Horizontal well water control mode and parameter optimization method and device suitable for offshore oil reservoir water injection development, medium and equipment

Abstract

The invention relates to a horizontal well water control mode and parameter optimization method, device, medium and equipment suitable for offshore oil reservoir water injection development, and the method comprises the following steps: obtaining a water control characteristic curve of each water control valve based on a fluid circulation test experiment, and fitting a pressure drop formula; through water-control-free reservoir numerical simulation, the daily production fluid profile and water content profile characteristics of a production well are obtained, and then a horizontal well water control packer section optimization scheme is determined; on the basis of a fitted pressure drop formula and a horizontal well water control sealing section optimization scheme, the pressure drops of the water control valve pieces are controlled to be at the same level, and the water control and oil increase effects of all the water control valve pieces are simulated; and according to the economic cost, the water control and oil increasing effects of all the water control valve pieces are compared, and the production well water control mode is determined. The method can improve the water control, well completion, oil increase and water control effects in actual production of the horizontal well.

Description

Technical Field

[0001] The present invention relates to the technical field of oilfield development, and in particular to a horizontal well water control mode and parameter optimization method, device, medium and equipment suitable for offshore oil reservoir water injection development. Background Art

[0002] During the development of horizontal wells in oil reservoirs, due to the influence of factors such as reservoir permeability heterogeneity, horizontal well heel effect, and natural fractures, the production profile is uneven, and the edge and bottom water coning phenomenon is prone to occur, resulting in reservoir flooding, reduced oil production, and affecting the development effect of the oil reservoir and the ultimate recovery rate.

[0003] In response to the above-mentioned problem of water control development in horizontal wells, a series of tools have been studied at home and abroad, including valve ICD, valve AICD and intelligent water control sleeves; and through appropriate non-uniform arrangement and other completion methods, the non-uniform profile of the horizontal well can be adjusted to improve the oil production and water control effect of the water control completion method of the horizontal well. However, the applicability range of valves and the optimization of arrangement and use have not been clear in the field.

[0004] If the appropriate water control method can be selected and the use scheme can be optimized according to the water invasion characteristics of horizontal wells during the scheme design stage, the horizontal well recovery rate can be effectively improved, and the oil increase effect of the water control completion method can be improved. Therefore, it is necessary to determine a horizontal well water control method and parameter optimization method suitable for offshore oil reservoir water injection development. Summary of the invention

[0005] In view of the above problems, the purpose of the present invention is to provide a horizontal well water control mode and parameter optimization method, device, medium and equipment suitable for offshore oil reservoir water injection development, which can improve the water control completion and oil increase and water control effect in the actual production of horizontal wells.

[0006] To achieve the above object, the present invention adopts the following technical solutions: The horizontal well water control mode and parameter optimization method applicable to offshore oil reservoir water injection development of the present invention comprises the following steps: Based on the fluid circulation test experiment, the water control characteristic curve of each water control valve is obtained, and the pressure drop formula is fitted; Through numerical simulation of non-water-controlled reservoirs, the daily liquid production profile and water content profile characteristics of the production wells are obtained, and then the optimization scheme of the water-controlled isolation section of the horizontal well is determined; Based on the fitted pressure drop formula and the optimization scheme of the water control isolation section of the horizontal well, the pressure drop of the water control valve components is controlled at the same level to simulate the water control and oil production increase effect of each water control valve component; Based on the economic cost, the water control and oil production increase effects of various water control valves are compared to determine the water control method for production wells.

[0007] The horizontal well water control mode and parameter optimization method, preferably, each of the water control valve components includes a nozzle-type ICD, a channel-type AICD and an intelligent sleeve: According to the water control characteristic curve, the nozzle ICD pressure drop and the channel AICD pressure drop are related to the viscosity. The pressure drop formula used is as follows:

[0008] In the formula, is the density of oil-water mixture; is the calibration density; is the viscosity of the oil-water mixture; To calibrate viscosity; is the valve flow rate; is the valve strength; is the flow index; is the viscosity index; According to the water control characteristic curve, the pressure drop of the intelligent sliding sleeve is related to the opening degree, and the pressure drop formula used is:

[0009] In the formula, is the sleeve flow rate, is the sleeve strength, is the sleeve opening.

[0010] The method for optimizing the water control mode and parameters of horizontal wells, preferably, the method obtains the daily liquid production profile and water content profile characteristics of the production well through numerical simulation of the oil reservoir without water control, and then determines the optimization scheme of the water control isolation section of the horizontal well, and the specific steps are: using the numerical simulation of the oil reservoir without water control to obtain the grid distribution characteristics of the daily liquid production and water content profile, converting the grid distribution characteristics of the daily liquid production and water content profile into uniform distribution characteristics of the daily liquid production and water content profile, and dividing the water control section based on the uniform distribution characteristics of the daily liquid production and water content profile along the length of the liquid production section in the waterless oil production period, the middle liquid extraction period, and the late liquid extraction period; Among them, the daily liquid production and water content profile distribution characteristics under the grid length are converted into the uniform distribution characteristics of the daily liquid production and water content profile under uniform length. The specific formula is as follows:

[0011]

[0012] In the formula, After the average length Liquid production per segment; For the The moisture content of each segment; is the length of the entire liquid production section; is the number of pre-segments; For the Rice daily oil production, For the water production per day; The 4th meter of daily water production.

[0013] The horizontal well water control mode and parameter optimization method, preferably, the pressure drop formula based on fitting and the optimization scheme of the horizontal well water control isolation section are used to control the pressure drop of the water control valve components at the same level, and simulate the water control and oil increase effect of each water control valve component. The specific steps are: The pressure drop of water control valves is controlled at the same level through the production pressure difference, and the water control valves are evenly arranged under the same segmentation conditions to ensure that the effects of each water control valve are compared by water control volume and oil increase volume under the same pressure drop, and the oil increase volume is used as an economic evaluation index to select water control valves with high economic benefits; The water control volume is defined as the difference between the cumulative water production without water control and the cumulative water production with water control under the same cumulative oil production conditions.

[0014] The present invention also provides a horizontal well water control and parameter optimization device suitable for offshore oil reservoir water injection development, comprising: The first processing unit is used to obtain the water control characteristic curve of each water control valve component based on the fluid circulation test experiment, and fit the pressure drop formula; The second processing unit is used to obtain the daily liquid production profile and water content profile characteristics of the production well through numerical simulation of the non-water-controlled oil reservoir, and then determine the optimization plan of the water-controlled isolation section of the horizontal well; The third processing unit is used to control the pressure drop of the water control valve components at the same level based on the fitted pressure drop formula and the optimization scheme of the water control isolation section of the horizontal well, and simulate the water control and oil increase effect of each water control valve component; The fourth processing unit is used to compare the water control and oil production increase effects of each water control valve component according to the economic cost, and determine the water control method of the production well.

[0015] The present invention also provides a computer storage medium on which a computer program is stored. When the computer program is executed by a processor, the horizontal well water control method and parameter optimization method steps suitable for offshore oil reservoir water injection development are implemented.

[0016] The present invention also provides a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, the horizontal well water control method and parameter optimization method steps applicable to offshore oil reservoir water injection development are implemented.

[0017] The present invention adopts the above technical solution, which has the following advantages: (1) Use the same production pressure difference to simulate the water control and oil increase effects of each water control valve component; (2) Use economic cost to analyze the water control and oil increase effects of each water control valve component, determine the water control method, improve the oil increase effect and economic benefits, and better meet the actual production needs. BRIEF DESCRIPTION OF THE DRAWINGS

[0018] Various other advantages and benefits will become apparent to those of ordinary skill in the art by reading the detailed description of the preferred embodiments below. The accompanying drawings are only for the purpose of illustrating the preferred embodiments and are not to be considered as limiting the present invention. Throughout the accompanying drawings, the same reference numerals are used to represent the same components. In the accompanying drawings: Figure 1 is a technical flow chart in an embodiment of the present invention; Figure 2 is the nozzle-type ICD water control characteristic curve in the embodiment of the present invention; Figure 3 is the water control characteristic curve of the channel type AICD in the embodiment of the present invention; Figure 4 is a water control characteristic curve of an intelligent sliding sleeve in an embodiment of the present invention; Figure 5 It is a grid distribution characteristic diagram of daily liquid production profile and water content profile along the A01H horizontal well in the embodiment of the present invention; Figure 6 It is a characteristic diagram of uniform distribution of daily liquid production profile and water content profile along the A01H horizontal well in the embodiment of the present invention; Figure 7 It is a grid distribution characteristic diagram of daily liquid production profile and water content profile along the B01H horizontal well in an embodiment of the present invention; Figure 8 It is a characteristic diagram of uniform distribution of daily liquid production profile and water content profile along the B01H horizontal well in an embodiment of the present invention; Fig. 9 It is a grid distribution characteristic diagram of daily liquid production profile and water content profile along the C01H horizontal well in an embodiment of the present invention; Fig.10 It is a characteristic diagram of uniform distribution of daily liquid production profile and water content profile along the C01H horizontal well in an embodiment of the present invention. DETAILED DESCRIPTION

[0019] The exemplary embodiments of the present invention will be described in more detail below with reference to the accompanying drawings. Although the exemplary embodiments of the present invention are shown in the accompanying drawings, it should be understood that the present invention can be implemented in various forms and should not be limited by the embodiments described herein. On the contrary, these embodiments are provided in order to enable a more thorough understanding of the present invention and to fully convey the scope of the present invention to those skilled in the art.

[0020] The present invention provides a horizontal well water control mode and parameter optimization method suitable for offshore oil reservoir water injection development, adopts the same production pressure difference to simulate the water control and oil increase effect of each water control valve component; adopts the economic cost to analyze the water control and oil increase effect of each water control valve component, determines the water control mode, improves the oil increase effect and economic benefits, and can better meet the needs of actual production.

[0021] like Figure 1 As shown, the horizontal well water control mode and parameter optimization method suitable for offshore oil reservoir water injection development provided by the present invention includes the following steps: S1. Based on the fluid circulation test experiment, the water control characteristic curve of each water control valve is obtained, and the pressure drop formula is fitted; S2. Through numerical simulation of non-water-controlled reservoirs, the daily liquid production profile and water content profile characteristics of the production wells are obtained, and then the optimization scheme of the water-controlled isolation section of the horizontal well is determined; S3. Based on the fitted pressure drop formula and the optimization scheme of the water control isolation section of the horizontal well, the pressure drop of the water control valve components is controlled at the same level to simulate the water control and oil increase effect of each water control valve component; S4. According to the economic cost, compare the water control and oil production increase effects of various water control valves and determine the water control method for the production wells.

[0022] In the above embodiment, preferably, each of the water control valve components includes a nozzle-type ICD, a channel-type AICD and an intelligent sleeve: According to the water control characteristic curve, the nozzle ICD pressure drop and the channel AICD pressure drop are related to the viscosity. The pressure drop formula used is as follows:

[0023] In the formula, is the density of oil-water mixture; is the calibration density; is the viscosity of the oil-water mixture; To calibrate viscosity; is the valve flow rate; is the valve strength; is the flow index; is the viscosity index; According to the water control characteristic curve, the pressure drop of the intelligent sliding sleeve is related to the opening degree, and the pressure drop formula used is:

[0024] In the formula, is the sleeve flow rate, is the sleeve strength, is the sleeve opening.

[0025] In the above embodiment, preferably, the daily liquid production profile and water content profile characteristics of the production well are obtained by numerical simulation of the water-free reservoir, and then the optimization scheme of the water control isolation section of the horizontal well is determined. The specific steps are: using the numerical simulation of the water-free reservoir to obtain the grid distribution characteristics of the daily liquid production and water content profile, converting the grid distribution characteristics of the daily liquid production and water content profile into uniform distribution characteristics of the daily liquid production and water content profile, and dividing the water control section based on the uniform distribution characteristics of the daily liquid production and water content profile along the length of the liquid production section in the water-free oil production period, the middle liquid extraction period, and the late liquid extraction period; Among them, the daily liquid production and water content profile distribution characteristics under the grid length are converted into the uniform distribution characteristics of the daily liquid production and water content profile under uniform length. The specific formula is as follows:

[0026]

[0027] In the formula, After dividing the length Liquid production per segment; For the The moisture content of each segment; is the length of the entire liquid production section; is the number of pre-segments; For the Rice daily oil production, For the Water production per meter per day; The 4th meter of daily water production.

[0028] In the above embodiment, preferably, the pressure drop formula based on the fitting and the optimization scheme of the water control isolation section of the horizontal well are used to control the pressure drop of the water control valve components at the same level, and simulate the water control and oil increase effect of each water control valve component. The specific steps are: The pressure drop of water control valves is controlled at the same level through the production pressure difference, and the water control valves are evenly arranged under the same segmentation conditions to ensure that the effects of each water control valve are compared by water control volume and oil increase volume under the same pressure drop, and the oil increase volume is used as an economic evaluation index to select water control valves with high economic benefits; The water control volume is defined as the difference between the cumulative water production without water control and the cumulative water production with water control under the same cumulative oil production conditions.

[0029] Embodiment 1: The present invention provides a horizontal well water control mode and parameter optimization method suitable for offshore oil reservoir water injection development, comprising the following steps: S1. Under the same experimental conditions, five kinds of industrial white oil and clean water with different viscosities were used to conduct fluid circulation tests on nozzle-type ICD, channel-type AICD water control valve components and intelligent sleeves to obtain the water control characteristic curves of nozzle-type ICD, channel-type AICD and intelligent sleeves.

[0030] like Figure 2 As shown in the figure, the nozzle ICD water control characteristic curve shows that the effect of fluid viscosity on the nozzle ICD pressure drop is related to the displacement: at high displacement, the effect of fluid viscosity on the valve pressure drop is small, and at low displacement, the valve pressure drop changes relatively more with viscosity. For example, when the flow rate is 10m³ / d, the valve pressure drop of 269cp fluid is about twice that of 1cp clean water.

[0031] like Figure 3 As shown in the figure, the water control characteristic curve of the AICD water control valve has the following characteristics: the pressure drop of the valve decreases with the increase of the viscosity of the fluid medium, and the pressure drop of the water control valve is the largest when the clean water flows through; the pressure drop of the valve decreases with the increase of the viscosity of the fluid medium and there is a critical value. When the viscosity of the fluid medium exceeds the critical value, the pressure drop of the valve increases with the increase of the viscosity. It is generally believed that when the viscosity of the fluid increases to a certain extent, the fluid mainly enters the swirl cavity from the branch flow channel, and the pressure drop of the valve is manifested as the pressure drop of the friction resistance along the way, which increases with the increase of viscosity.

[0032] like Figure 4 As shown in the figure, the water control characteristic curve of the intelligent sleeve shows that the water control characteristic of the intelligent sleeve is affected by two factors: the sleeve opening and the flow rate. The pressure drop is inversely proportional to the sleeve opening and directly proportional to the flow rate, that is, the pressure drop of the intelligent sleeve decreases with the increase of the opening and increases with the increase of the flow rate.

[0033] Since the above water control characteristic curve shows that there is a certain relationship between nozzle ICD and fluid viscosity, the AICD valve pressure drop fitting formula is uniformly adopted, as follows:

[0034] In the formula, is the density of oil-water mixture, in kg / m³; is the calibration density in kg / m³; is the viscosity of the oil-water mixture, in cp; is the calibration viscosity, in cp; is the valve flow rate, in m³ / d; is the valve strength; is the flow index; is the viscosity index.

[0035] The water control characteristic curve is fitted using the above formula to obtain the pressure drop formula coefficient of the water control valve, as shown in Table 1.

[0036] Table 1 Water control valve pressure drop formula coefficient table

[0037] In addition, the pressure drop fitting formula of the smart sleeve is as follows:

[0038] In the formula, is the sleeve flow rate, in m³ / d; is the sleeve strength; is the sleeve opening.

[0039] The water control characteristic curve is fitted using the above formula to obtain the pressure drop formula coefficient of the water control valve, as shown in Table 2.

[0040] Table 2 Intelligent Sleeve Pressure Drop Formula Coefficient Table

[0041] S2. Through numerical simulation of the production well without water control reservoir, the distribution characteristics of the liquid production profile and the water content profile are obtained; and according to the distribution characteristics of the liquid production profile and the water content profile, the optimization scheme of the water control completion isolation section is determined.

[0042] The M oil field is a bottom water reservoir type, which generally has the characteristics of medium porosity and high permeability. The crude oil viscosity is 3-16cp under geothermal conditions, which belongs to the category of thin oil, and the production pressure difference is very small. Therefore, this embodiment selects the A01H well in the M oil field for the applicability analysis of water control valve components.

[0043] Among them, the production characteristics of Well A01H under the condition of completion without water control are as follows: A01H, with a burial depth of about 1410m, a total reservoir thickness of about 15m, geological reserves of 353,000 cubic meters, an average porosity of 20.7%, an average permeability of 2317mD, underground viscosity of crude oil of 15.23cp, and water body energy of about 10.2 times; A01H well is 581m long and has a water avoidance height of about 10m.

[0044] Due to the numerical simulation software currently used, the output profile is to obtain the oil and water production of each section according to the length of the grid. When the length of the grid passed by the horizontal well is uneven, the output daily oil and water production is extremely uneven, resulting in a large gap between the obtained liquid production profile and the real physical profile, which does not conform to the actual situation; and the profile division of water control sections is based on the real physical section liquid production section to divide similar sections together. If each section of the output profile is divided according to the grid block profile, the water content of the liquid production of the sections divided together may not be similar, thereby weakening the water control and oil increase effect; therefore, in this embodiment, the liquid production output according to the length of the grid block is converted into a liquid production profile output uniformly according to the length. The specific formula is as follows:

[0045]

[0046] In the formula, After dividing the length Liquid production per segment, For the The moisture content of each segment, is the length of the entire liquid production section, is the number of pre-segments, For the Rice daily oil production, For the Meters of water production per day.

[0047] Under the condition of no water control, the numerical simulation of the reservoir production was 2409 days, with a daily oil production of 150m2 / day. When the oil production was less than 150m2 / day, liquid production was carried out, and the maximum daily liquid production was limited to 3000m2 / day. Figure 5 As shown, numerical simulation software is used to output the daily liquid production and water content profiles along the horizontal wells at the grid length in the first, second and third years according to the well grid. It can be seen that the A01H well passes through 36 grid lengths in total. Using the conversion formula, the 36 grid lengths are divided into 16 sections with uniform lengths. The average length of each section is 36.3 meters. The vertical permeability distribution is highly heterogeneous, and the permeability breakthrough coefficient is 3.0. The distribution characteristics of the liquid production profile and water content profile along the uniform length of the A01H well are obtained.

[0048] like Figure 6 As shown in the figure, based on the distribution characteristics of the production and water content profiles along the uniform length of Well A01H, the entire Well A01H is divided into three sections: the heel, middle and toe for water control and oil increase design. Among them, the daily liquid production and water content of the production sections No. 5-12 (middle) along the horizontal well are high, with water control potential; the water content of the production sections No. 1-4 (heel) and No. 13-16 (toe) along the horizontal well is low, with oil increase potential.

[0049] S3. Based on the segmented characteristics of the A01H horizontal well, ICD and AICD valves are evenly arranged according to the length of the liquid production section. The density of the water control valve is determined by trial calculation using the fitted pressure drop formula, and the pressure drop of the water control valve in the later stage of production is uniformly controlled at 1Mpa, thereby comparing the water control effects of different water control valves. In other embodiments, the pressure drop of the water control valve can be controlled at different sizes according to actual conditions.

[0050] In this embodiment, the 9-point statistical averaging method in reservoir numerical simulation is used to obtain the production pressure difference, which is used to characterize the near-wellbore pressure drop; wherein the production pressure difference represents the formation seepage pressure drop under the production condition without water control, and represents the sum of the valve pressure drop and the formation seepage pressure drop under the production condition of water control.

[0051] Since the water content is low and the viscosity of the oil-water mixture is high in the early stage of production, the pressure drop of the AICD valve is lower than that of the ICD at the same flow rate; while in the later stage of production, the fluid is mainly water with low viscosity, and the pressure drop of the AICD is greater than that of the ICD at the same flow rate; therefore, the ICD mainly plays a role in the oil well extraction period, while the AICD mainly plays a role in the stable production period of the oil well (high water content).

[0052] In this embodiment, the water control volume is defined as the difference in cumulative water production under the same cumulative oil production conditions, that is, the cumulative water production at the end of production without water control minus the cumulative water production at the end of water control under the same cumulative oil production. This more reasonably explains the water control effects of the three water control methods when the cumulative oil production is the same compared with those without water control.

[0053] Through the above method, the characteristics of the cumulative oil production and cumulative water production under each water control method are obtained, as shown in Table 3. The results show that the three water control completion methods have obvious oil production effects, ICD and AICD have similar oil production effects, ICD has slightly more cumulative oil production, and the intelligent sleeve has the best oil production effect. The ICD with uniform distribution of water control valves has a cumulative oil production of 22,880 cubic meters, the AICD with uniform distribution has a cumulative oil production of 21,310 cubic meters, and the intelligent sleeve has a cumulative oil production of 36,940 cubic meters.

[0054] Table 3 Cumulative production results of different water control methods for A01H horizontal well

[0055] S4. Cost analysis of each water control method is shown in Table 4. From the perspective of oil increase effect, the intelligent sleeve has the best oil increase effect. From an economic perspective, the increase in revenue brought by oil increase is shown in the following table. Weighing the increased revenue and additional costs of the three water control methods, the ICD valve water control completion method with the highest profit should be used in Well A01 of M Oilfield.

[0056] Table 4 Cost analysis of different water control methods for A01H horizontal well

[0057] Embodiment 2: In this embodiment, the B01H well in the N oil field is selected for water control method and parameter optimization design. Among them, the burial depth of the B01H well is about 1238m, and the total thickness of the reservoir is about 17.8m. The average porosity is 28.0%, the average permeability in the horizontal direction near the well is 500mD, and the underground crude oil viscosity is about 93.8cp. The A1H well is 275m long, the heel end is close to the edge water, and the angle between the horizontal wellbore and the edge water is close to 30 degrees.

[0058] like Figure 7As shown in the figure, under the condition of no water control, the reservoir numerical simulation production of B01H well was carried out for 3650 days. The numerical simulation software was used to calculate the grid distribution characteristics of daily liquid production and water content profile along the horizontal well under the grid length in the first, second and third years according to the well grid, and the formula was used to divide it into 9 sections with uniform length, and the daily liquid production and water content profile distribution characteristics along the uniform length of B01H well were obtained. Figure 8 As shown in the figure, according to the uniform distribution characteristics of daily liquid production and water content profile along the horizontal well, the B01H well is divided into three sections for water control and oil increase design. Among them, the heel-end liquid production section 1-3 has high daily liquid production and water content, which is the first water control section; the middle liquid production section 4-7 has medium daily liquid production and water content, which is the second water control section; the toe-end 8-9 has the lowest daily liquid production and water content, which is the third water control section.

[0059] Based on the segmented characteristics of the B01H horizontal well, ICD and AICD valves are evenly distributed according to the length of the liquid production section. The pressure drop of the valves is uniformly controlled at 0.9 MPa through trial calculation, and the pressure drop of the smart sleeve is also uniformly controlled at 0.9 MPa, and the cumulative oil and water production characteristics of each water control method are obtained, as shown in Table 5. The results show that compared with the condition without water control, the three water control completion methods have obvious oil increase effects, the AICD oil increase effect is significantly better than the ICD, and the smart sleeve is the best, the ICD cumulative oil increase is 50070 cubic meters, the AICD cumulative oil increase is 59630 cubic meters, and the smart sleeve increases oil by 80080 cubic meters; the three water control completion methods have obvious water control effects, the AICD water control effect is significantly better than the ICD, the smart sleeve is the best, the ICD water control volume is 765430 cubic meters, the AICD water control volume is 877710 cubic meters, and the smart sleeve water control volume is 2073010 cubic meters.

[0060] Table 5 Cumulative production results of B01H horizontal well with different water control methods

[0061] The cost analysis of each water control method is shown in Table 6. From the perspective of oil increase effect, the smart sleeve has the best oil increase effect. From an economic perspective, the increase in revenue brought by oil increase is shown in the following table. Weighing the increased revenue and additional costs of the three water control methods, the B01H well in the N oil field uses the most profitable smart sleeve water control completion method.

[0062] Table 6 Cost analysis of different water control methods for B01H horizontal well

[0063] Embodiment 3: In this example, the C01H well is selected, which belongs to the edge water drive reservoir in a block of the N oil field. The stratum where it is located is about 1258m deep, and the total thickness of the reservoir is about 14.5m. The average porosity is 26.9%, the average permeability in the horizontal direction near the well is 1460mD, and the underground crude oil viscosity is about 94.9cp. The C01H well is 301m long, the toe is close to the edge water, and the angle between the horizontal wellbore and the edge water is close to 10 degrees.

[0064] The numerical simulation of reservoir production was carried out under no water control conditions for 10 years. The daily oil production was set to 50m3. When it was less than 50m3, liquid production was carried out. The maximum daily liquid production was set to 650m3 / d. The production pressure difference change process was 0.23MP-1.07MPa-0.54MPa using the 9-point method of reservoir numerical simulation. The cumulative oil production in 10 years was 107,600 cubic meters, and the cumulative water production was 1.9857 million cubic meters. The numerical simulation software was used to output the daily liquid production and water content profile distribution characteristics along the horizontal well grid length in the first, second and third years according to the well grid length, such as Fig. 9 As shown in the figure, it can be seen that the C01H well passes through 47 grids in total. According to the corresponding formula, the 47 grids are divided into nine sections with uniform lengths for processing, and the daily liquid production and water content profile distribution characteristics along the uniform length of the horizontal well are obtained.

[0065] like Fig.10 As shown in the figure, the heel end liquid production section 1-3 has a low daily liquid production and water content, which can be used as the first water control section; the middle liquid production section 4-8 has a high daily liquid production and water content, which can be used as the second water control section; the toe end 9-10 has the lowest daily liquid production and water content, which can be used as the third water control section. Therefore, the entire C01H well is divided into three sections for water control and oil increase design.

[0066] Based on the segmented characteristics of C01H horizontal well, ICD and AICD valves are evenly distributed according to the length of the liquid production section. The pressure drop of the valves is uniformly controlled at 0.9MPa through trial calculation, and the pressure drop of the smart sleeve is also uniformly controlled at 1Mpa, and the water control and oil increase effect under each water control method is obtained, as shown in Table 7. The results show that compared with the condition without water control, the three water control completion methods have obvious oil increase effect, AICD oil increase effect is significantly better than ICD, and smart sleeve is the best, ICD cumulative oil increase is 4,400 cubic meters, AICD cumulative oil increase is 4,700 cubic meters, and smart sleeve oil increase is 6,500 cubic meters; the three water control completion methods have obvious water control effect, AICD water control effect is significantly better than ICD, smart sleeve is the best, ICD water control volume is 206,100 cubic meters, AICD water control volume is 216,600 cubic meters, and smart sleeve water control volume is 310,800 cubic meters.

[0067] Table 7 Cumulative production results of C01H horizontal well with different water control methods

[0068] From the perspective of oil increase effect, the intelligent sleeve has the best oil increase effect. From an economic perspective, the increase in revenue brought by oil increase is shown in the following table. Weighing the increased revenue and additional costs of the three water control methods, the AICD water control completion method with the highest profit should be used for Well C01H in the N oilfield, as shown in Table 8.

[0069] Table 8 Cost analysis of different water control methods for C01H horizontal well Water control method Increase oil increase oil (Wanfang) (Wanfang) International oil price US$ per barrel (06.07) US dollar to RMB exchange rate Packer cost (10,000 yuan) Valve parts / sleeve cost (10,000 yuan) Increased profit (10,000 yuan) Increased profits compared to ICD No water control 0 75.55 1:7.245 0 0 0.00 -228.77 ICD 0.4417 75.55 1:7.245 12 1 228.77 0.00 AICD 0.4714 75.55 1:7.245 12 5 241.03 12.26 Smart Sleeve 0.6462 75.55 1:7.245 12 103 238.70 9.94 Therefore, the present invention adopts the above-mentioned horizontal well water control method and parameter optimization method suitable for offshore oil reservoir water injection development, which can determine the water control method according to the water invasion characteristics of the horizontal well, improve the oil increase effect and economic benefits, and better meet the actual production needs.

[0070] Embodiment 4: The present invention also provides a horizontal well water control and parameter optimization device suitable for offshore oil reservoir water injection development, comprising: The first processing unit is used to obtain the water control characteristic curve of each water control valve component based on the fluid circulation test experiment, and fit the pressure drop formula; The second processing unit is used to obtain the daily liquid production profile and water content profile characteristics of the production well through numerical simulation of the non-water-controlled oil reservoir, and then determine the optimization plan of the water-controlled isolation section of the horizontal well; The third processing unit is used to control the pressure drop of the water control valve components at the same level based on the fitted pressure drop formula and the optimization scheme of the water control isolation section of the horizontal well, and simulate the water control and oil increase effect of each water control valve component; The fourth processing unit is used to compare the water control and oil production increase effects of each water control valve component according to the economic cost, and determine the water control method of the production well.

[0071] Embodiment 5: The present invention also provides a computer storage medium on which a computer program is stored. When the computer program is executed by a processor, the horizontal well water control method and parameter optimization method steps suitable for offshore oil reservoir water injection development are implemented.

[0072] Embodiment 6: The present invention also provides a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, the horizontal well water control method and parameter optimization method steps applicable to offshore oil reservoir water injection development are implemented.

[0073] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, rather than to limit it. Although the present invention has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or make equivalent replacements for some of the technical features therein. However, these modifications or replacements do not deviate the essence of the corresponding technical solutions from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. A horizontal well water control mode and parameter optimization method suitable for offshore oil reservoir water injection development, characterized in that: The following steps are involved: Based on the fluid circulation test experiment, the water control characteristic curve of each water control valve is obtained and the pressure drop formula is fitted; Through numerical simulation of non-water-controlled reservoirs, the daily liquid production profile and water cut profile characteristics of the production wells are obtained, and then the optimization scheme of the water-controlled isolation section of the horizontal well is determined; Based on the fitted pressure drop formula and the optimization scheme for the water control and isolation sections of horizontal wells, the pressure drop of the water control valves was controlled at the same level to simulate the water control and oil production increase effects of each water control valve. Based on the economic cost, the water control and oil production increase effects of various water control valves are compared to determine the water control method for production wells.

2. The method for optimizing the water control mode and parameters of a horizontal well according to claim 1, characterized in that: The water control valve components include nozzle-type ICD, channel-type AICD and intelligent sliding sleeve: According to the water control characteristic curve, the pressure drop of nozzle-type ICD and channel-type AICD are both related to viscosity. The pressure drop formula used is as follows: Where, is the density of oil-water mixture; is the calibration density; is the viscosity of the oil-water mixture; To calibrate viscosity; is the valve flow rate; is the valve strength; is the flow index; is the viscosity index; According to the water control characteristic curve, the pressure drop of the intelligent sliding sleeve is related to the opening degree. The pressure drop formula used is: Where, is the sleeve flow rate, is the sleeve strength, is the sleeve opening.

3. The method for optimizing the water control mode and parameters of a horizontal well according to claim 1, characterized in that: The numerical simulation of the non-water-controlled reservoir is used to obtain the daily liquid production profile and water cut profile characteristics of the production well, and then determine the optimization scheme of the water control isolation section of the horizontal well. The specific steps are: using the numerical simulation of the non-water-controlled reservoir to obtain the grid distribution characteristics of the daily liquid production and water cut profile, converting the grid distribution characteristics of the daily liquid production and water cut profile into uniform distribution characteristics of the daily liquid production and water cut profile, and dividing the water control section based on the uniform distribution characteristics of the daily liquid production and water cut profile along the length of the liquid production section in the waterless oil production period, the middle liquid extraction period, and the late liquid extraction period; The daily liquid production and water content profile distribution characteristics under the grid length are converted into uniform profile distribution characteristics of daily liquid production and water content under uniform length. The specific formula is as follows: Where, After dividing the length equally Liquid production per section; For the The moisture content of each section; is the length of the entire liquid production section; is the number of pre-segments; For the Rice daily oil production, For the Water production per meter per day; The 4th meter of daily water production.

4. The method for optimizing the water control mode and parameters of a horizontal well according to claim 1, characterized in that: Based on the fitted pressure drop formula and the optimization scheme for the water control isolation section of the horizontal well, the pressure drop of the water control valve components is controlled at the same level to simulate the water control and oil production increase effect of each water control valve component. The specific steps are as follows: The pressure drop of the water control valves is controlled at the same level by the production pressure difference. The water control valves are evenly arranged under the same segment conditions. The effect of each water control valve is compared by comparing the water control volume and oil increase volume under the same pressure drop. The oil increase volume is used as the economic evaluation indicator to select the water control valve with the highest economic benefit. The water control volume is defined as the difference between the cumulative water production without water control and the cumulative water production with water control under the same cumulative oil production conditions.

5. A horizontal well water control and parameter optimization device suitable for offshore oil reservoir water injection development, characterized in that: include: The first processing unit is used to obtain the water control characteristic curve of each water control valve component based on the fluid circulation test experiment and fit the pressure drop formula; The second processing unit is used to obtain the daily liquid production profile and water cut profile characteristics of the production well through numerical simulation of the non-water-controlled oil reservoir, and then determine the optimization plan of the water-controlled isolation section of the horizontal well; The third processing unit is used to control the pressure drop of the water control valve components at the same level based on the fitted pressure drop formula and the optimization plan for the water control and isolation section of the horizontal well, and simulate the water control and oil production increase effect of each water control valve component; The fourth processing unit is used to compare the water control and oil production increase effects of various water control valves according to economic costs and determine the water control method for the production well.

6. A computer storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the steps of the method for optimizing water control and parameters of horizontal wells applicable to water injection development of offshore oil reservoirs according to any one of claims 1 to 4 are implemented.

7. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein: When the processor executes the computer program, the steps of the method for optimizing the water control mode and parameters of horizontal wells applicable to water injection development of offshore oil reservoirs as described in any one of claims 1 to 4 are implemented.

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