Method and device for evaluating yield increasing capacity of shale gas well

Abstract

The invention discloses a method and device for evaluating the yield increasing capacity of a shale gas well. The method for evaluating the yield increasing capacity of the shale gas well comprises the steps that stratum energy basic information, material basic information and effective fracture flow capacity information of a target shale gas well are determined respectively; based on the stratum energy basic information, the material basic information and the effective fracture flow capacity information, yield increasing capacity information of the target shale gas well is determined; and evaluating the yield increasing capacity of the target shale gas well based on the yield increasing capacity information. The problems of excessive basic data, excessive related fields, lack of unified evaluation standards and the like are avoided, expression of the yield increasing capacity of the target shale gas well is clear, the yield increasing capacity of the target shale gas well is evaluated, the used data volume is small, and the yield increasing capacity of the target shale gas well can be evaluated stably. And quantitative evaluation of the yield increasing capacity of the shale gas well is realized.

Description

Technical Field

[0001] This invention relates to the field of mineral resource assessment technology, and in particular to a method and apparatus for assessing the production capacity of shale gas wells. Background Technology

[0002] With the continuous development of shale gas well development technology, more and more shale gas wells are being developed. However, due to differences in shale gas well development technologies at different times, the current production capacity of shale gas wells developed at different times also varies. Continuing to exploit wells with low production capacity may lead to a decrease in shale gas production, resulting in extraction costs exceeding the price of the extracted shale gas volume. Summary of the Invention

[0003] To better assess the production enhancement capacity of shale gas wells, this invention provides a method and apparatus for assessing the production enhancement capacity of shale gas wells.

[0004] In a first aspect, embodiments of the present invention provide a method for evaluating the production enhancement capacity of shale gas wells, including:

[0005] Determine the formation energy basis information, material basis information, and effective fracture flow capacity information of the target shale gas well, respectively;

[0006] Based on the formation energy information, the material information, and the effective fracture flow capacity information, the production enhancement capacity information of the target shale gas well is determined.

[0007] The production enhancement capacity of the target shale gas well is assessed based on the aforementioned production enhancement capacity information.

[0008] In one or more optional embodiments, the method for assessing the production enhancement capacity of a shale gas well includes determining the formation energy fundamental information of the target shale gas well in the following manner:

[0009] Obtain the current formation pressure, initial formation pressure, and target encounter rate of the target shale gas well during drilling;

[0010] Based on the current formation pressure, the initial formation pressure, and the target drilling encounter rate during drilling of the target shale gas well, the pressure difference coefficient of the target shale gas well is determined;

[0011] The pressure difference coefficient is used as the basic information of formation energy for the target shale gas well.

[0012] In one or more optional embodiments, determining the pressure difference coefficient of the target shale gas well based on the current formation pressure, the initial formation pressure, and the target drilling encounter rate during drilling of the target shale gas well includes:

[0013] Based on the current formation pressure, the initial formation pressure, and the target drilling success rate during drilling of the target shale gas well, the pressure difference coefficient of the target shale gas well is determined according to the following formula 1:

[0014]

[0015] Where M is the pressure difference coefficient of the target shale gas well, and P c P represents the current formation pressure of the target shale gas well. i denoted as , where is the initial formation pressure of the target shale gas well, and K is the target drilling encounter rate during drilling of the target shale gas well.

[0016] In one or more optional embodiments, the method for assessing the production enhancement capacity of a shale gas well includes determining the material basis information of the target shale gas well by:

[0017] Obtain the current actual cumulative production, standard well production, and actual and designed stimulation length of the target shale gas well during the fracturing process;

[0018] Based on the current actual cumulative production of the target shale gas well and the production of the standard well, combined with the actual and designed stimulation length of the target shale gas well during the fracturing process, the production difference coefficient of the target shale gas well is determined.

[0019] The production difference coefficient is used as the material basis information for the target shale gas well.

[0020] In one or more optional embodiments, the determination of the production difference coefficient of the target shale gas well based on the current actual cumulative production of the target shale gas well, the production of the standard well, and the ratio of the actual stimulation length of the target shale gas well to the designed stimulation length during fracturing includes:

[0021] Based on the current actual cumulative production of the target shale gas well and the production of the standard well, combined with the actual and designed stimulation length of the target shale gas well during fracturing, the production difference coefficient of the target shale gas well is determined according to the following formula 2:

[0022]

[0023] Where Z is the production difference coefficient of the target shale gas well, Q0 is the standard well production of the target shale gas well, and Q c L1 represents the current actual cumulative production of the target shale gas well, L1 represents the actual fracturing length of the target shale gas well during the fracturing process, and L represents the designed fracturing length of the target shale gas well.

[0024] In one or more optional embodiments, the method for assessing the production enhancement capacity of a shale gas well includes determining the effective fracture flow capacity information of the target shale gas well in the following manner:

[0025] Obtain the remaining effective fracture volume, initial effective fracture volume, and wellbore bridge plug removal rate of the target shale gas well;

[0026] Based on the remaining effective fracture volume, initial effective fracture volume, and wellbore bridge plug removal rate of the target shale gas well, the effective fracture flow coefficient of the target shale gas well is determined;

[0027] The effective fracture flow coefficient is used as the effective fracture flow capacity information of the target shale gas well.

[0028] In one or more optional embodiments, determining the effective fracture flow coefficient of the target shale gas well based on the remaining effective fracture volume, the initial effective fracture volume, and the wellbore bridge plug removal rate includes:

[0029] Based on the remaining effective fracture volume, initial effective fracture volume, and wellbore bridge plug removal rate of the target shale gas well, the effective fracture flow coefficient of the target shale gas well is determined according to the following formula 3:

[0030]

[0031] Where J is the effective fracture flow coefficient of the target shale gas well, V0 is the initial effective fracture volume of the target shale gas well, and V f denoted as , where is the remaining effective fracture volume of the target shale gas well; P is the bridge plug removal rate of the target shale gas well.

[0032] In one or more optional embodiments, determining the production enhancement capacity information of the target shale gas well based on the formation energy fundamental information, the material fundamental information, and the effective fracture flow capacity information includes:

[0033] Based on the formation energy information, the material information, and the effective fracture flow capacity information, the production enhancement capacity information of the target shale gas well is determined according to the following formula 4:

[0034] T = A*M + B*Z + C*J, Formula 4;

[0035] Where T represents the production enhancement capacity information of the target shale gas well, M represents the formation energy basis information of the target shale gas well, Z represents the material basis information of the target shale gas well, J represents the effective fracture flow capacity information of the target shale gas well, and A, B, and C are pre-set constants.

[0036] Secondly, embodiments of the present invention provide an evaluation device for the production enhancement capacity of shale gas wells, comprising:

[0037] The basic information acquisition module is used to determine the formation energy basic information, material basic information, and effective fracture flow capacity information of the target shale gas well, respectively.

[0038] The production capacity determination module is used to determine the production capacity information of the target shale gas well based on the formation energy basic information, the material basic information and the effective fracture flow capacity information.

[0039] The production enhancement capacity assessment module is used to assess the production enhancement capacity of the target shale gas well based on the production enhancement capacity information.

[0040] Thirdly, embodiments of the present invention provide a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the method for evaluating the production capacity of shale gas wells as described in the first aspect.

[0041] Fourthly, embodiments of the present invention provide a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the program to implement the method for evaluating the production capacity of shale gas wells as described in the first aspect.

[0042] Fifthly, embodiments of the present invention provide a computer program product containing instructions that, when run on a computer device, cause the computer device to execute the shale gas well production enhancement assessment method as described in the first aspect.

[0043] The beneficial effects of the above-described technical solutions provided in the embodiments of the present invention include at least the following:

[0044] This invention provides a method for evaluating the production enhancement capacity of shale gas wells. By determining the formation energy foundation information, material foundation information, and effective fracture flow capacity information of the target shale gas well, the production enhancement capacity information of the target shale gas well is determined, and the production enhancement capacity of the target shale gas well is evaluated based on this information. Determining the production enhancement capacity of the target shale gas well using only its formation energy foundation information, material foundation information, and effective fracture flow capacity information avoids problems such as excessive basic data, involvement of too many fields, and lack of unified evaluation standards. This makes the expression of the production enhancement capacity of the target shale gas well clearer, and the evaluation of the production enhancement capacity of the target shale gas well using this information requires less data and can provide a relatively stable assessment. Ultimately, this method can effectively identify the production enhancement capacity of different shale gas wells, achieve quantitative evaluation of the production enhancement capacity of shale gas wells, and thus improve the targeting and effectiveness of production enhancement measures, thereby improving the gas well development effect.

[0045] Other features and advantages of the invention will be set forth in the following description, and will be apparent in part from the description, or may be learned by practicing the invention. The objects and other advantages of the invention may be realized and obtained by means of the structures particularly pointed out in the written description and the accompanying drawings.

[0046] The technical solution of the present invention will be further described in detail below with reference to the accompanying drawings and embodiments. Attached Figure Description

[0047] The accompanying drawings are provided to further illustrate the invention and form part of the specification. They are used in conjunction with embodiments of the invention to explain the invention and do not constitute a limitation thereof. In the drawings:

[0048] Figure 1 This is a flowchart of a method for evaluating the production enhancement capacity of shale gas wells according to Embodiment 1 of the present invention;

[0049] Figure 2 This is a flowchart of another method for evaluating the production capacity of shale gas wells according to Embodiment 2 of the present invention;

[0050] Figure 3 This is a schematic diagram of the structure of an evaluation device for enhancing the production capacity of a shale gas well according to Embodiment 3 of the present invention;

[0051] Figure 4 This is a schematic diagram of the structure of a computer device for implementing a method for evaluating the production capacity of shale gas wells according to an embodiment of the present invention. Detailed Implementation

[0052] To enable those skilled in the art to better understand the present invention, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of the present invention.

[0053] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this invention 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 of the invention 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 a 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.

[0054] The inventors have discovered that current traditional assessment methods for shale gas wells, such as geological and engineering parameter analysis, require careful analysis of the physical and chemical properties of shale, reservoir pressure, permeability, and engineering parameters such as drilling technology, completion methods, and fracturing techniques to evaluate the production potential of shale gas wells. These methods often require excessive basic data, involve overly complex assessment processes, encompass too many fields, and lack unified assessment standards. Therefore, it is necessary to determine an accurate and reasonable assessment method to evaluate the production capacity of shale gas wells and avoid the aforementioned problems. In view of these problems, this invention is proposed to provide a method and apparatus for assessing the production capacity of shale gas wells that overcomes or at least partially solves the aforementioned problems.

[0055] Example 1

[0056] Figure 1 This invention provides a flowchart of a method for evaluating the production enhancement capacity of shale gas wells, according to Embodiment 1. This embodiment is applicable to situations where key parameters are obtained by refining basic data, and the production enhancement capacity of shale gas wells is effectively identified and expressed in data format. This method can be executed by a shale gas well production enhancement capacity evaluation device, which can be implemented in hardware and / or software and can be configured in a computer device with data processing capabilities. Figure 1 As shown, the method includes:

[0057] S110. Determine the formation energy basis information, material basis information, and effective fracture flow capacity information of the target shale gas well.

[0058] Formation energy baseline information can be the percentage of shale gas energy in the target shale gas well relative to the total shale gas energy in the target shale gas well before production, given the current target drilling rate. This energy includes, but is not limited to, shale gas pressure, as well as energy generated, adsorbed, dissolved, and migrated. Material baseline information can be the percentage of remaining shale gas in the target shale gas well relative to the total shale gas volume in the target shale gas well before production, given the current ratio of actual fracture stimulation length to designed stimulation length. Effective fracture flow capacity information can be the percentage of the volume of fluid injected into the target shale gas well that did not return from the formation after injection, relative to the volume of fluid injected into the target shale gas well before production, given the current wellbore plug removal rate. The target shale gas well can be the shale gas well for which shale gas production enhancement capacity is to be assessed.

[0059] Before assessing the production enhancement capacity of a target shale gas well, basic data related to the well will be acquired and analyzed to determine the formation's basic energy information, material information, and effective fracture flow capacity. This approach minimizes the problem of excessive and broad-ranging basic data on the target shale gas well. The basic data can include all data recorded from the time of production to the assessment of the target shale gas well. This invention does not impose any limitations on this.

[0060] In one alternative approach, determining the formation energy baseline information of the target shale gas well may include steps A1-A3:

[0061] Step A1: Obtain the current formation pressure, initial formation pressure, and target encounter rate of the target shale gas well during drilling.

[0062] Step A2: Determine the pressure difference coefficient of the target shale gas well based on the current formation pressure, initial formation pressure, and target drilling encounter rate during drilling.

[0063] Step A3: Use the pressure difference coefficient as the basic information of formation energy for the target shale gas well.

[0064] The current formation pressure can be the pressure of shale gas in the target shale gas well at the time of evaluation. The initial formation pressure can be the pressure of shale gas in the target shale gas well before it is developed.

[0065] When determining the basic information of formation energy in a target shale gas well, since shale gas is present in the target shale gas well and the shale gas in the target shale gas well will be continuously collected during the extraction process, the gas pressure of the shale gas in the target shale gas well will gradually decrease as the target shale gas well is extracted, which will lead to a gradual reduction in formation energy in the target shale gas well.

[0066] Therefore, when determining the basic formation energy information of the target shale gas well, the current formation pressure is detected and recorded, and the initial formation pressure of the target shale gas well is obtained from the basic data of the target shale gas well.

[0067] To accurately obtain the difference coefficient between the current formation pressure and the initial formation pressure, after obtaining the initial and current formation pressures of the target shale gas well, the pressure difference coefficient of the target shale gas well can be determined according to the target drilling encounter rate during drilling and the current and initial formation pressures, based on the following formula 1:

[0068]

[0069] Where M is the pressure difference coefficient of the target shale gas well, and P c P represents the current formation pressure of the target shale gas well. i denoted as , where is the initial formation pressure of the target shale gas well, and K is the target drilling encounter rate during drilling of the target shale gas well.

[0070] This pressure difference coefficient is then used as the fundamental information about the formation energy of the target shale gas well. Specifically, the pressure difference coefficient describes the difference between the current formation pressure and the initial formation pressure at the target well drilling rate.

[0071] For example, taking a shale gas well in a certain area as an example, the formation energy basic information of candidate wells 1-24 in the shale gas wells in that area is calculated and recorded as shown in Table 1.

[0072] Table 1

[0073]

[0074]

[0075] In one alternative approach, determining the material basis information of the target shale gas well may include steps B1-B3:

[0076] Step B1: Obtain the current actual cumulative production and standard well production of the target shale gas well, as well as the actual and designed stimulation length of the target shale gas well during the fracturing process.

[0077] Step B2: Based on the current actual cumulative production of the target shale gas well and the production of the standard well, and combined with the actual and designed stimulation length of the target shale gas well during the fracturing process, determine the production difference coefficient of the target shale gas well.

[0078] Step B3: Use the production difference coefficient as the material basis information for the target shale gas well.

[0079] The current actual cumulative production can be the cumulative amount of shale gas extracted from the target shale gas well from the time of its production capacity assessment to the time of the assessment.

[0080] Standard well production refers to the maximum production capacity of a well under ideal conditions, assuming no adverse effects from other factors (such as pressure channeling or fluid accumulation). Standard well production can be calculated based on the geographical location of the target shale gas well, its size, and the total production volume of shale gas wells under similar historical conditions.

[0081] The actual fracturing section length can be the actual length of the horizontal section that has been fracturing during the fracturing process of the target shale gas well, while the designed fracturing section length can be the planned horizontal section length for fracturing when the fracturing design is carried out before fracturing the target shale gas well. This invention does not impose any limitations on this.

[0082] After the fracturing of a shale gas well is completed, the length of the horizontal section designed for fracturing and stimulation has been determined. However, due to the continuous production of the target shale gas well, the shale gas content in the target shale gas well will gradually decrease. Therefore, when determining the material basis information of the target shale gas well, the current actual cumulative production of shale gas in the target shale gas well and the production of the standard well will be detected.

[0083] To accurately determine the shale gas content in a target shale gas well, after obtaining the current actual cumulative production and the production of a standard well, the shale gas content in the current target shale gas well will be calculated. Specifically, the shale gas content in the current target shale gas well is the standard well production minus the current actual cumulative production.

[0084] After determining the shale gas content in the current target shale gas well, the production difference coefficient between the shale gas content in the current target shale gas well and the production of the standard well is calculated based on the shale gas content in the current target shale gas well and the production of the standard well. The production difference coefficient is calculated as: (Shale gas content in the current target shale gas well / Standard well production * Actual fracturing length / Designed fracturing length).

[0085] After determining the current actual cumulative production and standard well production of the target shale gas well, and considering the actual and designed stimulation lengths of the target shale gas well during fracturing, the production difference coefficient of the target shale gas well is determined according to the following formula 2:

[0086]

[0087] Where Z is the production difference coefficient of the target shale gas well, and Q0 is the standard well production of the target shale gas well; Q c L1 is the current actual cumulative production of the target shale gas well; L1 is the actual stimulation length of the target shale gas well during fracturing; L is the designed fracturing stimulation length of the target shale gas well.

[0088] For example, taking a shale gas well in a certain area as an example, the material basis information of candidate wells 1-24 in the shale gas wells in that area is calculated and recorded as shown in Table 2.

[0089] Table 2

[0090]

[0091]

[0092] In one alternative approach, determining the effective fracture flow capacity information of a target shale gas well may include steps C1-C3:

[0093] Step C1: Obtain the remaining effective fracture volume, initial effective fracture volume, and wellbore bridge plug removal rate of the target shale gas well.

[0094] Step C2: Determine the effective fracture flow coefficient of the target shale gas well based on the remaining effective fracture volume, the initial effective fracture volume, and the wellbore bridge plug removal rate.

[0095] Step C3: Use the effective fracture flow coefficient as information on the effective fracture flow capacity of the target shale gas well.

[0096] The remaining effective fracture volume can be the volume of fluid that did not return from the formation after being injected into the current target shale gas well. The initial effective fracture volume can be the volume of fluid that did not return from the formation after being injected into the target shale gas well before it was exploited. This invention does not impose any limitations on this.

[0097] When exploiting a target shale gas well, it is often necessary to inject fracturing fluid into the well to expand the reservoir fracture network. The sand or ceramic particles in the fracturing fluid act as proppant, preventing the fractures from closing after the fracturing fluid returns. This improves the fracture network of the reservoir, allowing the shale gas stored within to be continuously released and transported to the surface.

[0098] Meanwhile, due to the long length of the horizontal section during fracturing, segmented fracturing is required. To achieve segmented fracturing, multiple bridge plugs need to be inserted into the wellbore. These bridge plugs are drilled out in a timely manner after fracturing is completed to ensure that the fracturing fluid in the fracture is discharged in a timely and effective manner.

[0099] Before fracturing a shale gas horizontal well, a bridge plug must be installed to segment the horizontal section. During fracturing, each segment is drilled out one by one to complete the segmented fracturing. However, if casing deformation occurs, the drilling tool cannot pass through, resulting in the bridge plug remaining inside the wellbore. This section of the wellbore cannot be fracturing, thus affecting the effective fracture flow capacity. Generally, without casing deformation, the bridge plug removal rate is 100%. Depending on the location and depth of the casing deformation, the more bridge plugs left behind, the lower the removal rate. The bridge plug removal rate of a shale gas well is fixed after fracturing is completed.

[0100] After determining the remaining effective fracture volume and the initial effective fracture volume of the target shale gas well, the effective fracture flow coefficient of the target shale gas well is determined according to the following formula 3, based on the wellbore bridge plug removal rate:

[0101]

[0102] Where J is the effective fracture flow coefficient of the target shale gas well; V0 is the initial effective fracture volume of the target shale gas well; V f denoted as , where is the remaining effective fracture volume of the target shale gas well; P is the bridge plug removal rate of the target shale gas well.

[0103] For example, taking a shale gas well in a certain area as an example, the effective fracture flow capacity information of candidate wells 1-24 in the shale gas wells in that area is calculated and recorded as shown in Table 3.

[0104] Table 3

[0105]

[0106]

[0107] S120. Based on formation energy fundamental information, material fundamental information, and effective fracture flow capacity information, determine the production enhancement capacity information of the target shale gas well.

[0108] Production enhancement capacity information can be a record of various parameters related to the production enhancement capacity of the target shale gas well.

[0109] Although step 110 has refined and summarized the basic data, the generated data is still extensive and cannot directly reflect the production enhancement capacity of the target shale gas well. Therefore, after obtaining the formation energy base information, material base information, and effective fracture flow capacity information from the basic data through calculation, these information can be summarized, and the summarized result can be determined as the production enhancement capacity information. This makes the expression of the production enhancement capacity of the target shale gas well clearer.

[0110] S130. Evaluate the production capacity of the target shale gas well based on production capacity information.

[0111] When assessing the production enhancement capacity of a target shale gas well, traditional methods often suffer from excessive data volume and difficulty in consistently evaluating the production enhancement capacity. Therefore, after steps S110 and S120, production enhancement capacity information is obtained, and the amount of data in this information is relatively small. Thus, the production enhancement capacity information is used to assess the production enhancement capacity of the target shale gas well, thereby reducing the amount of data used in the assessment and enabling a more stable assessment of the production enhancement capacity of the target shale gas well.

[0112] This invention provides a method for evaluating the production enhancement capacity of shale gas wells. By determining the formation energy foundation information, material foundation information, and effective fracture flow capacity information of the target shale gas well, the production enhancement capacity information of the target shale gas well is determined, and the production enhancement capacity of the target shale gas well is evaluated based on this information. Determining the production enhancement capacity of the target shale gas well using only its formation energy foundation information, material foundation information, and effective fracture flow capacity information avoids problems such as excessive basic data, involvement of too many fields, and lack of unified evaluation standards. This makes the expression of the production enhancement capacity of the target shale gas well clearer, and the evaluation of the production enhancement capacity of the target shale gas well using this information requires less data and can provide a relatively stable assessment. Ultimately, this method can effectively identify the production enhancement capacity of different shale gas wells, achieve quantitative evaluation of the production enhancement capacity of shale gas wells, and thus improve the targeting and effectiveness of production enhancement measures, thereby improving the gas well development effect.

[0113] Example 2

[0114] Figure 2 This is a flowchart of another method for evaluating the production enhancement capacity of shale gas wells provided in Embodiment 2 of the present invention. This embodiment further optimizes the process of determining the production enhancement capacity information of a target shale gas well based on formation energy fundamental information, material fundamental information, and effective fracture flow capacity information, as described in the previous embodiments. This embodiment can be combined with various optional schemes in one or more of the above embodiments. Figure 2 As shown, the method includes:

[0115] S210. Determine the formation energy basis information, material basis information, and effective fracture flow capacity information of the target shale gas well.

[0116] S220. Based on formation energy fundamental information, material fundamental information, and effective fracture flow capacity information, the production enhancement capacity information of the target shale gas well is determined according to the following formula 4:

[0117] T = A*M + B*Z + C*J, Formula 4;

[0118] Where T represents the production enhancement capacity information of the target shale gas well, M represents the formation energy basis information of the target shale gas well, Z represents the material basis information of the target shale gas well, J represents the effective fracture flow capacity information of the target shale gas well, and A, B, and C are pre-set constants.

[0119] Because different target shale gas wells have different characteristics, the impact of formation energy fundamental information, material fundamental information, and effective fracture flow capacity information on the production enhancement capacity of target shale gas wells also varies. Therefore, it is necessary to pre-determine the proportion of formation energy fundamental information, material fundamental information, and effective fracture flow capacity information in the production enhancement capacity information based on the characteristics of the target shale gas well itself, and then calculate the production enhancement capacity information that is suitable for the current target shale gas well.

[0120] For example, taking a shale gas well in a certain area, when the formation energy baseline information is ≥0.55, the remaining formation energy is high; when the material baseline information is ≥0.3, the material baseline information is high; and when the effective fracture flow capacity information is ≥0.35, the effective fracture flow capacity information is high.

[0121] Table 4 shows the evaluation table of basic formation energy information for shale gas wells in a certain region. Based on the geological conditions of the shale gas wells in this area and the results of formation pressure change simulations using a single-well analytical model, it was finally determined that a pressure difference coefficient M ≥ 0.55 indicates high remaining formation energy, while M < 0.55 indicates low remaining formation energy. Here, M represents the basic formation energy information. Based on this, the constant A corresponding to the basic formation energy information of the target shale gas well was determined to be 0.55.

[0122] Table 4

[0123]

[0124] Similarly, referring to Table 5, which is an evaluation table of material basis information for shale gas wells in a certain region, and combining the decline rate curves of standard wells in different production areas of the block, a reasonable decline rate fluctuation range was determined. Ultimately, the production difference coefficient Z ≥ 0.3 indicates a high remaining material basis, and Z < 0.3 indicates a low remaining material basis. Here, Z represents the material basis information. Based on this, the constant B corresponding to the material basis information of the target shale gas well was determined to be 0.3.

[0125] Table 5

[0126]

[0127] Similarly, see Table 6, which shows the evaluation table of effective fracture flow capacity information for shale gas wells in a certain region. Based on the average injected fluid discharge ratio of shale gas wells in different areas of this region, the standard for the effective fracture flow capacity information of the target shale gas well is determined. Here, J represents the effective fracture flow capacity information. The constant C corresponding to the effective fracture flow capacity information of the target shale gas well is 0.35.

[0128] Table 6

[0129]

[0130] After determining the evaluation criteria for formation energy basis information, material basis information, and effective fracture flow capacity information, the corresponding constants are substituted into Formula 4 to obtain the production enhancement capacity information of the target shale gas well: T = 0.55M + 0.3Z + 0.35J.

[0131] S230. Assess the production capacity of the target shale gas well based on production capacity information.

[0132] According to the technical solution of the present invention, the production enhancement capacity information of shale gas wells is determined by formula. This allows the method of judging the production enhancement capacity of shale gas wells by means of formation energy base information, material base information and effective fracture flow capacity information to be adaptively modified according to the characteristics of the target shale gas well itself, thereby ensuring the accuracy and stability of the overall system as much as possible.

[0133] Example 3

[0134] Based on the same inventive concept, this invention also provides an evaluation device for the production enhancement capacity of shale gas wells. Figure 3 This is a schematic diagram of a shale gas well production enhancement capacity assessment device provided in Embodiment 3 of the present invention. This embodiment is applicable to situations where key parameters are obtained by refining basic data, and the production enhancement capacity of shale gas wells is effectively identified and expressed quantifiably. This shale gas well production enhancement capacity assessment device can be implemented in hardware and / or software, and can be configured in a computer device with data processing capabilities. Figure 3 As shown, the device includes: a basic information acquisition module 310, a production capacity information determination module 320, and a production capacity evaluation module 330. Wherein:

[0135] The basic information acquisition module 310 is used to determine the formation energy basic information, material basic information and effective fracture flow capacity information of the target shale gas well, respectively.

[0136] The production capacity determination module 320 is used to determine the production capacity information of a target shale gas well based on formation energy basic information, material basic information and effective fracture flow capacity information.

[0137] The production capacity assessment module 330 is used to assess the production capacity of a target shale gas well based on production capacity information.

[0138] Based on the above embodiments, optionally, the basic information acquisition module 310 includes:

[0139] The formation pressure acquisition unit is used to acquire the current formation pressure and initial formation pressure of the target shale gas well.

[0140] The pressure coefficient determination unit determines the pressure difference coefficient of the target shale gas well based on the current formation pressure, the initial formation pressure, and the target drilling encounter rate during drilling.

[0141] The formation energy determination unit is used to use the pressure difference coefficient as the basic information of formation energy for the target shale gas well.

[0142] Based on the above embodiments, optionally, the basic information acquisition module 310 includes:

[0143] The well production acquisition unit is used to acquire the current actual cumulative production and standard well production of the target shale gas well.

[0144] The production coefficient determination unit determines the production difference coefficient of the target shale gas well based on the current actual cumulative production and standard well production, combined with the actual and designed stimulation length of the target shale gas well during the fracturing process.

[0145] The material information determination unit is used to use the production difference coefficient as the material basis information of the target shale gas well.

[0146] Based on the above embodiments, optionally, the basic information acquisition module 310 includes:

[0147] The fracture volume acquisition unit is used to acquire the remaining effective fracture volume and the initial effective fracture volume of the target shale gas well.

[0148] The effective fracture flow coefficient determination unit is used to determine the effective fracture flow coefficient of the target shale gas well based on the remaining effective fracture volume, the initial effective fracture volume, and the wellbore bridge plug removal rate.

[0149] The effective fracture flow capacity information determination unit is used to use the effective fracture flow coefficient as the effective fracture flow capacity information of the target shale gas well.

[0150] Optionally, based on the above embodiments, the production capacity information determination module 320 is specifically used for:

[0151] Based on formation energy fundamental information, material fundamental information, and effective fracture flow capacity information, the production enhancement capacity information of the target shale gas well is determined according to the following formula 4:

[0152] P = A*M + B*Z + C*J, Formula 4;

[0153] Wherein, P represents the production enhancement capacity information of the target shale gas well, M represents the formation energy basis information of the target shale gas well, Z represents the material basis information of the target shale gas well, J represents the effective fracture flow capacity information of the target shale gas well, and A, B, and C are pre-set constants.

[0154] The shale gas well production enhancement capacity assessment device provided in this embodiment of the invention can execute the shale gas well production enhancement capacity assessment method provided in any embodiment of the invention, and has the corresponding functional modules and beneficial effects of the method.

[0155] Example 4

[0156] Based on the same inventive concept, this embodiment of the invention also provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-described method for evaluating the production capacity of shale gas wells.

[0157] Example 5

[0158] Based on the same inventive concept, this embodiment of the invention also provides a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the program, it implements the above-described method for evaluating the production capacity of shale gas wells. Figure 4 A schematic diagram of a computer device 10 that can be used to implement embodiments of the present invention is shown. The computer device is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The computer device can also represent various forms of mobile devices, such as personal digital processors, cellular phones, smartphones, wearable devices (e.g., helmets, glasses, watches, etc.), and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely illustrative and are not intended to limit the implementation of the invention described and / or claimed herein.

[0159] like Figure 4As shown, the computer device 10 includes at least one processor 11 and a memory, such as a read-only memory (ROM) 12 or a random access memory (RAM) 13, communicatively connected to the at least one processor 11. The memory stores computer programs executable by the at least one processor. The processor 11 can perform various appropriate actions and processes based on the computer programs stored in the ROM 12 or loaded from storage unit 18 into the RAM 13. The RAM 13 may also store various programs and data required for the operation of the computer device 10. The processor 11, ROM 12, and RAM 13 are interconnected via a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0160] Multiple components in computer device 10 are connected to I / O interface 15, including: input unit 16, such as keyboard, mouse, etc.; output unit 17, such as various types of monitors, speakers, etc.; storage unit 18, such as disk, optical disk, etc.; and communication unit 19, such as network card, modem, wireless transceiver, etc. Communication unit 19 allows computer device 10 to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks.

[0161] Processor 11 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of processor 11 include, but are not limited to, central processing unit (CPU), graphics processing unit (GPU), various special-purpose artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, digital signal processors (DSPs), and any suitable processor, controller, microcontroller, etc. Processor 11 performs the various methods and processes described above, such as methods for evaluating the production enhancement capacity of shale gas wells.

[0162] In some embodiments, the method for assessing the production capacity of shale gas wells can be implemented as a computer program tangibly contained in a computer-readable storage medium, such as storage unit 18. In some embodiments, part or all of the computer program can be loaded and / or installed on computer device 10 via ROM 12 and / or communication unit 19. When the computer program is loaded into RAM 13 and executed by processor 11, one or more steps of the method for assessing the production capacity of shale gas wells described above can be performed. Alternatively, in other embodiments, processor 11 can be configured to perform the method for assessing the production capacity of shale gas wells by any other suitable means (e.g., by means of firmware).

[0163] Example 6

[0164] Based on the same inventive concept, this embodiment of the invention also provides a computer program product containing instructions. When the computer program product is run on a computer device, it causes the computer device to execute the above-described method for constructing three-dimensional streamlines of deep-water gravity flow sandstone reservoirs or the above-described method for evaluating the production capacity of shale gas wells.

[0165] Various embodiments of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), application-specific standard products (ASSPs), systems-on-a-chip (SoCs), payload-programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various embodiments may include implementations in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which may be a dedicated or general-purpose programmable processor, capable of receiving data and instructions from a storage system, at least one input device, and at least one output device, and transmitting data and instructions to the storage system, the at least one input device, and the at least one output device.

[0166] Computer programs used to implement the methods of the present invention may be written in any combination of one or more programming languages. These computer programs may be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, such that when executed by the processor, the computer programs cause the functions / operations specified in the flowcharts and / or block diagrams to be performed. The computer programs may be executed entirely on a machine, partially on a machine, or as a standalone software package, partially on a machine and partially on a remote machine, or entirely on a remote machine or server.

[0167] In the context of this invention, a computer-readable storage medium can be a tangible medium that may contain or store a computer program for use by or in conjunction with an instruction execution system, apparatus, or device. A computer-readable storage medium may include, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, apparatus, or devices, or any suitable combination of the foregoing. Alternatively, a computer-readable storage medium may be a machine-readable signal medium. More specific examples of machine-readable storage media include electrical connections based on one or more wires, portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fibers, portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination of the foregoing.

[0168] To provide interaction with a user, the systems and techniques described herein can be implemented on a computer device having: a display device for displaying information to the user (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor); and a keyboard and pointing device (e.g., a mouse or trackball) through which the user provides input to the computer device. Other types of devices can also be used to provide interaction with the user; for example, feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form (including sound input, voice input, or tactile input).

[0169] The systems and technologies described herein can be implemented in computing systems that include backend components (e.g., as data servers), or computing systems that include middleware components (e.g., application servers), or computing systems that include frontend components (e.g., user computers with graphical user interfaces or web browsers through which users can interact with implementations of the systems and technologies described herein), or any combination of such backend, middleware, or frontend components. The components of the system can be interconnected via digital data communication (e.g., communication networks) of any form or medium. Examples of communication networks include local area networks (LANs), wide area networks (WANs), blockchain networks, and the Internet.

[0170] A computing system can include clients and servers. Clients and servers are generally located far apart and typically interact through communication networks. The client-server relationship is created by computer programs running on the respective computers and having a client-server relationship with each other. The server can be a cloud server, also known as a cloud computing server or cloud host, which is a hosting product within the cloud computing service system to address the shortcomings of traditional physical hosts and VPS services, such as high management difficulty and weak business scalability.

[0171] It should be understood that the various forms of processes shown above can be used, with steps reordered, added, or deleted. For example, the steps described in this invention can be executed in parallel, sequentially, or in different orders, as long as the desired result of the technical solution of this invention can be achieved, and this is not limited herein.

[0172] The specific embodiments described above do not constitute a limitation on the scope of protection of this invention. Those skilled in the art should understand that various modifications, combinations, sub-combinations, and substitutions can be made according to design requirements and other factors. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of this invention should be included within the scope of protection of this invention.

Claims

1. A method for evaluating the production enhancement capacity of shale gas wells, characterized in that, include: Determine the formation energy basis information, material basis information, and effective fracture flow capacity information of the target shale gas well, respectively; Based on the formation energy information, the material information, and the effective fracture flow capacity information, the production enhancement capacity information of the target shale gas well is determined. The production enhancement capacity of the target shale gas well is assessed based on the aforementioned production enhancement capacity information.

2. The method according to claim 1, characterized in that, This includes determining the formation energy fundamental information of the target shale gas well through the following methods: Obtain the current formation pressure, initial formation pressure, and target encounter rate of the target shale gas well during drilling; Based on the current formation pressure, the initial formation pressure, and the target drilling encounter rate during drilling of the target shale gas well, the pressure difference coefficient of the target shale gas well is determined; The pressure difference coefficient is used as the basic information of formation energy for the target shale gas well.

3. The method according to claim 2, characterized in that, The determination of the pressure difference coefficient of the target shale gas well based on the current formation pressure, the initial formation pressure, and the target body encounter rate during drilling of the target shale gas well includes: Based on the current formation pressure, the initial formation pressure, and the target drilling success rate during drilling of the target shale gas well, the pressure difference coefficient of the target shale gas well is determined according to the following formula 1: Where M is the pressure difference coefficient of the target shale gas well, and P c P represents the current formation pressure of the target shale gas well. i denoted as , where is the initial formation pressure of the target shale gas well, and K is the target drilling encounter rate during drilling of the target shale gas well.

4. The method according to claim 1, characterized in that, This includes determining the material basis information of the target shale gas well through the following methods: Obtain the current actual cumulative production, standard well production, and actual and designed stimulation length of the target shale gas well during the fracturing process; Based on the current actual cumulative production of the target shale gas well and the production of the standard well, combined with the actual and designed stimulation length of the target shale gas well during the fracturing process, the production difference coefficient of the target shale gas well is determined. The production difference coefficient is used as the material basis information for the target shale gas well.

5. The method according to claim 4, characterized in that, The production difference coefficient of the target shale gas well is determined based on the current actual cumulative production of the target shale gas well, the production of the standard well, and the ratio of the actual stimulation length of the target shale gas well to the designed stimulation length during fracturing. This includes: Based on the current actual cumulative production of the target shale gas well and the production of the standard well, combined with the actual and designed stimulation length of the target shale gas well during fracturing, the production difference coefficient of the target shale gas well is determined according to the following formula 2: Where Z is the production difference coefficient of the target shale gas well, Q0 is the standard well production of the target shale gas well, and Q c L1 represents the current actual cumulative production of the target shale gas well, L1 represents the actual fracturing length of the target shale gas well during the fracturing process, and L represents the designed fracturing length of the target shale gas well.

6. The method according to claim 1, characterized in that, This includes determining the effective fracture flow capacity information of the target shale gas well through the following methods: Obtain the remaining effective fracture volume, initial effective fracture volume, and wellbore bridge plug removal rate of the target shale gas well; Based on the remaining effective fracture volume, initial effective fracture volume, and wellbore bridge plug removal rate of the target shale gas well, the effective fracture flow coefficient of the target shale gas well is determined; The effective fracture flow coefficient is used as the effective fracture flow capacity information of the target shale gas well.

7. The method according to claim 6, characterized in that, The determination of the effective fracture flow coefficient of the target shale gas well based on the remaining effective fracture volume, initial effective fracture volume, and wellbore bridge plug removal rate includes: Based on the remaining effective fracture volume, initial effective fracture volume, and wellbore bridge plug removal rate of the target shale gas well, the effective fracture flow coefficient of the target shale gas well is determined according to the following formula 3: Where J is the effective fracture flow coefficient of the target shale gas well, V0 is the initial effective fracture volume of the target shale gas well, and V f Let P be the remaining effective fracture volume of the target shale gas well, and P be the bridge plug removal rate of the target shale gas well.

8. The method according to any one of claims 1-7, characterized in that, The determination of the production enhancement capacity information of the target shale gas well based on the formation energy fundamental information, the material fundamental information, and the effective fracture flow capacity information includes: Based on the formation energy information, the material information, and the effective fracture flow capacity information, the production enhancement capacity information of the target shale gas well is determined according to the following formula 4: T = A*M + B*Z + C*J, Formula 4; Where T represents the production enhancement capacity information of the target shale gas well, M represents the formation energy basis information of the target shale gas well, Z represents the material basis information of the target shale gas well, J represents the effective fracture flow capacity information of the target shale gas well, and A, B, and C are pre-set constants.

9. A device for evaluating the production enhancement capacity of shale gas wells, characterized in that, include: The basic information acquisition module is used to determine the formation energy basic information, material basic information, and effective fracture flow capacity information of the target shale gas well, respectively. The production capacity determination module is used to determine the production capacity information of the target shale gas well based on the formation energy basic information, the material basic information and the effective fracture flow capacity information. The production enhancement capacity assessment module is used to assess the production enhancement capacity of the target shale gas well based on the production enhancement capacity information.

10. A computer-readable storage medium having a computer program stored thereon, characterized in that, When executed by the processor, the program implements the method for evaluating the production enhancement capacity of shale gas wells as described in any one of claims 1-8.

11. A computer device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the program, it implements the method for evaluating the production enhancement capacity of shale gas wells as described in any one of claims 1-8.

12. A computer program product comprising instructions that, when run on a computer device, causes the computer device to perform an evaluation method for the production enhancement capacity of a shale gas well as described in any one of claims 1-8.

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