14 results about "Measured depth" patented technology

This invention relates to the field of earthwork trenching technology, specifically to a method and system for excavating slope trenches for prefabricated quick-assembly grid beams. In this invention, by collecting high-density discrete coordinates of the slope and constructing a reference straight-line vector connecting the beginning and end, the geometric correction depth of each surface point relative to the ideal flat bottom surface is calculated. This eliminates nonlinear errors caused by the original slope undulations, ensuring that the bottom surface of the trench accurately adapts to the straight-line configuration of the prefabricated components. The resistance gradient change characteristics during the excavation process are combined with a clustering algorithm to dynamically lock the interface between soft and hard geological layers. The excavation depth required by the geometric design is fused and compared with the measured depth of the geotechnical boundary in the same coordinate system. Based on the comparison results, differentiated cutting or stripping commands are intelligently generated. When encountering hard rock layers higher than the designed bottom surface, a fuzzy PID algorithm is activated to enhance hydraulic driving force and ensure cutting efficiency. In soft soil operating areas, standard pressure is maintained to reduce energy consumption.

This invention relates to the field of oil and gas exploration technology, and discloses a method for determining the lower limit depth of sandstone reservoir exploration based on diagenetic evolution constraints. Based on the measured porosity, permeability, and corresponding measured depth of sandstone of different lithologies within the study area, compaction evolution equations and permeability evolution equations for each lithology are fitted and constructed according to the diagenetic evolution mechanism. The economic lower limit of stable daily production per well is determined according to the economic evaluation of oil and gas development in the study area. Based on oil testing data, quantitative relationships between production capacity and porosity, and between production capacity and permeability are established. The economic lower limit is converted into corresponding lower limits of reservoir porosity and permeability, which are then substituted into the compaction evolution equations and permeability evolution equations for each lithology to obtain the lower limit depth of exploration for that lithology using current technology. This invention reveals the evolution law of reservoir properties with depth for different lithologies from a genetic perspective, organically coupling economic and technical conditions with geological laws to achieve accurate and differentiated prediction of the lower limit depth of exploration.

A borehole stability index can be determined by using received user inputs and received subterranean formation characteristics. The portion of the subterranean formation characteristics that represent the rock stresses can be transformed to a coordinate system, such as a cylindrical system. Subterranean formation parameters can be calculated from the transformed characteristics. A lithology-specific algorithm can be applied to the subterranean formation parameters to generate a borehole stability index. The borehole stability analysis can then be performed using the subterranean formation parameters. The borehole stability analysis can be performed at incremental radial distance layers into the subterrane formation from a borehole wall. The borehole stability analysis can be performed at various measured depth layers within a measured depth interval of the borehole where the borehole stability index is the algorithmic combination of the individual calculated borehole stability indexes at each measured depth layer.

Methods and systems are provided for automated closed-loop control of drilling trajectory during directional drilling, which define target inclinations and / or target azimuths for a sequence of automated control loops performed over distances of measured depth during directional drilling, wherein the sequence of automated control loops transition from drilling a curve or bend in a wellbore to drilling a horizontal or lateral section or tangent section of the wellbore. In embodiments, the sequence of automated control loops can be configured to incrementally change dog leg severity of the wellbore in a pre-defined manner with the final dog leg severity being at or near zero.

Data from a well survey includes information on wellbore depth in combination with inclination and azimuth or bending moment taken at measured depth intervals with sufficient short spans to detect micro doglegs in a wellbore over lengths less than, for example, thirty meters. A conversion quantifies micro dogleg severity detected for expression in units of degrees per standardized set length. The converted quantification may also be used in circle-based equations to determine maximum tool length or width for passing tools through the wellbore due to the micro doglegs. Disposing the tool in the wellbore may occur at a location identified to accommodate the tool.

An apparatus for drilling a well which includes a drill bit (2) arranged at the end of a length of drill tubing (4), a motor (3) to rotate the drill bit and steering means to steer the drill bit, and including torque measuring means (5) to measure the torque applied to the drill bit continuously and processing means to calculate values for the mechanical specific energy (MSB) and measured depth data over time whilst drilling. The processing means includes comparison means which is configured to compare the measured data with known data to determine the nature of the formation (6) being drilled compared to known types of formation, and which processing means is configured to indicate a change from a first formation type to a second formation type, thus indicating the presence of a formation boundary, when the drill bit is adjacent to or just past the formation boundary (7).

The application relates to the technical field of oilfield development, in particular to a horizontal well liquid production profile detection method based on a magnetic resonance multiphase flowmeter. An inlet end of the magnetic resonance multiphase flowmeter is connected with an oil outlet end of a coiled tubing through well control devices of a well head, an outlet end of the magnetic resonance multiphase flowmeter is connected with an external transport pipeline, and an oil inlet end of the coiled tubing is arranged in a target layer section of a horizontal well. The method comprises the following steps: obtaining the flow rate of produced liquid of the target layer section by using the magnetic resonance multiphase flowmeter; obtaining the phase content rate of the produced liquid of the target layer section by using the magnetic resonance multiphase flowmeter; calculating the fluid production of the target layer section based on the flow rate, the phase content rate and the pipe diameter of the coiled tubing; repeating the above steps until the measurement of the fluid production of all layer sections of the horizontal well is completed; matching the fluid production of each layer section of the horizontal well with the measured depth, and drawing the horizontal well liquid production profile. The method can solve the problems of high cost, unstable precision and influence on production timeliness of the current production logging technology.

The utility model belongs to the technical field of measurement and detection, and discloses a depth template detection tool, which comprises a base (1), a spring pressing plate (2), a standard square block (3), a pressing block (4), a depth micrometer (5), a detected depth template (6) and a gauge block (7), the base comprises a bottom plate which is horizontally arranged and a vertical plate which is vertically arranged at the left end of the bottom plate; the depth micrometer (5) is arranged at the right end of the bottom plate, the measured depth template (6) and the gauge block (7) are arranged on the bottom plate in parallel, and the left ends of the measured depth template (6) and the gauge block (7) are flush with the right end surface of the standard square block (3); a spring pressing plate (2) is arranged between the left end surface of the standard square block (3) and the vertical plate; the measured depth sample plate (6) is pressed on the bottom plate through the pressing block (4); and the length of the gauge block (7) is the same as the designed length of the measured depth sample plate (6). The device can be applied to the verification work of the depth sample plate, the accuracy of the verification result is improved, and the verification work time is shortened by 30%.

An automated workflow for processing dual arrival events consisting of: (1) an automated time pick that located and characterized dual compressional and shear arrival events present in acoustic waveform measurements; and (2) a ray tracing inversion procedure that inverted these time picks and constructed a locally layered formation model of slowness along the well trajectory. The disclosed workflow embodiments provide the following benefits: (1) an automated time pick which estimates the variation of the arrival event with measured depth and determines whether the shoulder bed is above or below the well track; and (2) a ray tracing inversion that determines the raypath type of the dual arrival event. The disclosed workflow embodiments provide a log display of tool layer and shoulder bed compressional and shear slowness which is useful for making correct porosity, VP / VS, and Poisson ratio estimates as well as other geomechanics answers.

Methods and systems are provided for automated closed-loop control of drilling trajectory during directional drilling to a geological target, which employ a surface-located predictive controller that interfaces to and cooperates with a downhole trajectory control system to automatically control the drilling direction of a drilling tool during the directional drilling. The predictive controller is configured to receive data representing a new reference trajectory for a given measured depth and generate output data representing a sequence of set-points for the new reference trajectory. The predictive controller is further configured to communicate the output data to the downhole trajectory control system to automatically control the drilling direction of the drilling tool to follow the new reference trajectory.

A method for extracting thermal energy from a geothermal reservoir having one or more features extending through the geothermal reservoir includes analyzing subsurface data to determine a measured depth of a feature of the one or more that intersects a production well, running a downhole tool along the production well to a location corresponding to the measured depth of the feature, and performing an intervention at the location using the downhole tool, wherein the intervention includes injecting a reactive solution into the feature, wherein the reactive solution is configured to penetrate the feature to a desired depth and according to a desired pattern based on an injection rate of the reactive solution into the feature and a reaction rate of the reactive solution with the feature.

The present application relates to the technical fields of measurement while drilling and data management, in particular to a real-time data management system based on near-bit geological parameter calibration, comprising: a data acquisition module capable of real-time acquisition of original data near the drill bit; an adaptive correction module capable of correcting original geological data, dynamically adjusting the sampling rate and compression strategy of the corrected geological data; an independent depth module capable of extracting axial motion acceleration using original acceleration data and original magnetic force data, obtaining downhole independent depth and error covariance thereof through inertial recursion; a depth alignment module capable of fusing the downhole independent depth and the ground measured depth to obtain optimal depth estimation and depth uncertainty thereof; aligning the corrected geological data with the optimal depth estimation to generate a logging-while-drilling curve with depth uncertainty; and an uncertainty management module capable of quality marking and visualization of the logging-while-drilling curve according to the depth uncertainty.

Methods and systems are provided for automatic closed-loop control of a drilling trajectory during directional drilling that define a target tilt angle and / or a target azimuth angle of a sequence of automatic control loops executed over a distance of a measured depth during directional drilling, wherein the sequence of automatic control loops transitions from a curved or curved portion in the drilled wellbore to a horizontal or transverse or tangential portion of the drilled wellbore. In an embodiment, the sequence of automatic control loops may be configured to progressively vary the dogleg severity of the wellbore in a predefined manner, the final dogleg severity being zero or near zero.

This invention belongs to the field of ultra-deep well depth correction, and discloses an ultra-deep well depth correction method, system, equipment, and storage medium. The method involves dividing the drill string's entry length into the well into two segments based on measuring points, acquiring the measured depth and temperature data, and the depth and axial tension data for each measuring point. Pre-constructed thermal expansion correction models and elastic tension correction models are input to calculate the total thermal expansion and total elastic tension. Finally, the corrected well depth is output based on the drill string's entry length. This method effectively solves the problem of insufficient accuracy in traditional well depth measurement due to drill string deformation, significantly improves the depth accuracy of ultra-deep well drilling, simplifies the correction calculation process, enhances operational convenience, and provides data support for wellbore trajectory reliability assessment, avoiding the shortcomings of existing correction methods such as poor performance, complex calculations, and lack of assessment models.