A method and apparatus for data reconciliation of horizontal or highly deviated wells

Abstract

The application provides a drilling monitoring method and device for a horizontal well or a highly deviated well, and the method comprises the following steps: establishing a well trajectory of a target formation according to a movement trajectory of a real drilling well; obtaining formation occurrence data of the target formation according to logging dip angle data of the real drilling well, and dividing the formation occurrence data in the target formation into occurrence domains to obtain a first occurrence domain of the target formation; establishing a structure model beside the well according to the well trajectory of the target formation and the first occurrence domain of the target formation; obtaining a second occurrence domain of the target formation according to the structure model beside the well, the well trajectory of the target formation and prestack depth domain seismic data; and if it is judged that the first occurrence domain of the target formation and the second occurrence domain of the target formation match, it is confirmed that the prestack depth domain seismic data is accurate. The device is used for executing the above method. The drilling monitoring method and device for the horizontal well or the highly deviated well provided by the embodiment of the application improve the drilling encountering rate of a single well reservoir.

Description

Technical Field

[0001] This invention relates to the field of oil extraction technology, specifically to a drilling monitoring method and device for horizontal wells or highly deviated wells. Background Technology

[0002] With the development of the petroleum industry, in order to reduce exploration and development costs and increase oil and gas reservoir production and recovery rates, drilling technologies for horizontal wells and highly deviated wells have been widely promoted.

[0003] In existing technologies, to improve the accuracy and reliability of structural models for horizontal wells or highly deviated wells, geological models are constructed based on three-dimensional visualization stratigraphic correlation and seismic interpretation depth domain fault models, respectively. However, due to insufficient precision in constraining seismic data, there is a risk that the well trajectory may miss the target or fail to encounter the reservoir.

[0004] Therefore, how to propose a drilling monitoring method for highly deviated or horizontal wells in order to determine the reliability of pre-stack depth domain seismic data during the drilling process has become an important issue that needs to be addressed in this field. Summary of the Invention

[0005] To address the problems in the prior art, embodiments of the present invention provide a drilling monitoring method and apparatus for horizontal wells or highly deviated wells, which can at least partially solve the problems existing in the prior art.

[0006] On the one hand, this invention proposes a drilling monitoring method for horizontal wells or highly deviated wells, comprising: Establish the well trajectory of the target formation based on the actual drilling trajectory; Based on the logging dip angle data of the actual drilled well, the formation attitude data is obtained, and the formation attitude data in the target formation is divided into attitude domains to obtain the first attitude domain of the target formation. Based on the well trajectory of the target formation and the first occurrence domain of the target formation, a well-side structural model is established; Based on the well-side structural model, the well trajectory of the target formation, and the pre-stack depth domain seismic data, the second occurrence domain of the target formation is obtained; If it is determined that the first dip domain of the target stratum and the second dip domain of the target stratum match, then the accuracy of the pre-stack depth domain seismic data is confirmed.

[0007] On the other hand, the present invention provides a drilling monitoring device for horizontal wells or highly deviated wells, comprising: The first module is used to establish the well trajectory of the target formation based on the actual drilling trajectory. The first acquisition module is used to obtain formation attitude data based on the logging dip angle data of the actual drilled well, and to divide the formation attitude data in the target formation into attitude domains to obtain the first attitude domain of the target formation. The second establishment module is used to establish a well-side structural model based on the well trajectory of the target formation and the first occurrence domain of the target formation; The second acquisition module is used to obtain the second attitude domain of the target stratum based on the well-side structural model, the well trajectory of the target stratum, and the pre-stack depth domain seismic data. The judgment module is used to confirm the accuracy of the pre-stack depth domain seismic data after determining that the first dip domain and the second dip domain of the target stratum match.

[0008] In another aspect, the present invention provides an electronic 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 drilling monitoring method for horizontal wells or highly deviated wells as described in any of the above embodiments.

[0009] In another aspect, the present invention provides a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the drilling monitoring method for horizontal wells or highly deviated wells as described in any of the above embodiments.

[0010] The drilling monitoring method and apparatus for horizontal or highly deviated wells provided in this invention establishes the well trajectory of the target formation based on the actual drilling trajectory, obtains formation attitude data based on the logging dip data of the actual drilling, and divides the formation attitude data within the target formation into attitude domains to obtain the first attitude domain of the target formation. Based on the well trajectory and the first attitude domain of the target formation, a well-side structural model is established. Based on the well-side structural model, the well trajectory of the target formation, and pre-stack depth domain seismic data, the second attitude domain of the target formation is obtained. If it is determined that the first attitude domain and the second attitude domain of the target formation match, the accuracy of the pre-stack depth domain seismic data is confirmed, which can verify the reliability of the pre-stack depth domain seismic data and improve the single-well reservoir encounter rate. Attached Figure Description

[0011] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort. In the drawings: Figure 1 This is a schematic flowchart of the drilling monitoring method for horizontal wells or highly deviated wells provided in the first embodiment of the present invention.

[0012] Figure 2 This is a schematic flowchart of the drilling monitoring method for horizontal wells or highly deviated wells provided in the second embodiment of the present invention.

[0013] Figure 3 This is a diagram showing the intersection of dip and well depth provided in the third embodiment of the present invention.

[0014] Figure 4 This is a diagram showing the intersection of dip angle and well depth provided in the fourth embodiment of the present invention.

[0015] Figure 5 This is a schematic flowchart of a drilling monitoring method for horizontal wells or highly deviated wells provided in the fifth embodiment of the present invention.

[0016] Figure 6 This is a schematic flowchart of the drilling monitoring method for horizontal wells or highly deviated wells provided in the sixth embodiment of the present invention.

[0017] Figure 7 This is a schematic diagram of a well trajectory in three-dimensional space provided in the seventh embodiment of the present invention.

[0018] Figure 8 This is a schematic diagram of the well-side structural model provided in the eighth embodiment of the present invention.

[0019] Figure 9 This is a schematic diagram of the matching between the well-side structural model and pre-stack depth domain seismic data provided in the ninth embodiment of the present invention.

[0020] Figure 10 This is a schematic diagram of the predicted next occurrence domain segment provided in the tenth embodiment of the present invention.

[0021] Figure 11 This is a schematic diagram of the drilling monitoring device for horizontal wells or highly deviated wells provided in the eleventh embodiment of the present invention.

[0022] Figure 12 This is a schematic diagram of the drilling monitoring device for horizontal wells or highly deviated wells provided in the twelfth embodiment of the present invention.

[0023] Figure 13 This is a schematic diagram of the drilling monitoring device for horizontal wells or highly deviated wells provided in the thirteenth embodiment of the present invention.

[0024] Figure 14 This is a schematic diagram of the drilling monitoring device for horizontal wells or highly deviated wells provided in the fourteenth embodiment of the present invention.

[0025] Figure 15 This is a schematic diagram of the drilling monitoring device for horizontal wells or highly deviated wells provided in the fifteenth embodiment of the present invention.

[0026] Figure 16 This is a schematic diagram of the physical structure of the electronic device provided in the sixteenth embodiment of the present invention. Detailed Implementation

[0027] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the embodiments of the present invention will be further described in detail below with reference to the accompanying drawings. Here, the illustrative embodiments and descriptions of the present invention are used to explain the present invention, but are not intended to limit the present invention. It should be noted that, unless otherwise specified, the embodiments and features in the embodiments of this application can be arbitrarily combined with each other.

[0028] The drilling monitoring method for horizontal wells or highly deviated wells provided in this embodiment of the invention includes, but is not limited to, a computer.

[0029] To facilitate understanding of the technical solution provided in this application, the relevant content of the technical solution in this application will be explained below.

[0030] In this embodiment of the invention, a horizontal well refers to a special well where the maximum inclination angle reaches or approaches 90° and maintains a certain length of horizontal section within the target formation. The maximum inclination angle of a horizontal well is generally not less than 86°. A highly deviated well refers to a directional well where the ratio of drilling length to vertical depth is greater than 2 and the inclination angle is between 55° and 86°.

[0031] To accurately establish highly deviated or horizontal wells, it is necessary to verify the accuracy of pre-stack depth-domain seismic data during actual drilling. Inaccurate pre-stack depth-domain seismic data can lead to the well failing to reach the target oil and gas layer, resulting in a missed target and development failure. Therefore, when pre-stack depth-domain seismic data is inaccurate, the seismic data analysis needs to be redone. When the pre-stack depth-domain seismic data is accurate and reliable, it can be used to determine the next drilling trajectory, thereby improving the reservoir encounter rate and well production per well.

[0032] Therefore, this invention provides a drilling monitoring method for horizontal or highly deviated wells. By establishing a wellbore structural model of the horizontal or highly deviated well, and then projecting the wellbore structural model onto a pre-stack depth-domain seismic profile, the method matches the pre-stack depth-domain seismic data to verify the accuracy and reliability of the pre-stack depth-domain seismic data. When the pre-stack depth-domain seismic data is accurate, using it to guide drilling tracking and target azimuth adjustment in horizontal or highly deviated wells can improve the reservoir encounter rate and production rate of a single well.

[0033] Figure 1 This is a schematic flowchart of the drilling monitoring method for horizontal wells or highly deviated wells provided in the first embodiment of the present invention, as shown below. Figure 1 As shown, the drilling monitoring method for horizontal wells or highly deviated wells provided in this embodiment of the invention includes: S101. Establish the well trajectory of the target formation based on the actual drilling trajectory; Specifically, during the drilling process, a wellbore generates a trajectory. Each point on this trajectory is represented by its coordinates in a geodetic coordinate system and its corresponding depth, indicating the vertical depth and horizontal offset of the well. The target formation is the segment containing the reservoir to be drilled, with a depth range. The portion of the wellbore's trajectory within the target formation is obtained and used as the well trajectory for that target formation. The coordinates of each point on the well trajectory can be represented as (x, y, z), where x and y represent the coordinates of that point in the geodetic coordinate system, and z represents the depth of that point.

[0034] For example, if the depth range of the target formation is 7,000 to 8,000 m, then the portion of the actual drilling trajectory within the 7,000 to 8,000 m range constitutes the well trajectory of the target formation.

[0035] S102. Based on the logging dip angle data of the actual drilled well, obtain the formation attitude data, and divide the formation attitude data in the target formation into attitude domains to obtain the first attitude domain of the target formation. Specifically, by using well logging dip data from actual drilling, a series of dip and dip angle data of the formations can be obtained during the drilling process. By sampling these dip and dip angle data along the depth direction, formation attitude data can be obtained. The formation attitude data within the target formation depth range is considered the formation attitude data within the target formation. Dividing the formation attitude data within the target formation into attitude domains yields the first attitude domain of the target formation. The first attitude domain of the target formation includes at least one attitude domain segment, with the dip and dip angle of each segment falling within a corresponding range. Different attitude domain segments exhibit significant differences in their dip and dip angle.

[0036] For example, logging instruments can be used to measure and obtain raw data from the well during actual drilling. Then, by analyzing and calculating this raw data using relevant software, logging inclination data and logging stratification data can be obtained. The logging stratification data refers to the well depth values ​​for each formation stratification. It should be noted that this well depth value is not the vertical depth, but rather the relative depth of the well trajectory itself.

[0037] By obtaining dip angle data from actual drilling wells, a series of strata dip and dip angle data are obtained. Then, sample points are acquired at depth intervals of 4m or 10m to obtain dip and dip angle data of the strata at each sample point. The dip and dip angle data of the strata at each sample point constitute the strata occurrence data.

[0038] S103. Based on the well trajectory of the target formation and the first occurrence domain of the target formation, establish a well-side structural model; Specifically, the well logging dip angle data and well logging stratification data corresponding to the first occurrence domain of the target formation are projected onto the well trajectory of the target formation, that is, the well logging dip angle data and well logging stratification data corresponding to the first occurrence domain of the target formation are mapped to the well trajectory of the target formation along the well depth value, thereby establishing a well-side structural model.

[0039] S104. Based on the well-side structural model, the well trajectory of the target formation, and the pre-stack depth domain seismic data, obtain the second occurrence domain of the target formation; Specifically, based on the well trajectory and pre-stack depth domain seismic data of the target stratum, the well trajectory of the target stratum can be projected into the pre-stack depth domain seismic data, and the pre-stack depth domain seismic data can be segmented along the well trajectory of the target stratum to obtain a pre-stack depth domain seismic reflection profile. Then, the well-side structural model can be projected onto the pre-stack depth domain seismic reflection profile to obtain the second occurrence domain of the target stratum.

[0040] For example, inputting 3D seismic data into relevant specialized software can output pre-stack depth-domain seismic data, where the data can be expressed as (x, y, Z), with Z representing the elevation value. Inputting well trajectory and pre-stack depth-domain seismic data into the same specialized software can yield pre-stack depth-domain seismic data and well trajectory data of the same scale and depth in the spatial domain. Since pre-stack depth-domain seismic data can be used to cut vertical 2D seismic profiles along any direction, cutting a 2D seismic profile along the well trajectory direction yields a pre-stack depth-domain seismic reflection profile, thus achieving matching between the well trajectory and the pre-stack depth-domain seismic data. Projecting the well-side structural model onto the pre-stack depth-domain seismic reflection profile then yields the second occurrence domain of the target stratum.

[0041] S105. If it is determined that the first dip domain of the target stratum and the second dip domain of the target stratum match, then the accuracy of the pre-stack depth domain seismic data is confirmed.

[0042] Specifically, the first dip domain of the target stratum is compared with the second dip domain of the target stratum. If the first dip domain of the target stratum matches the second dip domain of the target stratum, it indicates that the error of the pre-stack depth domain seismic data is within an acceptable range, thus confirming the accuracy of the pre-stack depth domain seismic data. If the first dip domain does not match the second dip domain, it indicates that the pre-stack depth domain seismic data is inaccurate, and it can be indicated that the pre-stack depth domain seismic data does not meet the requirements.

[0043] For example, the dip angles of the dip segments corresponding to the first and second dip regions are compared. If the dip angle error is within the corresponding preset range, then the first and second dip regions match. If the dip angle error exceeds the corresponding preset range, then the first and second dip regions do not match.

[0044] The drilling monitoring method for horizontal or highly deviated wells provided in this invention establishes the well trajectory of the target formation based on the actual drilling trajectory, obtains formation attitude data based on the logging dip data of the actual drilling, and divides the formation attitude data within the target formation into attitude domains to obtain the first attitude domain of the target formation. Based on the well trajectory and the first attitude domain of the target formation, a well-side structural model is established. Based on the well-side structural model, the well trajectory of the target formation, and pre-stack depth domain seismic data, the second attitude domain of the target formation is obtained. If it is determined that the first attitude domain and the second attitude domain of the target formation match, the accuracy of the pre-stack depth domain seismic data is confirmed, which can verify the reliability of the pre-stack depth domain seismic data and improve the single-well reservoir encounter rate.

[0045] Based on the above embodiments, the drilling monitoring method for horizontal wells or highly deviated wells provided in this embodiment of the invention further includes: If it is determined that the first dip domain and the second dip domain of the target stratum do not match, a prompt message indicating that the pre-stack depth domain seismic data does not meet the requirements will be output.

[0046] Specifically, the first dip domain of the target stratum is compared with the second dip domain of the target stratum. If the first dip domain does not match the second dip domain, it indicates that the pre-stack depth domain seismic data is not accurate enough. A prompt message indicating that the pre-stack depth domain seismic data does not meet the requirements is output so as to obtain accurate pre-stack depth domain seismic data for drilling.

[0047] Figure 2 This is a schematic flowchart of the drilling monitoring method for horizontal wells or highly deviated wells provided in the second embodiment of the present invention, as shown below. Figure 2 As shown, based on the above embodiments, further, the step of dividing the stratigraphic attitude data within the target stratum into attitude domains to obtain the first attitude domain of the target stratum includes: S201. Based on the stratigraphic attitude data within the target formation, draw the intersection diagram of the dip direction and well depth and the intersection diagram of the dip angle and well depth of the target formation; wherein, the stratigraphic attitude data includes dip direction data and dip angle data; Specifically, the formation occurrence data includes dip data and dip angle data. Based on the dip data within the target formation, a cross-sectional diagram of the dip of the target formation and the well depth can be drawn. Based on the dip angle data within the target formation, a cross-sectional diagram of the dip angle of the target formation and the well depth can be drawn.

[0048] For example, Table 1 contains stratigraphic attitude data within the target stratigraphic segment. Based on the stratigraphic attitude data in Table 1, a plot is drawn... Figure 3 The diagram showing the intersection of dip and well depth and Figure 4 The diagram showing the intersection of dip angle and well depth is shown. In, for example... Figure 3 In the graph, the horizontal axis represents the dip direction, and the vertical axis represents the depth. Figure 4 In the diagram, the horizontal axis represents the inclination angle, and the vertical axis represents the depth.

[0049] Table 1 Stratigraphic attitude data within the target stratigraphic interval

[0050] S202. Based on the dip angle data within the target formation and a preset number of division thresholds, obtain the first occurrence domain of the target formation; wherein, the preset number of division thresholds are set based on the intersection diagram of the dip direction and well depth and the intersection diagram of the dip angle and well depth of the target formation. Specifically, starting from the initial depth of the target stratum, the absolute value of the difference between two adjacent dip angles in the dip angle data within the target stratum can be calculated. Then, this absolute value is compared with a division threshold. If the absolute value of the difference is greater than the division threshold, it indicates a change in attitude. The depth value between the depth values ​​corresponding to the two adjacent dip angles is taken as the boundary between two attitude segments. The dip angle with the smaller corresponding depth value and the dip angle with a depth value less than the depth value corresponding to that dip angle and an absolute value of the difference between the two adjacent dip angles less than or equal to the division threshold constitute one attitude segment. The number of attitude segments included in the first attitude segment of the target stratum is equal to a preset number plus 1. If there is only one division threshold, then after obtaining the above attitude segments, the remaining attitude data within the target stratum constitute another attitude segment.

[0051] If multiple threshold values ​​are available, starting from the larger depth value corresponding to the two adjacent dip angles, the absolute value of the difference between two adjacent dip angles within the target stratum is calculated. This absolute value is then compared to the next threshold value to determine if an abrupt change in attitude has occurred. This process continues until all threshold values ​​have been used, resulting in a preset number plus one attitude segment. When determining an abrupt change in attitude, once an attitude segment is identified using a threshold value, that threshold value is no longer used, and the next threshold value is applied.

[0052] Understandably, before utilizing the stratigraphic attitude data within the target stratum, data cleaning can be performed on the stratigraphic attitude data to remove abnormal data. For example, anomaly dip thresholds and abnormal dip angle thresholds can be set. If the dip included in the stratigraphic attitude data is greater than the abnormal dip threshold, then the data corresponding to dips greater than the abnormal dip threshold are removed from the stratigraphic attitude data; similarly, if the dip included in the stratigraphic attitude data is greater than the abnormal dip angle threshold, then the data corresponding to dip angles greater than the abnormal dip angle threshold are removed from the stratigraphic attitude data.

[0053] For example, based on Figure 3 and Figure 4 A threshold of 10 can be set. Figure 3 Three anomalous dips were clearly identified. A dip threshold of 200 was set, and the dip angle data corresponding to these three anomalous dips were removed from the target strata. Starting at depth 7853.21, the absolute value of the difference between adjacent dip angles was calculated and compared with a division threshold of 10. The absolute value of the difference between the dip angle 9.65 at depth 8063.97 and the dip angle 26.4 at depth 8128.48 was 16.75, which is greater than 10. Therefore, the stratigraphic attitude data within the target strata from depth 7853.21 to depth 8063.97, after removing the anomalous data, constitutes the first attitude domain segment of the first attitude domain of the target strata. The remaining stratigraphic attitude data within the target strata constitutes the second attitude domain segment of the first attitude domain of the target strata. The average value of the values ​​at depths 8063.97 and 8128.48 was calculated to be 8096.23, rounded to 8100, which served as the boundary between the first and second attitude domain segments. The average value of each dip angle in the first dip zone can be calculated as 9, which is taken as the dip angle of the first dip zone. The average value of each dip angle in the second dip zone can be calculated as 22, which is taken as the dip angle of the second dip zone.

[0054] Figure 5 This is a schematic flowchart of the drilling monitoring method for horizontal wells or highly deviated wells provided in the fifth embodiment of the present invention, as shown below. Figure 5 As shown, obtaining the second dip domain of the target stratum based on the well-side structural model, the well trajectory of the target stratum, and pre-stack depth-domain seismic data includes: S501. Based on the well trajectory and pre-stack depth domain seismic data of the target formation, obtain the pre-stack depth domain seismic reflection profile of the target formation; Specifically, by inputting the well trajectory and pre-stack depth-domain seismic data of the target formation into relevant specialized software, data of the same scale and depth in the spatial domain can be obtained, representing the pre-stack depth-domain seismic data and the well trajectory. Since pre-stack depth-domain seismic data can be used to cut vertical two-dimensional seismic profiles in any direction, two-dimensional seismic profiles can be cut along the well trajectory direction from the pre-stack depth-domain seismic data, resulting in pre-stack depth-domain seismic reflection profiles. These pre-stack depth-domain seismic reflection profiles achieve matching between the well trajectory and the pre-stack depth-domain seismic data.

[0055] S502. Project the well-side structural model onto the pre-stack depth domain seismic reflection profile of the target stratum to obtain the second occurrence domain of the target stratum.

[0056] Specifically, since the well-side structural model is obtained based on the well trajectory of the target stratum and the first attitude domain of the target stratum, including the data of the well trajectory of the target stratum and the data of the first attitude domain, the well-side structural model is projected along the well trajectory onto the pre-stack depth domain seismic reflection profile of the target stratum. The data of the first attitude domain is also projected onto the pre-stack depth domain seismic reflection profile of the target stratum, thus forming the second attitude domain of the target stratum.

[0057] Based on the above embodiments, the step of determining whether the first dip region of the target stratum and the second dip region of the target stratum match includes: If it is determined that the dip angle of each dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region satisfy the dip angle matching rule, then the first dip region of the target stratum and the second dip region of the target stratum are matched; wherein the first dip region and the second dip region include the same number of dip segments and correspond one-to-one.

[0058] Specifically, the first and second attitude domains of the target stratum have the same number of attitude domain segments, and these segments correspond one-to-one. The average dip angle of each attitude domain segment can be calculated as the dip angle of each segment. The absolute value of the error between the dip angle of each attitude domain segment in the first attitude domain and the dip angle of its corresponding segment in the second attitude domain is calculated. Then, it is determined whether the dip angle of each attitude domain segment in the first attitude domain and the dip angle of its corresponding segment in the second attitude domain, as well as the calculated absolute value of each error, satisfy the dip angle matching rule. If the dip angle matching rule is satisfied, then the first and second attitude domains of the target stratum match; otherwise, they do not match. The dip angle matching rule is preset.

[0059] Based on the above embodiments, the tilt angle matching rule further includes: The dip angle of each dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region belong to the corresponding threshold range, and the absolute value of the error between the dip angle of each dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region is less than the corresponding set value.

[0060] Specifically, the absolute value of the error between the dip angle of each dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region is calculated. It is then determined whether the dip angle of each dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region belong to a corresponding preset range. If they belong to the preset range, the absolute value of the error is compared with a set value. If the absolute value of the error is less than the set value, then the dip angle of each dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region satisfy the dip angle matching rule. The preset range and set value are set according to actual needs, and this embodiment of the invention does not impose limitations.

[0061] For example, the first dip region of the target stratum includes two dip region segments, and the second dip region of the target stratum also includes two dip region segments. The corresponding dip angle matching rule is: The dip angle of the first dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region are within a first threshold range, and the absolute value of the error between the dip angle of the first dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region is less than a first set value. The dip angle of the second dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region are within the second threshold range, and the absolute value of the error between the dip angle of the second dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region is less than a second set value.

[0062] For example, the first attitude domain of the target stratum includes attitude domain segment A and attitude domain segment B, and the second attitude domain of the target stratum includes attitude domain segment a and attitude domain segment b. Attitude domain segment A corresponds to attitude domain segment a, and attitude domain segment B corresponds to attitude domain segment b. Set the first threshold range as (p1, p2], which corresponds to the first set value k1; the second threshold range as (p3, p4], which corresponds to the second set value k2. Calculate the average value of each dip angle within the attitude domain A as the dip angle of attitude domain A. Similarly, calculate the dip angle of attitude domain B. The dip angles of attitude domain a and attitude domain b can be obtained through measurement. Calculate the absolute value of the error between the dip angle of attitude domain A and the dip angle of attitude domain a to obtain the first value, and calculate the absolute value of the error between the dip angle of attitude domain B and the dip angle of attitude domain b to obtain the second value. Determine whether the dip angles of attitude domain A and attitude domain a are greater than p1 and less than or equal to p2. If the dip angles of attitude domain A and attitude domain a are greater than p1 and less than or equal to p2, then... If the dip angle of dip segment a is greater than p1 and less than or equal to p2, then the dip angles of dip segments A and B in the target stratum fall within the first threshold range. Next, it is determined whether the first value is less than k1. Then, it is determined whether the dip angles of dip segments B and B are greater than p3 and less than or equal to p4. If they are, then the dip angles of dip segments B and B in the target stratum fall within the second threshold range. Next, it is determined whether the second value is less than k2. If the first value is less than k1 and the second value is less than k2, then the dip angles of dip segments A and B in the first dip domain of the target stratum and the corresponding dip angles of dip segments a and b in the second dip domain satisfy the dip angle matching rule.

[0063] Based on the above embodiments, further, establishing the well trajectory of the target formation according to the actual drilling trajectory includes: The well trajectory of the target formation is established with an aspect ratio of 1:1.

[0064] Specifically, when establishing the well trajectory of the target formation, the well trajectory of the target formation is established with an aspect ratio of 1:1 to keep the vertical depth and horizontal offset of the well trajectory in the same proportion, so that the subsequent well-side structural model will not be distorted due to stretching or compression, which helps to ensure the authenticity and reliability of the measured dip angle.

[0065] Figure 6 This is a schematic flowchart of the drilling monitoring method for horizontal wells or highly deviated wells provided in the sixth embodiment of the present invention, as shown below. Figure 6 As shown, based on the above embodiments, the drilling monitoring method for horizontal wells or highly deviated wells provided in this embodiment of the invention further includes: S601. Based on the second occurrence domain of the target stratum and the target layer position, obtain the seismic data occurrence after well trajectory extension; Specifically, after confirming the accuracy of the pre-stack depth domain seismic data, it is necessary to determine whether the next well trajectory needs to be corrected. The attitude of the well trajectory extension seismic data, including dip angle, can be measured using the second attitude domain of the target stratum and the target layer horizon. The target layer horizon is pre-determined and is the horizon from which the oil reservoir can be drilled.

[0066] S602. Based on the dip angle corresponding to the attitude of the seismic data after the well trajectory extension and the dip angle of the last attitude segment of the first attitude domain of the target stratum, determine whether to adjust the dip of the well trajectory.

[0067] Specifically, the dip angle corresponding to the attitude of the seismic data after well trajectory extension is compared with the dip angle of the last attitude segment of the first attitude domain of the target formation. If the dip angle corresponding to the attitude of the seismic data after well trajectory extension matches the dip angle of the last attitude segment of the first attitude domain of the target formation, it indicates that the well trajectory extension can drill into the reservoir within the target formation, and therefore no adjustment to the dip of the well trajectory is needed. If the dip angle corresponding to the attitude of the seismic data after well trajectory extension does not match the dip angle of the last attitude segment of the first attitude domain of the target formation, it indicates that the well trajectory extension cannot directly drill into the reservoir within the target formation, and the extended well trajectory is invalid, resulting in economic losses, and therefore the dip of the well trajectory needs to be adjusted. The dip angle corresponding to the attitude of the seismic data after well trajectory extension is obtained by calculating the average value of each dip angle in the attitude of the seismic data after well trajectory extension.

[0068] For example, if the absolute value of the difference between the dip angle corresponding to the attitude of the seismic data after well trajectory extension and the dip angle of the last segment of the first attitude domain of the target stratum is less than or equal to a preset value, then the dip angle corresponding to the attitude of the seismic data after well trajectory extension is consistent with the dip angle of the last segment of the first attitude domain of the target stratum. If the absolute value of the difference between the dip angle corresponding to the attitude of the seismic data after well trajectory extension and the dip angle of the last segment of the first attitude domain of the target stratum is greater than the preset value, then the dip angle corresponding to the attitude of the seismic data after well trajectory extension is inconsistent with the dip angle of the last segment of the first attitude domain of the target stratum. The preset value is set based on practical experience, and this embodiment of the invention does not impose any limitations.

[0069] The following embodiment of the invention provides a drilling monitoring method for horizontal wells or highly deviated wells. Taking the application of this method on the highly deviated well S6 as an example, the specific implementation process of the drilling monitoring method for horizontal wells or highly deviated wells provided in this embodiment of the invention is explained.

[0070] The first step is to obtain the well trajectory of the target formation through the movement trajectory of well S6. The movement trajectory of well S6 is then projected onto a three-dimensional space with geodetic coordinates to establish the three-dimensional well trajectory. Well S6 has a depth of over 8301 meters. Each point within the well depth (sampled at intervals) has a coordinate value (x, y, z), where x and y are geodetic coordinates projected onto the surface, and z is the well depth. The three-dimensional well trajectory is shown below. Figure 7 As shown, Figure 7 In the center, E, S, and N represent the east, south, and north directions, respectively, indicating the geodetic coordinate system. Figure 7 The black curved line in the middle represents the actual well trajectory in the established three-dimensional space. The well trajectory of the target formation can be obtained based on the depth range of the target formation. The depth range of the target formation of well S6 is 7853.21 to 8301.19 meters, which means that there is an oil-bearing reservoir in the formation range of 7853.21 to 8301.19 meters.

[0071] The second step involves obtaining the first occurrence zone of the target formation within a depth range of 7853.21–8301.19 meters using the well logging dip data from well S6. Table 1 shows the measured occurrence data of the target formation within this depth range. Each well depth sample point has two values: dip direction and dip angle. Cross-plots are plotted between the dip direction and the corresponding well depth for each value. The resulting cross-plots of dip direction and well depth are shown below. Figure 3 As shown, the intersection diagram of the obtained dip angle and well depth is as follows: Figure 4 As shown. Figure 3 As shown, wells shallower than 8100 meters have a dip direction mainly within the 0–80° dip range, with three abnormal sample points needing to be removed; wells deeper than 8100 meters have a dip direction mainly within the 110–180° dip range. Similarly, as Figure 4 As shown, the 8100-meter well depth serves as the dividing line, separating the well into two dip zones: shallower zones have dip angles less than 18°, while deeper zones have dip angles greater than 18°. Therefore, the build-up section of Well S6 can be divided into two attitude zones, with the 8100-meter well depth as the boundary. Table 2 shows the attitude zones of Well S6. The average dip angle of the first attitude zone (shallower than 8100 meters) is 9°, while the average dip angle of the second attitude zone (deeper than 8100 meters) is 22°.

[0072] Table 2 Occurrence Zoning Table of Well S6

[0073] The third step involves constructing a well-side structural model using the first and second dip zones of the target formation (7853.21–8301.19 meters) and the well trajectory of the target formation. The established well-side structural model is shown below. Figure 8As shown, the well-side structural model includes two dip zones: dip zone one, which extends from a depth of 7853 to 8060 m and has a dip angle of 9°; and dip zone two, which extends from a depth of 8100 to 8300 m and has a dip angle of 22°.

[0074] Step 4: Using the pre-stack depth-domain seismic data from well S6, the aforementioned well-side structural model, and the well trajectory of well S6, the second occurrence domain of the target strata is obtained. The well trajectory of well S6 is projected onto the pre-stack depth-domain seismic data using the same geodetic coordinate system, and a pre-stack depth-domain seismic reflection profile is cut along the extension direction of the well trajectory, as shown below. Figure 9 As shown, the well-side structural model was projected onto the pre-stack depth-domain seismic reflection profile. The well trajectory was segmented along depths of 7853m and 8100m, resulting in two segments: ① and ②. Segment ① corresponds to the first dip domain segment of the well trajectory, and segment ② corresponds to the second dip domain segment. The x, y, and z scales of the pre-stack depth-domain seismic data are consistent, all in meters, without relative stretching or compression. The dip angle of layer 2 in segment ① can be directly measured as 8.1°, and the dip angle of layer 2 in segment ② as 19.7°. The dip angle matching rule is as follows: the dip angle of dip domain segment 1 and the dip angle of corresponding segment ① are between 0° and 20°, with a dip angle error of less than 20%; the dip angle of dip domain segment 2 and the dip angle of corresponding segment ② are between 20° and 40°, with a dip angle error of less than 15%.

[0075] The calculated dip angle of segment ① is found to have an error of 10% compared to the dip angle of segment one of the attitude domains, i.e., (9-8.1) / 9=10%. The calculated dip angle of segment ② (19.7°) and segment two (22°) is found to have an error of 10.4%, i.e., (22-19.7) / 22=10.4%. It can be determined that the dip angles of segment one and segment ① are within the range of 0-20°, and the dip angle error of 10% is less than 20%; the dip angles of segment two and segment ② are within the range of 20°-40°, and the dip angle error of 10.4% is less than 15%. Therefore, the first attitude domain matches the second attitude domain of the target stratum, and the pre-stack depth domain seismic data is accurate.

[0076] Step 5: Determine whether to adjust the well trajectory. Since pre-stack depth-domain seismic data is accurate, the next drilling trajectory can be determined using depth-domain seismic data. Based on segment ② and the target layer position, segment ③ is divided on the pre-stack depth-domain seismic reflection profile, such as... Figure 10As shown, the dip angle of section 3, layer 2, is measured to be 23.2 degrees, which is basically consistent with the measured dip angle of section 2 in the occurrence domain, 22°. This ensures that the well trajectory extension can reach the reservoir, and the next drilling step can continue along the original well trajectory without adjusting the dip of the well trajectory. If the dip angle of section 3, layer 2, is inconsistent with the measured dip angle of section 2 in the occurrence domain, then the well trajectory extension will not reach the reservoir, and the extended well trajectory will be invalid, resulting in economic losses, and correction will be required.

[0077] Figure 11 This is a schematic diagram of the drilling monitoring device for horizontal or highly deviated wells provided in the eleventh embodiment of the present invention, as shown below. Figure 11 As shown, the drilling monitoring device for horizontal or highly deviated wells provided in this embodiment of the invention includes a first establishment module 1101, a first acquisition module 1102, a second establishment module 1103, a second acquisition module 1104, and a judgment module 1105, wherein: The first establishment module 1101 is used to establish the well trajectory of the target formation based on the movement trajectory of the actual drilled well; the first acquisition module 1102 is used to obtain formation attitude data based on the logging dip data of the actual drilled well, and divide the formation attitude data within the target formation into attitude domains to obtain the first attitude domain of the target formation; the second establishment module 1103 is used to establish a well-side structural model based on the well trajectory of the target formation and the first attitude domain of the target formation; the second acquisition module 1104 is used to obtain the second attitude domain of the target formation based on the well-side structural model, the well trajectory of the target formation, and pre-stack depth domain seismic data; the judgment module 1105 is used to confirm the accuracy of the pre-stack depth domain seismic data after determining that the first attitude domain and the second attitude domain of the target formation match.

[0078] Specifically, during the drilling process, the actual well generates a trajectory. Each point in the trajectory is represented by its coordinates in a geodetic coordinate system and its corresponding depth, indicating the vertical depth and horizontal offset of the well. The target formation is the segment containing the reservoir to be drilled, with a depth range. The first establishment module 1101 acquires the portion of the actual well's trajectory within the target formation, which serves as the well trajectory for the target formation. The coordinates corresponding to each point on the well trajectory can be represented as (x, y, z), where x and y represent the coordinates of that point in the geodetic coordinate system, and z represents the depth of that point.

[0079] The first acquisition module 1102 obtains a series of dip and dip angle data of the formation during drilling by using well logging dip angle data from actual drilling. Then, by sampling the dip and dip angle data along the depth direction, formation attitude data can be obtained. The formation attitude data within the target formation depth range is used as the formation attitude data within the target formation. Dividing the formation attitude data within the target formation into attitude domains yields the first attitude domain of the target formation. The first attitude domain of the target formation includes at least one attitude domain segment, and the dip and dip angle of each attitude domain segment are within a corresponding range, with significant differences in dip and dip angle between different attitude domain segments.

[0080] The second establishment module 1103 projects the well logging dip angle data and well logging stratification data corresponding to the first occurrence domain of the target formation onto the well trajectory of the target formation, that is, maps the well logging dip angle data and well logging stratification data corresponding to the first occurrence domain of the target formation to the well trajectory of the target formation along the well depth value, thereby establishing a well-side structural model.

[0081] The second acquisition module 1104, based on the well trajectory and pre-stack depth domain seismic data of the target stratum, can project the well trajectory of the target stratum into the pre-stack depth domain seismic data, and segment the pre-stack depth domain seismic data along the well trajectory of the target stratum to obtain a pre-stack depth domain seismic reflection profile. Then, it can project the well-side structural model onto the pre-stack depth domain seismic reflection profile to obtain the second occurrence domain of the target stratum.

[0082] The judgment module 1105 compares the first dip region of the target stratum with the second dip region of the target stratum. If the first dip region of the target stratum matches the second dip region, it indicates that the error of the pre-stack depth domain seismic data is within an acceptable range, and the pre-stack depth domain seismic data is confirmed to be accurate. If the first dip region does not match the second dip region, it indicates that the pre-stack depth domain seismic data is inaccurate, and the module can indicate that the pre-stack depth domain seismic data does not meet the requirements.

[0083] The drilling monitoring device for horizontal or highly deviated wells provided in this invention establishes the well trajectory of the target formation based on the actual drilling trajectory, obtains formation attitude data based on the logging dip data of the actual drilling, and divides the formation attitude data within the target formation into attitude domains to obtain the first attitude domain of the target formation. Based on the well trajectory and the first attitude domain of the target formation, a well-side structural model is established. Based on the well-side structural model, the well trajectory of the target formation, and pre-stack depth domain seismic data, the second attitude domain of the target formation is obtained. If it is determined that the first attitude domain and the second attitude domain of the target formation match, the accuracy of the pre-stack depth domain seismic data is confirmed, which can verify the reliability of the pre-stack depth domain seismic data and improve the single-well reservoir encounter rate.

[0084] Figure 12 This is a schematic diagram of the drilling monitoring device for horizontal or highly deviated wells provided in the twelfth embodiment of the present invention, as shown below. Figure 12 As shown, based on the above embodiments, the drilling monitoring device for horizontal wells or highly deviated wells provided in this embodiment of the invention further includes an output module 1106, wherein: The output module 1106 is used to output a prompt message indicating that the pre-stack depth domain seismic data does not meet the requirements after determining that the first attitude domain and the second attitude domain of the target stratum do not match.

[0085] Figure 13 This is a schematic diagram of the drilling monitoring device for horizontal or highly deviated wells provided in the thirteenth embodiment of the present invention, as shown below. Figure 13 As shown, based on the above embodiments, the first obtaining module 1102 further includes a drawing unit 11021 and a first obtaining unit 11022, wherein: The drawing unit 11021 is used to draw a cross-sectional diagram of the dip direction and well depth of the target formation and a cross-sectional diagram of the dip angle and well depth based on the formation attitude data within the target formation; wherein, the formation attitude data includes dip data and dip angle data; the first obtaining unit 11022 is used to obtain a first attitude region of the target formation based on the dip angle data within the target formation and a preset number of division thresholds; wherein, the preset number of division thresholds is set based on the cross-sectional diagrams of the dip direction and well depth and the cross-sectional diagrams of the dip angle and well depth of the target formation; Figure 14 This is a schematic diagram of the drilling monitoring device for horizontal or highly deviated wells provided in the fourteenth embodiment of the present invention, as shown below. Figure 14 As shown, based on the above embodiments, the second obtaining module 1104 further includes a second obtaining unit 11041 and a third obtaining unit 11042, wherein: The second obtaining unit 11041 is used to obtain the pre-stack depth domain seismic reflection profile of the target stratum based on the well trajectory and pre-stack depth domain seismic data of the target stratum; the third obtaining unit 11042 is used to project the well-side structural model onto the pre-stack depth domain seismic reflection profile of the target stratum to obtain the second occurrence domain of the target stratum.

[0086] Based on the above embodiments, the determination module 1105 is further specifically used for: If it is determined that the dip angle of each dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region satisfy the dip angle matching rule, then the first dip region of the target stratum and the second dip region of the target stratum are matched; wherein the first dip region and the second dip region include the same number of dip segments and correspond one-to-one.

[0087] Based on the above embodiments, the tilt angle matching rule further includes: The dip angle of each dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region belong to the corresponding threshold range, and the absolute value of the error between the dip angle of each dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region is less than the corresponding set value.

[0088] Based on the above embodiments, the first establishment module 1101 is further specifically used for: The well trajectory of the target formation is established with an aspect ratio of 1:1.

[0089] Figure 15 This is a schematic diagram of the drilling monitoring device for horizontal or highly deviated wells provided in the fifteenth embodiment of the present invention, as shown below. Figure 15 As shown, based on the above embodiments, the drilling monitoring device for horizontal wells or highly deviated wells provided in this embodiment of the invention further includes a third acquisition module 1107 and a determination module 1108, wherein: The third acquisition module 1107 is used to obtain the seismic data attitude after well trajectory extension based on the second attitude domain of the target stratum and the target layer position; the determination module 1108 is used to determine whether to adjust the dip of the well trajectory based on the dip angle corresponding to the next drilling trajectory of the target stratum and the dip angle of the last attitude domain segment in the second attitude domain of the target stratum.

[0090] The embodiments of the device provided in this invention can be used to execute the processing flow of the above-described method embodiments. Its functions will not be repeated here, but can be referred to the detailed description of the above-described method embodiments.

[0091] Figure 16This is a schematic diagram of the physical structure of the electronic device provided in the nineteenth embodiment of the present invention, as shown below. Figure 16 As shown, the electronic device 600 may include a processor 100 and a memory 140. The memory 140 is coupled to the processor 100. The processor 100 may call logical instructions in the memory 140 to execute the following methods: establishing a well trajectory of the target formation based on the movement trajectory of the actual drilled well; obtaining formation attitude data based on the well logging dip data of the actual drilled well, and dividing the formation attitude data within the target formation into attitude domains to obtain a first attitude domain of the target formation; establishing a well-side structural model based on the well trajectory of the target formation and the first attitude domain of the target formation; obtaining a second attitude domain of the target formation based on the well-side structural model, the well trajectory of the target formation, and pre-stack depth-domain seismic data; if it is determined that the first attitude domain and the second attitude domain of the target formation match, then the accuracy of the pre-stack depth-domain seismic data is confirmed.

[0092] This embodiment discloses a computer program product, which includes a computer program stored on a non-transitory computer-readable storage medium. The computer program includes program instructions, and when the program instructions are executed by the computer, the computer can execute the methods provided in the above-described method embodiments, such as: establishing a well trajectory of a target formation based on the movement trajectory of an actual drilled well; obtaining formation attitude data based on the well logging dip data of the actual drilled well, and dividing the formation attitude data within the target formation into attitude domains to obtain a first attitude domain of the target formation; establishing a well-side structural model based on the well trajectory of the target formation and the first attitude domain of the target formation; obtaining a second attitude domain of the target formation based on the well-side structural model, the well trajectory of the target formation, and pre-stack depth-domain seismic data; and confirming the accuracy of the pre-stack depth-domain seismic data if it is determined that the first attitude domain and the second attitude domain of the target formation match.

[0093] This embodiment provides a computer-readable storage medium storing a computer program that causes a computer to execute the methods provided in the above-described method embodiments. For example, the methods include: establishing a well trajectory of a target formation based on the movement trajectory of an actual drilled well; obtaining formation attitude data based on well logging dip data from the actual drilled well, and dividing the formation attitude data within the target formation into attitude domains to obtain a first attitude domain of the target formation; establishing a well-side structural model based on the well trajectory and the first attitude domain of the target formation; obtaining a second attitude domain of the target formation based on the well-side structural model, the well trajectory of the target formation, and pre-stack depth-domain seismic data; and confirming the accuracy of the pre-stack depth-domain seismic data if it is determined that the first attitude domain and the second attitude domain of the target formation match.

[0094] like Figure 16 As shown, the electronic device 600 may also include: a communication module 110, an input unit 120, an audio processor 130, a display 160, and a power supply 170. It is worth noting that the electronic device 600 does not necessarily need to include these components. Figure 16 All components shown; in addition, the electronic device 600 may also include Figure 16 For components not shown in the figure, refer to existing technologies. It is worth noting that this figure is exemplary; other types of structures can also be used to supplement or replace this structure to achieve telecommunications functions or other functions.

[0095] like Figure 16 As shown, the processor 100, sometimes also referred to as a controller or operating control, may include a microprocessor or other processor device and / or logic device. The processor 100 receives inputs and controls the operation of various components of the electronic device 600.

[0096] The memory 140 may be, for example, one or more of a cache, flash memory, hard drive, removable media, volatile memory, non-volatile memory, or other suitable devices. It may store the aforementioned failure-related information, and also store a program for executing that information. The processor 100 may execute the program stored in the memory 140 to perform information storage or processing, etc.

[0097] Input unit 120 provides input to processor 100. Input unit 120 may be, for example, a keypad or touch input device. Power supply 170 provides power to electronic device 600. Display 160 displays images and text. Display 160 may be, for example, an LCD display, but is not limited thereto.

[0098] Memory 140 can be a solid-state memory, such as read-only memory (ROM), random access memory (RAM), SIM card, etc. It can also be a memory that retains information even when power is off, can be selectively erased, and contains more data; examples of memory 140 are sometimes referred to as EPROM, etc. Memory 140 can also be some other type of device. Memory 140 includes a buffer 141 (sometimes referred to as buffer memory). Memory 140 may include an application / function storage unit 142 for storing application programs and function programs or processes for executing the operation of electronic device 600 by processor 100.

[0099] The memory 140 may also include a data storage unit 143 for storing data, such as contacts, digital data, pictures, sounds, and / or any other data used by the electronic device. The driver storage unit 144 of the memory 140 may include various drivers for the electronic device for communication functions and / or for performing other functions of the electronic device (such as messaging applications, address book applications, etc.).

[0100] The communication module 110 includes a transmitter / receiver that transmits and receives signals via antenna 111. The communication module 110 is coupled to processor 100 to provide input signals and receive output signals, which can be the same as in a conventional mobile communication terminal.

[0101] Based on different communication technologies, multiple communication modules 110 can be configured in the same electronic device, such as cellular network modules, Bluetooth modules, and / or wireless LAN modules. The communication module 110 is also coupled to a speaker 131 and a microphone 132 via an audio processor 130 to provide audio output via the speaker 131 and receive audio input from the microphone 132, thereby realizing typical telecommunications functions. The audio processor 130 may include any suitable buffer, decoder, amplifier, etc. Additionally, the audio processor 130 is coupled to the processor 100, enabling on-device recording via the microphone 132 and on-device playback of stored sound via the speaker 131.

[0102] Those skilled in the art will understand that embodiments of the present invention can be provided as methods, systems, or computer program products. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention can take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0103] This invention is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart illustrations and / or block diagrams. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0104] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0105] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0106] In the description of this specification, the references to terms such as "an embodiment," "a specific embodiment," "some embodiments," "for example," "example," "specific example," or "some examples," etc., indicate that a specific feature, structure, material, or characteristic described in connection with that embodiment or example is included in at least one embodiment or example of the invention. In this specification, the illustrative expressions of the above terms do not necessarily refer to the same embodiment or example. Furthermore, the specific features, structures, materials, or characteristics described may be combined in any suitable manner in one or more embodiments or examples.

[0107] The specific embodiments described above further illustrate the purpose, technical solution, and beneficial effects of the present invention. It should be understood that the above descriptions are merely specific embodiments of the present invention and are not intended to limit the scope of protection of the present invention. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the scope of protection of the present invention.

Claims

1. A data verification method for horizontal wells or highly deviated wells, characterized in that, include: Establish the well trajectory of the target formation based on the actual drilling trajectory; Based on the logging dip angle data of the actual drilled well, the formation attitude data is obtained, and the formation attitude data in the target formation is divided into attitude domains to obtain the first attitude domain of the target formation. Based on the well trajectory of the target formation and the first occurrence domain of the target formation, a well-side structural model is established; Based on the well-side structural model, the well trajectory of the target formation, and the pre-stack depth domain seismic data, the second occurrence domain of the target formation is obtained; If it is determined that the first dip domain of the target stratum and the second dip domain of the target stratum match, then the accuracy of the pre-stack depth domain seismic data is confirmed. Specifically, the step of dividing the stratigraphic attitude data within the target stratum into attitude domains to obtain the first attitude domain of the target stratum includes: Based on the stratigraphic attitude data within the target formation, plots are drawn that represent the intersection of dip direction and well depth, and the intersection of dip angle and well depth; wherein, the stratigraphic attitude data includes dip direction data and dip angle data; Based on the dip angle data within the target formation and a preset number of division thresholds, a first occurrence domain of the target formation is obtained; wherein, the preset number of division thresholds is set based on the intersection diagram of the dip direction and well depth and the intersection diagram of the dip angle and well depth of the target formation. The step of establishing a well-side structural model based on the well trajectory of the target formation and the first occurrence domain of the target formation includes: The well logging dip angle data and well logging stratification data corresponding to the first occurrence domain of the target formation are projected onto the well trajectory of the target formation to establish a well-side structural model. The step of obtaining the second dip domain of the target stratum based on the well-side structural model, the well trajectory of the target stratum, and pre-stack depth-domain seismic data includes: Based on the well trajectory and pre-stack depth-domain seismic data of the target formation, the pre-stack depth-domain seismic reflection profile of the target formation is obtained; The well-side structural model is projected onto the pre-stack depth domain seismic reflection profile of the target stratum to obtain the second occurrence domain of the target stratum.

2. The method according to claim 1, characterized in that, Also includes: If it is determined that the first dip domain and the second dip domain of the target stratum do not match, a prompt message indicating that the pre-stack depth domain seismic data does not meet the requirements will be output.

3. The method according to claim 1, characterized in that, The step of determining whether the first dip region of the target stratum and the second dip region of the target stratum match includes: If it is determined that the dip angle of each dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region satisfy the dip angle matching rule, then the first dip region of the target stratum and the second dip region of the target stratum are matched; wherein the first dip region and the second dip region include the same number of dip segments and correspond one-to-one.

4. The method according to claim 3, characterized in that, The tilt angle matching rules include: The dip angle of each dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region belong to the corresponding threshold range, and the absolute value of the error between the dip angle of each dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region is less than the corresponding set value.

5. The method according to claim 1, characterized in that, The process of establishing the well trajectory of the target formation based on the actual drilling trajectory includes: The well trajectory of the target formation is established with an aspect ratio of 1:

1.

6. The method according to any one of claims 1 to 5, characterized in that, Also includes: Based on the second occurrence domain of the target stratum and the target layer position, the seismic data occurrence after well trajectory extension is obtained; Based on the dip angle corresponding to the next drilling trajectory of the target formation and the dip angle of the last occurrence segment in the second occurrence domain of the target formation, determine whether to adjust the dip of the well trajectory.

7. A data verification device for horizontal wells or highly deviated wells, characterized in that, include: The first module is used to establish the well trajectory of the target formation based on the actual drilling trajectory. The first acquisition module is used to obtain formation attitude data based on the logging dip angle data of the actual drilled well, and to divide the formation attitude data in the target formation into attitude domains to obtain the first attitude domain of the target formation. The second establishment module is used to establish a well-side structural model based on the well trajectory of the target formation and the first occurrence domain of the target formation; The second acquisition module is used to obtain the second attitude domain of the target stratum based on the well-side structural model, the well trajectory of the target stratum, and the pre-stack depth domain seismic data. The judgment module is used to confirm the accuracy of the pre-stack depth domain seismic data after determining that the first dip domain and the second dip domain of the target stratum match. The first obtaining module includes: The drawing unit is used to draw a cross-plot of dip and well depth and a cross-plot of dip angle and well depth of the target formation based on the formation attitude data within the target formation; wherein, the formation attitude data includes dip data and dip angle data; The first obtaining unit is used to obtain a first occurrence domain of the target formation based on dip angle data within the target formation and a preset number of division thresholds; wherein the preset number of division thresholds is set based on the intersection diagram of dip and well depth and the intersection diagram of dip angle and well depth of the target formation. Specifically, the second establishment module is used to project the well logging dip angle data and well logging stratification data corresponding to the first occurrence domain of the target formation onto the well trajectory of the target formation to establish a well-side structural model. The second obtaining module includes: The second acquisition unit is used to obtain the pre-stack depth domain seismic reflection profile of the target formation based on the well trajectory and pre-stack depth domain seismic data of the target formation. The third obtaining unit is used to project the well-side structural model onto the pre-stack depth domain seismic reflection profile of the target stratum to obtain the second occurrence domain of the target stratum.

8. The apparatus according to claim 7, characterized in that, Also includes: The output module is used to output a prompt message indicating that the pre-stack depth domain seismic data does not meet the requirements after determining that the first attitude domain and the second attitude domain of the target stratum do not match.

9. The apparatus according to claim 7, characterized in that, The judgment module is specifically used for: If it is determined that the dip angle of each dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region satisfy the dip angle matching rule, then the first dip region of the target stratum and the second dip region of the target stratum are matched; wherein the first dip region and the second dip region include the same number of dip segments and correspond one-to-one.

10. The apparatus according to claim 9, characterized in that, The tilt angle matching rules include: The dip angle of each dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region belong to the corresponding threshold range, and the absolute value of the error between the dip angle of each dip segment in the first dip region and the dip angle of the corresponding dip segment in the second dip region is less than the corresponding set value.

11. The apparatus according to claim 7, characterized in that, The first establishment module is specifically used for: The well trajectory of the target formation is established with an aspect ratio of 1:

1.

12. The apparatus according to any one of claims 7 to 11, characterized in that, Also includes: The third acquisition module is used to obtain the seismic data attitude after well trajectory extension based on the second attitude domain of the target stratum and the target layer position; The determination module is used to determine whether to adjust the dip of the well trajectory based on the dip angle corresponding to the next drilling trajectory of the target formation and the dip angle of the last dip segment in the second dip domain of the target formation.

13. An electronic 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 computer program, it implements the method according to any one of claims 1 to 6.

14. A computer-readable storage medium having a computer program stored thereon, characterized in that, When the computer program is executed by a processor, it implements the method described in any one of claims 1 to 6.

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