A method for determining an oil and gas production mode and related equipment

Abstract

The application discloses an oil and gas exploitation mode determination method and related equipment. The method comprises the following steps: acquiring geological information and historical exploitation information of a first injection well and a first production well in a first well area; calculating a static connectivity coefficient and a producing connectivity coefficient of a target layer section according to the geological information and the historical exploitation information; and determining an exploitation mode of the first injection well and the first production well in the target layer section based on the static connectivity coefficient and the producing connectivity coefficient. The method provided in the application acquires geological information and historical exploitation information of production wells and injection wells in a well area, and the static connectivity coefficient and the producing connectivity coefficient can well represent the remaining exploitation potential of the well area, and can well guide subsequent work of oil and gas exploitation, so that a correct exploitation mode can be determined, oil and gas production capacity can be improved, resources can be fully developed, and the economy of exploitation can be improved.

Description

Technical Field

[0001] This specification relates to the field of oil and gas extraction, and more specifically, to a method for determining oil and gas extraction methods and related equipment. Background Technology

[0002] As oilfield development progresses to the mid-to-late stages, heavy oil development has become an important source of production capacity. Crude oil with high viscosity and density is called heavy oil. Heavy oil faces significant flow resistance, making it difficult to flow from the reservoir into the wellbore or to be lifted from the wellbore to the surface. Currently, methods such as chemical flooding, fire flooding, and steam flooding can be used to extract heavy oil.

[0003] Current technologies rely on connectivity to guide heavy oil extraction methods such as chemical flooding, fire flooding, and steam flooding. However, existing connectivity data is only used for estimation based on geological characteristics. Since oilfield development has reached the mid-to-late stages and the cost of heavy oil extraction is relatively high, determining the remaining oil and gas reserves in already extracted wells and adjusting extraction methods accordingly are crucial factors affecting the economics of oil and gas extraction. Currently, there is no reliable method for this. Summary of the Invention

[0004] The summary section introduces a series of simplified concepts, which will be further explained in detail in the detailed description section. The summary section of this invention is not intended to limit the key features and essential technical features of the claimed technical solution, nor is it intended to determine the scope of protection of the claimed technical solution.

[0005] In order to accurately determine the remaining oil and gas reserves in the wellbore during the middle and late stages of oilfield development and to make reasonable adjustments to the well's development method, the present invention proposes, in a first aspect, a method for determining the oil and gas development method, the method comprising:

[0006] Obtain geological and historical mining information for the first injection well and the first production well in the first well area;

[0007] Calculate the static connectivity coefficient and dynamic connectivity coefficient of the target stratum based on the above geological information and historical mining information.

[0008] Based on the aforementioned static connectivity coefficient and the aforementioned dynamic connectivity coefficient, the mining methods of the aforementioned first injection well and the aforementioned first production well in the aforementioned target stratum are determined.

[0009] Optionally, the aforementioned geological information includes connectivity thickness and interpretation layer thickness, the aforementioned historical mining information includes historical perforation information, and the aforementioned calculation of the static connectivity coefficient and dynamic connectivity coefficient of the target layer based on the aforementioned geological information and the aforementioned historical mining information includes:

[0010] The static connectivity coefficient of the target segment is obtained based on the aforementioned connectivity thickness and the aforementioned interpretation layer thickness.

[0011] The aforementioned active connectivity coefficient of the target segment is obtained using the aforementioned perforation information, the aforementioned connectivity thickness, and the aforementioned interpretation layer thickness.

[0012] Optionally, obtaining the activated connectivity coefficient of the target segment through the perforation information, the connectivity thickness, and the interpretation layer thickness includes:

[0013] Determine the perforation connection segment based on the above perforation information;

[0014] The average value of the ratio of the perforation connection thickness of the first production well and the first injection well to the thickness of the interpretation layer is the above-mentioned operational connectivity coefficient.

[0015] Optionally, the exploitation methods of the first injection well and the first production well in the target formation are determined based on the aforementioned static connectivity coefficient and the aforementioned dynamic connectivity coefficient, including:

[0016] If the difference between the static connectivity coefficient and the dynamic connectivity coefficient is greater than a preset coefficient, additional perforations are added at the corresponding positions of the target layers of the first injection well and the first production well.

[0017] Optionally, the above methods also include:

[0018] Given that the first production well is located on the common boundary between the first well area and the second well area, the geological information and historical mining information of the second injection well are obtained, wherein the second injection well is an injection well in the second well area;

[0019] The mining methods of the first production well, the first injection well, and the second injection well are obtained based on the geological information and historical mining information of the first production well, the first injection well, and the second injection well.

[0020] Optionally, the above methods also include:

[0021] Based on the geological information and historical mining information of the first injection well and the first production well, the first static connectivity coefficient and the first dynamic connectivity coefficient are calculated.

[0022] The extraction method of the first injection well in the target stratum is determined based on the first static connectivity coefficient and the first dynamic connectivity coefficient.

[0023] Optionally, the above methods also include:

[0024] The second static connectivity coefficient and the second dynamic connectivity coefficient are calculated based on the geological information and historical mining information of the second injection well and the first production well.

[0025] The extraction method of the second injection well in the target stratum is determined based on the second static connectivity coefficient and the second dynamic connectivity coefficient.

[0026] Optionally, the above methods also include:

[0027] The mining method of the first production well in the target stratum is determined based on the first static connectivity coefficient, the first operational connectivity coefficient, the second static connectivity coefficient, and the second operational connectivity coefficient.

[0028] Optionally, the above geological information may also include the permeability of the connected sections;

[0029] The above methods also include:

[0030] The seepage index is calculated based on the permeability of the connected segment, the thickness of the connected segment, and the perforation information.

[0031] The above-mentioned methods for determining the extraction of the first injection well and the first production well in the target formation based on the static connectivity coefficient and the dynamic connectivity coefficient include:

[0032] Based on the aforementioned static connectivity coefficient, the aforementioned mobilization connectivity coefficient, and the aforementioned seepage index, the mining methods of the aforementioned first injection well and the aforementioned first production well in the aforementioned target stratum are determined.

[0033] Optionally, the above-mentioned determination of the exploitation methods of the first injection well and the first production well in the target formation based on the static connectivity coefficient, the kinetic connectivity coefficient, and the seepage index includes:

[0034] If the difference between the static connectivity coefficient and the dynamic connectivity coefficient is greater than the preset coefficient and the seepage index is greater than the preset index, additional perforations are added at the corresponding positions of the target layers of the first injection well and the first production well.

[0035] Secondly, the present invention also proposes an oil and gas extraction method determination device, comprising:

[0036] The acquisition unit is used to acquire geological information and historical mining information of the first injection well and the first production well in the first well area;

[0037] The calculation unit is used to calculate the static connectivity coefficient and dynamic connectivity coefficient of the target layer based on the above geological information and the above historical mining information.

[0038] The determining unit is used to determine the mining method of the first injection well and the first production well in the target stratum based on the static connectivity coefficient and the dynamic connectivity coefficient.

[0039] Thirdly, an electronic device includes: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program stored in the memory to implement the steps of the method for determining the oil and gas extraction method as described in any of the first aspects above.

[0040] Fourthly, the present invention also proposes a computer-readable storage medium having a computer program stored thereon, wherein the computer program, when executed by a processor, implements the method for determining the oil and gas extraction method of any of the above claims in the first aspect.

[0041] In summary, the method for determining oil and gas extraction methods proposed in this application includes: acquiring geological information and historical extraction information of the first injection well and the first production well in the first well area; calculating the static connectivity coefficient and dynamic connectivity coefficient of the target formation based on the geological information and historical extraction information; and determining the extraction method of the first injection well and the first production well in the target formation based on the static connectivity coefficient and dynamic connectivity coefficient. The method provided in this application, by reasonably dividing the well area and acquiring geological information and historical extraction information of the production wells and injection wells within the well area, quantitatively calculates the static connectivity coefficient and dynamic connectivity coefficient using the geological information and historical extraction information. The static connectivity coefficient can indirectly represent the inherent recoverable quantity, and the dynamic connectivity coefficient can indirectly characterize the historical extraction quantity. The static connectivity coefficient and dynamic connectivity coefficient can effectively characterize the remaining extraction potential of the well area and can effectively guide subsequent oil and gas extraction work, so as to determine the correct extraction method, improve oil and gas production capacity, fully develop resources, and enhance the economic efficiency of extraction.

[0042] The method for determining oil and gas extraction methods of the present invention, and other advantages, objectives and features of the present invention will be partly apparent from the following description, and partly understood by those skilled in the art through study and practice of the present invention. Attached Figure Description

[0043] Various other advantages and benefits will become apparent to those skilled in the art upon reading the following detailed description of preferred embodiments. The accompanying drawings are for illustrative purposes only and are not intended to limit this specification. Furthermore, the same reference numerals denote the same parts throughout the drawings. In the drawings:

[0044] Figure 1 This is a schematic flowchart of a method for determining oil and gas extraction methods provided in an embodiment of this application;

[0045] Figure 2A schematic diagram of an oilfield well layout provided for an embodiment of this application;

[0046] Figure 3 This is a schematic diagram illustrating the principle of determining an oil and gas extraction method, provided in an embodiment of this application.

[0047] Figure 4 This is a schematic diagram illustrating the principle of another oil and gas extraction method provided in the embodiments of this application;

[0048] Figure 5 This is a schematic diagram illustrating the principle of another oil and gas extraction method provided in the embodiments of this application;

[0049] Figure 6 This is a schematic diagram of an oil and gas extraction method determination device provided in an embodiment of this application;

[0050] Figure 7 This is a schematic diagram of an electronic device structure for determining an oil and gas extraction method, provided in an embodiment of this application. Detailed Implementation

[0051] In summary, the method provided in this application, by reasonably dividing the well area and obtaining geological and historical mining information of production and injection wells within the well area, quantitatively calculates the static connectivity coefficient and the dynamic connectivity coefficient using the geological and historical mining information. The static connectivity coefficient can indirectly represent the inherent recoverable quantity, and the dynamic connectivity coefficient can indirectly characterize the historical mining quantity. The static and dynamic connectivity coefficients can effectively characterize the remaining mining potential of the well area and can effectively guide subsequent oil and gas mining work, so as to determine the correct mining method, improve oil and gas production capacity, fully develop resources, and enhance the economics of mining.

[0052] The terms "first," "second," "third," "fourth," etc. (if present) in the specification, claims, and accompanying drawings of this application are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus. The technical solutions of the embodiments of this application will now be clearly and completely described in conjunction with the accompanying drawings. Obviously, the described embodiments are only a part of the embodiments of this application, and not all of them.

[0053] Please see Figure 1 This is a schematic flowchart of a method for determining oil and gas extraction methods provided in an embodiment of this application, which may specifically include:

[0054] S110. Obtain geological information and historical mining information of the first injection well and the first production well in the first well area;

[0055] Specifically, as oilfield development progresses to the mid-to-late stages, heavy oil development has become a crucial area for replacing production capacity. Crude oil with high viscosity and specific gravity is called heavy oil. Heavy oil faces significant flow resistance, making it difficult to flow from the reservoir into the wellbore or to be lifted from the wellbore to the surface. Currently, methods such as chemical flooding, fire flooding, and steam flooding can be used to extract heavy oil. However, since oilfield development has reached the mid-to-late stages and the cost of heavy oil extraction is relatively high, determining the remaining oil reserves in already extracted wells and adjusting the extraction methods accordingly are crucial factors affecting the economics of oil and gas extraction. Currently, there is no reliable method for this.

[0056] The method provided in this embodiment first divides the well area according to the location relationship between injection wells and production wells, and obtains the geological information and historical mining information of injection wells and production wells within the same well area. For example... Figure 2 The image shows a well area delineation map of an oilfield belonging to the delta front subfacies sedimentary region. The development method is reverse nine-point steam drive, with a total of six well areas. It should be noted that geological information can be obtained through geological exploration, seismic exploration, drilling, logging, and well logging to acquire thickness information and oil reservoir information at different depths. Historical production information includes the perforation locations of production and injection wells. The target layer is the selected target depth range, determined based on the specific oil layer depth in the oilfield. The well area delineation and development methods are not limited to the reverse nine-point steam drive method described above; other drive methods can also be used.

[0057] S120. Calculate the static connectivity coefficient and dynamic connectivity coefficient of the target layer based on the above geological information and the above historical mining information.

[0058] Specifically, based on geological and historical production information, the connectivity between production wells and injection wells can be determined, and the static connectivity coefficient of the connectivity section can be obtained based on its geological information. The static connectivity coefficient is the average ratio of the thickness of the connecting layer to the thickness of the interpreted layer between production and injection wells, and can indirectly characterize the inherent recoverable amount of oil and gas. The operational connectivity coefficient is the average ratio of the thickness of the connecting layer to the thickness of the interpreted layer that has already been extracted by production and injection wells, and can indirectly characterize the historical extraction volume of oil and gas.

[0059] S130. Based on the above static connectivity coefficient and the above dynamic connectivity coefficient, determine the mining method of the above first injection well and the above first production well in the above target layer.

[0060] Specifically, based on the above steps, the inherent recoverable amount of oil and gas can be indirectly characterized by the static connectivity coefficient, while the historical recovery amount can be indirectly characterized by the dynamic connectivity coefficient. The remaining recoverable amount, or recovery potential, of the connecting section between the production well and the injection well can be determined using both static and dynamic connectivity coefficients. The extraction method can then be determined based on this recovery potential.

[0061] It should be noted that the terms "first production well" and "first injection well" are used for illustrative purposes only. In actual applications, injection wells within the same well area are also affected by the geological and historical mining information of other production wells within that area. Alternatively, "first production well" can be understood as a collective term for all production wells within the first well area.

[0062] In summary, the method provided in this application, by reasonably dividing the well area and obtaining geological and historical mining information of production and injection wells within the well area, quantitatively calculates the static connectivity coefficient and the dynamic connectivity coefficient using the geological and historical mining information. The static connectivity coefficient can indirectly represent the inherent recoverable quantity, and the dynamic connectivity coefficient can indirectly characterize the historical mining quantity. The static and dynamic connectivity coefficients can effectively characterize the remaining mining potential of the well area and can effectively guide subsequent oil and gas mining work, so as to determine the correct mining method, improve oil and gas production capacity, fully develop resources, and enhance the economics of mining.

[0063] In some examples, the geological information mentioned above includes connectivity thickness and interpretation layer thickness, the historical mining information mentioned above includes historical perforation information, and the calculation of the static connectivity coefficient and dynamic connectivity coefficient of the target section based on the geological information and the historical mining information mentioned above includes:

[0064] The static connectivity coefficient of the target segment is obtained based on the aforementioned connectivity thickness and the aforementioned interpretation layer thickness.

[0065] The aforementioned active connectivity coefficient of the target segment is obtained using the aforementioned perforation information, the aforementioned connectivity thickness, and the aforementioned interpretation layer thickness.

[0066] Specifically, such as Figure 3 Taking the example shown, 4-17 is the first injection well, and 3-17 is the first production well. Based on geological information, the interpretation layers of well 4-17 within the target stratum include 6 layers from 1A to 6A (the negative portion in the figure), and the interpretation layers of the first production well are 5 layers from 1B to 5B. Based on the depth and geological information of the interpretation layers of the two wells, and considering their similar geological characteristics within a certain depth error range, 1A to 1B are determined to be connecting segment 1. Correspondingly, a total of 4 connecting segments are formed between the two wells.

[0067] The connectivity thickness is the thickness of the connected segment. The connectivity thickness of well 4-17 is: h 1A +h2A +h 5A+ h 6A The thickness of the connecting section in well 3-17 is: h 1B +h 3B +h 4B+ h 5B The thickness of the layer in well 4-17 is: h 1A +h 2A +h 3A+ h 4A+

[0068] h 5A+ h 6A The thickness of the interpretable layer in well 3-17 is: h 1B +h 2B +h 3B+ h 4B+ h 5B .

[0069] The static connectivity coefficient can be expressed as:

[0070] Static connectivity coefficient = ((connection thickness of production well / interpretation layer thickness of production well) + (connection thickness of injection well / interpretation layer thickness of injection well)) / 2(1)

[0071] Taking wells 4-17 and 3-17 as examples, based on equation (1), the static connectivity coefficient of these two wells can be expressed as: ((h 1A +h 2A +h 5A+ h 6A ) / (h 1A +h 2A +h 3A+ h 4A+ h 5A+ h 6A )+(h 1B +h 3B +h 4B+ h 5B ) / (h 1B +h 2B +h 3B+ h 4B+ h 5B )) / 2.

[0072] The connectivity coefficient is used to determine which connected layers have been mined based on historical perforation information, and the connectivity coefficient of the mined layers is calculated based on the perforation information, the connected thickness, and the interpretation layer thickness.

[0073] In summary, by quantitatively calculating the static connectivity coefficient and the dynamic connectivity coefficient, the inherent production volume, already produced volume, and remaining production volume of the connecting section between two wells can be quantitatively expressed, so as to guide the subsequent production work and determine the most suitable oil and gas extraction method.

[0074] In some examples, obtaining the activated connectivity coefficient of the target segment using the perforation information, the connectivity thickness, and the interpretation layer thickness includes:

[0075] Determine the perforation connection segment based on the above perforation information;

[0076] The average value of the ratio of the perforation connection thickness of the first production well and the first injection well to the thickness of the interpretation layer is the above-mentioned operational connectivity coefficient.

[0077] Specifically, the perforation connectivity section is determined based on the perforation information. A connectivity section is defined as a section where, under the premise of connectivity, the well has perforated again in the corresponding interpretation layer, meaning that this section has already been mined. (Continuing with...) Figure 3 Taking wells 4-17 and 3-17 as examples, the interpretation layers corresponding to connecting sections 1 to 4 in well 4-17 are 1A, 2A, 5A, and 6A. Based on historical perforation information, it is determined that 1A and 2A have been perforated. Therefore, the perforated connecting sections of well 4-17 are 1A and 2A. Correspondingly, the perforated connecting sections of well 3-17 are determined to be 2B and 3B. The thickness of the perforated connecting section of well 4-17 is: h 1A +h 2A The thickness of the perforation connecting section of well 3-17 is h. 2B +h 3B .

[0078] The connectivity coefficient can be defined as the average of the ratio of the connectivity thickness of the perforated connecting sections of the production well and the injection well to the thickness of the aforementioned interpretation layer, specifically expressed by the following formula:

[0079] Utilization connectivity coefficient = ((connection thickness of the perforated connecting section of the production well / interpretation layer thickness of the production well) + (connection thickness of the perforated connecting section of the injection well / interpretation layer thickness of the injection well)) / 2 (2)

[0081] Taking wells 4-17 and 3-17 as examples, based on equation (2), the mobility coefficient of wells 4-17 and 3-17 is: ((h 1A +h 2A ) / (h 1A +h 2A +h 3A+ h 4A+ h 5A+ h 6A )+(h 2B +h3B ) / (h 1B +h 2B +h 3B+ h 4B+ h 5B )) / 2.

[0082] In summary, the operational connectivity coefficient is calculated by measuring the connectivity thickness and interpretation layer thickness of the perforated connecting sections of production wells and injection wells. The operational connectivity coefficient quantitatively represents the historical mining situation of the connecting sections.

[0083] In some examples, the exploitation methods of the first injection well and the first production well in the target formation are determined based on the aforementioned static connectivity coefficient and the aforementioned mobilization connectivity coefficient, including:

[0084] If the difference between the static connectivity coefficient and the dynamic connectivity coefficient is greater than a preset coefficient, additional perforations are added at the corresponding positions of the target layers of the first injection well and the first production well.

[0085] Specifically, the static connectivity coefficient can indirectly represent the inherent recoverable volume, while the dynamic connectivity coefficient can indirectly characterize the historical recovery volume. The difference between the static and dynamic connectivity coefficients can indirectly characterize the remaining recovery potential of the well area and quantify this potential. Based on this calculation result and combined with big data from actual production, patterns are summarized, and a reasonable preset coefficient is determined. When the coefficient is greater than the preset coefficient, adding perforations to the target layer can release the remaining recovery potential and achieve ideal economic benefits. When the coefficient is less than or equal to the preset coefficient, although there may still be some remaining recovery potential in the well area, considering the costs of adding perforations and other work, the ideal economic benefits may not be achieved. Taking wells 4-17 and 3-17 as examples, the static connectivity coefficient of both wells is calculated to be 0.85, and the dynamic connectivity coefficient is 0.42. Based on production data, the preset coefficient is 0.25 (i.e., when the difference between the static and dynamic connectivity coefficients is greater than 0.25, oil and gas production can be increased by adding perforations, achieving ideal economic benefits). The difference between the static and dynamic connectivity coefficients of the two wells is: 0.85 - 0.42 = 0.43 > 0.25. Therefore, oil and gas production can be increased by adding perforations. Furthermore, as... Figure 3 As shown, since perforations have already been performed in sections 1A, 2A, and 3B of wells 4-17 and 3-17, additional perforations have been performed in sections 5A and 6A of well 4-17 and sections 1B, 4B, and 5B of well 3-17. This can increase oil and gas production and improve the economic benefits of the well area.

[0086] In summary, production data can be used to determine reasonable preset coefficients. When the difference between the static connectivity coefficient and the dynamic connectivity coefficient is greater than the preset coefficient, oil and gas production can be increased by adding perforations at the corresponding locations in the target layer, thereby improving the economic benefits of the well area. This method can quantitatively analyze the oil and gas reservoir potential of a well area, thus providing reliable guiding parameters for determining and converting well area development methods.

[0087] In some examples, the above method also includes:

[0088] Given that the first production well is located on the common boundary between the first well area and the second well area, the geological information and historical mining information of the second injection well are obtained, wherein the second injection well is an injection well in the second well area;

[0089] The mining methods of the first production well, the first injection well, and the second injection well are obtained based on the geological information and historical mining information of the first production well, the first injection well, and the second injection well.

[0090] Specifically, such as Figure 2 As shown, during well area delineation, some production wells are located on the boundary between two injection wells. In this case, the production well's capacity is simultaneously affected by both injection wells. Therefore, the extraction method for all three wells should be comprehensively considered, taking into account the geological information and historical mining information of the two injection wells and one production well. Taking well areas 5 and 6 as examples, well 4-13 is an injection well within well area 6, well 5-13C is a production well on the boundary between well areas 1 and 2, and well 8-13 is an injection well within well area 5. The principle diagram of the extraction method for these three wells in the target formation is shown below. Figure 4 Since production well 5-13C is influenced by both wells 4-13 and 8-13, the determination of the connecting sections must be based on the geological characteristics of all three wells. Understandably, the connecting sections are defined as the strata where the geological characteristics of all three wells are consistent at a certain depth. Therefore, there are a total of three connecting sections across the three wells. Based on historical perforation information, the perforation status of each well within the connecting sections can be determined, thus identifying the perforated connecting sections for each well. Furthermore, the static and dynamic connectivity coefficients between wells 4-13 and 5-13C can be calculated using the methods described above. Similarly, the static and dynamic connectivity coefficients between wells 8-13 and 5-13C can also be calculated. Based on these static and dynamic connectivity coefficients, the remaining oil and gas storage potential between each pair of wells can be determined, and these calculation results can guide the oil and gas field's exploitation methods.

[0091] It should be noted that when a production well is located on the boundary of multiple well areas, such as well 6-14C, the well is affected by multiple injection wells. It is necessary to comprehensively consider the location information and historical mining information of the production well and multiple injection wells. The principle for determining this is similar to that of this method, and will not be elaborated here.

[0092] In summary, the method provided in this embodiment, when the production well is located on the boundary of two well zones and is affected by the injection wells in both well zones, determines the connectivity section by comprehensively considering the geological information and historical mining information of the injection wells in the two well zones and the production well. This method is more in line with the characteristics of actual production. The static connectivity coefficient and dynamic connectivity coefficient calculated based on this method can accurately guide the oil and gas extraction method.

[0093] In some examples, the above method also includes:

[0094] Based on the geological information and historical mining information of the first injection well and the first production well, the first static connectivity coefficient and the first dynamic connectivity coefficient are calculated.

[0095] The extraction method of the first injection well in the target stratum is determined based on the first static connectivity coefficient and the first dynamic connectivity coefficient.

[0096] Specifically, when a production well is located on the boundary between two well zones, the connectivity segment is determined by integrating the geological information of all three wells. The static connectivity coefficient and dynamic connectivity coefficient can be calculated separately. (The last sentence appears to be incomplete and possibly refers to a different topic.) Figure 4 Taking wells 4-13 and 5-13C as examples, after determining the connecting sections, the first static connectivity coefficient between wells 4-13 and 5-13C is determined to be 0.6 and the first dynamic connectivity coefficient is determined to be 0.5 according to the above method. The difference between the first static connectivity coefficient and the first dynamic connectivity coefficient is 0.1 < 0.25. Therefore, adding perforations will not bring good economic benefits, and the original production method should be maintained.

[0097] In summary, when a production well is located at the boundary of multiple well areas, the connectivity segment can be determined by using the geological information of multiple well areas and the production well. After determining the connectivity segment, the static connectivity coefficient and dynamic connectivity coefficient can be determined based on the combination of a production well and a injection well. This method can quantify the remaining oil and gas reserves of the first production well and the first injection well, and better guide oil and gas production.

[0098] In some examples, the above method also includes:

[0099] The second static connectivity coefficient and the second dynamic connectivity coefficient are calculated based on the geological information and historical mining information of the second injection well and the first production well.

[0100] The extraction method of the second injection well in the target stratum is determined based on the second static connectivity coefficient and the second dynamic connectivity coefficient.

[0101] Specifically, when a production well is located on the boundary between two well zones, the connectivity segment is determined by integrating the geological information of all three wells. The static connectivity coefficient and dynamic connectivity coefficient can be calculated separately. (The last sentence appears to be incomplete and possibly refers to a different topic.) Figure 4 Taking wells 8-13 and 5-13C as examples, after determining the connecting sections, the second static connectivity coefficient between wells 8-13 and 5-13C is determined to be 0.8 and the second dynamic connectivity coefficient is determined to be 0.4 according to the above method. The difference between the second static connectivity coefficient and the second dynamic connectivity coefficient is 0.4, which is greater than 0.25. Therefore, supplementing perforations can bring good economic benefits. Supplementing perforations in the first production well and the second injection well, and combining historical perforation information, can effectively increase oil and gas production by supplementing perforations in sections 1D and 4D of the first production well and sections 3E and 5E of the second injection well.

[0102] In summary, when a production well is located at the boundary of multiple well areas, the connectivity segment can be determined by using geological information from multiple well areas and the production well. After determining the connectivity segment, the static connectivity coefficient and dynamic connectivity coefficient can be determined based on the combination of a production well and a injection well. This method can quantify the remaining oil and gas reserves of the first production well and the second injection well, and better guide oil and gas production.

[0103] In some examples, the above method also includes:

[0104] The mining method of the first production well in the target stratum is determined based on the first static connectivity coefficient, the first operational connectivity coefficient, the second static connectivity coefficient, and the second operational connectivity coefficient.

[0105] Specifically, when a production well is located on the boundary of multiple well areas, the connectivity segment is determined by the geological information of multiple well areas and production wells. The production well located on the boundary is simultaneously affected by multiple injection wells. By calculating the static connectivity coefficient and dynamic connectivity coefficient of multiple sets of production wells and injection wells respectively, and superimposing the influence of multiple sets, the mining method of the first production well can be well determined.

[0106] In some examples, the geological information mentioned above also includes the permeability of connected segments;

[0107] The above methods also include:

[0108] The seepage index is calculated based on the permeability of the connected segment, the thickness of the connected segment, and the perforation information.

[0109] The above-mentioned methods for determining the extraction of the first injection well and the first production well in the target formation based on the static connectivity coefficient and the dynamic connectivity coefficient include:

[0110] Based on the aforementioned static connectivity coefficient, the aforementioned mobilization connectivity coefficient, and the aforementioned seepage index, the mining methods of the aforementioned first injection well and the aforementioned first production well in the aforementioned target stratum are determined.

[0111] Specifically, permeability is the ability of oil and gas to penetrate a geological formation, and it can be measured using many existing methods, which will not be elaborated upon here. Taking wells 4-17 and 3-17 as examples, according to the methods described above, the connected sections of wells 4-17 and 3-17 consist of four segments. The permeability of each well in these four connected segments is obtained for well 4-17: k 1A =1000mD,k 2A =900mD,k 5A =1000mD and k 6A =900mD; in well 3-17: k 1B =10mD,k 3B =900mD,k 4B =800mD and k 5B =800mD. Based on existing theories, it is believed that if the permeability difference within the same layer exceeds three times, the conductivity is very poor and can be ignored. However, the actual oil and gas permeability is also related to the thickness of the layer. Therefore, this embodiment proposes the concept of a permeability index to quantitatively evaluate the permeability of each connecting segment between two wells, thereby guiding oil and gas extraction. The permeability index can be expressed by Formula 3:

[0112] Permeability index = ((thickness of the connecting perforation in a certain section of the production well × permeability of the connecting section of the production well) + (thickness of the connecting perforation in a certain section of the injection well × permeability of the connecting section of the injection well) / 2 (3)

[0113] For example, the permeation index of connected segment 1 = (h 1A ×k 1A +k 1B ×h 1B ) / 2

[0114] Formula (3) allows for the quantitative analysis of the impact of interconnected layer thickness and permeability on production and injection wells. A preset index can be determined using actual production data. When the index is greater than the preset index, it indicates strong permeability of the interconnected layer, making it suitable for supplementary perforation work to increase oil and gas production. When the index is less than the preset index, the effort required for supplementary perforation exceeds the benefits of increased production.

[0115] For example, without considering the influence of the permeability index, based on the aforementioned calculations, additional perforations were added to sections 5A and 6A of Well 4-17 and sections 1B, 4B, and 5B of Well 3-17. However, considering the permeability index, based on actual production data, a preset index of 0.3 is considered reasonable. Calculations show that the permeability index for connected section 1 is 0.2, for connected section 2 it is 0.4, for connected section 3 it is 0.5, and for connected section 1 it is 0.43. Since the permeability index for connected section 1 is less than the preset index, no additional perforations are added to connected section 1. Therefore, adding additional perforations to sections 5A and 6A of Well 4-17 and sections 4B and 5B of Well 3-17 can achieve the effect of increasing production capacity and improving economic efficiency.

[0116] In summary, the method provided in this embodiment combines permeability with the thickness of the connecting perforation to propose the concept of a flow index, which can better indicate the oil and gas flow capacity of the connecting section. By comparing with a preset index determined by historical production data, connecting sections with strong flow capacity can be selected for supplementary perforation operations, which can effectively improve oil and gas production and increase economic benefits.

[0117] In some examples, the above-mentioned determination of the exploitation methods of the first injection well and the first production well in the target formation based on the static connectivity coefficient, the activated connectivity coefficient, and the seepage index includes:

[0118] If the difference between the static connectivity coefficient and the dynamic connectivity coefficient is greater than the preset coefficient and the seepage index is greater than the preset index, additional perforations are added at the corresponding positions of the target layers of the first injection well and the first production well.

[0119] Specifically, by comprehensively considering the static connectivity coefficient and the aforementioned dynamic connectivity coefficient and seepage index, the embodiments of this application can make a good assessment of the remaining oil and gas reserves of the target layer, and use the seepage index to characterize the oil and gas flow capacity to guide the exploitation method of each connected section.

[0120] In summary, when the difference between the static connectivity coefficient and the dynamic connectivity coefficient is greater than the preset coefficient and the seepage index is greater than the preset index, adding perforations at the corresponding positions of the target layers of the first injection well and the first production well can ensure that the remaining oil and gas reserves in the target layers of the added perforations are sufficient and that the oil and gas flowability is good enough. In this way, the potential for the remaining oil and gas extraction is quantified, which effectively guides the determination and conversion of oil and gas extraction methods.

[0121] Please see Figure 6 One embodiment of the oil and gas extraction method determination device in this application may include:

[0122] Acquisition unit 21 is used to acquire geological information and historical mining information of the first injection well and the first production well in the first well area;

[0123] Calculation unit 22 is used to calculate the static connectivity coefficient and dynamic connectivity coefficient of the target layer based on the above geological information and the above historical mining information;

[0124] The determining unit 23 is used to determine the mining method of the first injection well and the first production well in the target stratum based on the static connectivity coefficient and the dynamic connectivity coefficient.

[0125] like Figure 7 As shown, this application embodiment also provides an electronic device 300, including a memory 310, a processor 320, and a computer program 311 stored in the memory 320 and executable on the processor. When the processor 320 executes the computer program 311, it implements the steps of any of the methods for determining the oil and gas extraction methods described above.

[0126] Since the electronic device described in this embodiment is the device used to implement the oil and gas extraction method determination device in the embodiment of this application, those skilled in the art can understand the specific implementation method and various variations of the electronic device in this embodiment based on the method described in the embodiment of this application. Therefore, how the electronic device implements the method in the embodiment of this application will not be described in detail here. Any device used by those skilled in the art to implement the method in the embodiment of this application is within the scope of protection of this application.

[0127] In practical implementation, when the computer program 311 is executed by the processor, it can achieve the following: Figure 1 Any of the corresponding implementation methods in the embodiments.

[0128] It should be noted that the descriptions of each embodiment in the above embodiments have different focuses. For parts that are not described in detail in a certain embodiment, please refer to the relevant descriptions in other embodiments.

[0129] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0130] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this application. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded computer, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create a machine for implementing the flowchart illustrations. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0131] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0132] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0133] This application also provides a computer program product, which includes computer software instructions that, when executed on a processing device, cause the processing device to perform actions such as... Figure 1 The process for determining the oil and gas extraction method in the corresponding embodiment.

[0134] A computer program product includes one or more computer instructions. When the computer program instructions are loaded and executed on a computer, all or part of the flow or function according to the embodiments of this application is generated. The computer may be a general-purpose computer, a special-purpose computer, a computer network, or other programmable device. The computer instructions may be stored in a computer-readable storage medium or transmitted from one computer-readable storage medium to another. For example, computer instructions may be transmitted from one website, computer, server, or data center to another website, computer, server, or data center via wired (e.g., coaxial cable, fiber optic, digital subscriber line (DSL)) or wireless (e.g., infrared, wireless, microwave, etc.) means. The computer-readable storage medium may be any available medium that a computer can store or a data storage device such as a server or data center that integrates one or more available media. The available medium may be a magnetic medium (e.g., floppy disk, hard disk, magnetic tape), an optical medium (e.g., DVD), or a semiconductor medium (e.g., solid-state disk (SSD)).

[0135] Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working processes of the systems, devices, and units described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0136] In the several embodiments provided in this application, it should be understood that the disclosed systems, apparatuses, and methods can be implemented in other ways. For example, the apparatus embodiments described above are merely illustrative; for instance, the division of units is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the coupling or direct coupling or communication connection shown or discussed may be through some interfaces, or indirect coupling or communication connection between apparatuses or units, and may be electrical, mechanical, or other forms.

[0137] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of this embodiment according to actual needs.

[0138] Furthermore, the functional units in the various embodiments of this application can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit. The integrated unit can be implemented in hardware or as a software functional unit.

[0139] If the integrated unit is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this application, in essence, or the part that contributes to the prior art, or all or part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods of the various embodiments of this application. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0140] The above embodiments are only used to illustrate the technical solutions of this application, and are not intended to limit it. Although this application has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the foregoing embodiments, or make equivalent substitutions for some of the technical features. Such modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of this application.

Claims

1. A method for determining oil and gas extraction methods, characterized in that, include: Obtain geological and historical mining information for the first injection well and the first production well in the first well area; Calculate the static connectivity coefficient and dynamic connectivity coefficient of the target stratum based on the geological information and the historical mining information; The mining methods of the first injection well and the first production well in the target stratum are determined based on the static connectivity coefficient and the dynamic connectivity coefficient. The geological information includes connectivity thickness and interpretation layer thickness, the historical mining information includes historical perforation information, and the calculation of the static connectivity coefficient and dynamic connectivity coefficient of the target layer based on the geological information and the historical mining information includes: The static connectivity coefficient of the target segment is obtained based on the connectivity thickness and the interpretation layer thickness; The static connectivity coefficient is: Static connectivity coefficient = ((connection thickness of production well / interpretation layer thickness of production well) + (connection thickness of injection well / interpretation layer thickness of injection well)) / 2; The active connectivity coefficient of the target segment is obtained by using the perforation information, the connectivity thickness, and the interpretation layer thickness; The step of obtaining the active connectivity coefficient of the target segment through the perforation information, the connectivity thickness, and the interpretation layer thickness includes: Determine the perforation connection segment based on the perforation information; The average value of the ratio of the perforation connection thickness of the first production well and the first injection well to the interpretation layer thickness is obtained as the activated connectivity coefficient; The activated connectivity coefficient is: Utilization connectivity coefficient = ((connection thickness of the perforated connecting section of the production well / interpretation layer thickness of the production well) + (connection thickness of the perforated connecting section of the injection well / interpretation layer thickness of the injection well)) / 2; Determining the exploitation methods of the first injection well and the first production well in the target formation based on the static connectivity coefficient and the dynamic connectivity coefficient includes: If the difference between the static connectivity coefficient and the dynamic connectivity coefficient is greater than a preset coefficient, additional perforations are added at the corresponding positions of the target formations of the first injection well and the first production well.

2. The method as described in claim 1, characterized in that, Also includes: When the first production well is located on the common boundary between the first well area and the second well area, the geological information and historical mining information of the second injection well are obtained, wherein the second injection well is an injection well in the second well area; The mining methods of the first production well, the first injection well, and the second injection well are obtained based on the geological information and historical mining information of the first production well, the first injection well, and the second injection well.

3. The method as described in claim 2, characterized in that, Also includes: Calculate the first static connectivity coefficient and the first dynamic connectivity coefficient based on the geological information and historical mining information of the first injection well and the first production well; The extraction method of the first injection well in the target stratum is determined based on the first static connectivity coefficient and the first dynamic connectivity coefficient.

4. The method as described in claim 3, characterized in that, Also includes: The second static connectivity coefficient and the second dynamic connectivity coefficient are calculated based on the geological information and historical mining information of the second injection well and the first production well; The extraction method of the second injection well in the target formation is determined based on the second static connectivity coefficient and the second dynamic connectivity coefficient.

5. The method as described in claim 4, characterized in that, Also includes: The mining method of the first production well in the target stratum is determined based on the first static connectivity coefficient, the first activated connectivity coefficient, the second static connectivity coefficient, and the second activated connectivity coefficient.

6. The method as described in claim 1, characterized in that, The geological information also includes the permeability of the connected sections; The method further includes: The seepage index is calculated based on the permeability of the connected segment, the thickness of the connected segment, and the perforation information. The step of determining the exploitation methods of the first injection well and the first production well in the target formation based on the static connectivity coefficient and the dynamic connectivity coefficient includes: The mining methods of the first injection well and the first production well in the target formation are determined based on the static connectivity coefficient, the dynamic connectivity coefficient, and the seepage index.

7. The method as described in claim 6, characterized in that, The method of determining the extraction mode of the first injection well and the first production well in the target formation based on the static connectivity coefficient, the dynamic connectivity coefficient, and the seepage index includes: If the difference between the static connectivity coefficient and the dynamic connectivity coefficient is greater than the preset coefficient and the seepage index is greater than the preset index, additional perforations are added at the corresponding positions of the target sections of the first injection well and the first production well.

8. An apparatus for determining oil and gas extraction methods, characterized in that, include: The acquisition unit is used to acquire geological information and historical mining information of the first injection well and the first production well in the first well area; The calculation unit is used to calculate the static connectivity coefficient and dynamic connectivity coefficient of the target layer based on the geological information and the historical mining information. The geological information includes connectivity thickness and interpretation layer thickness, and the historical mining information includes historical perforation information. The calculation unit is further configured to obtain the static connectivity coefficient of the target segment based on the connectivity thickness and the interpretation layer thickness; The static connectivity coefficient is: Static connectivity coefficient = ((connection thickness of production well / interpretation layer thickness of production well) + (connection thickness of injection well / interpretation layer thickness of injection well)) / 2; The active connectivity coefficient of the target segment is obtained by using the perforation information, the connectivity thickness, and the interpretation layer thickness; Determine the perforation connection segment based on the perforation information; The average value of the ratio of the perforation connection thickness of the first production well and the first injection well to the interpretation layer thickness is obtained as the activated connectivity coefficient; The activated connectivity coefficient is: Utilization connectivity coefficient = ((connection thickness of the perforated connecting section of the production well / interpretation layer thickness of the production well) + (connection thickness of the perforated connecting section of the injection well / interpretation layer thickness of the injection well)) / 2; The determining unit is used to determine the mining methods of the first injection well and the first production well in the target stratum based on the static connectivity coefficient and the dynamic connectivity coefficient; The determining unit is further configured to, when the difference between the static connectivity coefficient and the dynamic connectivity coefficient is greater than a preset coefficient, supplement perforations at the corresponding positions of the target segments of the first injection well and the first production well.

9. An electronic device, comprising: A memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that the processor, when executing the computer program stored in the memory, implements the steps of the method for determining oil and gas extraction methods as described in any one of claims 1-7.

10. A computer-readable storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by the processor, it implements the method for determining the oil and gas extraction method as described in any one of claims 1-7.

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