Downhole tool for reservoir testing

FIELD: oil and gas production.

SUBSTANCE: group of inventions refers to oil and gas producing industries, particularly to tools for survey of reservoirs and for sampling. The group of inventions consists of a tool, of a method of evaluation of parametres of underground reservoir, and of a method of well sampling. The facility includes a unit lowered into the well on a cable; the unit is installed at a preset position in the going to the underground reservoir borehole of the well; the unit is equipped with a boring tool recovering samples of core from the reservoir and a tool for reservoir testing designed to sampling of fluid mediums in the reservoir; in working position this tool is connected with the boring tool recovering samples of core.

EFFECT: increased efficiency of operation, reduced dimensions, combining separate tools in the same component.

27 cl, 17 dwg

 

Background of invention

Well, as a rule, drill into the earth to extract natural oil and gas deposits, as well as other desirable materials enclosed in the geological strata of the earth's crust. The well drill into the ground and sent to a specific geological situation from the drilling rig at the Earth's surface.

After interest layer is reached, drillers often explore the reservoir and its contents through the use of downhole tools (instruments) for estimating parameters of the reservoir. Some types of downhole tools for estimating parameters of a productive formation form part of the drill string and are used during the drilling process. They are called, for example, downhole tools (instruments) for "logging while drilling (PBC)or downhole tools (instruments) for measurement while drilling (IPA)". Other downhole tools for estimating parameters of a productive formation used in some time after the well is drilled. Typically, these downhole tools lowered into the well, using the cable for electronic communications and transmission of energy. These tools are referred to as downhole tools, down to the cable.

One type of downhole tool, turn on the Abele, called the "tool for testing layer (probowalem layer)". The term "tool for testing layer" is used to describe such a downhole tool for measuring parameters of the reservoir, which is able to suck the fluid from the formation into the downhole tool. In practice the instrument (device) for testing seam can perform many functions evaluation of reservoir parameters, such as the ability to perform measurements (i.e. measurements of pressure and temperature fluid), to process the data and store samples of the reservoir fluid. Thus, in this description, the term "tool for testing layer covers the downhole tool, which sucks the fluid from the formation into the downhole tool (instrument) to assess, regardless of stores whether the instrument samples or not. Examples of tools for evaluating reservoir shown and described in U.S. patent No. 4860581 and 4936139, which are both assigned to the assignee of the present invention.

During operations on the reservoir test borehole fluid, as a rule, absorbed in the downhole tool and subjected to measurement, analysis, collected and/or produced. In cases where fluid medium (usually produced fluid) is collected, what is sometimes called the "sampling fluid," she as a rule, absorbed in the selected cell and is transported to the surface for further analysis (often in the laboratory).

When fluid is drawn into the instrument, as a rule, perform a variety of measurement parameters downhole fluid for determination of reservoir properties and reservoir conditions such as the pressure of the fluid in the reservoir, the permeability of the reservoir and point initial boiling point of the reservoir fluid. Permeability refers to the filtration capacity of the reservoir. High permeability corresponds to the low resistance to the motion of the fluid. Point initial boiling point refers to the pressure fluid, in which the dissolved gases will be released in the form of bubbles from the reservoir of fluid. These and other properties can be important when making decisions about wells.

Another downhole tool, generally, the descent into the well bore by means of a cable, called "core drilling tool (tool for drilling with coring)". In contrast to instruments for testing of the reservoir, which are mainly used for sampling fluid, the tool for drilling with coring is used to obtain the sample reservoir rock.

A typical tool for drilling with coring includes core bits, called "core drills", to the which serves forward into the wall of the reservoir, so the sample is called "the core sample (column breeds)can be extracted from the reservoir. Then the core sample can be moved to the surface, where it can be analysed to assess, among other things, "capacity" of the reservoir (called the porosity and permeability of the material that forms a layer, the chemical and mineral composition of fluid and mineral deposits contained in the pores of the formation, and/or residual water in the material layer. Information obtained from analysis of the core sample, can also be used for making decisions concerning wells.

Downhole operations for coring, generally fall into two categories: axial drilling with coring and drilling a lateral coring. "Axial drilling with coring"or conventional core drilling involves the application of axial force to submission core drill bit in the borehole bottom. As a rule, this is done after the drillstring is removed or raised from the well bore, core bit for rotary drilling with a cavity for receiving the core sample down into the hole on the end of the drill string. An example of a tool for axial drilling with coring shown in U.S. patent No. 6006844, assigned to Baker Hughes.

On the contrary, when the drilling side coring" core bit will DIGOUT in the radial direction of the downhole tool and leaned forward through the side wall of the drilled wellbore. When drilling with a side coring drill string, as a rule, cannot be used to rotate the coring bit, and it also cannot ensure the availability of load required to feed the bit into the formation. Instead, the tool for drilling with coring should create a torque which causes rotational movement of the coring bit and the axial force called the load on the drill bit", needed to feed the drill bit firmly into the reservoir. Another problem associated with the drilling side coring, refers to the size limits of the wellbore. The available space is limited by the diameter of the wellbore. There should be enough space to accommodate a device designed to actuate the core bit, and enough space to extract and store the core sample. The type of core in side the selection of the core has a diameter of about 1.5 inches (about 3.8 cm)and a length less than 3 inches (about 7.6 cm), although the dimensions may vary with size of the wellbore. Examples of tools for drilling lateral coring shown and described in U.S. patent No. 4714119 and 5667025 the same applicant.

Like downhole tools for testing seam tools for drilling with coring, as a rule, put in the trunk squag the us on the cable after the completion of drilling for the analysis of downhole conditions. Additional operations commissioning descent on the cable downhole tool for testing the formation and subsequent commissioning of descent on cable tool drilling with coring causes additional delay of work in the wellbore. It is desirable that operations formation test using cable and drilling with coring using cable were combined in one tool, descent into the hole on the cable. However, the energy requirements of conventional tools for drilling with coring were incompatible with a valid power of existing re-entry on cable oprobivala layer. A typical tool for drilling a lateral coring consumes a power of approximately 2.5 to 4 kW. On the contrary, the usual tools for testing of the reservoir, usually made with the possibility of generation capacity, which constitutes only about 1 kW. Electronic and power connectors (connections) in the downhole tool (apparatus) for sampling formation, as a rule, are not intended to transfer power to ensure the work of the descent on cable tool drilling with a side coring.

It should be noted that in U.S. patent No. 6157893, assigned to Baker Hughes, shows the drilling tool from the tool for drilling with coring and probe. the contrast of operations with the use of cable drilling tools have additional features, generation and transmission of energy generated by the flow of drilling mud through the drill string. The additional energy provided by the drilling tool, currently unavailable for transactions using the cable. Thus, there is a need in the descent into the well on a cable node, capable how to take samples of the fluid, and drilling with coring.

In addition, it is desirable that any downhole tool with the combined abilities perform drilling with coring and sampling of the reservoir had one or more of the following characteristics: improved performance on the testing and/or sampling, the reduced size of the tool, the ability to perform drilling with coring and formation test in the same location in the wellbore and/or by means of one and the same instrument and/or the ability to efficiently and effectively combine separate tools for drilling with coring and sampling in the same component and/or downhole tool.

The invention

In one or more embodiments implementing the invention relates to spuskaemogo on the cable node, which includes the tool for drilling with coring designed for taking core samples from the reservoir, and a tool for evaluating reservoir, DL designed the sampling fluid from a formation, tool to test reservoir connected in operating position with the tool for drilling with coring.

In one or more embodiments implementing the invention relates to a method for estimating the parameters of the reservoir, which includes the downhill descent on the cable node in the wellbore, the actuation tool for evaluating reservoir attached to the node, descent into the well on a cable to obtain samples of fluid from the reservoir, and actuation of the tool for drilling with coring attached to the node, descent into the well on a cable for receiving the core sample.

In one or more embodiments implementing the invention relates to a downhole tool, comprising a housing for the tool with the hole, core bits, located near the hole in the tool body and selectively retractable through him, and the discharge line, located near the coring bit, and sealing surface located near the distal end of the outlet line.

In one or more embodiments implementing the invention relates to a method of sampling borehole samples (samples), which includes obtaining the core sample through the use of core drill bit located on the unit for sampling and sample in the downhole tool is ment, a rotation unit for sampling, establishment messages fluid between the bypass line in the unit for sampling and sample matrix and the extraction of formation fluid from the reservoir through the drain line.

In one or more embodiments implementing the invention relates to a method of sampling borehole samples (samples), which includes the establishment of messages fluid between the bypass line in the downhole tool and the formation through the promotion packer seal for contact with the formation, receiving the core sample through the use of core bits are made to the configuration, allowing to push in the sealing zone packer seal, pulling the core from the coring bit in the selected cell and the extraction of formation fluid from the reservoir through the drain line.

In one or more embodiments implementing the invention relates to the mounting connection, intended for the connection of tool modules, which includes a top module having a bottom connector mounting connection at the lower end of the upper module and the lower module having a top connector mounting connection on the upper end of the lower module. The upper module may include a cylindrical body which is intended for receiving the lower module, the first on the water line, adapter with female sockets having at least one covering the nest. The lower module may include a second gate line, the adapter covered with pins and one or more covered pins located in the specified adapter so that at least part of one or more covered pin protrudes upward from the specified adapter.

In one or more embodiments implementing the invention relates to a method of joining two modules borehole site, which includes the insertion of a bottom module in the cylindrical body of the upper module, insert the covered pins in the adapter with the covered pins in the lower module into the holes covering the slots in the adapter covering the slots in the upper module, the lowering of the adapter with the covered pins with adapter with female sockets and insert the covered connector outlet line at the top module in covering the outlet connector line the bottom of the module.

Other aspects and advantages of the invention will become apparent from the following description and appended claims.

Brief description of drawings

Figure 1 shows the schematic view of the descent into the well on a cable node that contains the tool for testing the formation and the tool for drilling sampling ke is on.

Figa is a schematic view of a tool for drilling with coring prior art.

Figv shows a schematic view of the tool for drilling with coring in accordance with one embodiment of the invention.

Figure 3 shows a graph showing the dependence of the efficiency of the engine for drilling with coring of the output power for two different velocities of flow of the working fluid in the engine for drilling with coring.

Figure 4 shows a plot of torque required for core bits, speed, and mechanical drilling speed.

Figure 5 shows the schematic view of the system of regulating the load on the bit in accordance with the embodiment of the invention.

6 shows a graph illustrating the gain in power for core bits depending on the bit position for the standard core bits.

Figa shows the cross section of the mounting connection prior to Assembly in accordance with one embodiment of the invention.

Figv shows the cross section of the mounting connection after Assembly in accordance with one embodiment of the invention.

Figs shows a magnified portion of the cross section of the mounting connection after Assembly in accordance with one embodiment of izopet the deposits.

Figa shows a cross-section of part of a downhole tool in accordance with one embodiment of the invention.

Figv shows a cross-section of part of a downhole tool in accordance with one embodiment of the invention.

Figs shows a cross-section of part of a downhole tool in accordance with one embodiment of the invention.

Fig.9 shows the cross-section of part of a downhole tool in accordance with one embodiment of the invention.

Figure 10 shows one variant of the method in accordance with the invention.

11 shows one variant of the method in accordance with the invention.

Fig shows one variant of the method in accordance with the invention.

Detailed description

Some embodiments of the present invention relate to spuskaemogo into the well on a cable node containing low-power tool for drilling with coring, which can be attached to the instrument for sampling reservoir. Other embodiments of the invention relate to the mounting connection that can be used to attach the tool for drilling with coring tool for sampling reservoir. Some embodiments of the invention relates to downhole tools is into, which includes a split node for sampling reservoir and drilling with coring.

Figure 1 shows a schematic view of the device 101, the descent into the barrel 105 wells from the drilling rig 100 in accordance with one embodiment of the invention. Spuskaemogo into the hole on the cable, the device 101 includes a tool 102 for sampling reservoir and the tool 103 for drilling with coring. The tool 102 to test reservoir connected in operating position with the tool 103 for coring through the mounting connection 104.

The tool 102 for sampling reservoir includes a transmitter 111, which may be ejected from the tool 102 for sampling reservoir to ensure its messages fluid from the formation F. the Supporting piston 112 can be included in the device 101 to facilitate pushing of the probe 111 to enter it into contact with the lateral wall of the wellbore and to stabilize the tool 102 in the wellbore. The tool 102 for sampling of the reservoir shown in figure 1, also includes a pump 114 to discharge the sample fluid through the tool and selected the camera 113 for storing samples of fluid. It may also include other components, such as power module, hydraulic module, the analysis module of the fluid and other devices.

The tool 103 for drilling with coring who engages node 125 for drilling with coring, made with a coring bit 121, area 124 of the storage for storing core samples, and interacting mechanisms 123 control (for example, mechanisms, shown in figure 5). In some embodiments, the implementation, as will be described below with reference to figv, tool 103 for drilling with coring consumes less than approximately 2 kW of power. In some particular embodiments, the implementation of the tool 103 for drilling with coring may consume less than approximately 1.5 kW and, in at least one embodiment, the tool 103 for drilling with coring consumes less than 1 kW. It may be desirable to combine tool 103 for drilling with coring tool 102 for sampling reservoir. Thrust lever 122 is used to stabilize the device 101 in a well bore (not shown), when the coring bit 121 runs.

The device of figure 1 is shown as having a set of modules connected together in the working position. However, the device also may be partially or fully represent the whole. For example, as shown in figure 1, the tool 102 for sampling layer may be a single entity, the tool for drilling with coring will be placed in a separate module attached in operating position by means of the mounting connection is of 104. Alternatively, the tool for drilling with coring can be integrated as a single unit in a common housing of the device 101.

Downhole tools often include multiple modules (i.e. sections of the tool, which perform different functions). In addition, more than one downhole tool or the component may be combined on the same cable to perform many tasks in the well during the same course of the cable. Modules are typically connected to wired connections, such as mounting connection 104, shown in figure 1. For example, one module of the tool for testing layer generally has a connector of the same type on its upper end and the connector of the second type at its lower end. The upper and lower connectors are designed to mate with each other in the working position. Through the use of modules and tools with the same designs of connectors all modules and tools can be connected end-to-end to form the knot, the descent into the well on a cable. Mounting connection can provide electrical connection hydraulic connection and the connection of drainage lines, depending on the requirements of the instruments on the cable. Electrical connection, as a rule, creates the possibility of power supply and communication.

In practice, tool, the descent into the well on a cable typically includes a number of different components, some of these components may consist of two or more modules (e.g., an instrument for testing the reservoir can be enabled sampling and pumping module). In this description, the term "module" is used to describe any of the individual instruments or the individual modules of the tools that can be connected to the node, descent into the hole on the cable. The term "module" refers to any part of the site, the descent into the well on a cable regardless of whether the module is part of a tool in a larger size or by separate instrument. It should also be noted that the term "tool, the descent into the well on a wire", is sometimes used in the art to describe the whole site, the descent into the well on a cable, including all of the individual tools that make up the site. In this description, the term "node, the descent into the well on a cable, is used in order to prevent any confusion (any "confusion") with separate tools, which form the node, the descent into the well on a cable (for example, a tool for drilling with coring tool for evaluating reservoir and the NMR instrument can be included in one node, the descent into the well on a cable).

2 is provided which provides a schematic view of the descent into the well on a cable tool 210 for drilling with coring prior art. The tool 210 includes a node 204 for drilling with coring with hydraulic motor 202 for drilling with coring, which drives the coring bit 201. Core bit 201 is used to retrieve the core sample (not shown) from the reservoir.

For submission core bits 201 into the reservoir it must be pressed into the reservoir in the process of bringing into rotation. Thus, the tool 210 for drilling with coring provides the application load on the bit, i.e. the force which presses the core bit 201 into the reservoir, and torque to the core bit 201. The tool 210 for drilling with coring shown in figa includes mechanisms for application both force and torque. Examples of apparatus for drilling with coring mechanisms for the application of weight on bit and torque are disclosed in U.S. patent No. 6371221 the same applicant.

The load on the bit in the tool 210 for drilling with coring prior art is created by motor 212 AC and node 211 management, which includes the hydraulic pump 213, the control valve 214 stream with feedback and kinematic piston 215. The motor 212 AC delivers energy to the hydraulic pump 213. The flow of working fluid from the hydraulic pump 213 regulares the valve-regulator 214 stream with feedback, and the pressure of the working fluid provides the actuation kinematic piston 215 to apply the load on the bit to core bit 201.

Torque is served by another electric motor 216 AC gear pump 217. The second motor 216 AC drives the gear pump 217, which delivers a steady stream of working fluid in the hydraulic motor 202 for drilling with coring. Hydraulic motor 202 for drilling with coring, in turn, provides the application of torque to the core bit 201, which causes the core bit 201 to rotate. Typically, gear pump 217 pumps approximately 4.5 gallons per minute (~17 liters per minute) of the working fluid under pressure from about 500 psig (~3,44 MPa). This creates a torque of approximately 135 inch-ounce (~0,953 Nm) at consumption from 2.5 to 4.0 kW, depending on the efficiency of the system. Typical operating speed (speed) core bit 201 is approximately 3000 rpm/min

As shown In figure 2, the tool 220 for drilling with coring in accordance with one embodiment of the invention uses two brushless motor 222, 226 DC instead of electric motors variable is th current on figa. Brushless motors 222, 226 DC made with the possibility of a more efficient operation compared to AC motors, which creates the possibility of tool 220 while consuming less energy (with less power). The tool 220 for drilling with coring on FIGU can be used, for example, in the tool 103 for drilling with coring of figure 1. While the ability of a tool for drilling with coring with a smaller capacity makes it useful for applications using descent by cable (together with the accompanying probowalem layer or without it), it can also be used in other downhole tools.

The first brushless motor 222 DC connected in operating position with the node 221 management, including hydraulic pump 223, the valve 224 and kinematic piston 225. The motor 222 DC drives the hydraulic pump 223, and the working fluid is pumped through the valve 224. The valve 224 is preferably a solenoid valve with pulse-width modulation. The valve control can be performed so as to provide for the regulation of the load on the bit. As will be described below with reference to figa and 6B, the solenoid valve can osushestvljali is so, that kinematic piston 225 is to apply a constant load on the bit, or so that the load on bit is adjusted to maintain a constant torque on the core bit 201.

The second brushless motor 226 DC drives the gear pump 227 high pressure, which feeds the working fluid in the hydraulic motor 202 for drilling with coring. In some embodiments, the implementation of the gear pump 227 high pressure is used for supplying a working fluid at a higher pressure and lower flow rate than in tools for drilling with coring prior art. This system provides what is termed here "low". For example, the tool 220 for drilling with coring shown in figv, can provide the injection of the working fluid at a rate of about 2.5 gallons per minute (~9,46 l/min) at a pressure of about 535 pounds per square inch (~3.7 MPa). The reduced flow rate of the working fluid to the hydraulic motor 202 for drilling with coring will bring core bits 201 in action with a lesser rate. For example, the velocity component of 2.5 gallons per minute at 535 pounds per square inch (~9,46 l/min and ~3,7 MPa), can provide speed core Dolo is a, component approximately 1600 rpm

This configuration may allow the consumption tool 220 for drilling with coring less than 2 kW of power. In some embodiments, the implementation of the tool 220 for drilling with coring may consume less than 1 kW of power.

Figure 3 shows a graph 300 according to engine efficiency for drilling with coring (Y-axis, in %) output power (axis X, W) for the two tools for drilling with coring. On this chart you can compare the dependence of efficiency on power tool 210 for drilling with coring on figa and tool 220 for drilling with coring on FIGU within the operating power range up to approximately 300 watts.

The first curve 301 shows the efficiency of the engine 202 for drilling with coring on figa at a flow rate of 4.5 gallons per minute (~17,03 l/min). At 300 watts, typical maximum output power tool for drilling with coring, the efficiency reaches its maximum 303 of approximately 30%. The second curve 302 shows the efficiency of the engine 202 for drilling with coring on figv at a flow rate of 2.5 gallons per minute (~9,46 l/min). The second curve 302 shows the maximum efficiency 304, accounting for more than 50% at an output power of 300 watts. Thus, by reducing the flow rate of 4.5 gallons per minute (~17,03 l/min) up to 2.5 g is Llona per minute (~9,46 l/min) motor efficiency for drilling with coring can be increased to values in excess of 50%. When the output power 300 W motor for drilling with coring with 50%efficiency will require input power less than 1 kW. This reduction of the required power creates the possibility of using the tool for drilling with coring together with a tool for testing the formation.

Figure 4 shows a three-dimensional graph 400 according to the required torque of the rotational speed in rpm and mechanical ROP for the model layer. A typical tool for drilling with coring vyborove the sample core in about 2-4 minutes. In this interval, no significant changes required torque with respect to the rotational speed of the drill bit. For example, at point 402 to 3000 Rev/min and 2 min/Kern tool for drilling with coring required torque, slightly in excess of 100 inch-ounce (~0,706 Nm). At the point 404 to 1500 Rev/min and 2 min/Kern drill bit also requires torque, slightly in excess of 100 inch-ounce (~0,706 Nm). Thus, the tool for drilling with coring in accordance with some variations of the invention made with the possibility of drilling and receiving the core sample at the same time as tools for drilling with coring prior art, but with lower power consumption.

Typical tools the coefficients (devices) for sampling reservoir, as a rule, not be able to provide power for tools for drilling with coring prior art. Low-power tool for drilling with coring on FIGU may consume power, constituting less than about 1 kW. At this reduced power consumption of one or more options for the implementation of low-power tool for drilling with coring can be combined with a tool for sampling reservoir so that as the sample fluid, and the core samples can be obtained during the same stroke of the cable. An additional advantage is that the sample fluid and the core sample can be obtained from the same location in the wellbore, which creates the opportunity for analysis of reservoir rock and fluid that it contains. Tools for drilling with coring and sampling can be installed in a predetermined position so as to provide the testing and/or sampling and samples from the same location or locations in a certain way relative to each other. However, for the ordinary practitioner in the art it will be obvious that one or more of the advantages of the present invention can be implemented even without the use of low-power tool glyburide with coring.

Figure 5 shows the node 500 control designed to regulate the load on the bit for coring bit. The control unit can be used, for example, as a site management tool for drilling with coring on figv. The node 500 includes a hydraulic pump 503, which pumps the working fluid in the hydraulic line 506 to the kinematic piston 507. Hydraulic pump 503 draws working fluid from the reservoir 505 and pumps the working fluid to the kinematic piston 507 on the pressure line 506. Kinematic piston 507 converts the hydraulic pressure into a force which acts on the motor 502 for drilling with coring to create a load on the bit. The valve 504 in the drain hydroline 509 creates the possibility of draining the working fluid from the pressure line 506 adjustable manner, so that the hydraulic pressure in the pressure line 506 and ultimately on kinematic piston 507 accurately controlled.

The valve 504 may be a solenoid valve with pulse-width modulation. The valve 504 is connected in the operating position with the regulator 508 with pulse-width modulation. The controller 508 with pulse-width modulation controls the valve based on the input signals from sensors 521, 531. Preferably solenoid valve 504 with pulse-width modulating the on switches between an open position and a closed position with high frequency. For example, the valve 504 can operate with a frequency of approximately 12 to 25 Hz. The portion of time during which the valve 504 is open determines the amount of the working fluid which passes through the valve 504. The greater the flow rate through the valve 504, the lower the pressure in the pressure line 506 and the less the load on the bit is applied from the kinematic piston 507. The lower the flow rate through the valve 504, the greater the pressure in the pressure line 506 and the greater the load on the bit is applied from the kinematic piston 507.

The controller 508 with pulse-width modulation can be connected in operating position with one or more sensors 521, 531. Preferably, the controller 508 with pulse-width modulation is connected at least with the sensor 521 and pressure sensor 531 torque. The sensor 521 pressure connected to the pressure line 506 so that it responds to the hydraulic pressure in the pressure line 506, and the sensor 531 torque is connected to the engine 502 for drilling with coring so that it responds to the torque output of the engine 502 for drilling with coring.

The control valve 504 may be performed so as to maintain the operational characteristics at a given level. For example, the control valve 504 may be so under arrivati essentially constant weight on bit. The control valve 504 may also be carried out so as to maintain essentially a constant torque output of the engine 502 for drilling with coring.

When the control valve 504 is performed to maintain a constant load on the bit, the controller 508 with pulse-width modulation to control the valve 504 based on the input signal from the sensor 521 pressure. When the load on the bit is too large, the controller 508 may provide a stay of the valve 504 is in the open position during most of the time. In this case, the working fluid in the pressure line 506 can flow through the valve 504 with a higher flow rate, which will lead to the reduction of the pressure acting on the kinematic piston 507, resulting in reduced load on the bit.

On the contrary, when the load on the bit will drop to values below a predetermined pressure, the controller 508 may provide a stay of the valve 504 in the closed position during most of the time. The working fluid in the pressure line 506 flows through the valve 504 with a lower flow rate, which will lead to an increase in the pressure acting on the kinematic piston 507, resulting in increased load on the bit.

When the control system on the basis of the torque sensor 531 torque measures the torque, which is ogin to the motor for drilling with coring. At a given frequency of rotation of the torque applied by the engine 502 for drilling with coring, will depend on the properties of the reservoir and the load on the bit. The controller 508 controls the valve 504 so that the torque output of the engine 502 for drilling with coring remains almost at a constant level. Given output torque may vary depending on tool and application. In some embodiments, the implementation of the given output torque of 100 inch-ounce (~0,706 Nm) to 400 inch-ounce (~2,82 Nm). In some embodiments, the implementation of the given output torque of approximately 135 inch-ounce (~0,953 Nm). In other embodiments, implementation of the given output torque of approximately 250 inch-ounce (~1.77 in Nm).

When the torque output of the engine 502 for drilling with coring exceeds a certain level, the controller 508 controls the valve 504 so that the valve 504 is open for most of the time. The working fluid with a higher flow rate will pass through the valve 504. This reduces the pressure in the pressure line 506, which causes a decrease in the hydraulic pressure acting on the kinematic piston 507. Reduced pressure on the kinematic piston 507 will lead to a reduced load on the bit and reduced the WMD torque required to maintain the frequency of rotation of the core drill bit (not shown in figure 5). Thus, the torque output of the engine 502 for drilling with coring will return to the specified level.

When the torque output of the engine 502 for drilling with coring is below a preset level, the controller 508 controls the valve 504 so that the valve 504 will be in the closed position during most of the time. The working fluid will pass through the valve 504 with a smaller flow rate. This leads to the increase of pressure in the pressure line 506, which causes an increase in hydraulic pressure acting on the kinematic piston 507. Increased pressure on the kinematic piston 507 will lead to increased load on the bit and to the increased torque required to maintain the frequency of rotation of the coring bit.

Figure 5 shows a system 500 management, which can provide load control bit to maintain a constant load on the bit, or maintain a constant torque on the core bit. Other systems may include only one sensor and to provide a control valve on the basis of measurements performed by only one sensor. Such embodiments of do not depart from the scope of the invention.

Figure 5 shows the config of the situation, in which, for example, the valve 504 is connected to the drain of hydroline 509, which passes to the reservoir 505. However, the invention is not limited thus. Other configurations are possible, such as where the valve allows removal of flow in other ways, as known in the art. Additionally, there may be used various combinations of pressure regulating and/or torque.

6 is a graph which shows the dependence of the gain in strength (Y-axis) for the load on the bit from the bit position (the X-axis, in inches/centimeters) for a typical tool for drilling sampling. Graph 601 shows that the gain in power is changed according to the interval of the provisions of the bit. Because the gain in strength is changed, the actual weight on bit will also be affected by changing the position of the bit, even if the hydraulic pressure applied to the kinematic piston (e.g., 516 figure 5), will be constant. This graph shows that the accurate maintenance of hydraulic pressure, as a rule, does not provide for maintaining a constant load on the bit. Thus, in some situations it is preferable to regulate the hydraulic pressure according to the torque.

Figa and 7B show cross-sections of the mounting connection 700 in accordance with one variant of implementation, the program of the invention. Mounting connection 700 may be used, for example, as a mounting connection 104 of figure 1. This mounting connection can be used to assemble the various components or modules of any downhole tool, such as the descent into the well on a cable by means of a flexible pipe of the drill or other tool. Figa shows the top module 701 and the lower module 702 directly before Assembly. Top module 701 includes a cylindrical sleeve 706, in which is inserted the lower module 702.

Top module 701 includes a covered connector 711 for the drain line with seals 727 designed to prevent the passage of fluid around the covered connector 711 for the drain line. Covered connector 711 for the drain line may, for example, be threaded into the upper module 701 (for example, in the area shown in General by the reference position 712). Covering the connector 751 for bypass lines in the lower module 702 is capable of receiving the covered connector 711 to the drain line when mounting connection 700 is assembled (assembled state shown in figv). The connector 711 for bypass line connects the outlet line 717 in the upper module 701 outlet line 757 in the lower module 702, so that there is a message on fluid between drainage lines 717, 757.

The top of the second module 701 also includes the adapter 714 with female sockets. Holes 753 nests are located in the adapter 714 with female sockets. Holes 753 nests are located in the upper module 701 to prevent capture or capture from outside fluid in the hole 753 nests.

The lower module 702 includes an adapter 754 covered pins 713, which are up from this adapter 754. The adapter 754 and covered pins 713 are located in a protective sleeve 773. In some embodiments, the implementation of the protective sleeve 773 held to a somewhat higher elevation than the upper part covered pins 713. In some embodiments, the implementation of the adapter 754 covered pins configured to move relative to the lower module 702 and thermowells 773. For example, on figa shows the spring 780, which provides popping adapter 754 covered by the pins in the upper position.

Perhaps the upper surface of the adapter 754 covered by the pins covered with boundary (mipomersen) seal 771, which is attached to the upper surface of the adapter 754 and has a convex protrusions that form a seal around each covered pin 713. Edge seal 771 shown in more detail in figs. Covered pins 713 protrude upward from the adapter 754. Edge seal 771 is located in the upper part of PE is ejdnika 754. Edge seal 771 preferably is an elastomeric material such as rubber, set around a covered pin 713 to prevent the flow of fluid in the coupler 754 and prevent the situation when the fluid interferes with the operation of any circuits, which can be located inside the adapter 754. In addition, the edge seal 771 compacts the end surface of the adapter 714 to displace the fluid from the space between the coupler 754 and the adapter 714 with female sockets. On figs shown closed the assembled state. Convex protrusions around each pin on the edge seal 771 provide a seal holes 753 covering the nests, so that fluid cannot enter the area of electrical connection when the modules 701, 702 are assembled together. This configuration seals are used to isolate each pin/socket electrically from the other pins and the mass of the tool.

Protective sleeve 773 may be perforated or porous. This allows fluid environments, captured inside the protective sleeve 773, to flow through the protective sleeve in the place where fluids will not interfere with the electrical connections between the covered pins 713 and holes 753 covering nests when mounting connection 700 is collected.

Figv displays the cross-section of the mounting connection 700 after Assembly. The lower module 702 is located inside the cylindrical sleeve 706 of the upper module 701. Seal 765 (e.g., annular seal) on the lower module 702 provides a seal relative to the inner wall of the cylindrical housing 706 to prevent the flow of fluid into the mounting connection 700.

Covered connector 711 to the outlet line of the upper module 701 included in the spanning connector 751 to the outlet line of the lower module 702. Seal 728 covered on the connector 711 for the drain line sealing the inner surface of the outer connector 751 for the drain line to prevent the passage of fluid around the connector 711 for the drain line. In the assembled condition of the covered connector 711 for the drain line connections for fluid between the outlet line 717 in the upper module 701 and the drain line 757 in the lower module 702.

It should be noted that this description refers to the seals, which are located in a single element to create a seal relative to the second element. For the ordinary practitioner in the art will understand that the seal can be placed in the second element for providing sealing relative to the first element. Provided that no restriction is not imposed by the description of the seal, which naili located in a particular item. Alternative configurations do not depart from the scope of the invention.

In the assembled state of the adapter 714 with covering nests presses down on the adapter 754 covered by the probes. Spring 780 creates the possibility of moving the adapter 754 down. Covered pins 713 are located in the holes 753 covering nests to create an electrical contact. The adapter 714 with covering the nest is located, at least partially, inside the protective sleeve 773.

In assembling the connection, shown in figv, protective sleeve 773 remains stationary relative to the lower module 702. Covered pins 713 also preferably located inside the protective sleeve 773. During Assembly of the adapter with female sockets comes in a protective sleeve 773 to pair with the covered pins 713 on the adapter 754, while he presses the adapter 754 down.

On figs shows an enlarged image of one part of the mounting connection 700 (figa and 7B) in the assembled position. The lower end surface of the adapter 714 with female sockets located at the boundary of the seal 771 on the upper surface of the adapter 754 covered by the probes. Covered pins 713 are holes 753 covering nests. Edge seal 771 seals holes 753 covering nests so that fluid cannot pass into the zone e is tricesimo contact when the modules 701, 702 are gathered together.

Protective sleeve 773 may include a seal 775. In an unassembled state (shown in figa) seal 775 seals the adapter 754 covered with pins to prevent the flow of fluid in the lower module 702 (figa and 7B). In the assembled state shown in figv and 7C, the adapter 714 with female sockets located so that it is in contact with the seal 775. In the assembled configuration, the seal 775 prevents the flow of fluid located in the mounting connection zone between the coupler 754 covered by the pins and the adapter 714 with covering the slots and prevents the situation in which the fluid prevents electrical contact. Seal 775 is also used to prevent the flow of fluid located in the mounting connection, in the lower module 702.

As discussed above, the protective sleeve 773 may be perforated or porous to allow passage of fluid through the protective sleeve 773. Protective sleeve 773 may be porous on the seal 775, but fluid cannot pass through the protective sleeve 773 under seal 775. Seal 775 prevents the passage of fluid through the porous protective sleeve 773 and in place between the adapter 754 covered with pins and the adapter 714 with covering the slots, and in the lower module 702.

On Fig and 9 shows the tools for evaluation of reservoir parameters, which have the ability as drilling with coring and sampling. Such a tool can be a tool, the descent into the well on a cable, or it can form part of other downhole tools, such as a drilling tool, a tool with a flexible pipe tool for completion or other tool.

Figa shows the cross section of the downhole tool 800 with a combined node 801, designed for sampling reservoir and drilling with coring, in accordance with one embodiment of the invention. Combined node can be located in the downhole tool or placed in a module made with the possibility of Association with the downhole tool.

The downhole tool 800 has a housing 802, which surrounds the combined node 801. The aperture 804 in the housing 802 tool creates the possibility of obtaining core samples and samples of the fluid from the reservoir. Hole 804 is preferably made with the possibility of his election closed to prevent the passage of fluid into the downhole tool. Combined node 801 includes block 806 for sampling. Block 806 for sampling and sample is located near the hole 804 so that it has DOS the UE to the hole 804.

Block 806 for sampling and samples may include probe 807 for selection of fluid and coring bits 808 on adjacent sides. Block 806 for sampling and sample can be rotated so that either of the two elements constituting the probe 807 for selection of fluid and coring bits 808, will be in a position where he has access to the hole 804. Figa shows a block 806 for sampling in the position in which the probe 807 for selection of fluid is in the position of the access hole 804.

The exact design of the probe for sampling the fluid is not intended to limit the invention. The following description is provided only as an example. Probe 807 for sampling a fluid medium includes a sealing surface 810, such as a packer designed for pressing against the wall (not shown) of the wellbore. When the sealing surface 810 creates a seal relative to the wall of the wellbore, a bypass line 812 in the probe 807 for the selection of the fluid will be communicated in fluid with the formation. Sealing surface 810 may represent packer seal or other seal to establish a message on fluid between the bypass line and the reservoir.

As shown in figa, pipeline 813 may be used to connect the drain line 812 in block 806 for selecting probe sample line 814 to sample the fluid in the tool 800. The connection between the drain line 812 and pipeline 813 provides the message to a fluid between the probe 807 for sampling and line 814 sample fluid.

The pipeline 813 preferably is a flexible pipe that supports the connection between the second outlet line 812 and line 814 sample fluid when the unit 806 for sampling and sample turn. The pipeline 813 provides the ability to offset the drain line 812 in block 806 for sampling and line 814 sample fluid medium relative to each other in the tool 800 while maintaining the message in a fluid environment. For example, on Fig shown In the tool 800 block 806 for sampling, rotated so that the coring bit 808 is next to the hole 804. The pipeline 813 is also moved so that the message on the fluid is still supported between the drain line 812 in block 806 for sampling and line 814 to sample the fluid in the tool 800.

In some embodiments, the implementation of the pipeline 813 is a telescopic rigid pipeline, which creates the possibility of the dynamic range of provisions. Other types of pipes or tubes can be used without departing from the scope of the invention.

To obtain a sample block 806 to select about the samples and extends through the hole 804 so, that sealing surface 810 (e.g., packer, as shown in figa and 8B) is in contact with a reservoir (not shown). Sealing surface 810 is pressed against the layer so that a bypass line 812 will be communicated in fluid with the formation. Formation fluid may be drawn into the housing 802 tool bypass line 812.

Core bits in block 808 806 for sampling and samples can be brought forward into the reservoir for receiving the core sample of the material layer. Figv shows the tool 800 block 806 for sampling, rotated so that the coring bit 808 is next to the hole 804. In this position, the coring bit 808 may be made to sample core from the reservoir (not shown). Once the core sample will be captured by the core bit 808, core bits 808 may be laid back in the tool 800. Fig In shows coring bit 808 in the designated position.

As shown in figa, after the capture of the core sample in the coring bit block 808 806 for sampling and sample can be rotated so that the coring bit 808 will be in a vertical position. From this position, the ejector 823 core can push the core sample (not shown) of the core bit 808 in the channel 822 to the core. In some embodiments, the implementation of the core may be stored in the analog 822 to the core. In other embodiments, implementation of the channel 822 for core may lead to the device for storing core samples, such as shown in figs.

Figs shows the camera 850 for storing core samples in accordance with one embodiment of the invention. Luggage 850 for storing core samples can be placed directly under the core bit and the ejection mechanism, such as core bits 808 and the ejector 823 core shown in figa. Sample core can be moved or filed with the camera 850 for core samples so that it can be retrieved at a later time for analysis.

Luggage 850 for core samples may include shut-off valves 852, 853. Shut-off valves 852, 853 can be used to separate the camera 850 for core samples into separate compartments and their isolation from each other, so that the multitude of core samples can be stored without contamination of one sample with another. For example, the lower shut-off valve 853 may be closed in preparation for storage of the core sample. Then the core sample can be moved into the chamber 850 for core samples, and the lower shut-off valve 853 will provide isolation of the core sample from something below the lower shut-off valve 853 (for example, from previously collected core samples). Once the core sample is in place, the upper locking clap the 852 may be closed to isolate the core sample from something, above the upper shut-off valve 852 (e.g., later collected core samples). Through the use of multiple isolation valves (e.g. valves 852, 853) camera for core samples can be divided into separate compartments, which will be isolated from other compartments.

It should be noted that the invention can be used other isolating mechanisms other than shut-off valves. For example, a valve with an adjustable orifice diameter or elastomeric valve can be used for isolation compartment in the sample chamber of the core. Provided that the type of valve does not limit the invention.

In some embodiments, the implementation of Luggage 850 for core samples can be connected to the line 814 sample fluid through the pressure line 857. Pressure line may include filling valve 856 for selective translation of the camera 850 for core samples in the position in which it communicates via a fluid line 814 sample fluid. In some embodiments, the implementation of Luggage 850 for core samples can be connected with the space of the wellbore through the eductor line 855. Ejector valve 854 may be selectively actuated to provide communication camera 850 for samples of core fluid from the wellbore. The term "STV is l wells" is used to describe volume, which was drilled. In the ideal case, the drilling mud clogs the wall of the well bore so that the inner space of the wellbore insulated from the reservoir. In the case where a bypass line (for example, line 812 to figa) communicates via a fluid layer, in some embodiments, the implementation of the ejector line 855 will be communicated in fluid with the wellbore.

Pressure line 857 creates the ability to store samples of the fluid in the same compartment of the camera for core samples, that is the core sample, which was taken from the same location in the wellbore. After the core sample will be in the place of storage (i.e., between shut-off valves 852, 853, which are closed), the filling valve 856 can be opened and the sample fluid can be pumped into the sample chamber of a core in the same compartment in which is stored the sample core. Ejector line 855 creates the possibility of pushing the fluid into the wellbore until then, while the core sample is completely immersed in the natural stratiform the fluid from this location.

On figs pressure line 857 is connected to the compartment (i.e. the zone between the check valves 852, 853) near the top of the compartment, and ejector line 855 is connected near the bottom of the compartment. Sample core can be stored in this position, in which egory, which formed part of the wall of the wellbore will be facing down. In this position, the area of the core sample that has been exposed to, caused by penetration of the drilling fluid, will be near the bottom of the core sample. Due to the connection of pressure and injection lines 857, 855, respectively in the upper and lower parts of the compartments, the sample fluid can provide the leaching of mud filtrate from the core sample in the process of filling the compartment natural reservoir of fluid (i.e. the breakdown of the fluid).

Fig.9 shows the cross section of the tool 900 for drilling with coring, comprising the combination tool 901 for sampling reservoir and drilling with coring in accordance with one embodiment of the invention. Combination tool 901 for sampling reservoir and drilling with coring includes probe 903 with core bits 902, located in it. The probe can be selectively retracted to enter into contact with the wall of the wellbore and create a seal relative to the reservoir. Core bits 902 can then be selectively extended (raise or drainage or without pull-out or withdrawal of the probe) to enter into contact with the wall of the wellbore.

Core bits 902 shown in figure 9 in the designated position, but it can be extended into the reservoir 91 for receiving the core sample. The tool 900 for drilling with coring also preferably includes an ejector or device 904 to eject the core. Once the core sample will be in the core bit 902, core bits 902 may be rotated, and the ejector 904 core may be nominated for removing the core sample from the coring bit 902 in storage (not shown). Combined site for sampling strata and sampling can be used in the downhole tool and rotated so that the core sample may be ejected in the selected camera. Alternatively, the core sample can be maintained in the core bit to remove it after removing the downhole tool to the surface.

The probe 903 also includes a seal for the fluid or packer 906 and the discharge line 908 for sampling fluid. When the packer 906 drawn in to the wall of the reservoir, a bypass line 908 isolated from the environment in the bore and communicates via a fluid from the reservoir. Reservoir fluids can be sucked into the tool 900 for drilling with coring outlet on line 908.

Packer 906 creates a sealing zone relative to the layer 912. Message in a fluid medium reservoir installed inside the sealed area of the packer. Hole outlet line 908 is preferably located inside the sealing zone near the packer 906. Where Lin is I 908 is also preferably adapted to receive fluid from the reservoir through the sealed area. Core bits 902 is configured to pull-out inside of the sealed zone and through the sealing zone packer 906.

In some embodiments, the implementation of a tool for drilling with coring on Fig-9 may be provided with selected cameras designed for storage of core samples and/or sample fluid. In at least one embodiment, the tool for drilling with coring can be used with the selected camera, in which the reservoir fluid stored in core samples taken from the same location in the wellbore, as the sample fluid, for example, selected camera 850, shown in figs. The downhole tool may include a separate sampling chamber for storing samples of the fluid, as is known in the art. The above description is not intended to limit the invention. Combined site for drilling with coring and sampling may also be provided with a hydraulic pump (not shown), analyzers fluid and other devices designed to facilitate the flow of fluid in the bypass line and/or analysis.

Figure 10 shows one variant of the method in accordance with the invention. The method includes the descending node on the cable in the wellbore at the stage 1002. The method also includes the AET actuation tool, for testing of the reservoir, attached to the node, descent into the well on a cable to extract formation fluid from the formation at the stage 1004. Site, the descent into the well on a cable may also include a tool for drilling with coring, which is attached to the node, descent into the hole on the cable. In this case, the method may include actuating tool for drilling with coring attached to the node, descent into the well on a cable for receiving the core sample at stage 1006.

Further, the method may include the direction of the core sample in the selected camera on the stage 1008 and the direction of the sample fluid in the selected camera on the stage 1010. Stage 1008, 1010 shown in this order, because the sample core is preferably moved to a selected chamber before the sample fluid then send in the selected camera. This creates the opportunity to full fill the selected camera breakdown of the fluid after the core sample is already placed in the selected cell. However, for typical specialists in the art it will be obvious that these operations can be performed in any order. It should also be noted that the stage 1008, 1010 are not required in all cases. For example, the core sample may remain in the core bit to transport it to the surface.

Finally, the method may include the extraction is giving node, the descent into the well on a cable, and analysis of samples and sampling stages 1012, 1014. The analysis of the sample (sample) can provide information that is used for subsequent drilling, completion or production from the well.

Figure 11 shows another variant of the method in accordance with the invention. The method includes obtaining the core sample of the rock formation at the stage 1102. This operation can be performed by means of pull-out core bit to the formation and application of torque and weight on bit to the core bit.

Further, the method may include rotating unit for sampling and sample in the downhole tool at stage 1104. This will result in rotation of the core drill bit so that the core sample may be ejected from the core bit at stage 1106. The method may also include the establishment of messages fluid between the bypass line and the seam on stage 1108. Thereafter, fluid may be extracted from the reservoir at stage 1110. Finally, the sample fluid is preferably directed to the selected camera on the stage 1112.

Fig shows another variant of the method in accordance with the invention. The method includes establishing message by fluid from the reservoir to the stage 1202. Further, the method may include receiving the core sample through pull-out kolinsky is th bit through the sealed area of the packer at the stage 1204. It should be noted that the core sample can be obtained before the establishment of messages in a fluid environment. The order of execution stages should not be considered as limiting the invention.

The method may include pushing the core sample from the coring bit in a selected camera on stage 1206. The method may also include removing a sample of fluid from the reservoir through the suction on the drain line, while the distal end of the bypass line is located inside the sealing zone packer seals on stage 1210.

Finally, the method may include the direction of the sample fluid in the selected camera on the stage 1212.

Embodiments of the present invention can provide one or more of the following advantages. Some embodiments of the invention creates the possibility of inclusion as a tool for drilling with coring and tools for sampling strata in the same node, the descent into the well on a cable or node for logging while drilling. Preferably this allows to obtain core samples and samples of the fluid from the same location in the wellbore. As the core sample, and the sample fluid from the same place allows to perform a more accurate analysis of the reservoir and its contents. In addition, one or more separate or and the ting that is integrated components for drilling with coring and/or sampling may be provided in many different configurations around the downhole tool.

Preferably, some embodiments of the tool for drilling with coring work with high efficiency. Higher efficiency creates the possibility of a tool for drilling with coring using less power.

Preferred embodiments of the invention, which include low-power tool for drilling with coring, create the possibility of obtaining the core sample while using less power in comparison with the prior art. In some embodiments, the implementation of low-power tool for drilling with coring consumes power, constituting less than 1 kW. Preferably schemes that are required to provide power to low-power tool for drilling with coring, have much less requirements compared with what is required in the case of tools for drilling with coring prior art. Thus, low-power tool for drilling with coring can be used in the same node, descent into the well on a cable together with other downhole tools that, as a rule, may not be capable of delivering high power required for tools for drilling with coring prior art.

Some embodiments of the tool to storm the Oia with coring in accordance with the invention include solenoid valves with pulse-width modulation as part of a feedback circuit for regulating hydraulic pressure, applied to the kinematic piston or other device that provides the application load on the bit. Preferably can be provided precise control solenoid valve with pulse-width modulation, so that the load on bit will be maintained at the specified level or approximately at the specified level.

In at least one embodiment, the solenoid valve pulse width modulation is performed on the basis of torque served on the core bit. Preferably the tool for drilling with coring with such a control device can provide precision control solenoid valve with pulse-width modulation, so that the pressure applied to the kinematic piston, will provide essentially a constant torque applied to the core bit.

Some embodiments of the invention relate to spuskaemogo into the well on a cable node, which includes mounting the connection holes covering the nests located in the lower part of the tool or module. Preferably fluid cannot be trapped in the holes covering the slots, and mounting the connection will be relatively free from interference, interfering with the electrical contacts is mswb. Preferably some options for implementation include a protective sleeve to prevent damage to the covered pins, which can be located in the upper part of the module or tool. In addition, embodiments of protective shells, which are perforated or porous, allow for passage of fluid, which could interfere with the electrical contact, through the protective sleeve and away from the electrical contacts.

Some embodiments of the node, the descent into the well on a cable in accordance with the invention include the selected camera, which creates the ability to store the core sample in the same chamber or compartment in which is stored the sample fluid. Preferably the core sample can be stored while being surrounded by the reservoir fluid medium, which is taken from the place where the sample was collected core.

Preferably selected Luggage with one or more liquid and injection lines creates the possibility of discharge of produced fluid through selected camera at a time when the core sample is selected the camera. Preferably, at least part of the mud filtrate in the core sample (i.e. mud filtrate, which has penetrated into the formation to obtain the core sample can be removed from the sample ke the to and from selected cameras.

Although the invention has been described with reference to a limited number of embodiments, for experts in the field of technology, reviewed this description, it will be obvious that can be developed other ways of implementation that do not depart from the scope of the invention as it is disclosed here. Accordingly, the scope of the invention should be limited only by the attached claims.

1. The descent into the well on a cable node, is made with possibility of installation in a predetermined position in the wellbore, held in an underground formation containing a tool for drilling with coring designed for taking core samples from the reservoir, and a tool for evaluating reservoir, designed for sampling fluid from the reservoir and connected in operating position with the tool for drilling with coring.

2. The node of claim 1, wherein the tool for drilling with coring contains the first brushless direct current motor, a hydraulic pump connected to the first brushless direct current motor, and the motor for drilling with coring, hydraulically connected with the first hydraulic pump.

3. The node according to claim 2, in which the tool for drilling with coring further comprises a second brushless who elektrodvigatel DC a second hydraulic pump connected in operating position with the second brushless direct current motor, and the kinematic piston which is connected by fluid from the second hydraulic pump.

4. The node according to claim 3, in which the tool for drilling with coring further comprises a solenoid valve with pulse-width modulation which is connected by fluid from the second hydraulic pump.

5. The node of claim 1, wherein the tool for drilling with coring further comprises a sampling chamber and the first gate line provided on the fluid outlet line tool for sampling strata and selected camera, with selected chamber configuration, providing the possibility of taking samples of core from the coring bit, located in the tool for drilling with coring.

6. The node of claim 1, wherein the tool for drilling with coring and tools for testing of the reservoir is connected by means of a mounting connection.

7. The node according to claim 6, in which the tool for testing layer contains one module selected from the group consisting of the upper module and the lower module, and the tool for drilling with coring contains another module from a group consisting of the upper module and the lower module, and the connection between these instruments is AMI includes a bottom connector mounting connection at the lower end of the upper module and the upper connector mounting connection on the upper end of the lower module, the upper module comprises a cylindrical housing designed to receive the lower module, the first gate line and the adapter with female sockets having at least one covering the slot, and the lower module contains the second gate line, the adapter covered with pins and one or more covered pins located in the specified adapter so that at least part of one or more covered pin protrudes upward from the adapter covered with pins.

8. The node according to claim 7, in which the tool for testing layer contains top module.

9. The node according to claim 7, in which the tool for testing layer contains the lower module.

10. The node according to claim 7, in which the base module further comprises a protective sleeve located around the adapter covered with pins.

11. The node according to claim 7, in which the adapter is covered with pins made with the possibility of displacement relative to the lower module and the bottom module further comprises a spring disposed under the adapter with a covered pin with application of an upward force to the adapter covered with pins.

12. The method of estimating parameters of an underground reservoir, comprising the following operations:
descent descent into the well on a cable node in the wellbore;
bringing in the step tool for evaluating reservoir, attached to the node, descent into the well on a cable to obtain samples of fluid from the reservoir;
actuation of the tool for drilling with coring attached to the node, descent into the well on a cable for receiving the core sample.

13. The method according to item 12, additionally comprising the following operations:
the direction of the core sample in the sampling chamber located in the node, descent into the well on a cable;
the direction of sample fluid in the selected cell.

14. The method according to item 13, additionally comprising the following operations:
removing a node, the descent into the well on a cable;
analysis of the core sample;
the analysis of the sample fluid.

15. The downhole tool, comprising a housing of the tool, having made a hole, core bits, located near the hole in the tool body and selectively retractable through him, and the discharge line, located near the coring bit, and
sealing surface located near the distal end of the outlet line.

16. The downhole tool according to 15 additionally containing block for sampling and samples located near the hole in the tool body, with this core bit is located at the first side of the block for sampling, and the sealing surface is located on the second hand Blo is for sampling and samples.

17. The downhole tool according to clause 16, in which the unit for sampling and samples attached to the tool can be rotated.

18. The downhole tool 17 in which the first bypass line is located in the unit for sampling and samples, and additionally includes a second bypass line and the piping connected between the first bypass line and the outlet line tool.

19. The downhole tool 15, in which the sealing surface includes packer seal, core bits are made with the possibility of promotion through the inner space of the sealed zone packer seal and the distal end of the bypass line is located inside the sealing zone packer seal and is connected in the operating position with the hydraulic pump.

20. The downhole tool according to 15 additionally containing the selected cell.

21. The downhole tool according to claim 20, in which the selected camera is divided by one or more valves.

22. The downhole tool according to claim 20, further containing a pressure line connected to the selected camera and connected to the drain line.

23. The method of sampling borehole samples through the downhole tool is made with possibility of installation in a predetermined position in the wellbore, held in an underground reservoir, comprising the following operation is:
obtaining the core sample from the formation through the use of core drill bit located on the unit for sampling and sample in the downhole tool;
a rotation unit for sampling;
the establishment messages fluid between the bypass line in the unit for sampling and reservoir;
removing the reservoir fluid from the reservoir through the drain line.

24. The method according to item 23, in which the establishment messages fluid between the bypass line in the unit for sampling and reservoir includes a pushing unit for sampling so that the packer located on the unit for sampling and sample comes into contact with the formation.

25. The method according to paragraph 24, further comprising pulling the core from the coring bit in the selected camera; and the direction of the reservoir fluid in the selected cell.

26. The method of sampling borehole samples, comprising the following operations:
the establishment messages fluid between the bypass line in the downhole tool and the formation through the promotion packer seal for contact with the reservoir;
obtaining the core sample through the use of core bits are made to the configuration, allowing to push in the sealing zone packer seal; extrusion of the core from the coring bit in the select the camera; removing the reservoir fluid from the reservoir through the drain line.

27. The method according to p, optionally including the direction of the reservoir fluid in the selected camera.



 

Same patents:

FIELD: oil and gas production.

SUBSTANCE: invention refers to oil producing industry and is designed for evaluating properties of reservoirs surrounding underground well. To achieve the object of the invention the method consists in recording time after completion of drilling at the depth interval, in determining permeability of reservoirs at the depth interval, in generating time cycling of pressure in a borehole of the well and in assessing periodic and un-periodic constituents of pressure measured in reservoirs at the depth interval. By time, periodic constituent and permeability there is determined coefficient of diffusion of pressure and water-permeability of reservoirs, also there is assessed area of zone of pressure build-up around the borehole of the well at the depth interval. Further, by time, coefficient of diffusion of pressure, water-permeability of reservoirs and un-periodic constituent there is determined an indicator of filtration of clay coating at the depth interval. By the indicator of filtration there is evaluated pressure gradient at the depth interval and extrapolation is carried out to determine reservoir pressure by pressure gradient and by area of zone of pressure build-up.

EFFECT: upgraded accuracy of evaluation of primary reservoir pressure due to more accurate determining parametres of filtrate leakage.

21 cl, 15 dwg

Depth sampler // 2360109

FIELD: mining.

SUBSTANCE: depth sampler consists of ballast chamber, of actuator with module of control, of main and additional sample taking chambers equipped with medium-separating pistons, hydro-resistors and valve units. Each medium-separating piston is equipped with a compensating tube, which connects under-piston cavities of sampling chambers between them. Also hydro-resistor is assembled at the end of each tube.

EFFECT: simplification and upgraded efficiency of operation of units of device, decreased dimensions of sampler, improved quality of separation of taken samples, and validity of measured information.

1 dwg

FIELD: mining.

SUBSTANCE: method consists in boring vertical, horizontal or inclined borehole, in recovery of core samples from collector rock, in applying thermal analysis for identification of separate chemical compounds of collector, in determining connection of per cent concentrations of minerals with parametres of porosity and penetrability by using multi-dimensional correlation-regressive analysis and obtaining plural linear correlation equations for concrete oil and gas deposits facilitating calculation of porosity and penetrability on base of data on mineralogical composition of oil and gas deposits.

EFFECT: reduced labour intensiveness, and upgraded accuracy and validity of determination of mineralogical composition of core material.

1 ex, 2 tbl, 4 dwg

FIELD: oil and gas industry.

SUBSTANCE: invention relates to evaluation procedure of oil and gas subterranean structure field. Test of rupture by discharge/release consists of charging of fluid, gas or its combination, containing desirable additions for compatibility with structure, at discharge pressure, exceeding structure rupture pressure, with following stopping period. Pressure decay during the stopping period is measured and analysed for the detection of penetrability and resistance of rupture face by means of preparation of specialised Cartesian diagram on the assumption of stopping data by means of application of corrected pseudovariable, such as data of corrected pseudopressure and data of corrected pseudotime. This analysis provides for data on diagram to be places lengthwise straight line along with constants or depending of pressure properties of fluid. Incline and intersection of straight line are correspondingly indicators of penetrability calculation and rupture face resistance R0.

EFFECT: reduction of harmful effects influence of depending from the pressure fluids properties at penetrability calculation and rupture face resistance of tank.

86 cl, 9 dwg

FIELD: oil and gas industry.

SUBSTANCE: invention relates to oil-producing industry and provided for receiving the information about geological formation, about casing pipe or about fluid in casing pipe. For this there are used requester and one or more sensing device in borehole. Requester is located in borehole, and it is usually implemented with ability of movement inside the borehole. Sensing device, which is fix installed in cut in casing pipe hole, allows body and vessel with corresponding electronics. Body of the sensing device is usually implemented with the ability of provision of hydraulic gate relative to hole in casing pipe. Requester and sensing device implement communication to each other by wireless method.

EFFECT: providing of on-line monitoring of cased boreholes parametres with simultaneous simplification of measurements.

36 cl, 9 dwg

FIELD: physics, measurements.

SUBSTANCE: proposed set of inventions relates to oil product, particularly, to getting and analysing the samples of in-place fluid medium. The proposed method comprises the steps that follow. First, optical density data on fluid medium sample is obtained for, at least, one-colour channel, water channel or a set of optical channels by measuring wavelength optical density with the help of fluid medium analyszer, and, at least, in one channel of fluid medium component to determined the fluid medium composition or properties with the help of fluid medium downhole sampler furnished with optical pickup. The colour absorption function is defined based on optical data for fluid medium sample in, at least, one colour channel. The part of optical density subject to color absorption, absorption in water in, at least, one aforesaid channel of fluid medium component. The electronic system designed to refine the data on the fluid medium sample incorporates an input device, memory coupled with input device and memory.

EFFECT: accurate data on fluid medium sample resulted from elimination of colour, water and scattering effects.

25 cl, 13 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: invention relates to device and method allowing the bench estimation in drilling. The proposed device arranged in wellbore, nearby the subsurface bench, comprises the casing, casing fluid inlet, fluid pump communicating with the said casing fluid inlet and incorporating the first piston fitted in the pumping chamber to suck in and discharge fluid when acted upon by tubing pressure.

EFFECT: device and method higher reliability and efficiency, space saving in river drill pipes.

18 cl, 10 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: invention relates to oil-and-gas industry and can be used in analysing fluid dynamics of gas medium at hydrocarbons deposits and subterranean gas storages. The proposed method comprises forcing gas medium indicator marks representing gas-filled micro granules with the dispersion degree of 0.5 to 0.6 into the bench through different injection holes and sampling from output holes. Note that indicator mark sampling is realised by forcing gas through sampling tube along with controlling gas passing time and the hole rate of yield, the sampling tube gas flow rate is determined from mathematical expression. The content of micro particles in indicator mark is determined from mathematical expression. The invention covers also the device to embody the above-described method.

EFFECT: continuous sampling, higher sampling efficiency and validity of results.

3 cl, 1 ex, 2 dwg

FIELD: oil and gas industry.

SUBSTANCE: invention refers to well boring, and can be used for preventing and eliminating troubles and accidents during boring process performed in the areas adjacent to or located just above the buried continental rift. Method involves rock sampling during boring process, and analysis of samples. At that terrigenous rocks are sampled from oil-and-gas bearing deposits of sedimentary cover, which are adjacent to or located just above the buried continental rift; rock samples are treated with 1:1 salt acid solution; laumontite zones are revealed in terrigenous masses of the cover by occurrence of silica jelly-like mass, which can mean that there are deep hidden breaks, and the appropriate activities preventing emergency situations are carried out.

EFFECT: simplifying the prediction method at maintaining accuracy of results and reducing costs required for method realisation.

FIELD: oil and gas industry.

SUBSTANCE: invention refers to search of gas deposits, and can be used for finding hydrocarbon raw material in terrigenous rocks of sedimentary cover. Method involves rock sampling from oil-and-gas bearing deposits during boring process. At that slurry sampled from sedimentary cover areas adjacent to or located just above buried continental rift is used as samples; samples are treated with heated 50% salt acid solution, and occurrence of silica jelly-like mass can mean that deposits are available.

EFFECT: improving accuracy of definition of gas and gas-condensate deposits.

FIELD: oil and gas extractive industry.

SUBSTANCE: method includes picking a sample of bed fluid under pressure by means of pump. Sample of fluid is then compressed by moveable piston, actuated by hydrostatic pressure in well through valve. Compressed sample of bed fluid is contained under high pressure inside the chamber with fixed volume for delivery to well surface. Moveable piston is in form of inner and outer bushings, moveable relatively to each other. At the same time several tanks for picking samples from several areas may be lowered into well with minimal time delays. Tanks may be emptied on well surface by evacuation pressure, to constantly provide for keeping of pressure of fluid sample above previously selected pressure.

EFFECT: higher reliability.

6 cl, 14 dwg

FIELD: geophysics.

SUBSTANCE: probe has non-magnetic hermetic body and cylindrical base, on which a hollow cylindrical magnetic duct is placed coaxially, with ring polar end pieces, ends of which are made in form of truncated cone with slanting angle of outer surface of end to cylindrical base, equal to 30 and ring polar shelf at middle portion and two generator coils, placed on both sides of ring polar shelf, and enabled oppositely. Probe also has an even number of indicator coils - multi-coil frames without a core, having a parallelogram shape in cross-section with slanting angle of greater side thereof to cylindrical base, calculated from formula. Indicator coils are placed axially and evenly distanced from cylindrical base, re placed evenly along the circle in two rows with maintenance of alignment between the latter and adjacently between each other, are made in two wires with forming of two windings. Upper row of indicator coils is placed above ring polar shelf, lower one - below it. Windings of indicator coils are connected in couples, enabled accordingly and successively. First couple has windings with the least number of coils, and is presented diametrically by opposite windings of indicator coils from different rows, and second - windings with number of coils being in 1.5 times greater and is formed due to connection of identical windings of indicator coils, placed at minimal space from each other, from different rows.

EFFECT: higher efficiency.

2 cl, 5 dwg, 1 ex

FIELD: oil industry.

SUBSTANCE: method includes making hermetic chambers with injection of good-compacting substance therein. Model is made in form of rectangular box or basin with filling of the latter with porous substance and its pressurization. Hermetic chambers are connected hydraulically to the model. Model and chambers are filled with low-compressible working liquid,. Volume of model pores is determined. Portion of working liquid is pumped from hermetic chambers into model at atmospheric pressure. Working liquid is fed into model with fixed pressure with control of working liquid amount, which amount flows backwards into hermetic chambers. coefficient of model compressibility is determined on basis of volume of liquid, which moved into hermetic chambers, fixed pressure and volume of pores in model.

EFFECT: higher efficiency.

3 cl, 2 dwg

FIELD: oil industry.

SUBSTANCE: method includes mounting elements, imitating cracks, in artificial porous substance. As elements, imitating bed cracks, metallic meshes folded twice or more are used. Areas and dimensions of meshes are determined by geometric likeness of modeled bed cracks. Porous substance is compacted between meshes. Model is hermetically sealed, vacuumized and filled with water under vacuum conditions. Water is pumped along and transversely to position of meshes. Penetrability of modeled bed is determined in said directions and water is displaced by model of oil.

EFFECT: higher efficiency.

FIELD: oil industry.

SUBSTANCE: device has hollow body which is a fragment of force pipeline at vertically placed portion of mouth armature. Tool for controlling flow of multi-component gas-liquid substance is made in form of valve, connected to rotary support. Sample chamber is a ring-shaped hollow in hollow body, placed at same level with valve and connected at inlet to flow of multi-component gas-liquid substance through extracting channels, made on hollow body. Extracting channels are made in form of side slits, positioned symmetrically relatively to valve rotation axis. Ring-shaped hollow on hollow body is connected at outlet to locking tool, mounted at extension of valve shaft and made in form of sample-taking valve. Valve shaft and sample-taking valve are interconnected through hollow intermediate shaft. Sample-taking valve is placed in the body of locking tool with possible reciprocal movement. Valve shaft and hollow intermediate shaft are interconnected with possible mutual rotation for a quarter of one turn.

EFFECT: simplified construction and maintenance, higher quality.

4 dwg

FIELD: oil and gas industry.

SUBSTANCE: device has body in form of calibrated cylinder. From both sides lids are connected to body. Inside the body separating piston and ball for mixing sample are placed. Also provided is hydraulic resistance for slow inlet of sample. Slide valve is used for safe inletting, pressurization and depressurization of taken fluid, is connected to lid and consists of rod with channels and bushing with clamp. Clamp is held between nuts interconnected by threads, one of which is connected to rod by thread. Needle valve consists of locking pin and axle-bearing and is used to drain pressure from closed space above slide valve prior to disconnection of sample-taking container from bed-testing equipment.

EFFECT: simplified construction, higher reliability.

3 dwg

FIELD: oil industry.

SUBSTANCE: device has hollow body mounted in force pipeline, inside of which body tool for controlling flow of multi-component gas-liquid substance is placed, probing chamber with extracting channels, locking tool with handle and guiding pipe, driving valve for picking sample, mounted with possible interaction with spring-loaded rod, placed inside the shaft of flow control tool. Hollow body is a fragment of force pipeline at vertical portion of mouth armature, control tool is made in form of valve of lesser diameter, then inner diameter of hollow body, and probing chamber is a ring-shaped hollow in hollow body, positioned at same level with valve and connected at input to flow of multi-component gas-liquid substance through extraction channels, made symmetrically to rotation axis of valve, and at output - to locking tool, while rod is provided with shelves for multi-start thread of appropriate cross-section, made at shaft on length of no less than quarter of axial step of this thread.

EFFECT: simplified construction, higher efficiency.

3 dwg

FIELD: oil industry.

SUBSTANCE: device has hollow cylindrical body, branch pipes for extraction and output of sample and locking element. Body is made thick-walled. End portions of body are made in form of truncated cone and interconnected, on the side of lesser bases by means of channel. Branch pipe for extraction of sample is made elongated, with length equal to body diameter, and is let through in transverse direction of body through the center of said channel. Within limits of branch pipe cross-section its hollow is separated by slanted solid wall on two portions, each of which is connected thereto. One portion of branch pipe hollow is meant for taking sample, other one - for feeding reagent into well product. To receive trustworthy information about sample, by setting flow to homogenous state, inner surface of cone, on the side of larger base, is provided with rigidly fixed blades for turbulization of flow flowing into body, while diameter of channel connecting cones is selected equal to diameters of their lesser bases.

EFFECT: simplified construction, broader functional capabilities, higher quality of sample.

2 cl, 3 dwg

FIELD: geophysics.

SUBSTANCE: device has non-magnetic body, electronic block, longitudinal and transverse probes with inductive coils, each of which has generator and receiver windings, while transverse probe has no less than three inductive coils, positioned along perimeter of central ferromagnetic core.

EFFECT: higher efficiency.

4 dwg

FIELD: well research, particularly means for drilling rock sample out of borehole in an airtight manner.

SUBSTANCE: device comprises case and hollow drill arranged in the case and having ring-shaped cutter. Stopper closing cartridge for sample receiving is kinematically linked with the drill by means of transmission mechanism. Transmission mechanism is formed as rotary drum with curved cut made in side surface thereof, deflecting finger and rotary arm. Deflecting finger slides in curved cut and is fixedly secured to drill body. Rotary arm is connected with the drum by one end thereof and with stopper by another end. Rotary arm is connected with stopper by means of mechanical couple including rod with plug. The stopper is arranged in cartridge lid and is made as rotary cylinder. Formed in the cylinder is through channel sized in accordance with the sample to be drilled out. Cylinder is provided with annular gaskets connected one to another by linear members. The rotary arm has an axis of rotation connected to device case.

EFFECT: simplified structure, increased reliability.

3 dwg

Up!