A development method for imbricate narrow strip edge water heavy oil reservoir

Abstract

The present invention relates to a development method for an imbricate narrow strip edge water heavy oil reservoir, and belongs to the technical field of petroleum extraction. The present invention is aimed at an imbricate narrow strip edge water heavy oil reservoir, and uses the data of the development wells that have been put into production and the results of numerical simulation to analyze, and uses the vertical utilization degree of the oil layer, the thermal energy utilization rate and the recovery rate as indicators to determine the position of the horizontal section in the oil layer; then the length of the horizontal section and the distance from the fault and the edge water are determined according to the situation of the oil reservoir itself; finally, the injection and production parameters of the oil layer to be developed are determined by numerical simulation and combined with the injection and production parameters of the horizontal wells that have been put into production. The present invention fully considers the characteristics of the imbricate narrow strip edge water heavy oil reservoir, adopts the development method of horizontal wells, and determines the method of horizontal well development through numerical simulation and the development effect of the horizontal wells that have been put into production, thereby maximizing the utilization degree and recovery rate of the imbricate narrow strip edge water heavy oil reservoir.

Description

Technical Field

[0001] The invention relates to a development method for an imbricate narrow-strip edge-water heavy oil reservoir, belonging to the technical field of oil exploitation. Background Art

[0002] Heavy oil fields are generally shallowly buried, and there are a large number of shallow heavy oil resources distributed at home and abroad. In the 21st century, new technologies and processes for heavy oil exploitation have been greatly developed, and conventional thermal recovery technology has been further matched and improved, and the utilization rate and recovery rate of heavy oil resources have been greatly improved. Abroad, the thickness of the heavy oil reservoir developed by steam injection is generally 10-40m, and the viscosity of crude oil in steam-driven reservoirs is basically within 10000mPa·s. For natural asphalt with a viscosity exceeding 10000mPa·s (called super-heavy oil in China), generally only steam huff-and-puff production is used. The most popular heavy oil exploitation technology abroad is horizontal well steam-assisted gravity drainage (SAGD), which has good adaptability to thick super-heavy oil reservoirs, and field tests have also achieved good results. Moreover, with the advancement of technology, the boundaries of heavy oil exploitation are developing towards a trend of relaxation, such as the thickness of the oil layer is reduced to 20ft (6m), and the viscosity of crude oil (underground conditions) is increased to 15000mPa.s.

[0003] In China, the burial depth of heavy oil fields is 90-1100m, and most of them are less than 500m. The thickness of a single oil layer is 1-4m, and the thickness of a combined layer is 3-15m. The viscosity of degassed crude oil at the oil layer temperature is 90-160000mPa·s. The pure total thickness ratio of the oil layer is about 0.5, and the area of ​​the oil sand body is generally 0.1-0.5km. 2 These heavy oil reservoirs are characterized by being "shallow, thin, thick, scattered, and small", with low resource grade, and basically fail to meet the heavy oil steam injection production standards at home and abroad. After technical breakthroughs, Henan Oilfield has achieved success in steam injection technology for this type of low-grade heavy oil reservoirs, and has achieved certain economic benefits. The steam injection production screening standards and development procedures suitable for the characteristics of this oilfield have been established, which has greatly broadened the heavy oil production field and successfully put heavy oil resources with a thickness of about 3m into industrial development.

[0004] Since 1994, the development of heavy oil in Henan Oilfield has mainly relied on high-cycle steam throughput optimization production technology and infill well steam throughput production technology. The average recovery rate has increased from 13.7% to 22.3%, and the annual throughput oil-steam ratio has reached 0.35-0.40, accumulating rich experience in the development of shallow thin-layer heavy oil at home and abroad. At present, most of the unused reserves of heavy oil are difficult to recover with low grade and poor efficiency, such as narrow strip-shaped edge-water heavy oil reservoirs, which have narrow oil-bearing width, small oil-bearing area, and oil layer distribution obviously controlled by faults. Vertically, they are distributed in a "roof-like" manner along the faults, and in a "shingled" manner in the plane. Due to the limitations of mining methods and process technology, there are two problems in the conventional vertical well steam injection and huff-and-puff development: First, due to the low degree of vertical superposition of oil layers, few oil layers are encountered in a single well, the controlled reserves of a single well are low, and the development efficiency is poor; second, due to the narrow oil-bearing width and the close proximity of the oil well to the oil-water boundary, the steam injection process is prone to cause the steam and edge water to communicate, resulting in finger-like invasion of edge water, low sweep coefficient, and low recovery rate. Summary of the invention

[0005] The purpose of the present invention is to provide a development method for an imbricate narrow strip edge water heavy oil reservoir, so as to solve the problems of low recovery rate and poor effect in the current development of imbricate narrow strip edge water heavy oil reservoir.

[0006] In order to solve the above technical problems, the present invention provides a method for developing an imbricate narrow strip edge water heavy oil reservoir, the method comprising the following steps:

[0007] 1) Determine the position of the horizontal section of the horizontal well in the oil layer to be developed based on the vertical production degree of the oil layer, the utilization rate of injected heat energy and the maximum recovery rate;

[0008] 2) According to the thickness of the oil layer to be developed, the relationship between the length of the horizontal well and the thickness of the oil layer is used, and the length of the horizontal section of the horizontal well is determined by combining numerical simulation, the actual production effect of the horizontal well and the temperature measurement profile;

[0009] 3) Determine the distance of the horizontal section of the horizontal well from the fault and edge water based on the development effect of the horizontal wells that have been put into production at different distances from the edge water and from the fault;

[0010] 4) Determine the injection and production parameters of the oil layer to be developed through numerical simulation and the development effect of the injection and production parameters of the horizontal wells that have been put into production; the injection and production parameters include the steam injection volume. The steam wave and volume of the horizontal well are optimized based on the development experience of the vertical well, and the calculation formula of the steam injection volume is obtained. The calculation formula is:

[0011] Q P =h*(120+240L / πr)

[0012] Among them, Q P is the steam injection volume of the horizontal well, h is the target layer thickness, L is the horizontal section length, and r is the sweep radius;

[0013] 5) Develop the oil layer according to the position of the horizontal section of the horizontal well in the oil layer to be developed, the length of the horizontal section of the horizontal well, the injection and production parameters, and the distance of the horizontal section of the horizontal well from the fault and the edge water.

[0014] The present invention is aimed at imbricate narrow strip edge water heavy oil reservoirs, and uses the data of the development wells that have been put into production and the results of numerical simulation to analyze, and uses the vertical utilization degree of the oil layer, the thermal energy utilization rate and the recovery rate as indicators to determine the position of the horizontal section in the oil layer; then the length of the horizontal section and the distance from the fault and the edge water are determined according to the situation of the oil reservoir itself; finally, the injection and production parameters of the oil layer to be developed are determined by numerical simulation and combined with the injection and production parameters of the horizontal wells that have been put into production. The present invention fully considers the characteristics of imbricate narrow strip edge water heavy oil reservoirs, adopts the development method of horizontal wells, and determines the method of horizontal well development through numerical simulation and the development effect of the horizontal wells that have been put into production, thereby maximizing the utilization degree and recovery rate of imbricate narrow strip edge water heavy oil reservoirs.

[0015] Furthermore, the injection-production parameters in step 4) also include injection-production ratio, steam injection intensity and liquid drainage rate.

[0016] Furthermore, in step 4), when determining the injection-production ratio, the steam throughput development effect under different production-injection ratios is numerically simulated, and the production-injection ratio corresponding to the best steam throughput development effect is selected.

[0017] Furthermore, the selected production-injection ratio is 1.1-1.3.

[0018] Further, the determined steam injection intensity is 10-25, in units of t / m.

[0019] Further, the determined drainage rate is 15-20, in units of t / d.

[0020] Furthermore, the position of the determined horizontal section in the oil layer to be developed is the middle and lower part of the oil layer.

[0021] Furthermore, the determined length of the horizontal section of the horizontal well is 70-100 m.

[0022] Furthermore, the determined horizontal section of the horizontal well is more than 45 m away from the fault and more than 15 m away from the edge water. BRIEF DESCRIPTION OF THE DRAWINGS

[0023] Figure 1 It is a flow chart of the development method of the imbricate narrow strip edge water heavy oil reservoir of the present invention;

[0024] Figure 2 This is a comparison diagram of the development effects of horizontal wells and vertical wells in the same layer of a certain oil reservoir in the first year in an embodiment of the present invention;

[0025] Figure 3 Schematic diagram of the influence of different well types on edge water in an embodiment of the present invention;

[0026] Figure 4 1 is a schematic diagram comparing the production of different well types in an embodiment of the present invention;

[0027] Figure 5 1 is a schematic diagram comparing the development effects of horizontal wells at different vertical positions in an embodiment of the present invention;

[0028] Figure 6 Schematic diagram of the effect of horizontal segment length on throughput effect in an embodiment of the present invention;

[0029] Figure 7 Schematic diagram of the relationship between the oil production of a horizontal well and the perforation length in an embodiment of the present invention;

[0030] Figure 8 Schematic diagram of the relationship between temperature, pressure distribution and permeability of a horizontal well in an embodiment of the present invention;

[0031] Figure 9a is a scatter plot of production effects of horizontal wells at different distances from edge water in an embodiment of the present invention;

[0032] Figure 9b is a scatter plot of production effects of horizontal wells at different distances from the fault in an embodiment of the present invention;

[0033] Fig.10 is a periodic production curve diagram of a horizontal well in an oil reservoir in an embodiment of the present invention;

[0034] Fig.11 Schematic diagram of the effect of production-injection ratio on steam throughput development index in an embodiment of the present invention;

[0035] Fig.12 is a schematic diagram of optimizing the critical discharge velocity of a horizontal well in an embodiment of the present invention;

[0036] Fig.13 1 is a schematic diagram of the calculation principle of the theoretical steam injection volume of a horizontal well in an embodiment of the present invention;

[0037] Fig.14 Schematic diagram of the relationship between the steam injection volume and the degree of recovery in an embodiment of the present invention;

[0038] Fig.15 Schematic diagram of optimization of gas injection intensity in horizontal wells in an embodiment of the present invention. DETAILED DESCRIPTION

[0039] The specific implementation of the present invention will be further described below in conjunction with the accompanying drawings.

[0040] In view of the problem that the current edge water heavy oil reservoirs with small fault blocks, thin thickness and narrow width are affected by technology and benefits, resulting in a relatively low degree of production, the present invention uses a fine description of the reservoir to accurately describe the fault occurrence and the location of the oil-water boundary, conducts reservoir engineering research, and optimizes reasonable development methods and injection and production parameters. The horizontal well development method is used to maximize the production degree, recovery rate and economic benefits of the imbricate narrow strip edge water heavy oil reservoir. The implementation process of this method is as follows Figure 1 As shown, the specific steps include the following steps.

[0041] 1. Conduct research on adaptability of different well types

[0042] In view of the characteristics of imbricate edge water reservoirs, the present invention has carried out a study on the adaptability of different well types, including horizontal wells, directional wells and vertical wells, as shown in Table 1 and Figure 2 As shown, it can be seen that the oil production rate and production degree of horizontal wells are much higher than those of directional wells and vertical wells; the present invention also studies the influence of different well types on edge water, such as Figure 3 As shown in the figure, it can be seen that when using vertical wells to develop edge water reservoirs, the pressure drop is point-type, and edge water fingering occurs at different pressure relief points, causing loss of available reserves, thereby affecting the recovery rate. However, when using horizontal wells to develop, the edge water advances evenly, which can increase the reserve sweep coefficient and thus improve the recovery rate. The production composition of different well types is shown in Figure 1. Figure 4 shown.

[0043] Table 1

[0044]

[0045] Since the fault dip angle of the imbricate edge water reservoir is relatively gentle, the vertical overlap degree of the oil layer is low and the oil-bearing width is narrow, which limits the development efficiency of vertical wells. In view of the geological characteristics of this oil reservoir and the research results of different well types, the present invention preferably uses horizontal wells to further suppress the advance of edge water, thereby further improving the recovery rate of this type of oil reservoir development.

[0046] 2. Conduct research on the optimal design of horizontal well deployment in narrow strip-shaped edge-water heavy oil reservoirs

[0047] The development effect of horizontal wells is closely related to the deployment conditions. The maximum oil drainage volume determines the single well production and benefits. The factors affecting the oil drainage volume mainly include the thickness of the deployed layer, the length of the horizontal section oil drainage, the distance from the fault and the edge water, and the position of the horizontal section in the oil layer. The present invention designs the deployment of horizontal wells in combination with the actual production effect of the horizontal wells that have been put into production.

[0048] 2-A: The best position of a horizontal well in an oil reservoir is the position where the oil layer has the highest vertical utilization, injection heat utilization rate and recovery rate:

[0049] In selecting the location of the horizontal well section, in addition to considering the interlayer, heterogeneity and sedimentary rhythm, factors such as the better heating effect of the upper part of the horizontal section than the lower part due to the overburden effect of injected steam, the gravity drainage of heavy oil and the heat loss to the cap and bottom layers should also be considered. The development effect of the horizontal section at different positions in the oil layer when the oil layer thickness is 5m was numerically simulated, such as Figure 5 As shown. The simulation shows that when the oil layer thickness is 5m, the horizontal section is most suitable at 2 / 3 of the distance from the top of the oil layer, with the minimum heat loss and the highest peak production and recovery rate. Therefore, in order to ensure better utilization of the oil layer, the present invention designs the horizontal section in the middle and lower part of the oil layer. As a preferred method, the horizontal section is deployed at 2 / 3 of the distance from the top of the oil layer.

[0050] 2-B: Determine the length of the horizontal section of the horizontal well based on the heat utilization rate and reservoir thickness:

[0051] Heat utilization is a key issue in the optimization of horizontal well section length for heavy oil thermal recovery. Steam injection thermal recovery horizontal wells are affected by heat loss in the straight and inclined wellbore sections and heat absorption in the horizontal section, which causes the terminal heating effect to deteriorate. Limited by reservoir conditions, steam injection, and oil production process conditions, for reservoirs with different oil layer depths, thicknesses, and crude oil viscosities, the length of the horizontal section is not the longer the better, but there is an optimal horizontal section length. According to numerical simulation, actual production effects of horizontal wells, and temperature measurement profile analysis, the horizontal well can achieve better development effects when the length of the horizontal section is between 70-100m. With the increase of the length of the production section, the daily production effect of the horizontal well has not shown significant improvement. The preferred horizontal section of the heavy oil reservoir is 70-100m. According to the specific thickness conditions, an optimization chart for the length and thickness of horizontal wells was established.

[0052] The numerical simulation is as follows Figure 6 As shown in the figure, the numerical simulation results show that 200m has no obvious advantage over 150m, so the optimal length of the thermal recovery horizontal well section is 150m. Since the process of numerical simulation failed to take into account the process conditions and specific heat loss in the actual production process. From the actual effect analysis of the normal horizontal wells that have been put into production, as the length of the perforation section increases, the oil production of the horizontal well stage has an upward trend. When the length reaches about 80 meters, the production no longer increases (such as Figure 7 According to actual temperature monitoring, it can be found that when the horizontal section length is greater than 80 meters, the temperature has an inflection point (as shown in Figure 8 As shown). Therefore, according to the numerical simulation and actual production in the present invention, the preferred horizontal section length is 70-100 meters.

[0053] 2-C: Determine the location of the horizontal section of the horizontal well in the reservoir:

[0054] In narrow strip oil reservoirs, the distance between the horizontal well and the fault and edge water should be considered. If the distance is too close to the fault, the excessive pressure during steam injection and huff-and-puff can easily cause the fault to open, affecting the gas injection effect; if the distance is too close to the edge water, it can easily cause the edge water to point forward or tongue forward, affecting the recovery rate. Therefore, the present invention uses the data of the horizontal wells that have been put into production, and through comparative analysis, it is found that when the distance between the horizontal well and the edge water is greater than or equal to 45 meters and the distance to the fault is greater than or equal to 15 meters, better development effects can be obtained. Figure 9a and Figure 9b To this end, when determining the position of the horizontal section of the horizontal well, the present invention sets the position of the horizontal section of the horizontal well at a position greater than or equal to 15 meters away from the fault and greater than or equal to 45 meters away from the edge water.

[0055] 3. Determine the injection and production parameters for horizontal well development

[0056] The main injection-production parameters that affect the development effect when developing horizontal wells in narrow strip oil reservoirs include production-injection ratio, steam injection volume and liquid discharge volume. The present invention uses numerical simulation technology and production dynamic data to comprehensively optimize the development effect under different injection-production parameter conditions, thereby determining the corresponding injection-production parameters.

[0057] 3-A: Determine the production-injection ratio:

[0058] If the production-injection ratio is too large, it will easily cause pressure drop and formation depletion in the near-wellbore area. For edge-water reservoirs, it may form a funnel, causing rapid advancement of edge water. If the production-injection ratio is too small, it will easily cause underground water accumulation, and it will be difficult for steam to affect the oil layer. Therefore, a reasonable production-injection ratio is very important for horizontal well development.

[0059] This embodiment obtains the production dynamic data of the developed wells, and obtains the normalized horizontal well period production curve, such as Fig.10 As shown, it can be seen that the first cycle has a better effect. In this cycle, the daily oil production of a single well is 9.3t, the oil-gas ratio is 1.07, and the water content is 41%. From the first cycle to the second cycle, the decrease is large, the daily oil production is about to reach 6.3t, the oil-gas ratio is reduced to 0.46, and the water content rises to 59%. The main reason for the large decrease is that the production-injection ratio of the first cycle is too large (1.8). For this reason, under the same environment, by adjusting the production-injection ratio of the first cycle, it is found that the production effect of subsequent cycles is stable. By comparison, it is found that when the production-injection ratio of cycles 1-5 is controlled at about 1.1, the cycle development effect is relatively stable. Therefore, according to the above analysis, the present invention adjusts the reasonable production-injection ratio of the first 5 cycles of the horizontal well to 1.1-1.3 to ensure the heating effect of steam and the utilization of edge water energy.

[0060] In order to further verify the rationality of the above-determined production-injection ratio, the present invention also simulates the development effect of steam huff-and-puff under different production-injection ratios by numerical simulation. The results are as follows: Fig.11As shown, the simulation results show that when the production-injection ratio is greater than 1.5, due to the large production pressure difference, the edge water advancement speed is accelerated, resulting in a rapid increase in the water content of the oil well, a decrease in the cumulative production of the oil well, and a poor development effect. The production-injection ratio needs to be set below 1.5. Therefore, through production and numerical simulation, the present invention sets the production-injection ratio of horizontal wells to 1.1-1.3.

[0061] 3-B: Determine the drainage speed:

[0062] High temperature and fast production are important measures to ensure heavy oil production. In order to reduce heat loss during recovery, the larger the drainage volume, the better. However, in order to suppress the intrusion of edge water and maintain energy, the drainage volume should not be too large. Therefore, it is necessary to determine a reasonable drainage speed.

[0063] According to the actual development effect of three horizontal wells developed in the same layer, when the maximum drainage volume is 13t / d, 20t / d and 27t / d, the cumulative oil production below 40% water cut is 1656t, 1672t and 1412t respectively. The specific change values ​​are shown in Table 2. It can be seen that it is most appropriate to control the maximum drainage speed at around 15-20t / d. When the water cut rises, in order to suppress the edge water advance, the maximum drainage speed should be appropriately reduced. When the water cut rises to more than 40%, the maximum drainage speed needs to be controlled at 15t / d. The numerical simulation results are shown in Fig.12 As shown in the figure, the critical drainage rate (maximum drainage rate) of steam stimulation of horizontal wells is 20-25t / d. In general, numerical simulation considers that the reservoir is relatively homogeneous, and the steam absorption and drainage effect is better, which is used as a guiding parameter for initial trial production. However, in the actual production process, the actual effect is affected by the heterogeneity of the reservoir, resulting in a decrease in the actual effect relative to the numerical simulation result. Therefore, an optimized value is selected by combining the results of the two, and the value given in this embodiment is 15-20t / d.

[0064] Table 2

[0065]

[0066] 3-C: Determine the periodic steam injection amount:

[0067] The steam injection volume is optimized mainly based on the swept volume of the steam, taking into account the length of the horizontal section and the thickness of the target layer. Based on the development experience of vertical wells, the steam injection volume per unit volume (m 3 ) Steam injection volume. The reasonable steam injection volume is calculated based on the steam wave volume of the horizontal well. The calculation principle is as follows: Fig.13 As shown in the figure, Qz is the steam injection volume of the vertical well, Qp is the steam injection volume of the horizontal well, K is the steam injection coefficient, L is the length of the horizontal section, and r is the sweep radius = 50m.

[0068] The degree of recoverable reserves in the perforation section is an indicator to measure whether a horizontal well can reach its own oil production. The higher the value, the better the development effect of the horizontal well. For this reason, the difference between the actual steam injection amount and the theoretical steam injection amount is used as the horizontal axis, and the degree of recoverable reserves in the perforation section is used as the vertical axis to obtain the relationship between the two, such as Fig.14 As shown in the figure, it is found through the intersection diagram that with the increase of the difference, the recovery degree of the horizontal well perforation section shows an obvious upward trend. When the theoretical steam injection amount is equal to the actual steam injection amount, the recovery degree of the horizontal well reaches a peak. With the continuous increase of the steam injection amount, the recovery degree of the horizontal well not only does not increase, but also shows a downward trend, which illustrates the reliability of the theoretical steam injection amount. Therefore, according to the actual and theoretical calculations, the present invention sets the gas injection intensity of the horizontal well to 10-25 (t / m).

[0069] Based on the horizontal well section length of 110 meters and the oil layer thickness of 4 meters, the steam injection volume is unchanged, and the steam huff and puff development indicators of the first four cycles of five different steam injection intensities of 10, 15, 20, 25, and 30 t / m are simulated, as shown in Table 3 and Fig.15 As shown, it can be seen that a steam injection intensity of 20-25t / m can achieve a relatively good development effect, with a relatively high oil-gas ratio and net oil production. Through the above process, the present invention can determine the position parameters and injection-production parameters of the horizontal well.

[0070] Table 3

[0071]

[0072] The scheme and effect of the present invention are described below with reference to a specific example. This example uses an oil reservoir of the H2Ⅲ1-H3Ⅲ4 layer system in a certain block, which has a burial depth of 421.0-793.9m and an oil-bearing area of ​​0.69km 2 , with geological reserves of 4.056 million tons. Due to the control of faults, the oil layers are distributed in narrow strips along the faults. The oil reservoirs are characterized by high crude oil viscosity, small oil-bearing area, narrow oil-bearing width and active edge water.

[0073] Conventional depressurization was used in the initial stage, and 1.557 million tons of geological reserves were used, with a reserve utilization rate of 38.4%. There are still 249.9×104t of reserves that have not been used. The unused reserves are mainly distributed in oil layers with high crude oil viscosity and narrow oil-bearing width. The produced layers of the reservoir (vertical well type) are produced by screw pump depressurization based on natural energy. The initial effect of oil well production is good, with an average daily oil production of 4.28t per well. However, the oil wells see water early, 1-4 months, and the water content rises quickly, with a rise rate of 8-25%. The oil production rate is low (only 0.74%), the comprehensive water content is high (78.4% on average), the oil production per well is low (0.84 tons / day), the recovery degree is low (6.28%), and the development effect is poor.

[0074] Based on the research results of the present invention, single oil layers H2Ⅲ3, H3Ⅰ1, 2 with an oil layer thickness greater than 3m and an oil-bearing width greater than 110m are preferred. 1 , 2 2 3. 12 horizontal wells were deployed in six sub-layers of H3Ⅲ4 for steam injection and huff-and-puff development. The initial peak oil production of steam injection and huff-and-puff was 19.4-40.6 tons, which is 3.9-8.2 times that of the surrounding vertical wells. The production capacity was 9-15 tons, which is 3-5 times that of the surrounding vertical wells. The oil-gas ratio was 1.07, and the development effect was good. As of December 31, 2021, the 12 horizontal wells had cumulatively injected 308,000 tons of steam, produced 108,000 tons of oil, had a comprehensive water content of 82.5%, an oil-gas ratio of 0.35, an average daily oil production of 4.5 tons per well, and a water recovery rate of 95%. The average daily oil production of the 12 horizontal wells was between 2.3 and 4.1 tons, and the cumulative oil production of a single well was between 2,872 and 17,345.7 tons, with a comprehensive water content of 47.2-85.6%. Calculated based on the controlled reserves of 263,000 tons, the oil production rate was 4.8%, the recovery degree was 34.6%, and the development effect was good.

[0075] The above examples prove that the horizontal well production method adopted in the present invention can improve the production rate of imbricate narrow strip edge water heavy oil reservoirs.

Claims

1. A method for developing an imbricate narrow strip edge water heavy oil reservoir, characterized in that: The method comprises the following steps: 1) Determine the location of the horizontal section of the horizontal well in the oil layer to be developed based on the vertical production degree of the oil layer, the utilization rate of injected heat energy and the maximum recovery rate; 2) According to the thickness of the oil layer to be developed, the length of the horizontal section of the horizontal well is determined by using the relationship between the length of the horizontal well and the thickness of the oil layer, combining numerical simulation, the actual production effect of the horizontal well and the temperature measurement profile; 3) Determine the distance of the horizontal section of the horizontal well from the fault and edge water based on the development effect of the horizontal wells that have been put into production at different distances from the edge water and from the fault; 4) Determine the injection and production parameters of horizontal wells through numerical simulation; the injection and production parameters include the steam injection volume. The steam wave volume of horizontal wells is optimized based on the development experience of vertical wells, and the calculation formula of steam injection volume is obtained. The calculation formula is: Q P =h*(120+240L / πr) Among them, Q P is the steam injection volume of the horizontal well, h is the target layer thickness, L is the horizontal section length, and r is the sweep radius; 5) Develop the oil layer to be developed based on the position of the horizontal section of the horizontal well in the oil layer to be developed, the length of the horizontal section of the horizontal well, the injection and production parameters, and the distance of the horizontal section of the horizontal well from the fault and the edge water.

2. The development method of the imbricate narrow strip edge water heavy oil reservoir according to claim 1, characterized in that: The injection and production parameters in step 4) also include the production and injection ratio, steam injection intensity and liquid drainage speed.

3. The method for developing an imbricate narrow-strip edge-water heavy oil reservoir according to claim 2, characterized in that: In the step 4), when determining the injection-production ratio, the steam huff-and-puff development effects under different production-injection ratios are numerically simulated, and the production-injection ratio corresponding to the best steam huff-and-puff development effect is selected.

4. The development method of the imbricate narrow strip edge water heavy oil reservoir according to claim 3, characterized in that: The selected production-injection ratio is 1.1-1.

3.

5. The method for developing an imbricate narrow strip edge water heavy oil reservoir according to claim 2, characterized in that: The determined steam injection intensity is 10-25, in units of t / m.

6. The method for developing an imbricate narrow-strip edge-water heavy oil reservoir according to claim 2, characterized in that: The determined drainage rate is 15-20, in t / d.

7. The method for developing an imbricate narrow-strip edge-water heavy oil reservoir according to claim 1, characterized in that: The position of the determined horizontal section in the oil layer to be developed is the middle and lower part of the oil layer.

8. The method for developing an imbricate narrow strip edge water heavy oil reservoir according to claim 1, characterized in that: The determined length of the horizontal section of the horizontal well is 70-100m.

9. The method for developing an imbricate narrow-strip edge-water heavy oil reservoir according to claim 1, characterized in that: The determined horizontal well section is more than 45m away from the fault and more than 15m away from the edge water.

Images