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

Abstract

The present 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, wherein the method comprises the following steps: based on a fluid circulation test experiment, obtaining the water control characteristic curve of each water control valve component and fitting a pressure drop formula; through numerical simulation of a non-water control oil reservoir, obtaining the daily liquid production profile and water content profile characteristics of the production well, and then determining the optimization scheme of the horizontal well water control isolation section; based on the fitted pressure drop formula and the horizontal well water control isolation section optimization scheme, controlling the pressure drop of the water control valve components to the same level, simulating the water control and oil production increase effect of each water control valve component; comparing the water control and oil production increase effect of each water control valve component according to economic cost, and determining the water control mode of the production well. The present invention can improve the water control completion and oil production increase and water control effect in the actual production of horizontal wells.

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 tail effect, and natural fractures, the production profile is uneven, and edge and bottom water coning is prone to occur, resulting in reservoir flooding, reduced oil production, and affecting the oil reservoir development effect and ultimate recovery rate.

[0003] To address the aforementioned water control issues in horizontal well development, a series of tools have been developed domestically and internationally, including valve ICDs, valve AICDs, and intelligent water control sleeves. Furthermore, by adjusting the uneven profile of horizontal wells through appropriate completion methods such as non-uniform placement, the effectiveness of these water control completions in increasing production and controlling water can be improved. However, the applicability of these valves and the optimization of their placement and use remain unclear in the field.

[0004] If the appropriate water control method and optimized application plan can be selected based on the water invasion characteristics of horizontal wells during the design phase, the horizontal well recovery rate can be effectively improved, and the oil production effect of the water control completion method can be enhanced. Therefore, it is necessary to determine a horizontal well water control method and parameter optimization method suitable for water injection development in offshore oil reservoirs. Summary of the Invention

[0005] In response to the above problems, the purpose of the present invention is to provide a horizontal well water control method 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 production control effect in the actual production of horizontal wells.

[0006] To achieve the above object, the present invention adopts the following technical solutions:

[0007] The horizontal well water control method and parameter optimization method applicable to offshore oil reservoir water injection development of the present invention comprises the following steps:

[0008] 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;

[0009] 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;

[0010] 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.

[0011] 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.

[0012] In 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 sliding sleeve:

[0013] 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:

[0014]

[0015] 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;

[0016] 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:

[0017]

[0018] Where, is the sleeve flow rate, is the sleeve strength, is the sleeve opening.

[0019] The method for optimizing the water control mode and parameters of horizontal wells is preferably to obtain the daily liquid production profile and water cut profile characteristics of the production well through numerical simulation of the non-water control reservoir, 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 control 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;

[0020] 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:

[0021]

[0022]

[0023] 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 day; The 4th meter of daily water production.

[0024] The horizontal well water control mode and parameter optimization method, preferably, the pressure drop formula based on the fitting and the optimization scheme for 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 production increase effect of each water control valve component. The specific steps are:

[0025] 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.

[0026] 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.

[0027] The present invention also provides a horizontal well water control and parameter optimization device suitable for offshore oil reservoir water injection development, comprising:

[0028] 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;

[0029] 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;

[0030] 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;

[0031] 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.

[0032] The present invention also provides a computer storage medium storing a computer program, which, when executed by a processor, implements the horizontal well water control method and parameter optimization method steps applicable to offshore oil reservoir water injection development.

[0033] The present invention also provides a computer device, including a memory, a processor, and a computer program stored in the memory and runnable on the processor. When the processor executes the computer program, the horizontal well water control method and parameter optimization method steps suitable for offshore oil reservoir water injection development are implemented.

[0034] The present invention has the following advantages due to the adoption of the above technical solution:

[0035] (1) Use the same production pressure difference to simulate the water control and oil increase effects of each water control valve component;

[0036] (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

[0037] Various other advantages and benefits will become apparent to those skilled in the art upon reading the detailed description of the preferred embodiment below. The accompanying drawings are for illustration purposes only and are not to be considered as limiting the present invention. Throughout the drawings, the same reference numerals are used to denote the same components. In the drawings:

[0038] Figure 1 is a technical flow chart in an embodiment of the present invention;

[0039] Figure 2 is the nozzle-type ICD water control characteristic curve in the embodiment of the present invention;

[0040] Figure 3 is the water control characteristic curve of the channel-type AICD in the embodiment of the present invention;

[0041] Figure 4 is the water control characteristic curve of the intelligent sliding sleeve in the embodiment of the present invention;

[0042] Figure 5 1 is a grid distribution characteristic diagram of daily liquid production profile and water cut profile along the A01H horizontal well in an embodiment of the present invention;

[0043] Figure 6 1 is a characteristic diagram of uniform distribution of daily liquid production profile and water cut profile along the A01H horizontal well in an embodiment of the present invention;

[0044] Figure 7 1 is a grid distribution characteristic diagram of daily liquid production profile and water cut profile along the B01H horizontal well in an embodiment of the present invention;

[0045] Figure 8 1 is a characteristic diagram of uniform distribution of daily liquid production profile and water cut profile along the B01H horizontal well in an embodiment of the present invention;

[0046] Figure 9 1 is a grid distribution characteristic diagram of daily liquid production profile and water cut profile along the C01H horizontal well in an embodiment of the present invention;

[0047] Figure 10 This is a characteristic diagram of the uniform distribution of daily liquid production profile and water cut profile along the C01H horizontal well in an embodiment of the present invention. DETAILED DESCRIPTION

[0048] Exemplary embodiments of the present invention will be described in more detail below with reference to the accompanying drawings. Although 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. Rather, these embodiments are provided 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.

[0049] The present invention provides a horizontal well water control method and parameter optimization method suitable for offshore oil reservoir water injection development. The method uses the same production pressure difference to simulate the water control and oil production increase effects of various water control valve components. The economic cost is used to analyze the water control and oil production increase effects of various water control valve components, determine the water control method, improve the oil production increase effect and economic benefits, and better meet the needs of actual production.

[0050] like Figure 1 As shown, the horizontal well water control mode and parameter optimization method applicable to offshore oil reservoir water injection development provided by the present invention includes the following steps:

[0051] S1. Based on the fluid circulation test experiment, obtain the water control characteristic curve of each water control valve component and fit the pressure drop formula;

[0052] S2. 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;

[0053] S3. 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 is controlled at the same level to simulate the water control and oil production increase effects of each water control valve;

[0054] S4. Based on 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.

[0055] 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:

[0056] 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:

[0057]

[0058] 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;

[0059] 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:

[0060]

[0061] Where, is the sleeve flow rate, is the sleeve strength, is the sleeve opening.

[0062] In the above embodiment, preferably, the daily liquid production profile and water cut profile characteristics of the production well are obtained by numerical simulation of the non-water-controlled reservoir, and then the optimization scheme of the water-controlled isolation section of the horizontal well is determined. 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;

[0063] 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:

[0064]

[0065]

[0066] 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 day; The 4th meter of daily water production.

[0067] In the above embodiment, preferably, the pressure drop formula based on the fitting and the optimization scheme for 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 production increase effect of each water control valve component. The specific steps are as follows:

[0068] 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.

[0069] 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.

[0070] Example 1:

[0071] 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:

[0072] S1. Under identical experimental conditions, five viscosities of industrial white oil and clean water were used to conduct fluid circulation tests on nozzle-type ICD, channel-type AICD water control valve components, and smart sleeves. The water control characteristic curves of these valves were obtained.

[0073] like Figure 2 As shown in the figure, the nozzle-type ICD water control characteristic curve shows that the effect of fluid viscosity on the pressure drop of the nozzle-type ICD is related to the displacement: at high displacement, the effect of fluid viscosity on the valve pressure drop is small, while at low displacement, the pressure drop of the valve varies significantly with viscosity. For example, at a flow rate of 10m³ / d, the pressure drop of the valve for a 269cp fluid is approximately double that of a 1cp clear water fluid.

[0074] like Figure 3 As shown in Figure 1, the water control characteristic curve of the AICD water control valve exhibits the following characteristics: valve pressure drop decreases with increasing fluid viscosity, reaching its maximum when clear water is flowing. There is a critical value at which the valve pressure drop decreases with increasing fluid viscosity. When the viscosity exceeds this critical value, the valve pressure drop increases with increasing viscosity. It is generally believed that when fluid viscosity reaches a certain level, the fluid primarily enters the swirl chamber through the branch flow channel, and the valve pressure drop manifests as a frictional pressure drop along the flow path, increasing with increasing viscosity.

[0075] like Figure 4 As shown in the figure, the water control characteristic curve of the smart sleeve shows that its water control characteristics are affected by two factors: the sleeve opening and the flow rate. The resulting pressure drop is inversely proportional to the sleeve opening and directly proportional to the flow rate. In other words, the pressure drop of the smart sleeve decreases with increasing opening and increases with increasing flow rate.

[0076] Since the above water control characteristic curve shows that there is a certain relationship between nozzle-type ICD and fluid viscosity, the AICD valve pressure drop fitting formula is uniformly adopted, as follows:

[0077]

[0078] Where, 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, the unit is cp; is the valve flow rate, in m³ / d; is the valve strength; is the flow index; is the viscosity index.

[0079] The above formula is used to fit the water control characteristic curve to obtain the pressure drop formula coefficient of the water control valve, as shown in Table 1.

[0080] Table 1 Water control valve pressure drop coefficient table

[0081]

[0082] In addition, the pressure drop fitting formula of the smart sleeve is as follows:

[0083]

[0084] Where, is the sleeve flow rate, in m³ / d; is the sleeve strength; is the sleeve opening.

[0085] The above formula is used to fit the water control characteristic curve to obtain the pressure drop formula coefficient of the water control valve, as shown in Table 2.

[0086] Table 2 Intelligent Sleeve Pressure Drop Formula Coefficients

[0087]

[0088] S2. Through numerical simulation of non-water-controlled reservoirs in production wells, the distribution characteristics of the liquid production profile and the water cut profile are obtained; and based on the distribution characteristics of the liquid production profile and the water cut profile, the optimization scheme for the water-controlled completion and isolation section is determined.

[0089] The M oilfield is a bottom water reservoir with medium porosity and high permeability. The crude oil viscosity is 3-16 cp under geothermal conditions, which is considered a thin oil. The production pressure difference is very small. Therefore, this example selects Well A01H in the M oilfield for the applicability analysis of water control valve components.

[0090] Among them, the production characteristics of Well A01H under the condition of no water control completion are as follows:

[0091] A01H has a burial depth of approximately 1,410m, a total reservoir thickness of approximately 15m, geological reserves of 353,000 cubic meters, an average porosity of 20.7%, an average permeability of 2,317mD, an underground viscosity of crude oil of 15.23cp, and a water body energy of approximately 10.2 times; the A01H well is 581m long and has a water avoidance height of approximately 10m.

[0092] Due to the numerical simulation software currently used, the output profile is based on the length of the grid through which the oil and water production of each section is obtained. When the length of the grid through which the horizontal well passes 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 profile liquid production section to divide similar sections together. If each output section is divided according to the grid block section, the water content of the divided sections may be different, thereby weakening the water control and oil increase effect; therefore, in this embodiment, the liquid production output according to the grid block length is converted into a liquid production profile output uniformly according to the length. The specific formula is as follows:

[0093]

[0094]

[0095] Where, After dividing the length equally Liquid production per section, 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.

[0096] Under the condition of no water control, the numerical simulation of the reservoir production was conducted for 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 in the figure, numerical simulation software was used to output the daily liquid production and water cut 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 Well A01H passes through 36 grid lengths in total. Using the conversion formula, the 36 grid lengths are divided into 16 segments of uniform length, with an average length of 36.3 meters per segment. 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 cut profile along the uniform length of Well A01H are obtained.

[0097] like Figure 6 As shown in the figure, based on the distribution characteristics of fluid production and water cut profiles along the uniform length of Well A01H, the entire well was divided into three sections: the heel, middle, and toe for water control and oil production enhancement design. Among them, the daily fluid production and water cut of horizontal well sections 5-12 (the middle section) along the well are high, indicating potential for water control. Meanwhile, the water cuts of horizontal well sections 1-4 (the heel) and 13-16 (the toe) along the well are low, indicating potential for oil production enhancement.

[0098] S3. Based on the segmented characteristics of the A01H horizontal well, ICD and AICD valves were evenly distributed along the length of the liquid-producing section. The density of the water control valves was determined by trial calculation using a fitted pressure drop formula. The pressure drop of the water control valves was uniformly controlled at 1 MPa in the late production period to compare the water control effects of different water control valves. In other embodiments, the pressure drop of the water control valves can be controlled to different levels based on actual conditions.

[0099] 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. The production pressure difference represents the formation seepage pressure drop under non-water control production conditions and represents the sum of the valve pressure drop and the formation seepage pressure drop under water control production conditions.

[0100] 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. However, 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 during the oil well liquid extraction period, while the AICD mainly plays a role during the oil well stable production period (high water content).

[0101] 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 before water control is completed under the same cumulative oil production conditions. This more reasonably illustrates the water control effects of the three water control methods when the cumulative oil production is the same compared with those without water control.

[0102] Using the above method, the cumulative oil and water production characteristics for each water control method were obtained, as shown in Table 3. The results show that the three water control completion methods significantly increase oil production. The ICD and AICD methods offer similar results, with ICD producing slightly more cumulative oil. The intelligent sliding sleeve method offers the best oil production. The ICD method, with uniformly distributed water control valves, produces 22,880 cubic meters of cumulative oil, the AICD method produces 21,310 cubic meters of cumulative oil, and the intelligent sliding sleeve method produces 36,940 cubic meters of cumulative oil.

[0103] Table 3 Cumulative production results of A01H horizontal well with different water control methods

[0104]

[0105] S4. Cost analysis of each water control method is shown in Table 4. From a production increase perspective, the intelligent sleeve method offers the best results. From an economic perspective, the increased revenue from increased production is shown in the following table. Weighing the increased revenue and additional costs of the three water control methods, Well A01 in the M Oilfield should utilize the most profitable ICD valve water control completion method.

[0106] Table 4 Cost analysis of different water control methods for A01H horizontal well

[0107]

[0108] Example 2:

[0109] This example uses Well B01H in the N Oilfield for water control optimization and parameter design. Well B01H is located at a depth of approximately 1238 meters, with a total reservoir thickness of approximately 17.8 meters. The average porosity is 28.0%, the average horizontal permeability near the wellbore is 500 mD, and the underground crude oil viscosity is approximately 93.8 cp. Well A1H is 275 meters long, with its heel end close to the edge water, and the horizontal wellbore angle with the edge water is approximately 30 degrees.

[0110] like Figure 7 As shown in the figure, under the condition of no water control, the reservoir numerical simulation of well B01H 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 along the horizontal well under the grid length in the first, second and third years according to the well grid. The grid was divided into 9 sections with uniform length using the formula to obtain the daily liquid production and water content profile distribution characteristics along the uniform length of well B01H. Figure 8 As shown in the figure, based on the uniform distribution characteristics of daily liquid production and water cut profile along the horizontal well, Well B01H is divided into three sections for water control and oil production increase design. Among them, the heel-end liquid production section 1-3 has high daily liquid production and water cut, which serves as the first water control section; the middle liquid production section 4-7 has medium daily liquid production and water cut, which serves as the second water control section; the toe-end liquid production section 8-9 has the lowest daily liquid production and water cut, which serves as the third water control section.

[0111] Based on the segmented characteristics of the B01H horizontal well, ICD and AICD valves were evenly distributed along the length of the production section. Through trial calculations, the valve pressure drop was uniformly controlled at 0.9 MPa, and the pressure drop generated by the intelligent sleeve was also uniformly controlled at 0.9 MPa. The cumulative oil and water production characteristics of each water control method were obtained, as shown in Table 5. The results show that compared with the conditions without water control, the three water control completion methods significantly increased oil production, with the AICD significantly outperforming the ICD, and the intelligent sleeve being the best. The ICD cumulative oil production increased by 50,070 cubic meters, the AICD by 59,630 cubic meters, and the intelligent sleeve by 80,080 cubic meters. The three water control completion methods also achieved significant water control, with the AICD significantly outperforming the ICD, and the intelligent sleeve being the best. The ICD controlled 76,543 cubic meters of water, the AICD controlled 87,771 cubic meters of water, and the intelligent sleeve controlled 207,301 cubic meters of water.

[0112] Table 5 Cumulative production results of B01H horizontal well with different water control methods

[0113]

[0114] A cost analysis of each water control method is shown in Table 6. In terms of oil production increase, the intelligent sliding sleeve method offers the best results. From an economic perspective, the increased revenue from increased oil production is shown in the following table. Weighing the increased revenue and additional costs of the three water control methods, Well B01H in the N Oilfield uses the most profitable intelligent sliding sleeve water control completion method.

[0115] Table 6 Cost analysis of different water control methods for B01H horizontal well

[0116]

[0117] Example 3:

[0118] This example uses Well C01H, a reservoir located in a block of the N oilfield, at an edge-water drive reservoir depth of approximately 1258 m and a total reservoir thickness of approximately 14.5 m. The reservoir has an average porosity of 26.9%, an average horizontal permeability near the wellbore of 1460 mD, and a viscosity of approximately 94.9 cp. Well C01H is 301 m long, with its toe close to the edge-water drive, and an angle of approximately 10 degrees between the horizontal wellbore and the edge-water drive.

[0119] Under the condition of no water control, the numerical simulation of oil reservoir production is carried out for 10 years. The daily oil production is set to 50m3. When it is less than 50m3, liquid production is carried out. The maximum daily liquid production is set to 650m3 / d. The production pressure difference variation process of the reservoir numerical simulation 9-point method is 0.23MP-1.07MPa-0.54MPa. The cumulative oil production in 10 years is 107,600 cubic meters and the cumulative water production is 1.9857 million cubic meters. The numerical simulation software is 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, as shown in the following figure: Figure 9As shown in Figure 2, well C01H passes through 47 grids in total. According to the corresponding formula, the 47 grids are divided into nine segments of uniform length for processing, and the daily fluid production and water cut profile distribution characteristics along the uniform length of the horizontal well are obtained.

[0120] like Figure 10 As shown, the heel-end production segments 1-3 have low daily fluid production and water cut, making them suitable for the first water control segment. The middle production segments 4-8 have high daily fluid production and water cut, making them suitable for the second water control segment. The toe-end production segments 9-10 have the lowest daily fluid production and water cut, making them suitable for the third water control segment. Therefore, the entire well C01H was divided into three segments for water control and oil production increase design.

[0121] Based on the segmented characteristics of the C01H horizontal well, ICD and AICD valves were evenly distributed along the length of the production section. Through trial calculations, the valve pressure drop was uniformly controlled at 0.9 MPa, and the pressure drop generated by the intelligent sleeve was also uniformly controlled at 1 MPa. The water control and oil production increase effects of each water control method were obtained, as shown in Table 7. The results show that compared with the conditions without water control, the three water control completion methods significantly increased oil production, with the AICD significantly outperforming the ICD, and the intelligent sleeve being the best. The ICD increased oil production by 4,400 cubic meters, the AICD by 4,700 cubic meters, and the intelligent sleeve by 6,500 cubic meters. The three water control completion methods also achieved significant water control effects, with the AICD significantly outperforming the ICD, and the intelligent sleeve being the best. The ICD controlled 206,100 cubic meters of water, the AICD controlled 216,600 cubic meters of water, and the intelligent sleeve controlled 310,800 cubic meters of water.

[0122] Table 7 Cumulative production results of C01H horizontal well with different water control methods

[0123]

[0124] In terms of oil production increase effectiveness, the intelligent sleeve has the best results. From an economic perspective, the increased revenue from increased oil production is shown in the table below. Weighing the increased revenue and additional costs of the three water control methods, the AICD water control completion method, which offers the highest profit, should be used for Well C01H in the N oilfield, as shown in Table 8.

[0125] Table 8 Cost analysis of different water control methods for C01H horizontal well

[0126] Water control method Increase oil increase oil (Wanfang) (Wanfang) International oil price US$ per barrel (06.07) USD to RMB exchange rate Packer cost (10,000 yuan) Valve / 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 Slide 0.6462 75.55 1:7.245 12 103 238.70 9.94

[0127] 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 injection effect and economic benefits, and better meet the actual production needs.

[0128] Example 4:

[0129] The present invention also provides a horizontal well water control and parameter optimization device suitable for offshore oil reservoir water injection development, comprising:

[0130] 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;

[0131] 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;

[0132] 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;

[0133] 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.

[0134] Example 5:

[0135] The present invention also provides a computer storage medium storing a computer program, which, when executed by a processor, implements the horizontal well water control method and parameter optimization method steps applicable to offshore oil reservoir water injection development.

[0136] Example 6:

[0137] The present invention also provides a computer device, including a memory, a processor, and a computer program stored in the memory and runnable on the processor. When the processor executes the computer program, the horizontal well water control method and parameter optimization method steps suitable for offshore oil reservoir water injection development are implemented.

[0138] 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 various 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 economic costs, compare the water control and oil production increase effects of various water control valves to determine the water control method for production wells; The water control valve components include nozzle-type ICD, channel-type AICD and intelligent 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; Among them, the daily liquid production profile and water cut profile characteristics of the production well are obtained through numerical simulation of the non-water controlled reservoir, and then the optimization scheme of the water control and isolation section of the horizontal well is determined. 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.

2. 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.

3. A horizontal well water control and parameter optimization device suitable for offshore oil reservoir water injection development based on the horizontal well water control method and parameter optimization method according to claim 1 or 2, 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.

4. 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 the water control mode and parameters of horizontal wells applicable to water injection development of offshore oil reservoirs as described in claim 1 or 2 are implemented.

5. 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 horizontal well water control method and parameter optimization method applicable to offshore oil reservoir water injection development as described in claim 1 or 2 are implemented.

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