Oil field exploration and development recovery ratio analysis method and system and storage medium

Abstract

The invention relates to the technical field of oil exploitation, in particular to a recovery efficiency analysis method and system for oil field exploration and development and a storage medium, and the recovery efficiency analysis method comprises the steps that S1, oil extraction circulation pressure information is collected, and a plunger pressure bump change index of a plunger pump is calculated; s2, in the valve response monitoring set, a valve response time threshold value is set, and valve response time is obtained; calculating a valve response variation exceeding index; s3, calculating a plunger pump stability balance evaluation coefficient according to the plunger pressure bump change index and the valve response variation exceeding index; and S4, the operation state of the plunger pump is judged according to the plunger pump stability balance evaluation coefficient. Prejudgment can be carried out in advance before the plunger pump goes wrong, corresponding measures are taken, equipment is intervened, maintained and repaired in time, and the production efficiency is improved; therefore, the oil recovery efficiency is improved, the oil recovery efficiency can be improved to the maximum extent, and sustainable production of an oil field is ensured.

Description

Technical Field

[0001] The present invention relates to the technical field of oil production, and in particular to a recovery rate analysis method, system and storage medium for oil field exploration and development. Background Art

[0002] Recovery factor is a crucial parameter in oilfield development, representing the ratio of the amount of crude oil produced to the reservoir's original geological reserves. Improving recovery factor has long been a research focus. Recovery efficiency analysis methods and systems for oilfield exploration and development are tools designed to assess and optimize resource recovery efficiency during oilfield development. When oilfield development enters its later stages, it may be observed that production in one production area is gradually declining, leading to lower recovery efficiency, while production in other production areas remains stable or increases. This discrepancy between production changes across production areas requires prompt identification of the underlying causes.

[0003] In practice, when monitoring the recovery efficiency of oilfield exploration and development equipment, oilfield developers analyze the recovery efficiency of oilfield exploration and development equipment based on the actual amount of oil recovered and the corresponding time. However, they fail to consider the impact of the actual operation of oilfield exploration and development equipment on recovery efficiency. As a result, they cannot provide early warning before oilfield exploration and development equipment fails, which affects recovery efficiency.

[0004] Prior art CN115422789B discloses a method and system for predicting waterflooding recovery rates in fault-block reservoirs, taking into account full-process optimization. The method includes: determining factors influencing waterflooding recovery rates in fault-block reservoirs; screening key control parameters for waterflooding recovery rates in fault-block reservoirs; determining the single-factor correlation between waterflooding recovery rates and key control parameters; designing a multi-factor orthogonal experimental scheme; and, for each experimental scheme, performing full-process waterflooding optimization, including stratified injection and production, well type conversion, and injection and production adjustment, with the goal of maximizing waterflooding recovery rates, to obtain the maximum waterflooding recovery rate. Based on the full-process optimization results of the orthogonal experiment, a least squares method is used to fit and determine a waterflooding recovery rate prediction model for the fault-block reservoir, thereby calculating the waterflooding recovery rate of the fault-block reservoir. This prediction method establishes a recovery rate prediction model based on the full-process waterflooding optimization results, truly reflecting the ultimate recovery rate achievable by the mine under current economic and technological conditions. However, it does not address the analysis of the main causes of reduced recovery efficiency, particularly the impact of recovery equipment on the recovery rate.

[0005] In addition, the prior art CN105888630B discloses a method for increasing oil recovery by fracturing a horizontal well for tight oil, comprising: after sandwashing the horizontal well when the reservoir pressure drops to a certain optimized pressure, water is injected into the reservoir at a specified daily injection rate; water injection is stopped when the pressure remains at 100% at the end of the injection period, and the cumulative water injection volume at this time is equal to the cumulative liquid production of the well in the previous production stage; after the water injection is completed, the horizontal well is shut down and enters the well-clogging stage, relying on imbibition and displacement to allow the reservoir crude oil to enter the high-permeability channel; during oil production, when the formation pressure within the control area of ​​the horizontal well drops to the rated pressure, the well is shut down and a second round of huff and puff is performed. This method also aims to increase the recovery rate, but does not analyze the recovery equipment when the recovery rate decreases, thereby ignoring the impact of the recovery equipment on the recovery rate.

[0006] Therefore, there is an urgent need to provide a recovery factor analysis method, system and storage medium for oil field exploration and development to clarify the impact of the operating status of oil field exploration and development equipment on recovery efficiency. Summary of the Invention

[0007] In order to solve the above technical problems existing in the prior art, the present invention provides a recovery factor analysis method, system and storage medium for oil field exploration and development.

[0008] To achieve the above object, the technical solution of the present invention is as follows:

[0009] A method for analyzing recovery rate of oil field exploration and development comprises the following steps:

[0010] S1. Collecting oil production cycle pressure information and calculating the plunger pressure fluctuation variation index of the plunger pump;

[0011] S2. In the valve response monitoring set, a valve response time threshold is set, the valve response time is obtained, and data having a valve response time greater than the valve response time threshold is screened; and a valve response variation excess index is calculated based on the data having a valve response time greater than the valve response time threshold;

[0012] S3. Calculate the plunger pump stability balance assessment coefficient based on the plunger pressure turbulence variation index and the valve response variation excess index;

[0013] S4. Determine the operating status of the plunger pump based on the plunger pump stability balance evaluation coefficient.

[0014] Furthermore, step S1 specifically includes: collecting the real-time pressure value in the plunger pump body, and calculating the plunger pressure turbulence change index based on the real-time pressure value and the set pressure value.

[0015] Furthermore, the calculation method of the plunger pressure fluctuation variation index is:

[0016]

[0017] Wherein, ylpx represents the plunger pressure fluctuation variation index, p represents the number of the real-time pressure value in the pump body during the plunger pump suction phase, k represents the number of the real-time pressure values ​​in the pump body during the plunger pump suction phase, p=1, 2, 3...k; q represents the number of the real-time pressure value in the pump body during the plunger pump discharge phase, m represents the number of the real-time pressure values ​​in the pump body during the plunger pump discharge phase, q=1, 2, 3...m; xry p Indicates the real-time pressure value in the pump body during the p-th plunger pump suction phase; sdy p Indicates the set pressure value corresponding to the real-time pressure value in the pump body during the p-th plunger pump suction phase; pcy q Indicates the real-time pressure value in the pump body during the qth plunger pump discharge phase; sp q It represents the set pressure value corresponding to the real-time pressure value in the pump body during the qth plunger pump discharge phase; t1 represents the time length corresponding to the plunger pump suction phase within the pressure fluctuation monitoring interval; t2 represents the time length corresponding to the plunger pump discharge phase within the pressure fluctuation monitoring interval; a and b represent weights.

[0018] Furthermore, the calculation method of the valve response variation exceedance index is:

[0019]

[0020] Wherein, fxbc represents the valve response variation exceedance index, m represents the number of valve response times in the valve response monitoring set whose valve response time is greater than the valve response time threshold, w represents the number of valve response times in the valve response monitoring set whose valve response time is greater than the valve response time threshold, w = 1, 2, 3, ... m; n represents the total number of valve response times in the valve response monitoring set; fxs w represents the valve response time of the w-th valve response time in the valve response monitoring set that is greater than the valve response time threshold, and fxy represents the valve response time threshold.

[0021] Furthermore, before calculating the plunger pump stability balance evaluation coefficient, the plunger pressure turbulence variation index and the valve response variation excess index are normalized.

[0022] Furthermore, the calculation method of the plunger pump stability balance evaluation coefficient is as follows:

[0023]

[0024] Among them, zswp represents the plunger pump stable balance evaluation coefficient, α1 and α2 represent proportional coefficients, and both α1 and α2 are greater than 0.

[0025] Furthermore, step S4 specifically includes: setting a plunger pump operation evaluation threshold, and when the plunger pump stability balance evaluation coefficient is greater than the plunger pump operation evaluation threshold, generating a warning signal, indicating that the plunger pump operation state has deteriorated and the plunger pump needs to be maintained;

[0026] Otherwise, return to step S1 and cyclically monitor the operating status of the plunger pump.

[0027] Furthermore, the plunger pump operation evaluation threshold is set according to the following standards: the critical values ​​of the plunger pressure turbulence change index and the valve response variation exceedance index are calculated respectively, and the critical plunger pump stability balance evaluation coefficient is calculated based on the critical plunger pressure turbulence change index and the valve response variation exceedance index, and the proportional value a is set. The product of the proportional value and the critical plunger pump stability balance evaluation coefficient is the plunger pump operation evaluation threshold.

[0028] The present invention also provides a recovery factor analysis system for oil field exploration and development, which adopts the above-mentioned recovery factor analysis method for oil field exploration and development, and comprises:

[0029] Data acquisition module, used to collect oil production cycle pressure information and valve response time;

[0030] A calculation module, used to calculate the plunger pressure turbulence variation index, the valve response variation excess index and the plunger pump stability balance evaluation coefficient;

[0031] The analysis module is used to judge the operating status of the plunger pump based on the plunger pump stability balance evaluation coefficient.

[0032] Furthermore, it also includes an early warning module for issuing an early warning according to the operating status of the plunger pump.

[0033] The present invention also provides a computer-readable storage medium having a computer program stored thereon, wherein the computer program, when executed by a processor, implements the above-mentioned oilfield exploration and development recovery factor analysis method.

[0034] Compared with the prior art, the present invention has the following beneficial effects:

[0035] The oilfield exploration and development recovery factor analysis method and system provided by the present invention calculates the plunger pressure fluctuation variation index of the plunger pump based on the real-time changes in the recovery factor and the oil production cycle pressure information; calculates the valve response variation excess index based on the valve response time; calculates the plunger pump stability balance assessment coefficient based on the plunger pressure fluctuation variation index and the valve response variation excess index; and determines the plunger pump operating status based on the plunger pump stability balance assessment coefficient. This method can predict plunger pump problems before they occur and take appropriate measures, enabling timely intervention, maintenance, and repair of the equipment to prevent more serious failures and downtime, thereby helping to reduce production interruptions and improve production efficiency. By monitoring the operating status of the plunger pump, unplanned maintenance and downtime can be reduced, lowering production costs. Ensuring the plunger pump is in good operating condition can avoid problems such as irregular fluid flow, pressure fluctuations, or production decline, thereby improving oil recovery efficiency, maximizing oil recovery efficiency, reducing production risks, and ensuring sustainable production in the oilfield, which helps to ensure the full development of oilfield resources. BRIEF DESCRIPTION OF THE DRAWINGS

[0036] Figure 1 Flow chart of the method of the present invention.

[0037] Figure 2 This is a system framework diagram of the present invention. DETAILED DESCRIPTION

[0038] The technical solution of the present invention will be clearly described below in conjunction with the accompanying drawings. Obviously, the described embodiments are not all embodiments of the present invention. All other embodiments obtained by ordinary technicians in this field without making creative work are within the scope of protection of the present invention.

[0039] It should be noted that, unless otherwise specifically stated, the relative arrangements of components and steps, and numerical expressions set forth in these embodiments should not be construed as limiting the scope of the present invention.

[0040] The following description of exemplary embodiments is merely illustrative and is not intended to limit the present invention, its application, or use in any sense. Technologies, methods, and apparatus known to those skilled in the art may not be discussed in detail herein, but to the extent applicable, such technologies, methods, and apparatuses should be considered part of this specification.

[0041] Example 1

[0042] The present invention provides a method for analyzing the recovery rate of oil field exploration and development. In the middle and late stages of oil field development, the recovery rate tends to decrease. Existing methods for improving the recovery rate usually include water drive or gas drive. However, if the recovery rate improvement effect is not obvious when using existing methods, there may be other factors affecting the recovery rate, such as oil production equipment. Or, based on experience, when the recovery rate drops significantly, the influence of the oil production equipment also accounts for part of the decline in the recovery rate. Therefore, the analysis of the recovery rate should also include the analysis of the operating status of the oil production equipment, such as the plunger pump, specifically Figure 1 As shown, the following steps are included:

[0043] S1. Collecting oil production cycle pressure information, comprehensively analyzing the degree to which the pressure in the plunger pump body within the pressure fluctuation monitoring interval deviates from the set pressure value, collecting the real-time pressure value in the plunger pump body, and calculating the plunger pressure fluctuation variation index of the plunger pump based on the real-time pressure value and the set pressure value; the calculation method of the plunger pressure fluctuation variation index is as follows:

[0044]

[0045] Wherein, ylpx represents the plunger pressure fluctuation variation index, p represents the number of the real-time pressure value in the pump body during the suction phase of the plunger pump, k represents the number of the real-time pressure values ​​in the pump body during the suction phase of the plunger pump, p=1, 2, 3...k, p and k are both positive integers greater than 1; q represents the number of the real-time pressure value in the pump body during the discharge phase of the plunger pump, m represents the number of the real-time pressure values ​​in the pump body during the discharge phase of the plunger pump, q=1, 2, 3...m, q and m are both positive integers greater than 1; xry p Indicates the real-time pressure value in the pump body during the p-th plunger pump suction phase; sdy p Indicates the set pressure value corresponding to the real-time pressure value in the pump body during the p-th plunger pump suction phase; pcy q Indicates the real-time pressure value in the pump body during the qth plunger pump discharge phase; sp q represents the set pressure value corresponding to the real-time pressure value within the pump body during the qth plunger pump's discharge phase; t1 represents the duration of the plunger pump's intake phase within the pressure fluctuation monitoring interval; t2 represents the duration of the plunger pump's discharge phase within the pressure fluctuation monitoring interval; a and b represent weights. The settings of a and b are based on the safety standards for the intake and discharge phases, as well as other practical considerations. For example, if the reservoir's underground pressure is relatively low, the intake phase may be more critical, so they can be set to 0.65 and 0.35, respectively.

[0046] S2. In the valve response monitoring set, a valve response time threshold is set, the valve response time is obtained, and data having a valve response time greater than the valve response time threshold is screened; and a valve response variation excess index is calculated based on the data having a valve response time greater than the valve response time threshold;

[0047] The valve response monitoring set includes multiple valve commands, each valve command corresponds to a valve response time, and the size of the valve response time reflects the normality of the valve response.

[0048] The calculation method of the valve response variation exceedance index is:

[0049]

[0050] Wherein, fxbc represents the valve response variation exceedance index, m represents the number of valve response times in the valve response monitoring set whose valve response time is greater than the valve response time threshold, w represents the number of valve response times in the valve response monitoring set whose valve response time is greater than the valve response time threshold, w=1, 2, 3...m, w, m are both positive integers greater than 1; n represents the total number of valve response times in the valve response monitoring set, n is a positive integer greater than 1; fxs w represents the valve response time of the w-th valve response time in the valve response monitoring set that is greater than the valve response time threshold, and fxy represents the valve response time threshold.

[0051] S3. Calculate the plunger pump stability balance assessment coefficient based on the plunger pressure fluctuation change index and the valve response variation exceedance index; conduct a comprehensive analysis of the oil production cycle pressure information and valve response information to evaluate the operating status of the plunger pump, thereby monitoring the operating status of the plunger pump in real time during the production process, so that the efficiency of oil production reaches the expected goal.

[0052] Before calculating the plunger pump stability balance evaluation coefficient, the plunger pressure turbulence variation index and the valve response variation exceedance index are normalized, and then the plunger pump stability balance evaluation coefficient is calculated. The calculation method is as follows:

[0053]

[0054] Among them, zswp represents the plunger pump stable balance evaluation coefficient, α1 and α2 represent proportional coefficients, and both α1 and α2 are greater than 0.

[0055] S4. Determine the operating status of the plunger pump based on the plunger pump stability balance evaluation coefficient.

[0056] Set the plunger pump operation evaluation threshold. When the plunger pump stable balance evaluation coefficient is greater than the plunger pump operation evaluation threshold, an early warning signal is generated, indicating that the plunger pump operation status has deteriorated and the plunger pump needs to be maintained.

[0057] Otherwise, return to step S1 and cyclically monitor the operating status of the plunger pump.

[0058] The larger the plunger pump stability and balance assessment coefficient, the worse the plunger pump's operating status, which in turn increases the adverse impact on oil recovery efficiency. A plunger pump operation assessment threshold is set. By comparing the plunger pump stability and balance assessment coefficient with the plunger pump operation assessment threshold, an early warning of the plunger pump's operating status is issued, allowing timely measures to be taken based on the plunger pump's operating status, thereby ensuring that oil recovery efficiency is not adversely affected.

[0059] When the plunger pump stability balance assessment coefficient is greater than the plunger pump operation assessment threshold, an operation warning signal is generated, indicating that the plunger pump's operating status is poor and will have an adverse impact on oil recovery efficiency. When the plunger pump stability balance assessment coefficient is less than or equal to the plunger pump operation assessment threshold, an operation stability signal is generated, indicating that the plunger pump is operating stably and no action is required.

[0060] When an operation warning signal is generated, it indicates that the plunger pump is in poor operating condition, which may have an adverse effect on oil recovery efficiency. This situation may lead to the following problems:

[0061] Poor plunger pump operation can lead to irregular fluid flow, pressure fluctuations, or decreased production, reducing oil recovery efficiency, slowing oil collection, increasing production costs, and even damaging the oilfield's recovery potential. Poor operation increases the risk of wear and damage to the plunger pump and its associated equipment. Unstable operation subjects equipment to additional stress and pressure, shortening its lifespan. Unstable plunger pump operation leads to production instability, making it difficult to implement oilfield production plans and requiring frequent maintenance and intervention.

[0062] The plunger pump operation assessment threshold is set based on the following criteria: The critical values ​​of the plunger pressure fluctuation index and the valve response variation exceedance index are calculated. The critical value is typically the threshold between normal operation and non-operation, i.e., the value at which the plunger pump operates at its worst. Based on the critical plunger pressure fluctuation index and valve response variation exceedance index, the critical plunger pump stability and balance assessment coefficient is calculated and a proportional value a is set. The proportional value a can be set based on experience and is typically around 80%. The product of the proportional value and the critical plunger pump stability and balance assessment coefficient is the plunger pump operation assessment threshold.

[0063] The present invention calculates the plunger pump stability balance evaluation coefficient by normalizing the plunger pressure turbulence change index and the valve response variation exceedance index, and provides an early warning of the plunger pump's operating status by comparing the plunger pump stability balance evaluation coefficient with the plunger pump operation evaluation threshold. When an operation early warning signal is generated, measures can be taken before problems occur in the plunger pump's operating status, which enables timely intervention, maintenance, and repair of equipment to prevent more serious failures and downtime, helping to reduce production terminals and improve production efficiency and recovery rate. By monitoring the operating status of the plunger pump, unplanned maintenance and downtime can be reduced, and production costs can be reduced. Ensuring that the plunger pump is in good operating condition can avoid problems such as irregular fluid flow, pressure fluctuations, or decreased production, thereby improving oil recovery efficiency, maximizing oil recovery efficiency, reducing production risks, and ensuring sustainable production of oil fields, helping to ensure that oil field resources are fully developed.

[0064] Example 2

[0065] The present invention also provides an oilfield exploration and development recovery rate analysis system, which adopts the oilfield exploration and development recovery rate analysis method provided in Example 1, such as Figure 2 Shown, including:

[0066] Data acquisition module, used to collect oil production cycle pressure information and valve response time;

[0067] A calculation module, used to calculate the plunger pressure turbulence variation index, the valve response variation excess index and the plunger pump stability balance evaluation coefficient;

[0068] The analysis module is used to judge the operating status of the plunger pump based on the plunger pump stability balance evaluation coefficient.

[0069] Preferably, it also includes an early warning module for issuing an early warning according to the operating status of the plunger pump.

[0070] Example 3

[0071] The present invention also provides a computer-readable storage medium having a computer program stored thereon. When the computer program is executed by a processor, the method for analyzing the recovery rate of oil field exploration and development provided in the first embodiment is implemented.

[0072] The above specific embodiments are only used to illustrate the technical solutions of the present invention and are not intended to limit the present invention. Although the present invention has been described in detail with reference to examples, those skilled in the art should understand that the technical solutions of the present invention may be modified or replaced by equivalents without departing from the scope of the technical solutions of the present invention, and all of these should be included in the scope of the claims of the present invention.

Claims

1. A method for analyzing recovery rate of oil field exploration and development, characterized in that: The following steps are involved: S1. Collecting oil production cycle pressure information and calculating the plunger pressure fluctuation variation index of the plunger pump; S2. In the valve response monitoring set, a valve response time threshold is set, the valve response time is obtained, and data having a valve response time greater than the valve response time threshold is screened; and a valve response variation excess index is calculated based on the data having a valve response time greater than the valve response time threshold; S3. Calculate the plunger pump stability balance assessment coefficient based on the plunger pressure turbulence variation index and the valve response variation excess index; S4. Determine the operating status of the plunger pump based on the plunger pump stability balance evaluation coefficient.

2. The method for analyzing oil recovery according to claim 1, wherein: Step S1 specifically includes: collecting the real-time pressure value in the plunger pump body, and calculating the plunger pressure fluctuation change index based on the real-time pressure value and the set pressure value.

3. The recovery factor analysis method according to claim 2, characterized in that: The calculation method of the plunger pressure fluctuation variation index is: Wherein, ylpx represents the plunger pressure fluctuation variation index, p represents the number of the real-time pressure value in the pump body during the plunger pump suction phase, k represents the number of the real-time pressure values ​​in the pump body during the plunger pump suction phase, p=1, 2, 3...k; q represents the number of the real-time pressure value in the pump body during the plunger pump discharge phase, m represents the number of the real-time pressure values ​​in the pump body during the plunger pump discharge phase, q=1, 2, 3...m; xry p Indicates the real-time pressure value in the pump body during the p-th plunger pump suction phase; sdy p Indicates the set pressure value corresponding to the real-time pressure value in the pump body during the p-th plunger pump suction phase; pcy q Indicates the real-time pressure value in the pump body during the qth plunger pump discharge phase; sp q It represents the set pressure value corresponding to the real-time pressure value in the pump body during the qth plunger pump discharge phase; t1 represents the time length corresponding to the plunger pump suction phase within the pressure fluctuation monitoring interval; t2 represents the time length corresponding to the plunger pump discharge phase within the pressure fluctuation monitoring interval; a and b represent weights.

4. The method for analyzing oil recovery efficiency according to claim 1, wherein: The calculation method of the valve response variation exceedance index is: Wherein, fxbc represents the valve response variation exceedance index, m represents the number of valve response times in the valve response monitoring set whose valve response time is greater than the valve response time threshold, w represents the number of valve response times in the valve response monitoring set whose valve response time is greater than the valve response time threshold, w = 1, 2, 3, ... m; n represents the total number of valve response times in the valve response monitoring set; fxs w represents the valve response time of the w-th valve response time in the valve response monitoring set that is greater than the valve response time threshold, and fxy represents the valve response time threshold.

5. The recovery factor analysis method according to claim 1, characterized in that: Before calculating the plunger pump stability balance evaluation coefficient, the plunger pressure bump variation index and the valve response variation exceedance index are normalized.

6. The method for analyzing oil recovery efficiency according to claim 5, wherein: The calculation method of the plunger pump stability balance evaluation coefficient is as follows: Among them, zswp represents the plunger pump stability balance evaluation coefficient, ylpx represents the plunger pressure turbulence variation index, fxbc represents the valve response variation exceedance index, α1 and α2 represent proportional coefficients, and both α1 and α2 are greater than 0.

7. The method for analyzing oil recovery efficiency according to claim 1, wherein: Step S4 specifically includes: setting a plunger pump operation evaluation threshold value, and when the plunger pump stability balance evaluation coefficient is greater than the plunger pump operation evaluation threshold value, generating a warning signal, indicating that the plunger pump operation state has deteriorated and the plunger pump needs to be maintained; Otherwise, return to step S1 and cyclically monitor the operating status of the plunger pump.

8. The method for analyzing oil recovery according to claim 7, wherein: The plunger pump operation evaluation threshold is set according to the following standards: the critical values ​​of the plunger pressure turbulence change index and the valve response variation exceedance index are calculated respectively; based on the critical plunger pressure turbulence change index and the valve response variation exceedance index, the critical plunger pump stability balance evaluation coefficient is calculated; the proportional value a is set; the product of the proportional value and the critical plunger pump stability balance evaluation coefficient is the plunger pump operation evaluation threshold.

9. A recovery factor analysis system for oilfield exploration and development, using the recovery factor analysis method for oilfield exploration and development according to any one of claims 1 to 8, characterized in that: include: Data acquisition module, used to collect oil production cycle pressure information and valve response time; A calculation module, used to calculate the plunger pressure turbulence variation index, the valve response variation excess index and the plunger pump stability balance evaluation coefficient; An analysis module is used to determine the operating status of the plunger pump based on the plunger pump stability balance evaluation coefficient; It also includes an early warning module for issuing early warnings according to the operating status of the plunger pump.

10. A computer-readable storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the recovery factor analysis method for oil field exploration and development according to any one of claims 1 to 8 is implemented.

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