or a programmable logic device (FPGA); the memory refers to a physical device used to store information, which typically involves digitizing the information and then storing it using media that utilizes electrical, magnetic, or optical methods. Examples include: various types of memory that store information using electrical energy, such as RAM and ROM; various types of memory that store information using magnetic energy, such as hard disks, floppy disks, magnetic tapes, magnetic core memory, bubble memory, and USB flash drives; and various types of memory that store information using optical methods, such as CDs or DVDs. Of course, there are other types of memory, such as quantum memories and graphene memories.

[0093] The device consisting of the aforementioned memory, processor, and computer program is implemented in a computer by the processor executing the corresponding program instructions. The processor can run various operating systems, such as Windows, Linux, Android, and iOS.

[0094] As an alternative implementation, the device may also include a display for showing diagnostic results for staff reference.

[0095] The above embodiments are preferred embodiments of the present invention, but the embodiments of the present invention are not limited to the above embodiments. Any other changes made without departing from the present invention should be considered as equivalent substitutions and are included within the protection scope of the present invention.

Claims

1. A star management method for deployment and implementation in relation to gas field development well, characterized by, Includes the following steps: 1) Obtain dynamic production data of existing similar gas wells implemented in the previous period, normalize the dynamic production data to obtain dimensionless production curves, predict the dimensionless production curves, extend the production time of the dimensionless production curves to the end of the evaluation period, so as to obtain the dimensionless production curves within the evaluation period. 2) Based on the production status and geological characteristics of existing similar gas wells implemented in the previous stage, establish the relationship between the initial production of gas wells and the key geological characteristic parameters of the gas reservoir and the key fracturing parameters, and use it as the expression for estimating the initial production of gas wells. 3) Based on the drilling footage, fracturing design, and surface conditions of the gas well, calculate the development investment required to achieve normal production of the gas well, including drilling and production costs; the fracturing design includes the number of fracturing layers, the number of fracturing stages, the scale of sand addition, the amount of liquid used, the sand ratio, and the materials used in the well. 4) Based on the key geological characteristic parameters and key fracturing design parameters of the newly deployed gas well, the initial production of the new gas well is estimated using the initial production estimation expression obtained in step 2). Then, combined with the dimensionless production curve obtained in step 1), the annual production of the new well during the evaluation period is predicted. 5) Based on the new well input costs obtained in step 3), the new well production forecast during the evaluation period obtained in step 4), gas prices, and the development and operation cost data of similar gas wells, the internal rate of return of the new well is calculated using the cash flow method. 6) If the internal rate of return of the newly deployed gas well does not meet the requirements for profitable development, optimize the deployment location, drilling and fracturing process of the newly deployed gas well, and repeat steps 3) to 5) until the internal rate of return of the newly deployed gas well meets the requirements for profitable development. 7) After the internal rate of return meets the requirements for profitable development, drilling is carried out according to the corresponding deployment location. After the newly deployed gas well is completed, fracturing optimization design is carried out again based on the geological characteristic parameters obtained from actual drilling. 8) Based on the redesigned fracturing system, repeat steps 3)-5) to redetermine the internal rate of return for the newly deployed gas wells; The expression for estimating the initial production of the gas well in step 2) is as follows: , , , Where 0.1728 is the dimension conversion coefficient. This represents the initial production estimate of the gas well, in units of... ; Indicates the number of hydraulic fracture segments; dimensionless. denoted as the gas layer encounter rate at the i-th fracturing stage, dimensionless; This represents the length of the i-th pressure crack, in meters. This represents the height of the i-th pressure crack, in meters. This represents the reservoir permeability at the i-th fracture, in mD; This indicates the viscosity of the gas, with units of mPa·s. This represents formation pressure, expressed in MPa. This indicates the bottom hole flowing pressure, expressed in MPa. This represents the gas seepage resistance gradient, with units of MPa / m; is the distance between the i-th crack and the cracks on both sides, in meters; This represents the fracturing displacement at the i-th fracture, in units of... ; This represents the amount of sand added at the i-th fracturing fracture, in units of... ; b, c, d, n, t, and w are all fitting parameters.

2. The star-rating management method for the deployment and implementation of gas field development wells according to claim 1, characterized in that, The method also includes optimizing and adjusting the fracturing discharge rate, sand ratio, sand addition scale, and liquid volume scale construction parameters in a timely manner based on the actual on-site construction conditions during the fracturing implementation phase of newly deployed gas wells.

3. The star management method for deployment and implementation in relation to gas field development well according to claim 1, characterized in that, The method also includes redetermining the internal rate of return (IRR) of newly deployed gas wells based on their actual initial production after fracturing.

4. The star management method for deployment and implementation of gas field development well according to any one of claims 1-3, characterized in that, The method also includes classifying and evaluating the development benefits of gas wells according to their internal rate of return (IRR), dividing the IRR into several star levels from small to large, and determining the corresponding star level based on the IRR of the gas well.

5. The star rating management method for deployment and implementation with respect to gas field development well of claim 1, wherein, The benefit development requirement in step 6) refers to the lower limit of the internal rate of return that benefit development needs to achieve.

6. The star rating management method for deployment and implementation with respect to gas field development well of claim 1, wherein, The starting point of the internal rate of return for two adjacent gas wells with different benefit ratings is 2 percentage points.

7. The star management method for deployment and implementation in relation to gas field development well of claim 1, wherein, Step 1) uses the ARPS method to predict the dimensionless production curve.

8. The star-rating management method for the deployment and implementation of gas field development wells according to claim 1, characterized in that, The process for determining the dimensionless production curve in step 1) is as follows: A. Obtain dynamic production data of gas wells of the same type as the newly deployed gas wells implemented in the early stage. Starting from the production date of each gas well, using the same time unit, give the output of the gas well at different time points according to the actual production situation, and use the shortest gas well production time among all gas wells as the target cutoff time for normalization. B. The average production of each gas well at different time points is taken as the normalized gas well production at the corresponding time point. C. Divide the normalized production of the gas well at different time points by the normalized initial production of the gas well to obtain the dimensionless production curve of the gas well with the initial production as the comparison object.

9. A star-rating management system for the deployment and implementation of gas field development wells, characterized in that, The system includes a processor and a memory, the processor executing a computer program stored in the memory to implement a star-rating management method for the deployment and implementation of gas field development wells as described in any one of claims 1-7.

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