Method for controlling operations in well and system for well-drilling

FIELD: mining industry.

SUBSTANCE: system includes mathematical model of drilling process in form of combined influence of conditions at pit-face and of drilling column operation. Model of drilling process is constantly renewed by results of well measurements performed during drilling operation. On basis of renewed drilling process model a set of optimal drilling parameters is determined and sent to system for controlling surface equipment. Also, system allows surface equipment control system to automatically adjust current control sets for surface equipment on basis of renewed optimal drilling parameters. Different control scenarios are generated and executed for transferring data to surface equipment control system on basis of current drilling mode.

EFFECT: optimized operation.

2 cl, 7 dwg

 

Link to simultaneously consider the application

This application declares the priority of provisional patent application U.S. No. 60/362009, registered on March 6, 2002

The technical field to which the invention relates.

The invention relates in General to the field of process control drilling for hydrocarbons. More specifically, the invention relates to optimized the operations of drilling, based on borehole measurements.

Prior art

Management of oil drilling is carried out by making decisions and immediate action drill master, Manager of mechanical and electrical systems of the rig. Drilling foreman, in a typical case, be directly controlled from the ground control station, for example, the rate of penetration of the drill pipe and its position attached to the string of drill pipes vertical load, the speed of rotation of the drill pipe and the flow rate of the drilling fluid. These parameters, among others, can be controlled within certain limits, such as the physical limitations of the rig equipment or, in some cases, the preset limits the input or output parameter, for example, may be limited torque load attached to the string of drill pipes. You the PRS drilling parameters wizard is the result of his General understanding of the feedback signals, it received from the surface equipment, and General observations. This incomplete information, because it is, in the typical case, does not include direct information about the behavior of the drill pipe string in the well, probatively strata or formations to be drilled, and their relation to the input parameters on the surface and the possible consequences and efficiency.

Currently, the drilling technique uses a large amount of ways to control the drilling and devices for their implementation, which allows to increase the efficiency of the drilling Assembly.

From the publication SU 1086143, E 21 In 44/00, publ. 15.04.1984 adopted by the applicant as a prototype, there is a method of control in the well, including the construction of an adaptive model of the technological process of drilling, representing the interaction terms in the bottom hole with the work of the drill pipe string, getting multiple results downhole measurements of drilling conditions during operation in the well, updating the model of the drilling process based on the results of downhole measurements of drilling conditions, shall determine the set of optimal drilling parameters based on the updated model of the drilling process, transferred to the control system ground equipment data about the optimal drilling parameters and Mogok atoe repeating the operations of receiving, updates, definitions and transmission during operation in the well.

In the model building exercise filling model of the drilling process parameters representing the Geology of the formations surrounding the wellbore.

When data transfer operations carried out definition drilling mode and execute the script sequence-based management of drilling mode.

In the prior art (see publication SU 1086134, E 21 B 44/00, publ. 15.04.1984) known system of drilling wells to determine the optimum operating levels for ground drilling equipment containing a string of drill pipe for drilling the wellbore, many measuring devices located in the string of drill pipes to produce results downhole measurements when working in the borehole, the downhole processing system containing the programmed commands stored in memory with the system when their performance is made with the possibility of constructing a model of the drilling process, representing the interaction terms in the bottom hole with the work of the drill pipe string, update the model of the drilling process based on the results of downhole measurements of drilling conditions, determine the set of optimal drilling parameters on the basis of the updated model of the drilling process, transmit to the control system ground equipment given what's on the optimal drilling parameters and repeated retrieval operations, updates, definitions and transmission during operation in the well. Measurement of drilling conditions contain measurement for estimation of parameters.

Widely used automatic optimal regulation of the process of deepening of wells that can be used to predict the optimal values of performance bits with heterogeneous drillability of the formation.

From the publication SU 1231946, E 21 B 44/00, publ. 27.11.1995 known system of drilling wells containing the interface control system ground equipment for communication with the control system ground equipment for receiving and transmitting data between the control system ground equipment and downhole processing system in which the processor is used for automatic control of ground equipment on the basis of the optimum drilling parameters.

Brief description of the invention

The described system of management operations in the wellbore using a computational model of the drilling process, representing a combined result of the conditions in the wellbore and work the drill pipe string. The model of the drilling process is continuously updated through the downhole measurements carried out in the drilling process. On the basis of the updated model of the drilling process is determined by the set of optimal drilling parameters, parade is involved in the control system ground equipment.

Additionally, it describes a system that allows the control system ground equipment to automatically adjust the current settings of the control surface based on the updated optimum drilling parameters. Developed and implemented various management scenarios to inform the control system ground equipment based on the current drilling mode.

In addition, the described system, which includes the model of the drilling process, representing operating parameters for process control drilling, reservoir properties that affect the drilling process, and properties of the mud that affect the drilling process.

In addition, the described system, which receives data from the control system ground equipment in addition to the data received according to the results of downhole measurements to update the model of the drilling process.

Brief description of drawings

Figure 1 depicts a typical configuration of the rig.

Figure 2 depicts a diagram showing software components of the described subject matter.

Figure 3 depicts a block diagram of the sequence of operations management software components, shown in figure 2.

Figure 4 depicts a block diagram of the sequence of operations during the descent of the drill pipe using the variants of embodiment of the invention, shown in figure 2 and 3.

Figure 5 depicts a block diagram of the operation of determining the mechanical ROP using embodiments of the invention shown in figure 2 and 3.

6 depicts a graph of the operation of determining the pressure of the hydraulic fracturing using embodiments of the invention shown in figure 2 and 3.

Detailed description of the invention

The interaction between the drilling process and the breed is the key to understanding and management of the drilling process. According to one variant of the invention, the downhole measurements carried out during the drilling process for a dynamic transmission model of layers of data representing the current downhole conditions while drilling. The updated model layers along with the current status and operating limitations for ground-based equipment is used to assess the current drilling modes and transmission to the control system ground equipment data about the updated operating parameters such as operating limitations and recommended optimal configuration and installation.

Figure 1 shows a drilling system 100 equipped with communication means between the control system ground equipment and systems for downhole measurements. As shown in figure 1, a drilling system 00 includes column 102 drill pipe, hanging on the drilling rig 106. Column 102 drill pipe passes through the drill rotor 108 in the bore 110. By the end of the column 102 drill pipe attached drill bit 112, and drilling carried out by rotating the upper actuator 142, with winch drive 144 holding the column 102 drill pipe, allows the pressure of the weight of the column 102 drill pipe on the drill bit 112. Drill bit 112 can be rotated by rotating the entire column 102 drill pipe communicated with the surface using a top drive 142 or drilling of the rotor 108 and the leading drill pipe 114. Alternatively, the drill bit 112 can rotate independently from the column 102 drill pipe through the downhole hydraulic downhole motor 116 located above the drill bit 112.

During drilling, drilling fluid is pumped drilling pumps 118, located on the surface 120, through the riser 122 and down the column 102 of drill pipes. The drilling fluid flowing in the column 102 of the drill pipe is pushed out through the jetting nozzle (not shown) at the end of the drill bit 112 and returns to the surface through the annular space 124 of the well, i.e. the space between the wall 110 of the well and casing 102 of drill pipes. To measure the necessary conditions in the borehole, one or more measurement module is 127 in downhole node columns 102 of drill pipes is one or more sensors or transducers 126. For example, the Converter 126 may be a strain gauge, which measures the load on the drill bit, or a thermocouple that measures the temperature in the bottom of the borehole 110. If necessary, you can apply additional sensors for measuring other parameters of drilling and rocks described above.

The results of measurements made by the sensors 126 are transmitted to the surface through the drilling fluid in the column 102 of drill pipes. First sensors 126 send signals representing the measured condition in the borehole, the downhole electronic unit 128. The signals from sensors 126 may be converted into digital form by the analog-digital Converter. Downhole electronic unit 128 accumulates binary characters or bits corresponding to the measurement results of the sensors 126, and forms one data frames. In data frames can be added extra bits for synchronization and error detection and correction. The signal is transmitted in accordance with a known technique, for example, on the carrier through the drilling fluid in the column 102 of drill pipes. Various electronic means, associated with mud pulse telemetry over a communication channel, known and for the sake of simplicity, will not be further be described here. The sensor 132 pressure on the riser 122 detects changes in pressure of the drilling fluid and generates alerts the crystals, reflecting these changes. The output signal of the sensor 132 pressure is converted into digital form by the analog-digital Converter and processed by the processor 134 signals, which allocates signs accepted by the carrier and sends the data to the computer 138. Can use other ways of communication with downhole tools, for example, data on drill pipe with a wired means of communication.

The results of downhole measurements, including data about the string of drill pipes, formation data, and other data reflecting conditions in the well, take, for example, the computer 138, and analyzes manually, for example, third-party service provider, serving the oil field. Based on the data produced reports sent to interested parties, such as drill master. This part of the reception and analysis of data about the conditions in the well is usually done separately from the automated control system for the ground equipment. Within the use of data reports about the conditions in the well to control the parameters of the drilling is carried out manually after the reports are generated and analyzed drill masters.

The second system, called system 140 control ground equipment, configured in such a way that it is related to the difference is the major equipment in the area of wells and manages its work. For example, the system 140 control ground equipment transmits the control signals and receives feedback signals from the upper actuator 142 to regulate and maintain the speed of rotation of the drill pipe, mud pump 118 to control the flow of drilling fluid passing through the system, and from the winch drive 144 to regulate and maintain the vertical load on the drill bit. The control system ground equipment can be configured so that she was connected with many other ground-based mechanisms that are involved in performing downhole operations, and managed.

Figure 1 also illustrates a typical operation of drilling multiple ground layers, each of which may exhibit very different characteristics. Due to these differences, the optimum drilling process may be different for each layer of the earth. In addition, although not shown, different segments of the drilling, for example, directional drilling may require the appointment of different optimal and threshold settings for drilling. Downhole measurement system 126 and 127 are used to detect changes of reservoir properties and the initiation or suggestions perform the modification control ground equipment. The results of downhole measurements also reflect the current conditions of the well, essential to the drilling process, such as the load on the drill bit, rate of penetration, the position of the drill bit and other.

Figure 2 shows a conceptual representation of one approach to the implementation of the described subject matter. The management process, for example, consists of script execution sequence of control operations and parameter values for each control operations. To build management process in accordance with the described embodiment of the invention applied to the following operations:

1) Definition 202 sequence control.

2) Definition 208 criteria for use.

3) Evaluation 220 parameters.

4) Definition 222 criterion to change the parameter.

The determination of the sequence of control operations includes the primary control 204 for normal operation, for example, drilling, lowering the drill pipe string and so on, and secondary control 206 to work other than normal, for example, in bad situations, such as loss of circulation of drilling mud, sticking the pipe string, excessive vibration. These control operations will be determined by the group of qualified professionals or individuals before it is required, and they will be built with consideration of model layers in the area targeted for drilling Operations management preserve in the database, which is a reference to one model layers.

For each sequence control will be the criterion to use 208. They can be entered manually, that is, the specialist will instruct the system to execute the script, or as a result of the automated analysis, for example, when there is excessive vibration that will start dampening script. Each scenario is introduced in module 208 criteria for use, which consists of:

a) Model 210 layers is independent of path properties in a geological context.

(b) a description of 212 wells - the size, location, content (e.g., drilling mud), orientation.

c) Describe 216 of the drill pipe geometry and characteristics, etc.

d) Model 218 drilling process simulates the interaction of the above items (a)-(C)by asking specific scenario. It may consist of several components.

The model of the drilling process is inverted to set the parameters for the script control.

Each management scenario can have several sets of parameters that will be stored in the database associated with the model layers. When they need to change, can be determined manually or automatically. For example, there may be changes in the parameters (for example, a vertical load is on the drill bit) in the scenario of drilling on the basis of lithological properties problemo layer.

Assessment 220 parameters includes receiving real-time or close to real time scale and the analysis of the results of measurements from downhole and surface equipment. Assessment 220 parameters include standard processing associated with specific devices included in the string of drill pipe, for example, configured as described 216 of the drill pipe. The evaluation process 220 parameters can also perform confirmation processing for confirming that certain characteristics "make sense" based on the model layers 210 and model 218 drilling process, for example, for a particular segment of the drilling or reservoir.

The criterion for change 222 option creates a framework for the implementation of the dynamic model 210 layers, descriptions, 212 wells and model 218 drilling process. For example, although the specific model layers initially configure on the basis of the expected ground layers, if the current in-situ measurements show a new layer or another depth of this layer, the model layers update to reflect these new lithological properties. Criterion 222 to change the parameter defines the limits of the parameter, which, when compared with the results from module 220 parameter estimation, provide the update and getting the appropriate model that takes into account izmenyaushemsia.

It should be noted that the combination of model layers 210 and model 218 drilling process it is possible to predict the future behavior of the system. It will also be possible to control the current drilling on the basis of expected future response of the system. This can be useful, for example, to increase the service life of drill bits.

Figure 3 shows a typical sequence of operations options for performing communication schemes described control system for the ground equipment. Starting in module 208 criteria for use, the input signals from the model layers 212, descriptions 214 wells and descriptions 216 of the drill pipes enter the model 218 drilling process to determine in real-time or near real-time forecast of current drilling. From the model 218 drilling process given a set of parameters 302 current management addressed in current scenario 304 control. Based on the input parameters of the script 304 control updates the interface 306 of the control system ground equipment, for example, the new optimized working installations and new threshold values. The process continues in paragraph 308 of the current control surface and downhole systems.

The system is adapted to dynamically update themselves based on the current operating conditions, including the response is from the ground, and downhole equipment. For example, based on the current control during the operation 308 is triggered a number of responses to update the model module 208 criteria for use. In addition, current monitoring conditions during the operation 308 may result during the operation 310 to change the script and the execution of another script. For example, if during the operation of the descending columns of the current set of control parameters reflects the resumption of normal drilling, the current scenario of the descent of the column is closed, and during the operation 310 will switch to the script drilling, such as scenario directional drilling. In paragraph 316 operation is performed diagnostics in part to determine the correct script to continue drilling or other operations. In this example, in operation 318, the resumption of drilling will be recognized as an event known drilling process and will cause the automatic execution during operation 322 new scenario, for example, directional drilling. If the new terms were not detected during the operation 318, the system is in operation 320 may transfer control to the drilling master, for example, continuous operation.

In the case when the set of current parameters does not mean the need to change the current scenario in the course of the operation 310, the system determines whether you have changed the e of one or more parameters of the current script. This situation occurs for example when the current drilling mode the output value in the process of drilling close to the emergency threshold, such as a sudden increase in the torque load during normal drilling. In this example, may be premature transition to the emergency eject script, but it may be appropriate to increase the flow rate of the drilling fluid to the drilling bit to avoid privacyware the drill bit. If during the operation 312 prescribed change option or during the operation 322 is activated a new scenario, in operation 302, the set of parameters is updated in the scope of the relevant parameters that exist in the system. If required parameters are not available under the current scenario, in operation 314, the control returns to module criterion to use to update the model to include new drilling parameters, such as transfer current control settings from one scenario to another, as well as initiating a new scenario with the most recent specific operating conditions.

The implementation of the above discussion can be illustrated by the example shown in figure 4, to control the rate of descent of the pipe in the wellbore to prevent the loss of circulation of drilling mud. First, x is de operation 402 is selected to run the script "the descent into the well". When the script does not exist, the operator can choose the option that allows you to build a script to order. Continuing in operation 404, the calculated pressure of the hydraulic fracturing model-based layers and descriptions of wells for each level of depth of the well or any other limitation of maximum pressure. These calculations are based on the measurement results 403 in real-time or near real coming from downhole tools to the string of drill pipes. To specify the maximum working pressure is introduced safety factor. Next, in operation 406 calculates the speed of advancement of the pipe (on the basis of descriptions of the well and the drill pipe and mud), which gives the maximum working pressure for each level of the well. The set of parameters of the script is filled during the operation 408 calculated control parameters, in this case, the maximum speed of advancement of the pipe at a specified depth. The script is executed with simultaneous current control during the operation 410 of the wellbore on the status of the failure. If a failure condition is detected, in operation 412, the script is replaced with, for example, if there is a loss of drilling fluid, performed scenario "loss of circulation of drilling mud" or is switched is on manual control.

On figa shows the block diagram of the operational sequence for a variant embodiment of the invention in relation to the management of mechanical rate of penetration (ROP). Typically, during the operation of drilling progress through the multilayer formation (shown in figv), where the layers have different physical properties, mechanical speed of drilling is determined to problemo at the moment of formation. As shown in more detail in figa, during operation 502 with a ground control station requested the script control mechanical speed of drilling. During drilling operations, for example, you can manually initiate the process. The script contains information about the model of the drilling process and communicates with the model layers. According to one variant of the invention, the model is stored independently from any of the many different scenarios of the drilling process. In this case, the script, for example, executes the request, require the necessary information from the model.

Drilling in the first layer formation begins at operation 504. The script then in operation 506 initiates the sequence, which rebuilds the various drilling parameters, causing a change in the drilling operations. Examples of drilling parameters include vertical load on the drill bit, the motor speed of rotation of the drill pipe,the position of the drill bit, etc. The drilling parameters change slightly in combination with each other in accordance with predetermined algorithms. The feedback circuit provides obtaining real-time response to a combination of reconstruction parameters. The feedback circuit, for example, may include well-known surface and downhole devices.

Based on the response of the feedback system uses the model variables drilling process and model layers to determine during operation 512 optimal mechanical ROP for problemo at the moment of formation. In operation 508, the measurement results as a response to the feedback at the same time are used to validate the current model layers. If the detected deviation, the model layers is updated during the operation 510 to reflect the new measurement results. This process occurs continuously during the entire drilling process of the first layer. The script continuously or upon request associated with an interface control system for the ground equipment to supply its new optimized operational data generated by the script.

According to another variant embodiment of the invention, the mechanical speed of drilling is optimized over the entire depth of the formation. In this case, the mechanical speed etc is checked for problemo at the moment of the reservoir is continuously compared with the currently active model layers, includes information for known and predicted depths to maximize the total mechanical ROP entire formation.

This method provides an automatic description of the characteristics of drilling for the formation through the automatic control of drilling parameters. The complex optimization algorithms (for example, the algorithm Monte Carlo etc) can continuously be applied in real-time. In addition, the script is able to make changes in the drilling process using a dynamic representation of the model layers in combination with the model of the drilling process.

Thus, the drill master is continuously updated operating range to control mechanical speed of drilling. According to one variant of the invention, the system generates an output signal in the form of a minimum level, maximum level, the optimal level and similar relative specified values. However, according to one variant of the invention, the minimum or maximum levels are not presented as absolute values, that is, as a certain number of revolutions per minute. This frees drill master from the need to believe that you may need permanent change of values of the rotation speed. On the contrary, continuous accurate led on the spacecraft into optimal working configuration invisible to the drill master. Easily achieved full automation of the drilling process with elimination of interference drill master at all (except for emergencies), whereby the script automatically detects the current optimal configuration.

Another variant implementation of the invention can be used to automatically control the operation of lowering and lifting of the scraper. In this case, either manually or automatically requested script lowering and lifting of the scraper. The process of lowering and lifting of the scraper is specifically associated with work in the range of pressures in the well. If the scraper is moving too fast, concomitant pressure drop under the drill bit is capable of applying a destructive force to the wellbore, sometimes unexpectedly causing the escape of gas into the wellbore.

A typical scenario process calculates the maximum rate of movement based on a combination of variables included in the model of the drilling process and model layers. In particular, the variable model of the drilling process may include hydraulic characteristics that relate the properties of the fluid and the movement of the pipe with the bottom-hole pressure. Alternatively, the hydraulic model can be included in the system as a module, separate from the model layers and the model of the drilling process. Hydraulic model, for example, configured for that is its reflection dynamically active view properties of fluid in the downhole portion of the well, and configured to account for changes in the properties of the drilling fluid due to changes in temperature and pressure and other factors, including the accumulation of drill cuttings.

The results of measuring the actual pressure can send the downhole devices to ensure interoperability in real-time model of the drilling process. Model layers in combination with a hydraulic model is used for the continuous comparison of the measurement results in real time with the current variable layer, for example, pore pressure, the pressure of the formation fracturing pressure hydraulic fracturing, etc. Thus, the feedback signals coming into the scenario scraper, give to the drilling master or fully automated controller, the speed of movement of the scraper is derived based on the current drilling conditions. It increases the effectiveness and safety compared with the known techniques, which depend on the given constraints, based on projected drilling conditions.

An additional option is shown in figure 6. Figure 6 presents a typical cross-section of the fault problemo layer. Schedule, in one embodiment of the invention, is used to select the density of the drilling fluid and evaluation of the working threshold density for a given spending the e flow of drilling mud. In particular, the x-axis represents the weight of the drilling fluid in the wellbore at the depth of the well. Alternatively, x can be used pure pressure values instead of the weight of the drilling fluid or the pressure gradient.

Figure 6 shows the range of densities of the mud (i.e. allowable mud density), estimated prior to drilling the well. Drilling with the drilling fluid (i.e. liquid), the density of which goes to the left of the line of destruction that leads to destruction. Conversely, drilling mud, the density of which goes to the right of the line of departure of the drilling fluid, will cause the absorption of the mud layer. The goal is the implementation of the drilling process by maintaining the pressure in the well, excluding these two extremes. Thus, according to this variant embodiment of the invention, the script mud flow rate is requested from another script process to maintain the proper flow of the drilling fluid in the wellbore and the wellbore. When the drilling process is ongoing, the results of downhole measurements in real time continuously compared with the model layers, including the pressure of the hydraulic fracturing, and processed using computerized optimization algorithms to determine n the improper balance between the flow of mud and other parameters, associated with particular carried out by the drilling process.

We have described above the typical options for automatic control of the drilling process using a dynamic model of the reservoir based on feedback. The above processes are selected as part of those processes, which are usually a running drill master. However, many other processes (not shown), such as directional drilling and drilling section (from point X to point Y), and change many other variables drilling parameters, such as continuous values D&I can be automated without departing from the described subject matter.

Described variant embodiment of the invention provides advantages over the known technical solutions. At the most basic level increased the overall efficiency of the drilling, because the process is bound to the specific properties of the reservoir model reservoir. In addition, since information about these properties is reviewed and updated during the drilling process, the model layers dynamically verifies its identity to better represent the existing and expected drilling conditions. The automated nature of the drilling process allows continuously optimized in accordance with established, sometimes complex algorithms, including multi-nested loops. Poetin directions automation extends the optimization process, whereas extensive database over a long period of time dimension in the processes of drilling, as well as the results of current measurements that were not used according to the prior art.

A continuous flow in the automated system of data about the drilling parameters during the drilling process feedback in real time provides improved consistency and accuracy of changes in drilling parameters, such as speed reduction running in the hole or increased mechanical ROP. In addition, constraints can be characterized as a floating maximum and minimum specified value, such as 90% of the automatically calculated the maximum number of revolutions per minute, which are dynamically updated, thus eliminating the interpretation of drilling master the physical limit of the absolute value of a parameter, such as a certain number of revolutions per minute.

Although the invention has been described in relation to a limited number of variants of its implementation, specialists in the art upon reading this description it will be clear that can be developed other embodiments of the invention without departing from the scope of the invention described here.

Accordingly, the scope of the invention should Ogre is NICEVT only by the attached claims.

1. The method of controlling the operation in the well, at which carry out the construction of the model of the drilling process, representing the interaction terms in the bottom hole with the work of the drill pipe string, getting multiple results downhole measurements of drilling conditions during operation in the well, updating the model of the drilling process based on the results of downhole measurements of drilling conditions, shall determine the set of optimal drilling parameters based on the updated model of the drilling process, transferred to the control system ground equipment data about the optimal drilling parameters and the repeated operations for retrieving, updating, determining and transmitting in progress in the borehole, wherein when the update operation advanced carry out updating the model of the drilling process based on the operational data of ground-based equipment received from the control system ground equipment.

2. The method according to claim 1, characterized in that during operation build the model additionally carry out filling model of the drilling process parameters representing the Geology of the formations surrounding the wellbore.

3. The method according to claim 1, characterized in that when data transfer operation is optionally carried out definition drilling mode and the execution of the script sequence is control-based drilling mode.

4. The method according to claim 3, characterized in that when data transfer operations transfer script output sequence control to the control system ground equipment.

5. The method according to claim 3, characterized in that the set of scenarios, sequence control is maintained at the same time.

6. The method according to claim 3, characterized in that scenario sequence control performs an operation selected from a group including operation of the descent into the well, the control of mechanical ROP, the pressure control of hydraulic fracturing, management, directional drilling, drilling site, the operation of the slip and the fishing operation.

7. The method according to claim 1, characterized in that the model of the drilling process contains the model layers.

8. The method according to claim 1, characterized in that the model of the drilling process includes hydraulic model.

9. The method according to claim 1, characterized in that when measuring drilling conditions provide measurements for formation evaluation.

10. The method according to claim 1, characterized in that it further perform the operation of automatic control of ground equipment on the basis of the optimum drilling parameters.

11. System of drilling wells to determine the optimum operating levels for ground drilling equipment containing interface management system is of ground equipment for communication with the control system ground equipment, the string of drill pipe for drilling the wellbore, many measuring devices located in the string of drill pipes to produce results downhole measurements when working in the borehole, the downhole processing system containing the programmed commands stored in memory with the system when their performance is made with the possibility of constructing a model of the drilling process, representing the interaction terms in the bottom hole with the work of the drill pipe string, update the model of the drilling process based on the results of downhole measurements, determine the set of optimal drilling parameters based on the updated model of the drilling process, transmit to the control system ground equipment data about the optimal drilling parameters and multiple repetition update operations, definitions and transmission during operation in the well, wherein the update operation further comprises updating the model of the drilling process based on the operational data of ground-based equipment received from the control system ground equipment.

12. System for drilling according to claim 11, characterized in that the operation of building the model further comprises populating the model of the drilling process parameters representing the Geology of the formations surrounding the wellbore.

13. Systems is drilling wells in claim 11, wherein the operation data further comprises determining the drilling mode and the script execution sequence based management of drilling mode.

14. System for drilling according to item 13, wherein the operation data includes transmitting the script output sequence control to the control system ground equipment.

15. System for drilling according to item 13, wherein many scenarios sequence control run at the same time.

16. System for drilling according to item 13, wherein the script sequence control performs an operation selected from a group including operation of the descent into the well, the control of mechanical ROP, the pressure control of hydraulic fracturing, management, directional drilling, drilling site, the operation of the slip and the fishing operation.

17. System for drilling according to claim 11, wherein the model of the drilling process contains the model layers.

18. System for drilling according to claim 11, wherein the model of the drilling process includes hydraulic model.

19. System for drilling according to claim 11, characterized in that the measuring drilling conditions contain measurements for formation evaluation.

20. System for drilling according to claim 11, atricauda is the, the processor is configured to perform automatic control of ground equipment on the basis of the optimum drilling parameters.

21. System for drilling according to claim 11, characterized in that it further comprises an interface control system ground equipment for receiving and transmitting data between the control system ground equipment and downhole processing system.



 

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FIELD: mining industry.

SUBSTANCE: system includes mathematical model of drilling process in form of combined influence of conditions at pit-face and of drilling column operation. Model of drilling process is constantly renewed by results of well measurements performed during drilling operation. On basis of renewed drilling process model a set of optimal drilling parameters is determined and sent to system for controlling surface equipment. Also, system allows surface equipment control system to automatically adjust current control sets for surface equipment on basis of renewed optimal drilling parameters. Different control scenarios are generated and executed for transferring data to surface equipment control system on basis of current drilling mode.

EFFECT: optimized operation.

2 cl, 7 dwg

Drilling plant // 2250342

FIELD: construction industry.

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EFFECT: higher efficiency.

4 cl, 6 dwg

FIELD: well drilling equipment, particularly for laying pipelines and for trenchless engineering system forming.

SUBSTANCE: system includes several hydraulic monitors, planetary reducers of rotator and control unit. Each hydraulic monitor is provided with fixed sliding unit located between hydraulic monitor and planetary reducer of drivers providing rotary and reciprocating movement and made as three flanges. The main flange is secured to planetary reducer, upper and lower ones are connected one to another and installed on hydraulic monitor body. Joint between the flanges is provided with sealing member. The main flange has parallel levers on which hydraulic cylinders connected with pressure-gauges are mounted. Hydraulic cylinder rods are connected with stop screws of upper flange lever. Two hydraulic cylinders and two pressure-gauges are installed on each hydraulic monitor. Pressure-gauge scales are recalibrated to index of torque developed by hydraulic monitor and are installed on gauge board located on drilling rig slider. Two regulating throttles are installed on liquid feed lines, which supply each monitor with working liquid.

EFFECT: possibility to determine power to synchronize operation of several hydraulic monitors.

7 dwg

FIELD: oil production industry, particularly for applying pressure to chisel providing with downhole motor.

SUBSTANCE: method involves installing acoustic noise transducer above downhole motor; converting downhole motor noise into ultrasound so that ultrasound have action on friction reduction between drill string and bottomhole motor and well walls to apply following effective pressure to chisel in accordance with geological-technical order.

EFFECT: increased efficiency of deviating and horizontal well drilling.

1 ex, 4 dwg

Well drilling rig // 2265121

FIELD: mining industry, particularly for drilling exploratory and pressure-relief wells before mineral extraction from formations, including outburst-dangerous formations and ones characterized with high gas content.

SUBSTANCE: drilling rig comprises housing, support, drive to rotate drilling rod provided with cutting tool and hydraulic cylinder for cutting tool pulldown. Electrohydraulic valve is installed in hydraulic cylinder circuit. Electric drive of electrohydraulic valve is linked with load-sensing unit, which detects load applied to drilling rod rotation drive. The electric drive is connected to load-sensing unit through amplifier relay to provide bringing amplifier relay into operation when load applied to rotation drive exceeds nominal load by 20-30%. Cutting tool is made as symmetric screw conveying surfaces defining forward and reverse strokes connected one with another through generatrix. Side cutting edges of surfaces defining forward and reverse strokes are spaced apart.

EFFECT: increased operational reliability along with reduced power inputs for drilling, possibility to remove rod from well with negligible deviation thereof from predetermined direction of drilling.

2 cl, 3 dwg

FIELD: borehole drilling, particularly to control drilling machine rod rotation.

SUBSTANCE: method involves performing drilling machine rod rotation frequency with the use of microprocessor-controlled servomotor on the base of signals received from rotational velocity and feed rate sensors. Above control is performed in two stages. At the first stage cutter rotation frequency is smoothly changed from 50 rpm to 700 rpm and optimal rotation frequency value corresponding to maximal drilling speed is determined with the use of microprocessor, which controls the servomotor. At the second stage optimal cutter rotation speed is set by microprocessor-operated servomotor.

EFFECT: increased reliability and accuracy of drilling machine rod rotation control.

2 cl, 3 dwg

FIELD: measuring equipment engineering, possible use for measuring flow and properties of solutions, in particular, in oil-gas extractive industry for controlling flow and properties of drilling and cementing agent during drilling of wells and their cementing.

SUBSTANCE: system contains indicators of pressure and temperature, device for measuring density of solution, device for measuring conductivity of solution, computing device, information display. Indicators of pressure and temperature, device for measuring solution density, solution conductivity meter and computing device are positioned in compact manner within one measuring module, installed in main pipeline; measuring module contains additionally device for measuring pressure drop on narrowing device, solution density meter is made in form of two-probe gamma density meter with low-background source of gamma-radiation, computing device provides, in accordance to given algorithm, for determining and computation of volumetric flow of solution, of mass flow of solution, of solution density, of electric conductivity or mineralization of solution, of solution temperature, of system pressure, content of solid phase in solution, well hydraulic losses coefficient; measuring module via information cable is connected to information display for controlling the process of drilling or cementing.

EFFECT: increased parameters being measured, increased reliability of system operation and decreased costs of same.

9 cl, 2 dwg

FIELD: measuring equipment, possible use for measuring volume, density and temperature of liquids in reservoirs connected to atmosphere in oil and gas extractive industry and prospecting for controlling volume, density and temperature of washing liquid in receiving and topping up vessels of drilling plants during drilling of wells.

SUBSTANCE: system contains at least two measuring modules, each one of which is represented by a structure, consisting of two coaxially positioned pipes, connected in upper section to hermetic section, in which devices for measuring level, pressure and temperature of washing liquid are positioned, electronics block, measuring modules are provided with overhanging supports for mounting in vessels and are connected by information cables to information display of driller.

EFFECT: increased precision of parameters being determined, and also increased reliability of system operation and decreased complexity of maintenance due to simplification of construction.

8 cl, 2 dwg

FIELD: automatic control systems specially adapted for well drilling operations used for drilling and operation of wells, blast-holes and for other procedures.

SUBSTANCE: recorder comprises body with electronic unit and power supply unit arranged in the body. Electronic unit includes microprocessor with executive program, x and y plane accelerometer, nonvolatile memory microcircuit, calendar time timing means, temperature sensor and data input-output port, which provides data output and input in computer with the use of communication interface. Microprocessor output is connected to the first input of nonvolatile memory microcircuit. X and y plane accelerometer is linked to the first microprocessor input, calendar time timing means is communicated with the second microprocessor input and temperature sensor output is connected to the third microprocessor input. Temperature sensor input is connected to power supply unit. Input and output of data input-output port are linked to microprocessor. Input of data input-output port is connected to power supply unit. Calendar time timing means input, the forth microprocessor input and accelerometer input are linked to the second nonvolatile memory microcircuit input.

EFFECT: increased accuracy and information content due to recording of new parameters, hydraulic downhole motor rotation speed, vertical tool vibration, temperature measurement and data binding to calendar time with high accuracy and decreased size.

2 dwg

FIELD: well drilling, particularly drilling of slightly inclined wells along with current well coordinate measurement.

SUBSTANCE: method involves determining axial load applied to bit, bit rotation speed, drilling mud supply rate and current hole bottom coordinates, namely zenith, apsidal and azimuth angles; measuring natural gamma radiation of rock to be drilled and longitudinal drilling string vibration by means of sensors included in downhole instrument of telemetering system provided with communication channel to communicate hole bottom with day surface; determining lithologically uniform drillable rock bound and longitudinal drilling string vibration corresponding to them; comparing obtained values of actual longitudinal bit vibrations with that obtained from estimated dependence and if above values differ drilling operation is terminated and bit is lifted for inspection thereof.

EFFECT: increased time of bit presence in well bottom.

1 ex, 2 dwg

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