Well new well daily oil production prediction method, device, equipment and storage medium

Abstract

The application discloses a new well production prediction method, device, equipment and storage medium. The method comprises the following steps: obtaining a daily oil production chart of unit thickness under different comprehensive water contents and different production pressure differences, wherein the daily oil production chart is obtained according to oil-water relative permeability test data of a developed reservoir; determining a comprehensive water content of a new well; determining a production pressure difference of the new well; and determining daily oil production of the new well based on the daily oil production chart according to the comprehensive water content and the production pressure difference.

Description

Technical Field

[0001] This application relates to the field of oil and gas extraction, and in particular to a method, apparatus, equipment and storage medium for predicting the daily oil production of a new well. Background Technology

[0002] After years of development, the remaining oil in an oil reservoir becomes dispersed, leading to a decline in reservoir production. To ensure the efficient development of the reservoir, it is necessary to design new wells to tap its potential based on the study of the remaining oil. The feasibility of designing new well locations and the accurate prediction of new well production are crucial.

[0003] Currently, the most reliable method for predicting new well designs is reservoir numerical simulation. However, the long time frame and high cost of conducting reservoir numerical simulations have limited its application in the field. Summary of the Invention

[0004] This application provides a method, apparatus, equipment, and storage medium for predicting the number of new wells. It can determine the design production rate of new wells in developed reservoirs without requiring reservoir numerical simulation studies, providing scientific decision-making support for on-site new well implementation and significantly shortening the implementation cycle. The technical solution is as follows:

[0005] According to one aspect of this application, a method for predicting the daily oil production of a new well is provided, the method comprising:

[0006] Obtain daily oil production charts per unit thickness under different comprehensive water cuts and different production pressure differentials. The daily oil production charts are obtained based on oil-water phase permeability test data of exploited oil reservoirs.

[0007] Determine the overall water cut of the new well; and determine the production pressure differential of the new well;

[0008] Based on the combined water cut and the production pressure difference, the daily oil production of the new well is determined according to the daily oil production chart.

[0009] In an optional design of this application, determining the daily oil production of the new well based on the combined water cut and the production pressure differential, using the daily oil production chart, includes:

[0010] In the daily oil production chart, the daily oil production per unit thickness corresponding to the comprehensive water content and the production pressure difference is read;

[0011] The daily oil production of the new well is calculated based on the daily oil production per unit thickness.

[0012] In an optional design of this application, determining the overall water cut of the new well includes:

[0013] Obtain the curve showing the relationship between water cut and recovery rate;

[0014] Determine the recovery level of the control well area corresponding to the new well;

[0015] In the water cut-production-production curve, the overall water cut of the design well area of ​​the new well is read based on the production level.

[0016] In an optional design of this application, determining the recovery level of the control area corresponding to the new well includes:

[0017] Calculate the geological reserves of the control well area corresponding to the new well;

[0018] Calculate the cumulative oil production belonging to the controlled well area;

[0019] The recovery rate of the controlled well area is calculated based on the geological reserves and the cumulative oil production.

[0020] In an optional design of this application, determining the production pressure differential of the new well includes:

[0021] Obtain the reservoir static pressure and bottom hole flow pressure of the new well.

[0022] The production pressure differential of the new well is determined based on the reservoir static pressure and the bottom flow pressure of the well.

[0023] In an optional design of this application, obtaining the daily oil production map per unit thickness under different combined water cuts and different production pressure differentials includes:

[0024] Based on the oil-water interpenetration test data, the daily liquid production per unit thickness was obtained under different comprehensive water content and different production pressure differentials;

[0025] Based on the daily liquid production per unit thickness under different overall water content and different production pressure differentials, the daily oil production per unit thickness under different overall water content and different production pressure differentials is calculated to obtain the chart.

[0026] In an optional design of this application, obtaining the daily liquid production per unit thickness under different water contents and different production pressure differentials based on oil-water interpenetration test data includes:

[0027] Based on the oil-water interpenetration test data, obtain the comprehensive water content corresponding to different water saturation levels;

[0028] Based on the oil-water phase permeation test data, the dimensionless liquid recovery index corresponding to different water saturation was obtained;

[0029] Calculate the Mi-Production Fluid Index when the water cut of the reservoir is zero;

[0030] Based on the dimensionless fluid production index and the fluid production index when the reservoir water cut is zero, calculate the fluid production index corresponding to different comprehensive water cuts.

[0031] Given different pressure differentials, based on the liquid production index corresponding to the different comprehensive water content, the daily liquid production per unit thickness under different comprehensive water content and different production pressure differentials is obtained.

[0032] According to one aspect of this application, a daily oil production prediction device for a new well is provided, the device comprising:

[0033] The acquisition module is used to acquire daily oil production charts per unit thickness under different comprehensive water cuts and different production pressure differentials. The daily oil production charts are obtained based on oil-water phase permeability test data of exploited oil reservoirs.

[0034] The first determining module is used to determine the overall water cut of the new well;

[0035] The second determining module is used to determine the production pressure differential of the new well;

[0036] The prediction module is used to determine the daily oil production of the new well based on the comprehensive water cut and the production pressure difference, using the daily oil production chart.

[0037] According to another aspect of this application, a computer device is provided, the computer device comprising: a processor and a memory, the memory storing a computer program, the computer program being loaded and executed by the processor to implement the method for predicting new well production as described above.

[0038] According to another aspect of this application, a computer-readable storage medium is provided that stores a computer program, which is loaded and executed by a processor to implement the method for predicting new well production as described above.

[0039] According to another aspect of this application, a computer program product is provided, the computer program product storing a computer program that is loaded and executed by the processor to implement the new well production prediction method as described above.

[0040] The beneficial effects of the technical solutions provided in this application include at least the following:

[0041] By using oil-water permeability test data from already exploited reservoirs, a daily oil production chart is pre-made. During the prediction phase, based on the comprehensive water cut and production pressure differential of the new well, the daily oil production of the new well is determined according to the pre-drawn daily oil production chart. This allows for rapid and accurate prediction of the designed production of the new well even without reservoir numerical simulation results, providing a scientific basis for decision-making regarding whether the designed well location can be implemented on-site. Attached Figure Description

[0042] To more clearly illustrate the technical solutions in the embodiments of this application, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0043] Figure 1 A flowchart illustrating a new well production prediction method provided by another exemplary embodiment of this application is shown;

[0044] Figure 2 A flowchart illustrating a new well production prediction method provided by another exemplary embodiment of this application is shown;

[0045] Figure 3 This application provides a schematic diagram of the relationship between water cut and recovery rate in a developed oil reservoir, as shown in another exemplary embodiment.

[0046] Figure 4 This illustration shows a schematic diagram of a daily oil production prediction chart under different water content and different pressure differentials provided in another exemplary embodiment of this application;

[0047] Figure 5 A block diagram of a new well production prediction apparatus provided in an exemplary embodiment of this application is shown;

[0048] Figure 6 A block diagram of a computer device provided in an exemplary embodiment of this application is shown. Detailed Implementation

[0049] To make the objectives, technical solutions, and advantages of this application clearer, the embodiments of this application will be described in further detail below with reference to the accompanying drawings.

[0050] Figure 1 A flowchart illustrating a method for predicting the daily oil production of a new well according to an exemplary embodiment of this application is shown. The method includes:

[0051] Step 102: Obtain daily oil production charts per unit thickness under different comprehensive water cuts and different production pressure differentials. The daily oil production charts are obtained based on oil-water phase permeability test data of exploited oil reservoirs.

[0052] Step 104: Determine the overall water cut of the new well;

[0053] Step 106: Determine the production pressure differential of the new well;

[0054] Step 108: Determine the daily oil production of the new well based on the comprehensive water cut and production pressure difference, using the daily oil production chart.

[0055] In summary, the method provided in this embodiment pre-creates a daily oil production chart based on oil-water intermittent test data of already exploited oil reservoirs. During the prediction phase, the daily oil production of the new well is determined based on the comprehensive water cut and production pressure differential of the new well, using the pre-drawn daily oil production chart. This method can quickly and accurately predict the production of the designed new well even without reservoir numerical simulation results, providing a scientific basis for decision-making regarding whether the designed well location can be implemented on-site.

[0056] Figure 2 A flowchart illustrating a method for predicting the daily oil production of a new well, provided in another exemplary embodiment of this application, is shown. The method includes:

[0057] Step 201: Based on the oil-water phase permeability test data of the exploited oil reservoir, obtain the daily liquid production per unit thickness under different comprehensive water cuts and different production pressure differentials;

[0058] 1) Based on the oil-water phase permeability test data of the exploited oil reservoirs, obtain the comprehensive water cut corresponding to different water saturation levels;

[0059] The relative permeability of the oil phase (k) in the oil-water phase permeability test data of the exploited oil reservoir ro ) and relative permeability of water phase (k rw Based on Formula 1, the comprehensive water content (f) corresponding to different water saturation levels is calculated. w The results are shown in Table 1.

[0060]

[0061] In Formula 1:

[0062] fw — represents the overall water content corresponding to different water saturation levels, in %;

[0063] μ w —Water viscosity, in mPa·s;

[0064] μ o —Oil viscosity, in mPa·s;

[0065] k ro —Relative permeability of the oil phase;

[0066] k rw —Relative permeability of the aqueous phase;

[0067] Where μ w μ o k was obtained from actual measurements of the sample. ro k rw This data was obtained from oil-water interpenetration test data.

[0068] Table 1. Oil-water phase permeation test data of developed reservoirs.

[0069] <![CDATA[S W ]]> <![CDATA[k ro ]]> <![CDATA[k rw ]]> <![CDATA[μ W ]]> <![CDATA[μ o ]]> fw <![CDATA[R L ]]> <![CDATA[J DL ]]> 0.4299 1 0 0.1748 3.08 0.00 0.00 1.00 0.4537 0.7173 0.0006 0.1748 3.08 0.48 4.17 0.72 0.4774 0.5068 0.002 0.1748 3.08 2.21 8.33 0.52 0.5012 0.3523 0.005 0.1748 3.08 7.51 12.51 0.38 0.5249 0.2404 0.0106 0.1748 3.08 20.15 16.66 0.30 0.5487 0.1604 0.0199 0.1748 3.08 41.52 20.84 0.27 0.5724 0.1041 0.0334 0.1748 3.08 64.74 25.00 0.30 0.5962 0.0649 0.0514 0.1748 3.08 81.92 29.17 0.36 0.6199 0.0383 0.0739 0.1748 3.08 91.70 33.33 0.46 0.6437 0.0207 0.1005 0.1748 3.08 96.53 37.50 0.60 0.6674 0.01 0.1306 0.1748 3.08 98.68 41.66 0.76 0.6912 0.0042 0.1635 0.1748 3.08 99.55 45.83 0.94 0.7149 0.002 0.1984 0.1748 3.08 99.82 49.99 1.14 0.7387 0.0019 0.2345 0.1748 3.08 99.86 54.17 1.34 0.7624 0.0021 0.2713 0.1748 3.08 99.86 58.32 1.55 0.7862 0 0.3032 0.1748 3.08 100.00 62.50 1.74

[0070] 2) Based on the oil-water phase permeability test data of the exploited oil reservoirs, obtain the dimensionless fluid recovery index corresponding to different water saturation levels;

[0071] Using the relative permeability of the oil phase (kro) and the relative permeability of the water phase (krw) from the oil-water phase permeability test data of the developed reservoir, the dimensionless liquid production index (JDL) corresponding to different water saturation was calculated according to Formula 2. The results are shown in Table 1.

[0072] The formula for calculating the dimensionless liquid collection index is as follows:

[0073]

[0074] In Formula 2:

[0075] J DL - Dimensionless liquid extraction index at different water cuts;

[0076] k ro —Relative permeability of the oil phase;

[0077] k rw —Relative permeability of the aqueous phase;

[0078] μ w —Water viscosity, mPa·s;

[0079] μ o —Oil viscosity, mPa·s;

[0080] 3) Calculate the Mi-Production Fluid Index when the reservoir water cut is zero;

[0081] Calculate the daily fluid production (WQ) of a single well in an already exploited oil reservoir when the water cut is zero in the early stages of development. L The perforation thickness (H) and production pressure differential (WΔP) are used to calculate the single-well fluid production index (WJ) for each oil well according to Formula 3. L ).

[0082]

[0083] 4) Based on the dimensionless fluid production index and the fluid production index when the reservoir water cut is zero, calculate the fluid production index corresponding to different comprehensive water cuts. The calculation results are shown in Table 2.

[0084]

[0085] In the formula:

[0086] WJ L - Fluid production index per meter when the water cut of the oil well is zero, t / (d·MPa.m);

[0087] WQL - Daily fluid production of the oil well when the water cut is zero in the initial stage of production, t / d;

[0088] H – Thickness of the oil well perforation, in meters;

[0089] WΔP – Production pressure difference when the water cut of the oil well is zero in the initial stage of production, MPa;

[0090] WJ L1 WJ L2 ...WJ Ln - The fluid production index of oil wells W1, W2...Wn when the water cut is zero, where n represents the number of oil wells with zero water cut at the beginning of production;

[0091] (J L fw = 0 - the water production index per meter when the water cut of the oil well in the reservoir is zero, t / (d·MPa.m).

[0092] 5) Given different pressure differentials, based on the rice extraction liquid index corresponding to different comprehensive water content, obtain the daily liquid production per unit thickness under different comprehensive water content and different production pressure differentials.

[0093]

[0094] In the formula:

[0095] J L - Rice extract index at different water contents, t / (d·MPa.m);

[0096] J DL - Dimensionless liquid extraction index at different water cuts;

[0097] (J L fw = 0 - the water content index when the water content is zero, t / (d·MPa.m).

[0098] Table 2. Rice-collecting liquid index corresponding to different comprehensive water content.

[0099] fw <![CDATA[(J L )fw=0]]> <![CDATA[J DL ]]> <![CDATA[J L ]]> 0 0.122 1.00 0.122 0.49 0.122 0.72 0.088 2.16 0.122 0.52 0.063 7.48 0.122 0.38 0.046 20.22 0.122 0.30 0.037 41.49 0.122 0.27 0.033 64.72 0.122 0.30 0.036 81.92 0.122 0.36 0.044 91.7 0.122 0.46 0.056 96.52 0.122 0.60 0.073 98.68 0.122 0.76 0.092 99.55 0.122 0.94 0.115 99.83 0.122 1.14 0.139 99.86 0.122 1.34 0.164 99.87 0.122 1.55 0.190 100 0.122 1.74 0.212

[0100] Step 202: Based on the daily liquid production per unit thickness under different comprehensive water content and different production pressure differentials, calculate the daily oil production per unit thickness under different comprehensive water content and different production pressure differentials.

[0101] Q L =J L ×ΔP............(Formula 6)

[0102] In the formula:

[0103] Q L - Daily fluid production per unit thickness at different water cuts in oil wells, t / m;

[0104] J L - Rice extract index at different water contents, t / (d·MPa.m);

[0105] ΔP – Oil well production pressure differential, MPa.

[0106] The calculation results are shown in Table 3:

[0107] Table 3 Daily liquid production per unit thickness under different comprehensive water content and production pressure differentials

[0108]

[0109] Note: L n This represents the daily liquid production rate per unit thickness of oil reservoir under different combined water cuts and n production pressure differentials.

[0110] Then, the daily oil production per unit thickness is calculated under different overall water cuts and different production pressure differentials. The daily oil production Q per unit thickness under different overall water cuts (fw) and different production pressure differentials (ΔP) is calculated using Formula 7. O The calculation results are shown in Table 4.

[0111] Q O =Q L ×(1-0.01×f w )............(Formula 7)

[0112] In the formula:

[0113] Q O - Daily oil production per unit thickness of wells under different production pressure differentials and water-cut conditions, t / m;

[0114] Q L - Daily fluid production per unit thickness of oil well, t / m;

[0115] f w - Water content in oil wells, %.

[0116] Table 4 Daily oil yield per unit thickness at different water contents

[0117] <![CDATA[f w ]]> P1 P2 P3 P4 P5 P6 P7 P8 P9 P10 P11 P12 P13 P14 P15 0 0.12 0.24 0.37 0.49 0.61 0.73 0.85 0.98 1.10 1.22 1.34 1.46 1.59 1.71 1.83 0.49 0.09 0.17 0.26 0.35 0.44 0.52 0.61 0.70 0.79 0.87 0.96 1.05 1.14 1.22 1.31 2.16 0.06 0.12 0.19 0.25 0.31 0.37 0.43 0.49 0.56 0.62 0.68 0.74 0.80 0.87 0.93 7.48 0.04 0.09 0.13 0.17 0.21 0.26 0.30 0.34 0.39 0.43 0.47 0.52 0.56 0.60 0.64 20.22 0.03 0.06 0.09 0.12 0.15 0.18 0.21 0.23 0.26 0.29 0.32 0.35 0.38 0.41 0.44 41.49 0.02 0.04 0.06 0.08 0.10 0.12 0.14 0.16 0.18 0.20 0.22 0.23 0.25 0.27 0.29 64.72 0.01 0.03 0.04 0.05 0.06 0.08 0.09 0.10 0.11 0.13 0.14 0.15 0.17 0.18 0.19 81.92 0.01 0.02 0.02 0.03 0.04 0.05 0.06 0.06 0.07 0.08 0.09 0.10 0.10 0.11 0.12

[0118] Note: P n This represents the daily oil production per unit thickness of oil layer under n production pressure differentials at different water cuts.

[0119] Based on different water content f w And the corresponding daily oil production Q per unit thickness under different pressure differences ΔP O Create charts showing daily oil production per unit thickness under different production pressure differentials and water content, such as... Figure 4 As shown.

[0120] Step 203: Obtain the curve showing the relationship between water cut and recovery rate;

[0121] Based on the relative permeability of the oil phase (kro), relative permeability of the water phase (krw), water saturation (sw), bound water water saturation (swi), and the experimentally measured water (μw) and oil viscosity (μo), the water cut (fw) and recovery degree (RL) corresponding to different water saturations (sw) are calculated using Formulas 1 and 8, as shown in Table 1. A curve showing the relationship between reservoir water cut and recovery degree is then constructed. Figure 3 As shown.

[0122]

[0123] In the formula:

[0124] R L - Recovery rate at different water saturation levels, %;

[0125] s w - Water saturation, decimal;

[0126] s wi - Water saturation of bound water, decimal;

[0127] Where s w s wi It was obtained from an oil-water interpenetration test.

[0128] Step 204: Determine the recovery level of the control well area corresponding to the new well;

[0129] Definition of control well area: The area enclosed by lines connecting oil and water wells within one well distance of the designed new well as the center.

[0130] 1) Calculate the geological reserves (N) of the control well area corresponding to the new well;

[0131] The oil-bearing area (A) in the control well area is measured, the oil layer thickness (H) and single reservoir coefficient (qoi) in the control well area are statistically analyzed, and the geological reserves (N) of the control well area are calculated according to Formula 9.

[0132] N = q oi ×A×H............(Formula 9)

[0133] In the formula:

[0134] N – Crude oil geological reserves, 10 4 t;

[0135] q oi - Cumulative production, 10 4 t;

[0136] A – Oil-bearing area, 10 4km 2 ;

[0137] H – Oil layer thickness, in meters (m).

[0138] 2) Calculate the cumulative oil production attributable to the controlled well area;

[0139] ① Calculate the cumulative oil production of each old oil well within one well distance from the design well.

[0140] ② The production of each old oil well is divided to obtain the cumulative oil production of each old oil well belonging to the new well control area. Old oil wells are those that have been produced.

[0141] A. When there are water injection wells around old oil wells, the cumulative oil production is attributed to the controlled wells based on their distribution.

[0142] The splitting coefficient of the well area is 0.2-0.4;

[0143] B. When there are no water injection wells around the oil well, the splitting coefficient belonging to the controlled well area is 0.5;

[0144] ③ Summarize the cumulative oil production of each old oil well within the new well control area to obtain the cumulative oil production N of the new well control area. p .

[0145] 3) Calculate the recovery rate of the controlled well area based on geological reserves and cumulative oil production;

[0146] The production rate (R) of the controlled well area of ​​the new well is obtained by formula 10;

[0147]

[0148] In the formula:

[0149] R – Recovery rate, %;

[0150] N – Crude oil geological reserves, 10 4 t;

[0151] N p - Cumulative production, 10 4 t;

[0152] Water content of the reservoir (f) w The relationship curve between recovery rate (R%) and recovery degree (R%) Figure 3 ), read the comprehensive water content (f) of the new well design well area. w ).

[0153] Step 205: Based on the production rate, read the overall water cut of the design well area of ​​the new well from the water cut-production rate curve;

[0154] Step 206: Obtain the reservoir static pressure and bottom hole flow pressure of the new well;

[0155] The static pressure P of the reservoir in the well area is determined by pressure measurement data of old wells in the already exploited reservoir of the designed new well area. 静 And the bottom flow pressure of the oil well, WBHP.

[0156] Step 207: Determine the production pressure differential of the new well based on the reservoir static pressure and the bottom-hole flowing pressure of the well.

[0157] Calculate the design production pressure difference of the new well: ΔP = P 静 -WBHP.

[0158] Step 208: In the daily oil production chart, read the daily oil production per unit thickness corresponding to the comprehensive water content and production pressure difference;

[0159] Chart of daily oil production per unit thickness under different production pressure differentials and water content ( Figure 4 ), read the water content (f) corresponding to the designed new well w Daily oil production per unit thickness under production pressure differential (ΔP) and production pressure differential (ΔP) (Q) O ).exist Figure 4 In the graph, the horizontal axis represents the total water content, and the vertical axis represents the production pressure difference.

[0160] Step 209: Calculate the daily oil production of the new well based on the daily oil production per unit thickness.

[0161] The daily oil production of the new well is calculated using Formula 11.

[0162] Q T =Q O ×H............(Formula 11)

[0163] In the formula:

[0164] Q T - Daily oil production from the well, in tons;

[0165] Q O - Daily oil production per unit thickness of oil well, t / m;

[0166] H – Perforation thickness in oil wells, in meters (m).

[0167] Figure 5 A block diagram of a new well production prediction apparatus provided in an exemplary embodiment of this application is shown. The apparatus includes:

[0168] The acquisition module 320 is used to acquire a daily oil production chart per unit thickness under different comprehensive water cuts and different production pressure differentials. The daily oil production chart is obtained based on the oil-water phase permeability test data of the exploited oil reservoir.

[0169] The first determining module 340 is used to determine the overall water content of the new well;

[0170] The second determining module 360 ​​is used to determine the production pressure differential of the new well;

[0171] The prediction module 380 is used to determine the daily oil production of the new well based on the comprehensive water cut and the production pressure difference, and on the daily oil production chart.

[0172] In one possible design of this embodiment, the prediction module 380 is used to read the daily oil production per unit thickness corresponding to the comprehensive water cut and the production pressure difference from the daily oil production chart; and calculate the daily oil production of the new well based on the daily oil production per unit thickness.

[0173] In one possible design of this embodiment, the first determining module 340 is used to obtain the water cut-production degree relationship curve; determine the production degree of the control well area corresponding to the new well; and read the comprehensive water cut of the design well area of ​​the new well based on the production degree from the water cut-production degree relationship curve.

[0174] In one possible design of this embodiment, the first determining module 340 is used to calculate the geological reserves of the control well area corresponding to the new well; calculate the cumulative oil production belonging to the control well area; and calculate the recovery degree of the control well area based on the geological reserves and the cumulative oil production.

[0175] In one possible design of this embodiment, the second determining module 360 ​​is used to obtain the reservoir static pressure and the bottom flow pressure of the well in the well area of ​​the new well; and to determine the production pressure difference of the new well based on the reservoir static pressure and the bottom flow pressure of the well in the well area.

[0176] In one possible design of this embodiment, the acquisition module 320 is used to acquire the daily liquid production per unit thickness under different comprehensive water content and different production pressure differentials based on the oil-water interpenetration test data; and to calculate the daily oil production per unit thickness under different comprehensive water content and different production pressure differentials based on the daily liquid production per unit thickness under different comprehensive water content and different production pressure differentials.

[0177] In one possible design of this embodiment, the acquisition module 320 is used to acquire the comprehensive water cut corresponding to different water saturations based on the oil-water interpenetration test data; acquire the dimensionless production index corresponding to different water saturations based on the oil-water interpenetration test data; calculate the meter production index when the reservoir water cut is zero; calculate the meter production index corresponding to different comprehensive water cuts based on the dimensionless production index and the meter production index when the reservoir water cut is zero; and, given different pressure differentials, acquire the daily production per unit thickness under different comprehensive water cuts and different production pressure differentials based on the meter production index corresponding to different comprehensive water cuts.

[0178] Figure 6 This illustration shows a structural block diagram of a computer device 400 provided in an exemplary embodiment of this application. The computer device 400 may be a smartphone, tablet computer, MP3 player (Moving Picture Experts Group Audio Layer III), MP4 player (Moving Picture Experts Group Audio Layer IV), laptop computer, or desktop computer. The computer device 400 may also be referred to as a user device, portable computer device, laptop computer device, desktop computer device, or other names.

[0179] Typically, computer device 400 includes a processor 401 and a memory 402.

[0180] Processor 401 may include one or more processing cores, such as a quad-core processor, an octa-core processor, etc. Processor 401 may be implemented using at least one hardware form selected from DSP (Digital Signal Processing), FPGA (Field-Programmable Gate Array), and PLA (Programmable Logic Array). Processor 401 may also include a main processor and a coprocessor. The main processor, also known as a CPU (Central Processing Unit), is used to process data in the wake-up state; the coprocessor is a low-power processor used to process data in the standby state. In some embodiments, processor 401 may integrate a GPU (Graphics Processing Unit), which is responsible for rendering and drawing the content to be displayed on the screen. In some embodiments, processor 401 may also include an AI (Artificial Intelligence) processor, which is used to handle computational operations related to machine learning.

[0181] Memory 402 may include one or more computer-readable storage media, which may be non-transitory. Memory 402 may also include high-speed random access memory and non-volatile memory, such as one or more disk storage devices or flash memory devices. In some embodiments, the non-transitory computer-readable storage media in memory 402 is used to store at least one instruction, which is executed by processor 401 to implement the new well production prediction method provided in the method embodiments of this application.

[0182] In some embodiments, the computer device 400 may also optionally include a peripheral device interface 403 and at least one peripheral device. The processor 401, memory 402, and peripheral device interface 403 can be connected via a bus or signal line. Each peripheral device can be connected to the peripheral device interface 403 via a bus, signal line, or circuit board. Specifically, the peripheral device includes at least one of the following: a radio frequency circuit 404, a touch display screen 405, a camera 406, an audio circuit 407, a positioning component 408, and a power supply 409.

[0183] Peripheral device interface 403 can be used to connect at least one I / O (Input / Output) related peripheral device to processor 401 and memory 402. In some embodiments, processor 401, memory 402 and peripheral device interface 403 are integrated on the same chip or circuit board; in some other embodiments, any one or two of processor 401, memory 402 and peripheral device interface 403 can be implemented on separate chips or circuit boards, which is not limited in this embodiment.

[0184] The radio frequency (RF) circuit 404 is used to receive and transmit RF (Radio Frequency) signals, also known as electromagnetic signals. The RF circuit 404 communicates with communication networks and other communication devices via electromagnetic signals. The RF circuit 404 converts electrical signals into electromagnetic signals for transmission, or converts received electromagnetic signals back into electrical signals. Optionally, the RF circuit 404 includes: an antenna system, an RF transceiver, one or more amplifiers, a tuner, an oscillator, a digital signal processor, a codec chipset, a user identity module card, etc. The RF circuit 404 can communicate with other computer devices through at least one wireless communication protocol. This wireless communication protocol includes, but is not limited to: the World Wide Web, metropolitan area networks, intranets, various generations of mobile communication networks (2G, 3G, 4G, and 5G), wireless local area networks, and / or Wi-Fi (Wireless Fidelity) networks. In some embodiments, the RF circuit 404 may also include circuitry related to NFC (Near Field Communication), which is not limited in this application.

[0185] Display screen 405 is used to display a UI (User Interface). This UI may include graphics, text, icons, videos, and any combination thereof. When display screen 405 is a touch display screen, it also has the ability to collect touch signals on or above its surface. These touch signals can be input as control signals to processor 401 for processing. In this case, display screen 405 can also be used to provide virtual buttons and / or a virtual keyboard, also known as soft buttons and / or a soft keyboard. In some embodiments, display screen 405 may be a single screen, positioned on the front panel of computer device 400; in other embodiments, display screen 405 may be at least two screens, respectively positioned on different surfaces of computer device 400 or in a folded design; in still other embodiments, display screen 405 may be a flexible display screen, positioned on a curved or folded surface of computer device 400. Furthermore, display screen 405 may be configured as a non-rectangular, irregular shape, i.e., a non-rectangular screen. Display screen 405 may be made of materials such as LCD (Liquid Crystal Display) or OLED (Organic Light-Emitting Diode).

[0186] The camera assembly 406 is used to acquire images or videos. Optionally, the camera assembly 406 includes a front-facing camera and a rear-facing camera. Typically, the front-facing camera is located on the front panel of the computer device, and the rear-facing camera is located on the back of the computer device. In some embodiments, there are at least two rear-facing cameras, which are any one of a main camera, a depth-sensing camera, a wide-angle camera, and a telephoto camera, to achieve background blurring by fusion of the main camera and the depth-sensing camera, panoramic shooting by fusion of the main camera and the wide-angle camera, VR (Virtual Reality) shooting, or other fusion shooting functions. In some embodiments, the camera assembly 406 may also include a flash. The flash can be a single-color temperature flash or a dual-color temperature flash. A dual-color temperature flash is a combination of a warm-light flash and a cool-light flash, which can be used for light compensation at different color temperatures.

[0187] The audio circuit 407 may include a microphone and a speaker. The microphone is used to collect sound waves from the user and the environment, converting the sound waves into electrical signals that are input to the processor 401 for processing, or input to the radio frequency circuit 404 for voice communication. For stereo sound acquisition or noise reduction purposes, multiple microphones may be used, each located in a different part of the computer device 400. The microphone may also be an array microphone or an omnidirectional microphone. The speaker is used to convert electrical signals from the processor 401 or the radio frequency circuit 404 into sound waves. The speaker may be a conventional diaphragm speaker or a piezoelectric ceramic speaker. When the speaker is a piezoelectric ceramic speaker, it can convert electrical signals not only into audible sound waves but also into inaudible sound waves for purposes such as distance measurement. In some embodiments, the audio circuit 407 may also include a headphone jack.

[0188] The positioning component 408 is used to locate the current geographical location of the computer device 400 in order to enable navigation or LBS (Location Based Service). The positioning component 408 can be a positioning component based on the US GPS (Global Positioning System), China's BeiDou system, or Russia's Galileo system.

[0189] Power supply 409 is used to supply power to the various components in computer device 400. Power supply 409 can be alternating current, direct current, a disposable battery, or a rechargeable battery. When power supply 409 includes a rechargeable battery, the rechargeable battery can be a wired rechargeable battery or a wireless rechargeable battery. A wired rechargeable battery is a battery that is charged via a wired line, while a wireless rechargeable battery is a battery that is charged via a wireless coil. The rechargeable battery can also be used to support fast charging technology.

[0190] In some embodiments, the computer device 400 further includes one or more sensors 410. The one or more sensors 410 include, but are not limited to: an accelerometer 411, a gyroscope 412, a pressure sensor 413, a fingerprint sensor 414, an optical sensor 415, and a proximity sensor 88.

[0191] Accelerometer 411 can detect the magnitude of acceleration along the three coordinate axes of a coordinate system established by computer device 400. For example, accelerometer 411 can be used to detect the components of gravitational acceleration along the three coordinate axes. Processor 401 can control touchscreen 405 to display the user interface in landscape or portrait view based on the gravitational acceleration signal acquired by accelerometer 411. Accelerometer 411 can also be used for games or for acquiring user motion data.

[0192] The gyroscope sensor 412 can detect the orientation and rotation angle of the computer device 400. The gyroscope sensor 412, in conjunction with the accelerometer sensor 411, can collect 3D motion data from the user on the computer device 400. Based on the data collected by the gyroscope sensor 412, the processor 401 can perform the following functions: motion sensing (e.g., changing the UI based on the user's tilt), image stabilization during shooting, game control, and inertial navigation.

[0193] The pressure sensor 413 can be disposed on the side bezel of the computer device 400 and / or on the lower layer of the touch display screen 405. When the pressure sensor 413 is disposed on the side bezel of the computer device 400, it can detect the user's grip signal on the computer device 400, and the processor 401 can perform left / right hand recognition or quick operation based on the grip signal collected by the pressure sensor 413. When the pressure sensor 413 is disposed on the lower layer of the touch display screen 405, the processor 401 can control the operable controls on the UI interface based on the user's pressure operation on the touch display screen 405. The operable controls include at least one of button controls, scroll bar controls, icon controls, and menu controls.

[0194] The fingerprint sensor 414 is used to collect a user's fingerprint. The processor 401 identifies the user based on the fingerprint collected by the fingerprint sensor 414, or vice versa. When the user's identity is identified as trusted, the processor 401 authorizes the user to perform relevant sensitive operations, including unlocking the screen, viewing encrypted information, downloading software, making payments, and changing settings. The fingerprint sensor 414 can be located on the front, back, or side of the computer device 400. When the computer device 400 has physical buttons or a manufacturer's logo, the fingerprint sensor 414 can be integrated with the physical buttons or the manufacturer's logo.

[0195] An optical sensor 415 is used to collect ambient light intensity. In one embodiment, the processor 401 can control the display brightness of the touch screen 405 based on the ambient light intensity collected by the optical sensor 415. Specifically, when the ambient light intensity is high, the display brightness of the touch screen 405 is increased; when the ambient light intensity is low, the display brightness of the touch screen 405 is decreased. In another embodiment, the processor 401 can also dynamically adjust the shooting parameters of the camera assembly 406 based on the ambient light intensity collected by the optical sensor 415.

[0196] A proximity sensor 416, also known as a distance sensor, is typically located on the front panel of a computer device 400. The proximity sensor 416 is used to detect the distance between the user and the front of the computer device 400. In one embodiment, when the proximity sensor 416 detects that the distance between the user and the front of the computer device 400 is gradually decreasing, the processor 401 controls the touchscreen display 405 to switch from a screen-on state to a screen-off state; when the proximity sensor 416 detects that the distance between the user and the front of the computer device 400 is gradually increasing, the processor 401 controls the touchscreen display 405 to switch from a screen-off state to a screen-on state.

[0197] Those skilled in the art will understand that Figure 4 The structure shown does not constitute a limitation on computer device 400, and may include more or fewer components than shown, or combine certain components, or use different component arrangements.

[0198] This application also provides a computer-readable storage medium storing at least one instruction, at least one program, code set, or instruction set, wherein the at least one instruction, the at least one program, the code set, or the instruction set is loaded and executed by the processor to implement the new well production prediction method provided in the above method embodiments.

[0199] Optionally, this application also provides a computer program product containing instructions that, when run on a computer device, cause the computer device to perform the new well production prediction method described in the above aspects.

[0200] The sequence numbers of the embodiments in this application are for descriptive purposes only and do not represent the superiority or inferiority of the embodiments.

[0201] Those skilled in the art will understand that all or part of the steps of the above embodiments can be implemented by hardware or by a program instructing related hardware. The program can be stored in a computer-readable storage medium, such as a read-only memory, a disk, or an optical disk.

[0202] The above description is merely an optional embodiment of this application and is not intended to limit this application. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this application should be included within the protection scope of this application.

Claims

1. A method of predicting the daily oil production of a new well, characterized in that, The method comprises: According to the oil-water relative permeability test data of the developed reservoir, the comprehensive water content corresponding to different water saturations is obtained, and the oil-water relative permeability test data includes oil phase relative permeability and water phase relative permeability; According to the oil-water relative permeability test data, the dimensionless liquid production index corresponding to different water saturations is obtained; The Mi liquid production index when the water content of the developed reservoir is zero is calculated; According to the dimensionless liquid production index and the Mi liquid production index when the water content of the developed reservoir is zero, the Mi liquid production index corresponding to different comprehensive water contents is calculated; Given different pressure differentials, based on the Mi liquid production index corresponding to different comprehensive water contents, the daily liquid production per unit thickness under different comprehensive water contents and different production pressure differentials is obtained; According to the daily liquid production per unit thickness under different comprehensive water contents and different production pressure differentials, a daily oil production per unit thickness under different comprehensive water contents and different production pressure differentials is calculated; The comprehensive water content of the new well is determined, and the production pressure differential of the new well is determined; According to the comprehensive water content of the new well and the production pressure differential of the new well, the daily oil production of the new well is determined based on the daily oil production per unit thickness under different comprehensive water contents and different production pressure differentials.

2. The method of claim 1, wherein, The daily oil production of the new well is determined based on the daily oil production per unit thickness under different comprehensive water contents and different production pressure differentials, which comprises: In the daily oil production per unit thickness under different comprehensive water contents and different production pressure differentials, the daily oil production per unit thickness corresponding to the comprehensive water content of the new well and the production pressure differential of the new well is read out; According to the daily oil production per unit thickness, the daily oil production of the new well is calculated.

3. The method of claim 1, wherein, The comprehensive water content of the new well is determined, which comprises: A water content and recovery degree relationship curve is obtained; The recovery degree of the control well area corresponding to the new well is determined; In the water content and recovery degree relationship curve, the comprehensive water content of the design well area of the new well is read out based on the recovery degree.

4. The method of claim 3, wherein, The recovery degree of the control well area corresponding to the new well is determined, which comprises: The geological reserves of the control well area corresponding to the new well are calculated; The cumulative oil production belonging to the control well area is calculated; According to the geological reserves and the cumulative oil production, the recovery degree of the control well area is calculated.

5. The method of claim 1, wherein, The production pressure differential of the new well is determined, which comprises: The well area reservoir static pressure and the oil well bottom hole flowing pressure of the new well are obtained; According to the well area reservoir static pressure and the oil well bottom hole flowing pressure, the production pressure differential of the new well is determined.

6. An apparatus for predicting the daily oil production of a new well, characterized by The device comprises: The acquisition module is configured to acquire comprehensive water cuts corresponding to different water saturations according to oil-water relative permeability test data of the exploited reservoir, the oil-water relative permeability test data including oil-phase relative permeability and water-phase relative permeability; acquire dimensionless liquid production indices corresponding to different water saturations according to the oil-water relative permeability test data; calculate a Miller liquid production index when water saturation of the exploited reservoir is zero; calculate Miller liquid production indices corresponding to different comprehensive water cuts according to the dimensionless liquid production indices and the Miller liquid production index when water saturation of the exploited reservoir is zero; acquire daily liquid production per unit thickness under different comprehensive water cuts and different production pressure differentials based on the Miller liquid production indices corresponding to the different comprehensive water cuts under different pressure differentials; and calculate a daily oil production per unit thickness map under different comprehensive water cuts and different production pressure differentials according to the daily liquid production per unit thickness under the different comprehensive water cuts and the different production pressure differentials. The first determination module is configured to determine a comprehensive water cut of a new well. The second determination module is configured to determine a production pressure differential of the new well. The prediction module is configured to determine daily oil production of the new well based on the daily oil production per unit thickness map according to the comprehensive water cut of the new well and the production pressure differential of the new well.

7. A computer device, comprising: The computer device comprises a processor and a memory, and the memory stores a computer program, which is loaded and executed by the processor to implement the new well daily oil production prediction method according to any one of claims 1 to 5.

8. A computer-readable storage medium, characterized in that, The computer readable storage medium stores a computer program, which is loaded and executed by the processor to implement the new well daily oil production prediction method according to any one of claims 1 to 5.

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