Methods and device for planning and dynamic update of sampling operations during drilling in underground formation

FIELD: oil and gas industry.

SUBSTANCE: method involves identification of a variety of processes and their parameters; with that, processes include drilling and sampling processes and parameters include drilling and sampling parameters. Also, the method involves processing of parameters for each of the processes by means of a special modelling processor creating forecasts related to formation sampling. With that, special modelling processor includes at least one of simulators of a well shaft hydraulic system, a simulator of filter cake of drilling mud, a simulator of formation stream or a simulator of tool feedback. The method also involves classification of forecasts related to formation sampling based on at least one of sample fluid medium quality, duration of sampling process, productivity of sampling process or cost of sampling, and planning of sampling operation based on classified forecasts.

EFFECT: improving efficiency or productivity of a sampling operation of formation fluid medium or operation.

25 cl, 15 dwg

 

BACKGROUND of INVENTION

In the operations of sampling during drilling, the drilling of the wellbore affect the amount of mud filtrate penetrating into the reservoir, the amount of energy available in the well for pumping fluid from the reservoir, and the time required to obtain samples of pristine formation fluid. In some examples, the drill equipment drill string may include downhole tool of sampling and/or testing fluid surrounding subsurface strata. Sampling can be performed using the formation tests, extracts the reservoir fluids at the desired locations of the wellbore or points of observations and/or experiencing taken the sample fluid in the borehole. However, to manage the process of obtaining samples of pristine formation fluid it is necessary to consider a large number of variables. Known methods of sampling while drilling rely heavily on the experience adjustments of the parameters of the sampling and drilling to perform relatively economically viable and efficient operation of sampling. However, such empirical methods are limited in volume and can reduce performance and/or increase the total cost of the operation of sampling, if the parameters BU is placed and/or sampling is not properly identified and/or not acceptable corrected.

Prior art in this field includes SPE 92380, representing the use of setprocessor modeling in conjunction with measurements of pore pressure or the pressure in the reservoir. Another example can be found in the publication of the patent application U.S. No. 2005/0235745. In addition, the publication of the patent application U.S. No. 2007/0079962 described block scheduling protective probe. The above documents are fully incorporated by reference in this description.

BRIEF DESCRIPTION of DRAWINGS

Figure 1 shows a schematic view of a variant of the system of the drilling rig.

Figure 2 schematically shows a variant of the method of implementing one or both modules logging while drilling figure 1.

Figure 3 shows a block diagram of the device according to the present invention.

Figure 4 shows the block diagram of the sequence of operations of the example method according to the present invention.

Figure 5 shows a more detailed block diagram of the sequence of operations of another variant of the method according to the present invention.

Fig.6-13 shows graphs illustrating the forecasts according to one aspect of the present invention.

Fig shows a graph illustrating an example of the output of the simulator response of the sampler, related to a possible programme of work of the tool.

Fig shows the circuit condition the device according to one or more aspects of the present invention.

DETAILED DESCRIPTION

The present invention should become clear from the following detailed description with the accompanying figures. Please note that according to standard practice in the industry, the various signs drawn not to scale. In fact, the size of various characteristics can be arbitrarily increased or reduced for clarity of discussion.

Some examples are shown above the figures and described in detail below. In the description of these examples are similar or identical positions can be used to identify identical or similar elements. In addition, several examples are described throughout this detailed description. Any signs of any example can be included or substituted, or may otherwise be combined with other features from other examples for the formation of new examples.

In General, are examples of the methods and devices described herein can be used for scheduling and dynamic optimization of the operations of the sampling reservoir fluid, running in connection with the drilling of a well bore in an underground formation. As described in more detail below, are examples of methods and devices, in contrast to many known methods of sampling formation fluid, provide integral is the amount of planning operations of drilling and sampling reservoir fluid and iterative dynamic update settings, associated with the operations of drilling and/or sampling, essentially, increase the efficiency and/or performance of the sampling reservoir fluid or work. More specifically, prior to drilling and sampling in which the example methods and devices, you can select or define the initial calculated or best predicted (for example, the most effective or economically feasible) plan drilling and sampling plan in a coordinated or integrated mode. In particular, in which the example methods and devices can be used statistics related to the sets of parameters of drilling and sampling, and appropriate parameter values to identify one or more possible scenarios for drilling and/or sampling plans or processes. As described in more detail below, each of the plans, scripts, or processes can be analyzed using, for example, setprocessor simulation, which may include one or more simulators, providing a relative comparison and/or systematization plans, scripts or methods on the basis of the calculated or estimated sampling results generated by each of the plans, scripts, or processes. In this mode, are examples of the methods and the device is provide in the choice of initial plans for drilling and/or sampling calculated or predicted to create the best results (for example, the most accurate and cost-effective) sampling.

Methods and apparatus according to the invention may optionally provide a dynamic update of the selected first plan (plan) drilling and/or sampling while drilling and/or during operations of sampling. More specifically, one or more values of parameters relating to the drilling and/or one or more values of parameters related to sampling can be collected or measured during drilling or during a temporary halt drilling. Data collected or measured values of the parameters can then be used to update (e.g., modification) of the selected first plan (plan) drilling and/or sampling. Such updates can occur dynamically during the operation of sampling formation fluid and/or may occur between activities drilling (i.e. during the temporary stop drilling) during the progress of the work sampling, which may consist of sampling formation fluid in one or more locations in the wellbore, which is drilling. Update plan (plans) drilling and/or sampling may occur multiple times during the execution of the work sampling, and such an update may include the ScanSnap one or more models (e.g., reservoir models, models of the filtration cake of the drilling fluid and so on), settings, etc.

Thus, as noted above, the methods and device described herein preferably provide for the creation of the initial plan of drilling and/or sampling so that the drilling and operation of the sampling plan jointly or in integrated mode. In addition, after the start of drilling the initial plan (the plans) drilling and/or sampling can be updated or modified during execution of the work sampling during drilling of the wellbore. As a result, which the example methods and apparatus provide a more efficient, productive and economically justified collecting and analyzing one or more samples of the reservoir fluid during the drilling action.

Figure 1 shows the system of the drilling rig, which can be used on land and/or sea, but are shown in figure 1 installation deployed on land. This system can be used in combination with the methods and device of the sampling while drilling, described in this document. However, be aware that the methods and device options described in this document, in General, can also be used with any other engine (s) of the drilling rig.

In a variant of the system of the drilling rig 1 barrel 11 wells is performed in one or more subterranean formations by rotary and/or directional directional drilling. Drill string 12 is suspended in the bore 11 of the well and includes the layout 100 of a bottom hole Assembly (BHA)having a drill bit 105 at its lower end. System on the surface includes a platform and layout of 10 towers, installed over the barrel 11 wells. Layout 10 tower includes a rotor 16, a leading drill pipe 17, crucible 18 and the rotary swivel 19. Drill string 12 rotates the rotor 16 that receives power from a not shown means and connected with the leading drill pipe 17 at the upper end of the drill string. Drill string 12 example suspended from crucible 18, attached to a traveling block (not shown), through the leading drill pipe 17 and the swivel 19, providing for the rotation of the drill string relative to the hookblock 18. System top drive you can use an alternative or in addition.

In the variant shown in figure 1, the system on the surface additionally includes the drilling fluid 26 that is stored in the tank 27, equipped on the rig floor. A pump 29 delivers the drilling fluid 26 to the inside of the drill string 12 through the hole in the swivel 19, providing for the passage of drilling mud down through the drill string 12 in the direction indicated by the arrow 8. The drilling fluid exits the drill string 12 through openings in the drill bit 105 and then circulates up carazzone the annular space between the outer surface of the drill string and the wall of the wellbore in the direction indicated by the arrow 9. The drilling fluid lubricates the drill bit 105 and carries the cuttings to the surface, back into the tank 27 for re-circulation, and creates a crust of mud, for example, filtration cork (not shown) on the walls of the barrel 11 of the well.

The layout 100 of the bottom of the drill string includes, among other things, multiple modules or tools, logging while drilling different types (two of which are indicated by the positions 120 and 120A), and/or modules of measurement while drilling (one of which is indicated by the position 130), rotary steerable or motor, and drill bit 105. The module 130 measurements while drilling measures the azimuth and inclination of the drill bit 105, which can be used to monitor the trajectory of the wellbore.

Each tool 120 and 120A are placed in a special heavy-weight drill pipe, known in the art, and contains several logging tools known types and/or devices of the sampling fluid. The tools 120 and 120A are made with measurements, processing and storage of information and data exchange with the module 130 measurements while drilling and/or directly with the equipment on the surface, such as computer 160 logging and control.

The computer 160 logging and management may include the user interface, is ensuring the reflection parameters of the input and/or output data, which can be associated with measurements obtained in the examples described herein, and/or projections associated with sampling in the formation F, such as the length of the zone of penetration of the drilling fluid (e.g., mud filtrate). The parameters entered in the computer 160 logging and management, may include seismic data (e.g., seismic and/or velocities of propagation of seismic waves), the logs uncased well bore, which includes estimates of the reservoir, and/or mechanical properties of rocks (e.g., the strength of the layer)associated with the formation F. in Addition or alternatively, the input parameters may include data related to the rheology of the drilling fluid, such as viscosity of the drilling fluid, the density of the drilling fluid, the yield point of the drilling fluid, the strength of the gel drilling fluid, the drill solution and/or the compressibility of the drilling fluid. Additionally, the input parameters may include the trajectory of the wellbore, the dimensions of the wellbore, the geometry of the drill string, the pump parameters (for example, the capacity of the pump), the drilling parameters, the sampling parameters and/or parameters. Although the computer 160 logging and control is shown in figure 1 located on the surface and in the vicinity of the drilling system installation is key, part or all of the computer 160 can be installed in the layout 100 of the bottom of the drill string and/or at the remote site.

Figure 2 shows a simplified diagram of the tool 200 logging while drilling, which can be used as tools 120 and/or 120A logging while drilling. In the shown example, the tool 200 logging while drilling refers to the type described in U.S. patent 7114562, assigned assignee of the present patent application and is fully incorporated herein by reference. However, other types of tools, logging while drilling can be used as a tool 200 logging while drilling.

The tool 200 logging while drilling 2 is provided with a probe 205, configured to provide communication with the formation F and sampling reservoir fluid 210 in the tool 200 logging while drilling, as shown by the arrows. The probe 205 may be installed, for example, in the blade 215 centralizer tool 200 logging while drilling and advancing of the blade 215 centralizer in contact with the wall 220 of the wellbore. The blade 215 centralizer is included in one or more of the blades, which may be in contact with the wall 220 of the wellbore.

Reservoir fluid 210 selected in the tool 200 logging while drilling probe 205 may be about is investigated to determine for example, the composition of the fluid, viscosity, density, optical density, absorbance, fluorescence, relative resistance and/or conductivity, dielectric constant, temperature, etc. the Tool 200 logging while drilling may also be provided with one or more blocks 230 for measuring the properties of the fluid and one or more sensors 235 made with the possibility of joint measurement parameters (e.g., process parameters, parameters etc). Block (blocks) 230 for measuring the properties of the fluid may include, for example, the light absorption spectrometer having multiple channels, each of which may correspond to a different wavelength. Thus, the block (blocks) 230 for measuring the properties of the fluid can be made to measure spectral information for a fluid selected from the formation F. This spectral information can be used to determine the composition and/or other properties of the fluid. Block (blocks) 230 for measuring the properties of the fluid may, in addition or alternatively, include a mass spectrometer and/or block chromatography spectrometer nuclear magnetic resonance, fluorescence spectrometer, the unit of measurement of the relative resistance and/or any other suitable unit of measurement properties of the fluid. Dimension p is obtained by block (or blocks) 230 measuring properties of a fluid medium, can be used by setprocessor 240 modeling for assistance (e.g., updates) the process of drilling and/or sampling. For example, setprocessor 240 modeling can be used to predict changes in properties of the reservoir fluid with depth to predict changes of the properties of the reservoir fluid with time during the sampling process and/or to generate wireline logs, calibration profile of the zone of penetration of the drilling fluid, as described in more detail below.

The sensors 235 may be designed to measure the pressure (for example, pressure on the probe 205 and the pressure in the annular space while drilling), temperature, flow rate of the drilling fluid (e.g., flow rate of the drilling fluid in the annular space), the density of the drilling fluid, the trajectory of the wellbore, the density of the reservoir fluid, the viscosity of the reservoir fluid, the location of the drill string and/or drill components relative to the wellbore, and/or obtain a slurry. Additionally or alternatively, the sensors 235 may be designed to measure, among other things, the ROP of the drill bit 105, the volume of the drilled formation, the speed of rotation of the layout 100 of the bottom of the drill string, the weight of the filtration cake of the drilling fluid, platanos and cake of the drilling fluid, the magnitude of the movement of the link 100 to the bottom of the drill string, filter mud, small measurement logging while drilling and/or depth of the drill string 12.

One or more parameters measured by the sensors 235 may be used by setprocessor 240 modeling to determine, predict and/or update flow in the wellbore, the intensity filter mud, model pore pressure, the mobility of the fluid in the reservoir, the distribution statistics of pressure, statistics, circulation of the drilling fluid, the parameters of the filtration cake of the drilling fluid and/or penetration of the drilling fluid (e.g., filtrate). In addition, some or all of the data, the measured parameters can be used by setprocessor 240 modeling to determine, predict and/or update the model of the filtration cake of the drilling fluid, the reservoir model (including a model of the reservoir fluid), model sediment filtration cake of the drilling fluid, the pattern of erosion of the filtration cake of the drilling fluid, model the compressibility of the filtration cake of the drilling fluid, the model permeability of the filtration cake of the drilling fluid, the model desorption of the filtration cake of the drilling fluid, downhole pressure and/or porosity of the formation. Additionally, one is n or more data of measured parameters can be used by setprocessor 240 modeling to determine forecasting and/or update the compressibility of the reservoir, the model of the drilling fluid, the model estimates of reservoir properties and/or properties of the drilling fluid, the equations of mechanics of fluid in the wellbore, the model instantaneous penetration model for stratified flow and/or model of the performance of the sampler. As noted above and described in more detail below, the above parameters and/or model can be updated dynamically using the data collected during the performance of work sampling during drilling of the wellbore to provide more effective and efficient selection and analysis of samples of formation fluid.

The sensors 235 may provide the output analog and/or digital signals, which may be digital representations of analog signals, processed to reduce noise and/or reduce the number of bits used to represent the output (i.e. compressed). The output can, in addition or alternatively, include one or more parameters derived from the measurement data and/or output one or more sensors.

The tool 200 logging while drilling may be equipped with devices, such as, for example, at least one pump 280 for selecting the desired amount of fluid from the formation F at a given performance. The tool 20 logging while drilling may also include a camera 245 sampling the fluid to rise to the surface, at least one flow line 260, hydraulically connected to the probe 205, pump 280 and at least one adjustable vent opening 270 that can be used to release the fluid, selected from the formation F into the wellbore (for example, during the operation of cleaning the sample). Backup piston 225 can also be equipped to facilitate the application of force, the clamping tool 200 logging while drilling and/or probe 205, to the wall 220 of the wellbore. In addition, to generate output data simulation and/or forecast which is an example of the tool 200 logging while drilling 2 includes setprocessor 240 modeling and block 250 data processing. However, setprocessor 240 modeling and/or block 250 data can be placed in another location in the tool or drill string and/or may be located partially or entirely on the surface.

Figure 3 shows a block diagram of a device 300 that can be used to implement setprocessor 240 modeling unit 250 data processing figure 2. As shown together in figure 2 and 3, setprocessor 240 simulation may include any number and/or any types of simulators, and the block 250, the data processing may include any number and/or any type of processor modules. In variant 3 setprocessor 240 simulation in which incorporates both a simulator 302 of the hydraulic system of the wellbore, the simulator 304 of the filtration cake of the drilling fluid, the simulator 306 reservoir flow and simulator 308 response of the instrument. Block 250, the data processing includes comparing the device 310, the initiating device 312 sorting device 314, the processor 316 and/or device 318 identification. Fewer, additional and/or different simulators and modules can be used to implement setprocessor 240 modeling unit 250 data processing to meet the needs of a particular application.

Although setprocessor 240 modeling and block 250 data shown as part of the tool 200 logging while drilling in figure 2, setprocessor 240 modeling and/or block 250 data can alternatively implement, at least partially in the module 130 measurements while drilling. Additionally or alternatively, setprocessor 240 modeling and/or block 250, the data processing can be implemented, partially or completely, as part of the computer 160 logging and control. For example, if the communication between the BHA 100 (figure 1) and the surface is carried out by high-speed communication channel (e.g., cabled drill pipe), the data rate may be sufficient to provide for the placement of setprocessor 240 modeling unit 250 data polnostyu computer 160 logging and control.

Although examples of the implementation method setprocessor 240 modeling unit 250 data processing 2 shown in figure 3, one or more elements, processes and/or devices shown in figure 3, you can merge, split, swap, delete, remove and/or implemented in other ways. In a more General sense, which is an example of setprocessor 240 modeling and/or block 250, the data processing can be implemented in hardware, software, firmware and/or any combination of hardware, software and/or firmware. Thus, for example, any imitators 302-308 and/or modules 310-318 can be implemented in one or more chains (chains), programmable processor (CPU), a specialized integrated circuit (ICS) (specialized IP), programmable logic device (devices) (PLD) and/or logic device, programmable consumer (devices) (FPGAs), etc. in Addition, which is an example of setprocessor 240 simulation and which is an example block 250, the data may include one or more elements, processors and/or devices in addition to, or replacement shows figure 3.

When using simulators 302-308 can automatically interact (EmOC is emer, to work together or to transmit data to exchange values of the parameters and/or other data) to perform analyses that can be used to update (e.g., iterative) drilling parameters and/or the sampling parameters to improve the results of sampling or work performed in connection with the drilling action. However, be aware that not all States of a given one of the simulators 302-308 must be compatible with the possible States of one or more other simulators 302-308. In fact, in some cases, only one set of parameters may be valid when all replicas 302-308 work together or interact for analysis or analyses required to update plans for drilling and/or sampling according to the examples described in this document.

For decision and/or determination of the equations of mechanics of fluid in the barrel 11 wells (figure 1) which is an example of setprocessor 240 modeling provided by the simulator 302 of the hydraulic system of the wellbore. Known simulator hydraulic system of the wellbore described in materials "Drilling Office help marketing firm Schlumberger® and The Integral Solution: New System Improves the Efficiency of Drilling Planning and Monitoring," SPE 39322 describing the module hydraulic system, designed for the Irma Schlumberger®, fully incorporated herein by reference. The simulator 302 of the hydraulic system of the wellbore has a capability of receiving and processing input data and generating output data relating to the mode of the stream (for example, distribution of the flow velocity and/or statistics of the distribution of pressure (for example, pressure in the annular space, the equivalent circulating density and/or equivalent static density). In particular, the mode of flow of drilling mud circulation can be shown turbulent or laminar, which, in turn, has implications for predictions performed by the simulator 304 of the filtration cake of the drilling fluid. Thus, the simulation results (or information associated with the simulation results)generated by the simulator 302 of the hydraulic system of the wellbore can be passed to the simulator 304 of the filtration cake of the drilling fluid, providing a more accurate simulation of the filtration cake of the drilling fluid in the wellbore simulator 304 of the filtration cake of the drilling fluid. In addition, the statistics of the pressure distribution can be translated into equivalent circulating density and/or equivalent static density.

The input data to the simulator 302 of the hydraulic system of the wellbore may be associated with parameters realo the AI mud, the drilling parameters and/or data collector. The parameters related to the rheology of the drilling fluid may include, among other things, the viscosity of the drilling fluid, the density of the drilling fluid, the yield point of the drilling fluid, the strength of the gel drilling fluid and/or the compressibility of the drilling fluid. The parameters related to the rheology of the drilling fluid, can be defined on the surface of, for example, in the laboratory and/or on the rig floor and then entered into the computer 160 logging and management (figure 1). The parameters related to the rheology of the drilling fluid may depend, for example, from pressure and/or temperature in the wellbore. The design pressure can be determined by the density of the drilling fluid and the measurement of the vertical depth of the drill string relative to the surface. The pressure can, in addition or alternatively, be determined from the measurements obtained by one or more sensors 235 (figure 2).

The parameters relating to the drilling, include the geometry of the drill string, the trajectory of the wellbore, the statistics of the velocity of circulation of the drilling fluid, the depth of the drill string, obtaining a slurry and/or the speed of rotation of the BHA. The geometry of the drill string may include the size and/or diameter of the various components of the BHA, which the traveler may include a drill bit, heavy-weight drill pipe, drill pipe and/or centralizers or stabilizers, etc. Geometry of the drill string and/or its location can be used to determine the cross-sectional area of flow of the drilling fluid on the trajectory of the wellbore.

The trajectory of the wellbore may be vertical, inclined and/or horizontal relative to the surface. The trajectory of the wellbore can be used to determine the location of the BHA in the wellbore. The location of the BHA in the wellbore can be used to define the shape of the cross-sectional area of flow of the drilling fluid (e.g., circular or Crescent) on the trajectory of the wellbore. This information and the performance of the pumping of the drilling fluid can be used to determine and/or predict the flow of the drilling fluid. For example, if the trajectory of the wellbore is horizontal relative to the surface, the arrangement of the bottom of the drill string may lie on her side, and, consequently, the shape of the cross-sectional area of flow of the drilling fluid can be, essentially, to be a sickle. Alternatively, if the trajectory of the wellbore is vertical relative to the surface, the arrangement of the bottom of the drill string may be up in the center section of the trunk VCS the new well and thus, the shape of the sectional area of flow of the drilling fluid may be essentially circular. In addition, the effect of gravity on the layout of the bottom of the drill string may also be taken into account by the simulator 302 of the hydraulic system of the wellbore.

The circulation rate of the drilling fluid associated with the performance of the pumping of the drilling fluid that is used, among other things, to determine the average flow rate of the drilling fluid over the cross section of the wellbore. Delays and/or interruptions in the circulation of the drilling fluid due to, for example, by attaching additional sections of drill pipe may also be considered.

The depth of the drill string (e.g., design depth refers to the depth of the drill string in the wellbore. The depth of the drill string can be used to generate models that are associated with the effect of pressure surges and/or swabbing (for example, moving the drill string and/or other components of the BHA along the shaft 11 wells (figure 1) may result in a decrease in pressure in the well, which, in turn, initiates the flow of hydrocarbons from the formation F). Additionally or alternatively, the depth of the drill string can be used to generate models that are associated with the influence of time between the time of opening of the reservoir is F (for example, rocks) drill bit 105 (figure 1) and time of sampling.

Obtaining cuttings associated with small particles of rock, detached from the formation F at destruction of the drill bit 105 reservoir F rocks in front of the drill bit 105. The amount of sludge depends on the volume of the reservoir drilled with the drill bit 105, and the type of drill bit. Receiving sludge affects the pressure in the wellbore and circulating current density, which is the apparent density of the drilling fluid circulation, derived by measuring the pressure produced by the drilling mud at a given depth. The effective density circulation takes into account the pressure drop in the annular space above the considered point in the reservoir F.

The speed of rotation of the drill string is associated with the frequency of revolutions per minute of the drill string relative to the borehole. The speed of rotation of the drill string affects the flow of the drilling fluid (e.g., whether the flow is laminar or turbulent). In addition, the speed of rotation of the drill string affects the mechanics of the filtration cake of the drilling fluid and the speed of penetration of the drilling fluid, i.e. the rate at which drilling mud, basically, the filtrate into the formation F.

The parameters related to the data collector, which mo the et also use the simulator 302 of the hydraulic system of the wellbore, include the temperature of the fluid in the well and, if available, temperature of the formation F. however, in other examples, any other number of parameters related to the data collector, the simulator 302 of the hydraulic system of the wellbore may be used instead of or in addition to those mentioned above.

To determine and/or predict the magnitude filtration rate or volume of the injected drilling fluid (e.g., filtrate) into the wall 220 of the wellbore along the trajectory of the wellbore, which is an example of setprocessor 240 modeling provided by the simulator 304 of the filtration cake of the drilling fluid. The simulator 304 of the filtration cake of the drilling fluid can be implemented using well-known simulator filtration cake of the drilling fluid, such as a simulator, described in the article "When Should We Worry About Supercharging in Formation Pressure While Drilling Measurements", SPE/IADC 92380, fully incorporated herein by reference. However, instead you can use any other simulator filtration cake of the drilling fluid. In General, the simulator 304 of the filtration cake of the drilling fluid receives and processes the input data to generate output data that is interrelated with the filtration rate or volume of drilling fluid that is pumped into the wall 220 of the wellbore along the trajectory of the wellbore. In addition to t the th, the simulator 304 of the filtration cake of the drilling fluid includes internal variables associated with the weight of the cake of the drilling fluid and/or compressed cake of the drilling fluid. The weight of the cake of the drilling fluid associated with the mass of material of solid particles deposited on the wall 220 of the wellbore. In General, you can monitor the properties of the crust of mud, such as thickness, porosity, permeability, compressibility, strength, filtration rate and/or the ability to freeze (for example, as described in "Model-Based Sticking Risk Assessment for Wireline Formation Testing Tool in the U.S. Gulf Coast," Underbill, W B, L. Moore, and G. H. Meeten, SPE 48963, fully incorporated herein by reference), for indicating when properties will need to be adjusted, essentially, for prevent sticking (loss) of the drill string and/or BHA in the wellbore.

The input data used for the simulator 304 of the filtration cake of the drilling fluid, can be associated with parameters of a crust of mud, parameters related to the data collector, and/or parameters of the hydraulic system of the wellbore, which can create or generate based on the information or data generated by the simulator 302 of the hydraulic system of the wellbore. Specifically, the parameters related to the crust of mud, include the settings for use in model sediments crust of mud, model erosion crust of mud, model the permeability of the cake of the drilling fluid and/or model desorption cake of the drilling fluid. Model fat cake of the drilling fluid is the amount of crust of mud deposited on the wall 220 of the wellbore as a function of the amount of mud filtrate, penetrating (e.g., leaking) into the formation F. the Model sediments cake of the drilling fluid can account for dynamic filtering, which may be associated with a material with simultaneous erosion and deposition in the cortex of the drilling fluid when the drilling fluid is circulated over the cake of the drilling fluid. In particular, dynamic filtering is associated with growth restriction crust of mud, when the filtration rate is too small relative to the shear stress produced by the cortex of the mud flow mud, preventing further buildup of solid particles on the crust of mud.

Model erosion crusts of mud represents the rate of erosion cake of the drilling fluid in the flow of drilling mud in the wellbore. For example, the crust of the drilling fluid may have a constant and rapid erosion, if the flow of the drilling fluid in the wellbore is turbulent.

Model the permeability of the cake of the drilling process is and/or model desorption cake of the drilling fluid is the permeability of the crust of mud, as a function of the mass of particles growing on the crust of mud. In addition, models of the permeability of the cake of the drilling fluid and/or model desorption cake of the drilling fluid present mode, in which the porosity of the cake of the drilling fluid varies with the thickness of the crust of mud.

The parameters related to the data collector, which can be used by the simulator 304 of the filtration cake of the drilling fluid include downhole pressure and model instant penetration. The bottomhole pressure is the pressure at the junction of the reservoir F and the (external) peel mud deposited on the wall 220 of the wellbore. The bottomhole pressure can be approximated by Plast pressure. For planning purposes, you can use the seismic data of the formation F and/or the collector to determine the pressure in the reservoir F, or information on pressure can be determined on the basis of pressure measurements made in nearby wells. However, in other examples, the pressure in the reservoir can be determined from the measurements obtained from the sensors 235 (figure 2). Alternatively, as described below, the bottomhole pressure can be estimated and/or determined using the simulator 304 of the filtration cake of the drilling fluid together with the simulator 306 flow layer.

Model instantaneous penetration, which can the be approximation, is filtering the drilling fluid to the formation of a crust of mud on the wall 220 of the wellbore. In particular, the model instantaneous penetration is the ability of the mud to displace and/or replace the relic stratiform the fluid (e.g. water, oil and/or gas in the pore spaces of reservoir rocks) at the outcrop drilling chisel formation of new surfaces during drilling. In General, the model instantaneous penetration depends, at least partially, from the formation permeability, the rheological properties of the drilling fluid and the pressure differential between the fluid circulation in the well bore and the formation.

As described above, the parameters of the hydraulic system of the wellbore may include the parameters used in determining the mode of the stream (e.g., flow rate) and/or statistical distribution of the pressure (for example, pressure in the annular space, the equivalent circulating density and/or equivalent static density). The stream mode can show that the flow is turbulent or laminar. The parameters of the hydraulic system of the wellbore that is used by the simulator 304 of the filtration cake of the drilling fluid, can be obtained at the output of the simulator 302 of the hydraulic system of the wellbore.

To determine and/or the evaluation in terms of parameters of the filtration cake of the drilling fluid and/or data collector which is an example of setprocessor 240 modeling is equipped with a simulator 306 reservoir flow. Known simulator 306 reservoir flow described in "ECLIPSE Finite Difference Simulation marketing reference material company Schlumberger® and in the article "Numerical Simulation of Mud-Filtrate Invasion in Deviated Wells," SPE 87919, fully incorporated in this document by reference. As applied to the sampling process simulator 306 reservoir flow receives and processes the input data to generate output data relating to the profile of the saturation tree zone wells with mud filtrate, the composition of selected samples of the fluid and the reaction layer on the sampling and/or downhole pressure. Identified and/or calculated bottom-hole pressure can be passed to the simulator 304 of the filtration cake of the drilling fluid to update and/or Refine the intensity filter mud. In turn, defined and/or calculated intensity filtering the drilling fluid can be used to update and/or Refine the bottomhole pressure. Although which is an example of setprocessor 240 modeling figure 3 includes the simulator 306 reservoir flow, in other examples, setprocessor 240 modeling may not be included in the simulator 306 reservoir flow. In such examples, the effects of filtering, sampling can be determined by previous sampling and/or drilling experience in the reservoir F and the data related to the intense is vnesti filter mud.

The input data used by the simulator 306 reservoir flow, can be associated with a drilling fluid parameters, parameters related to the data collector, the sampling parameters and/or parameters related to sampler model or model of instrument. As discussed in more detail below, one or more parameters related to the model of the sampler can be obtained or derived from the output of the simulator 308 response of the instrument and can then be used to control the sampling operation.

The parameters relating to the drilling mud, may include the intensity of the filtration of the drilling fluid, the density of mud filtrate, is the viscosity of the mud filtrate, the relative permeability of the mud filtrate and/or the compressibility of the mud filtrate. The filtration rate can be determined and/or calculated using the simulator 304 of the filtration cake of the drilling fluid.

The parameters related to the data collector, which can be used by the simulator 306 reservoir flow, include the pressure in the reservoir, the porosity of the formation, the composition of formation fluid (and therefore the density of the components and concentration/saturation), phase behavior of the reservoir fluid, the viscosity of the reservoir fluid, timemost the reservoir fluid, the compressibility of the reservoir, the ratio of capillary pressure and/or relative permeability of the reservoir fluid.

The porosity of the formation can be determined and/or calculated log charts uncased borehole core samples, data of neighboring wells and/or seismic surveys. In addition, the compressibility of the reservoir may determine and/or calculate log charts uncased borehole core samples, the propagation velocity of seismic waves and/or local information on the formation F. in Addition, the pressure in the reservoir can be determined and/or calculated by correlation of pore pressure, log charts uncased borehole data, seismic surveys, and/or local information on the formation F (for example, data of neighboring wells).

Properties of the reservoir fluid can be determined by neighboring wells. Properties of the reservoir fluid can be adjusted on the basis of measurements obtained by the block 230 measurements of fluid and/or sensors 235 figure 2. Alternatively, the properties of the reservoir fluid and/or reservoir properties can be adjusted so that the saturation profile mud generated and/or predicted from measurements of logs uncased wellbore (for example, small dimension relative Prony is emoti), matches and/or is similar to the profile of the saturation mud generated and/or predicted by the simulator 306 reservoir flow. In the simulator 306 reservoir flow can be used to update the calculation and/or Refine the parameters of the filtration cake of the drilling fluid and/or parameters related to the data collector.

As discussed in the material, "Invasion Revisited", July 1991 issue of Oil Review, pp. 10-20 fully incorporated herein by reference, the profile of the zone of penetration of the drilling fluid is water-based can be adopted by small-scale measurement of relative permeability. When the drilling fluid is oil-based penetrates into the reservoir (such as a layer F of figure 1), measuring the relative resistance can be inefficient to determine during the drilling profile of the penetration zone. In these circumstances may be made other measurements, detecting the contrast in properties between the penetrating fluid medium and formation fluid environments. In particular, these measurements can be measurements of nuclear magnetic resonance, obtained using tool ProVision and/or measurement of the capture cross-section of a core, for example, the EcoScope tool, both supplied by Schlumberger®.

In a variant, where the simulator 306 reservoir flow should simulate the flow in the sampler simulator 306 reservoir flow may include some parameters corresponding to the sampler. For example, the simulator 306 reservoir flow may include data associated with the geometry of the sampling probe (for example, the diameter of the probe 205 figure 2), the volume of the flow line (for example, flow line 260 figure 2) and other components of the tool, such as, for example, as the geometry and dimensions of the sealing bearing on the probe 205 and/or the geometry of the stabilizer 215.

Simulator 306 reservoir flow can be used to determine the flow of the fluid selected in the sampler (for example, the tool 200 logging while drilling figure 2), the pumped volume of fluid and/or information associated with the composition and/or contamination of the pumped volume of fluid.

To determine and/or identify performance and/or operation of the sampler (e.g., tool 200 logging while drilling figure 2), which is an example of setprocessor 240 modeling can be equipped with a simulator 308 response of the instrument. In General, the simulator 308 response tool receives and processes the input data to generate output data relating to the work tool, the actual pressure drop and/or the actual intensity of the flow. The input data may be associated with the speed of circulation of the drilling fluid, drilling fluid and/or those which the temperature in the wellbore. Additionally or alternatively, the input data can be linked to model the response of the reservoir, the efficiency of energy conversion and/or work restrictions sampler. Restrictions sampler may include maximum operating temperature, maximum power consumption, maximum differential pressure, minimum flow rate and/or maximum flow. Additionally, the input data may correspond to model the response of the fluid, which can be obtained at the output of the simulator 306 reservoir flow.

Simulator 306 reservoir flow and simulator 308 response tool can be used to optimize conditions of pumping. For example, some of the BHA (for example, the layout 100 of the bottom of the drill string 1) can be equipped with a turbine (not shown), operate the alternator (not shown). In the work of the turbine is opened to the influence of the flow of the drilling fluid circulating in a wellbore, for power generation, and thus, the greater the flow rate, the more energy and/or power available to the components in the layout 100 of the bottom of the drill string (figure 1) and/or tool 200 logging while drilling (figure 2), etc. in Addition, when increasing the intensity of filing uravago solution of greater volume of fluid can be extracted in a given period of time, and, normally, therefore, less time is required to obtain a sufficiently pure sample (for example, samples of pristine formation fluid) for testing. However, although there is evidence of the benefits of increasing the flow rate of the drilling fluid, with increasing flow rate of the drilling fluid, the amount of erosion cake of the drilling fluid also increases. In addition, with increasing flow rate the amount of penetration of the drilling fluid into the formation F also increases, which may increase if the flow in the wellbore becomes turbulent.

When using the output of the simulator 302 of the hydraulic system of the wellbore simulator 304 of the filtration cake of the drilling fluid and/or simulator 306 reservoir flow can use the simulator 308 response of the instrument, and, in turn, the output of the simulator 308 response of the instrument can use the simulator 302 of the hydraulic system of the wellbore simulator 304 of the filtration cake of the drilling fluid and/or simulator 306 reservoir flow. The interaction between the simulator 306 reservoir flow and simulator 302 of the hydraulic system of the wellbore simulator 304 of the filtration cake of the drilling fluid and/or the simulator 308 response of the instrument can provide management with erah, described in this document the terms pumping to optimize the amount of energy produced by the turbine and reduce the time required to obtain sufficiently pure samples with maintaining adequate filtration cake of the drilling fluid on the wall of the wellbore and the limit of penetration of the drilling fluid into the formation F.

For comparison, for example, output data (for example, theoretical response)generated by setprocessor 240 simulations with actual measurements obtained from block 230 measurements of fluid and/or sensors 235, block 250 data supplied comparing device 310. Comparing the device 310 may compare the output generated by setprocessor 240 simulations with actual measurements to determine, does the project place of sampling (for example, a specific location in the wellbore). Additionally or alternatively, the comparing device 310 may compare the predictions associated with the different processes, plans and/or scenarios to identify processes that reduce the cost of sampling, increasing the quality of samples of fluid and/or reducing the duration of the sampling process.

To start the operation of the sampling and/or drilling unit 250 data supplied by the originating device 312. Initsiiruyushchego 312 starts drilling on the basis of systematic forecast associated with the various activities of drilling and/or sampling, processes, plans or scenarios. Additionally or alternatively, the initiating device 312 starts the sampling operation on the basis of systematic predictions associated with the various activities, processes, plans or scripts.

For sorting and/or organizing the output of setprocessor 240 modeling unit 250 data supplied sorting device 314. Sorting device 314 sorts and/or organizes the forecasts associated with different processes. In particular, the sorting device 314 may sort and/or to systematize the processes according to the quality of the sample fluid, the duration of the sampling process, the cost associated with the sampling process, and/or the amount of risk associated with obtaining samples of the fluid. Additionally or alternatively, the sorting device 314 may provide identification parameter (s) (e.g., parameter (s) of sampling), having the greatest impact on the quality of the sample fluid.

To identify the different processes and/or parameters associated with the operations of drilling and/or sampling unit 250 data supplied by the device 318 identification. Various processes may be associated with drilling and/or visiting th is, where sampling should occur in the wellbore. Additionally or alternatively, the device 318 identification can identify the parameters of the filtration cake of the drilling fluid and/or parameters associated with loose crust of mud, reservoir parameters, the operating parameters of the instrument and/or data related to the model of the hydraulic system of the wellbore, some, or all, based on the measured response of the reservoir to the selection operation of the sampling and/or drilling.

Figs.4 and 5 show a flowchart of the sequence of methods that you can use for integrated planning and dynamic update operations drilling and/or sampling in the subterranean formation (e.g., the formation F figure 1). In particular, are examples of methods can be used to optimize the planning, operations, drilling and/or sampling reservoir fluid to improve the performance of operations or work sampling, to reduce the cost associated with the operations or work sampling, and/or to increase the quality of the received samples of the reservoir fluid. Which is an example of the ways 4 and 5 can be used in connection with the arrangement 100 of the bottom of the drill string, the block 230 measurement of the fluid sensors 235, setprocessor 240 modeling and/or block the m 250 data processing figure 2. In addition, methods 4 and 5 can be used to implement the simulator 302 of the hydraulic system of the wellbore simulator 304 of the filtration cake of the drilling fluid, simulator 306 reservoir flow simulator 308 response tool, comparing the device 310, the initiating device 312 sorting device 314, processor 316 and/or device 318 identification 3.

In General, which is an example of the ways 4 and 5 can be implemented using software and/or hardware. In some embodiments of the flowchart of the sequence of operations can be represented in the form of machine-readable instructions, and, thus, is an example of how block diagrams of a sequence of operations can be implemented fully or partially with the execution of machine-readable instructions. Such machine-readable instructions may be executed by one or more computers 160 logging and management (figure 1), block 250 data processing (figure 2) and/or processor 316 (Fig 3). In particular, processor or any other suitable device for executing machine-readable instructions may choose such instructions from a storage device (e.g., storage devices with random access (MS random access), a persistent storage device is STV (ROM), etc) and execute these instructions. In some implementations, one or more of the operations shown in the flowchart of the sequence of operations figure 4 and 5 can be implemented manually. Although examples of the ways described with reference to the flowchart of the sequence of operations figure 4 and 5, the specialist in the art it should be clear that other ways of implementing the layout 100 of the bottom of the drill string, block 230 measurement of the fluid sensors 235, setprocessor 240 modeling unit 250 data 2 and simulator 302 of the hydraulic system of the wellbore simulator 304 of the filtration cake of the drilling fluid, simulator 306 reservoir flow simulator 308 response tool, comparing the device 310, the initiating device 312 sorting device 314, processor 316 and device 318 identification figure 3 can, additionally or alternatively, be used to optimize the planning, operations, drilling and/or operations of sampling. For example, the execution order of the blocks shown in the flowchart of the sequence of operations figure 4 and 5, can be changed and/or some of the described blocks can be rearranged, deleted, or merged.

Figure 4 shows a General block diagram of a variant of a method 400 for scheduling sampling and associated activities drilling for improvement of product is italinate and/or effectiveness of the operations or work sampling reservoir fluid. Variant of the method 400 is shown for better understanding, in General, processes that can be used to improve performance and/or efficiency of operations of sampling formation fluid, and a more detailed example is provided below in connection with figure 5.

As shown in figure 4, method 400 begins with planning before drilling (stage 402). In General, the planning operation is performed at the stage 402 includes selecting the initial set of drilling parameters and the sampling parameters in a coordinated or integrated mode (i.e. together) to create an estimate or forecast the best starting point for subsequent operations of drilling and/or sampling. Such coordinated or integrated choice of initial parameters can provide a more rapid and effective optimization of parameters and works subsequent drilling and/or sampling, thus providing a more rapid and efficient optimization of the sampling results. As a result, the method 400 can preferably be used to provide significantly more accurate results of sampling formation fluid more cost-effective way than many known methods of sampling formation fluid.

As described in more detail below, the planning operation is performed on the stage 40, this may include the choice of statistical data relating to the operations of drilling and/or sampling, and the use of such statistical data to evaluate the many possible scenarios of drilling and/or sampling plans or processes. Statistics usually include parameter values for many parameters related to the operations of drilling and/or sampling, corresponding to the possible scenarios of drilling and/or sampling or plans. Thus, each scenario of drilling and/or sampling, or the plan may include one or more sets of possible parameters of drilling and sampling and associated statistical values of the parameters that can be obtained, for example, during the previous steps of drilling and/or sampling.

The sets of possible parameters of drilling and sampling, corresponding to the possible scenarios of drilling and/or sampling plans or processes may include, for example, the parameters of the sampler, such as the type of sampler, the type of lifting equipment (e.g., wireline, a drill string), configuration (configuration) of the drill string) and/or geometrical parameters, the dimensions of the BHA, etc. Parameters of drilling and sampling may alternatively or additionally include parameters of the wellbore, such as traktorista well, the dimensions of the wellbore, the point or depth of sampling, drilling fluid parameters, such as flow rate of the drilling fluid (mud), the type of drilling fluid (mud) or composition and/or property or rheology, such as viscosity, density, yield strength, the strength of the gel, compressibility, filtering characteristics, the parameters of the filtration cake of the drilling fluid, etc. in Addition, parameters of drilling and sampling may alternatively or additionally include the sampling parameters, such as time of sampling (for example, a specific time and/or if the sampling during stop drilling or during flight BHA) and duration, etc, the parameters of the reservoir or collector, including seismic data, permeability and other mechanical properties of reservoir parameters reservoir fluid, or any other parameters that may affect the quality, efficiency and/or performance of the drilling and/or sampling.

As noted above, each of the possible scenarios of drilling and/or sampling plans or processes includes a set or combination of parameters and related statistics or saved values for each parameter. As described in more detail below and shown in figure 5, the planning operation is performed on the article is Hai 402, given such scenarios and related parameters and parameter values in setprocessor 240 modeling and, in turn, in one or more simulators 302-308 to calculate or predict the performance and/or cost (costs)associated with each of the scenarios or plans. The estimated performance and/or value can then be used for mapping and/or selection of the initial scenario of drilling and/or sampling plan or process and, thus, the choice of initial parameters of drilling and/or sampling to create the best starting point for subsequent operations of drilling and/or sampling.

After completion of the planning stage 402 and the start of drilling operations in method 400 collect data during the drilling stage 404. Such collected data may include parameters measured, for example, tools, logging while drilling or measurement while drilling. In particular, the parameters of the drilling fluid, temperature and pressure in the wellbore, the geometry of the wellbore trajectory, etc., properties of the formation, the properties of the reservoir fluid (e.g., collected during one or more operations of sampling (for example, during one or more preliminary tests), when drilling is temporarily stopped), etc. can be measured and collected for satanoperca time or alternatively, to meet the specified condition or set of conditions (for example, the achievement of a specific depth of penetration of one or more measured values of the parameters in some of the project a range of values above or below the threshold and so on). When used in this document, the term "pre-test" refers to the test when sampling the fluid, which can provide information related to the mobility of the fluid in the reservoir, Plast pressure and/or one or more properties of the reservoir fluid.

In any case, after the completion in the method 400 of data collection in stage 404, at stage 406 is updated sampling plan based on the data collected in stage 404. This update of the sampling plan provides update models and related parameters selected during the planning stage 402, the actual data pertaining to the wellbore and the reservoir, which Buryats and where and take samples. As a result, any subsequent operation (operation) sampling can be made more efficient and/or productive.

After updating the sampling plan at stage 406, the method 400 performs sampling according to the updated sampling plan at stage 408. As described in more detail below and shown in figure 5, the operation (operation) sampling, is undertaken at stage 408, can be iteratively dynamically changed, modified or updated to further clarify the operation of sampling. In other words, the operation (operations) sampling performed at stage 408, it is possible to manage or update it in real time to further Refine performance operations (operations) sampling. This update in real-time may include measurement and analysis of the reaction or the properties of the reservoir and/or properties of the reservoir fluid, the adjustment of one or more drilling parameters (e.g., flow rate of the drilling fluid), the adjustment of the flow rate of the fluid sample, the update of the model parameters on the basis of the analysis and then the repetition or continuation of the operation of sampling. One or more update operations sampling or cycles can be performed to determine the method 400, the sampling in a particular location of the wellbore or at the depth completed.

After completion of the transaction (transactions) sampling at stage 408 (for example, in a particular place in the wellbore or at the depth of one or more models and/or subsequent drilling plans can be updated. Such updates may be based on one or more analyses of the results of the operation (operations) of the samples obtained at the Tadei 408, and can include updating and/or correcting a comprehensive range related to the drilling parameters to further improve any subsequent operations of drilling and/or sampling.

In method 400 then determines whether to perform additional drilling and/or sampling at stage 412, and, if Yes, control returns to the step 404, which collect data during the additional drilling. Otherwise, the method 400 can perform analysis upon completion of their work on stage 414 using, for example, a simulator (not shown). This analysis following completion of the work may include analysis and/or interpretation of the data response of the formation and properties of fluid.

Method 400, in General, is a method for dynamic scheduling of drilling and related operations of sampling for more effective and efficient collection and analysis of samples of the reservoir fluid. However, note that the method 400 shown in figure 4, can be implemented in many specific cases to achieve the same results for different applications. Additionally, although the specific order of operations shown in figure 4, in various specific embodiments of the method 400, you can change the order and/or exclude one or more BC the Cove, shown in figure 4, and/or to incorporate one or more additional blocks and associated operations. For example, the analysis following completion of the work on stage 414 can not be performed in all embodiments of the method 400.

Figure 5 block diagram of the sequence of operations shows one particular embodiment of the method 400 shown in figure 4. The method 500 shown in figure 5, begins with the collection of statistical data relating to the previous operations of drilling and/or sampling at the stage 502. Such data can, for example, to collect in one or more databases, which can be placed in the computer 160 logging and management (figure 1) or, at least, to be available for him. After the collection of statistical data or data of past periods at the stage 502 of method 500 automatically plan the actions or operations of drilling and sampling at stage 504. Together stage 502 and 504 plan prior to drilling and, thus, correspond, in General, stage 402 4.

In any case, at the stage 504 can use the device 318 identification (figure 3) to identify two or more possible scenarios, plans or methods for the operations of drilling and/or sampling. Specifically, each of these scenarios, plans or methods may consist of combinations of corresponding or maintains osvezenih drilling parameters and/or the sampling parameters and the corresponding values of the parameters, you can get in whole or in part from data collected at the stage 502.

The parameters may include parameters of the method, the drilling parameters, the parameters of the filtration cake of the drilling fluid, the sampling parameters, reservoir parameters, the parameters of the sampler and/or the characteristics of the mud, some or all of which can be obtained before the start of drilling operations and/or operations of sampling. Some drilling parameters include the trajectory of the wellbore, the dimensions of the wellbore, the dimensions of the BHA, the properties of the mud, the statistics of the flow rate of the drilling fluid, the configuration of the BHA, the duration of the operation of the sampling and/or the time at which the sample was taken from the formation F. the reservoir Parameters may include seismic data relating to the reservoir F, the acoustic data relating to the reservoir F, data, wireline logs uncased wellbore related to the formation F, the properties of the fluid, permeability, capillary pressure and associated data related to the reservoir F, and/or mechanical properties of rocks (e.g., the strength of the layer).

The drilling fluid may include data obtained by laboratory measurements, and/or performance of a particular drilling fluid (which of rastvorov) in the same or similar layers and/or under similar conditions. The drilling fluid may include the composition of the drilling fluid, the rheology of the drilling fluid, which includes the viscosity of the drilling fluid, the density of the drilling fluid, the yield point of the drilling fluid, the strength of the gel drilling fluid, the compressibility of the drilling fluid and/or filtering characteristics of the mud.

Each of the scenarios, plans or methods and corresponding or related parameters can then analyze, evaluate, or process using one or more simulators 302-308. For example, performance scenarios, plans or methods can be defined using one or more simulators 302-308. Such performance can be defined for scripts, plans, or methods, including various provisions of the sampler (e.g., tool 200 logging while drilling figure 2) relative to the drill bit (for example, the drill bit 105 figure 1). Specifically, for example, the position of the sampler relative to the drill bit may be associated with the sampling parameters that can be used by the simulator 306 reservoir flow and/or simulator 304 of the filtration cake of the drilling fluid to generate output data, which, in turn, can be used to determine and/or calculate the parameters of mud cake brown is on the solution and/or data collector.

Performance can also be defined for different configurations of the stabilizer. Specifically, the simulator 302 of the hydraulic system of the wellbore (figure 3) can process or analyze possible scenarios, plans or processes with different configurations of the regulator or, in General, the geometry of the drill string to generate output that can be used to address and/or determine the equations of the mechanics of fluid to the wellbore drilled wells.

One or more simulators 302-308 can also be used to determine performance-related scenarios, plans or processes, which includes various operations of sampling. For example, the relative performance of scenarios, plans or methods with sampling time stop drilling, sampling, during lifting of the BHA (e.g., BHA 100 figure 1) from the wellbore (for example, the barrel 11 wells figure 1) after drilling of the wellbore to the design depth and/or determined using the sampling tool on wireline. Additionally, different time periods of sampling may be associated with the sampling parameters that can be used by the simulator 306 reservoir flow to generate output data that is used to define the level of contamination of the fluid take samples and/or other data, related to the collector.

Additionally, scenarios, plans or processes can be evaluated or analyzed to determine the effects (impacts) of the use of various types of drilling fluids (e.g., performance sampling). Specifically, for example, information representing different types of drilling fluids, can use the simulator 302 of the hydraulic system of the wellbore simulator 304 of the filtration cake of the drilling fluid, the simulator 306 reservoir flow and/or simulator 308 response of the instrument to generate output data that is used to determine whether the cost of use of alternative drilling fluid during drilling and/or sampling process to be justified. Similarly, one or more simulators 302-308 can be used to determine the effects of various flow rate of the drilling fluid. For example, statistics of various flow rate of the drilling fluid can be associated with the drilling parameters that may be used by the simulator 302 of the hydraulic system of the wellbore (figure 3) to generate output data used for decision and/or determination of the equations of mechanics of fluid in the wellbore.

More generally identified possible scenarios, plans or method and related parameters and parameter values handle setprocessor 240 modeling and/or block 250 data to generate forecasts, associated with the sampling reservoir. These predictions can be, in General, relate to the performance and/or value of transactions (operations) sampling. Additionally, it is possible to generate predictions relating to the dynamic penetration of the drilling fluid for each of the identified scenarios, plans or methods. For example, the block 250 data processing and/or setprocessor 240 simulation can handle seismic data and/or data logging chart uncased wellbore to determine the estimation of the pore pressure of the reservoir on the trajectory of the wellbore. Similarly, data logging chart uncased wellbore can process block 250 data processing and/or setprocessor 240 modeling to determine the trajectory of the wellbore porosity of the formation, lithology of the formation, the structural information of the reservoir, the type of reservoir fluid saturation of the reservoir fluid medium and/or calculations of permeability, etc. Additionally, setprocessor 240 modeling and/or block 250, the data processing can process data related to mechanical rock properties, to assess the rate of penetration of the drill bit 105 of the reservoir and/or to identify and/or define constraints for the intensity of the pumping formation fluid during sampling, for example, the R, pump (e.g. pump 280 figure 2).

After processing or analysis setprocessor 240 modeling and/or data unit 250 of possible scenarios, plans or methods and related parameters and values parameters sorting device 314 (Fig 3) sorts and/or organizes the predictions associated with the different scenarios, plans or processes. Sorting device 314 can systematize methods (e.g., scenarios) according to the quality of the sample fluid (e.g., the final quality of the sample), the duration of the sampling process, the cost associated with the sampling process (for example, the cost of sampling), and/or according to the amount of risk associated with obtaining samples of the fluid. In addition, the sorting device 314 may provide identification parameter (s) (e.g., parameter (s) drilling and/or sampling), with the greatest impact on the quality of the fluid sample. Additionally, comparing the device 310 may compare the predictions associated with the different scenarios, plans or ways of identifying scripts, plans, methods and/or parameters that reduce the cost of sampling, improve the quality of the fluid sample and/or reducing the duration of the sampling process.

After sorting and/or organizing the sorting device is CMV 314 forecasts, associated with different scenarios, plans or processes, block 250 data plans operations drilling and sampling on the basis of systematic predictions. In particular, on the basis of systematic forecasting unit 250 data can identify the configuration of the BHA, drilling fluid, drilling technology to be used, the time at which the drilling operations shall be temporarily discontinued for obtaining samples of the fluid, the place or places where the drilling operations shall be temporarily discontinued for obtaining samples of the fluid, the circulation rate of the drilling fluid, the intensity of sampling formation fluid, the duration of pumping formation fluid, the composition of selected samples of the fluid, whether the sample () to get after the cessation of drilling or during lifting link the bottom of the drill string from the wellbore.

After performing the initial planning of the operations of drilling and/or sampling at stage 504, which is an example of a process 500, start drilling at stage 506 according to the initial plan. During the execution of the plan drilling is possible to perform the data collection. Specifically, in method 500, data can be collected drilling during the drilling stage 508. For example, during drilling tools 120, 120A Karot the MS while drilling (figure 1) and/or sensors 235 can be used to measure parameters, associated with the actual rate of penetration of the drill bit 105, the amount of movement of the link 100 to the bottom of the drill string (figure 1) and/or the speed of rotation of the layout 100 of the bottom of the drill string (figure 1), each of which can use the simulator 302 of the hydraulic system of the wellbore (figure 3) to update and/or Refine the statistics of hydraulic flow in the barrel 11 wells. Additionally or alternatively, the measured parameters can be related to the actual flow rate of the mud pump (e.g., the flow rate of the drilling fluid)that can be used by the simulator 302 of the hydraulic system of the wellbore to update and/or Refine the statistics of hydraulic flow in the barrel 11 wells. Additionally, the measured parameters can be related to the actual trajectory of the wellbore that can be used by the simulator 302 of the hydraulic system of the wellbore to update and/or Refine the calculation of reservoir pressure on the barrel 11 wells. Additionally, the measured parameters can be associated with the filtration of the drilling fluid and/or small dimensions, logging while drilling, each of which can be used to assess the profile of the zone of penetration of the fluid for calibrating models of the drilling fluid, for calibration of the model mud cake Burov the solution and/or for calibration of the model layer. Additionally, the measured parameters may be associated with the well pressure and temperature in the well, which can be analyzed and compared with the output data and/or forecasts setprocessor 240 simulation (figure 2). On the basis of measured parameters parameters rheology of the drilling fluid and temperature in the well can be adjusted to obtain the similarity between the predictions generated by setprocessor 240 modeling and measurements obtained by the tools 120, 120A logging while drilling and/or sensors 235. In addition, you can take measurements in mud and/or cuttings from the formation F at the wellhead, which can use the simulator 306 reservoir flow to update and/or Refine the reservoir model and/or the simulator 302 of the hydraulic system of the wellbore to update and/or Refine a model of the filtration cake of the drilling fluid.

During the passage of drilling in method 500 can determine whether the selected preliminary or initial sample (for example, should be performed pre-test) at stage 510. For example, comparing the device 310 (Fig 3) can compare the values of parameters measured during drilling (e.g., data collected at stage 508), with the predictions generated by setprocessor 240 modeling to determine achieved if a CR is planned, the sampling point. Design the sampling point can be regarded as achieved when measurements made by instruments 120, 120A logging while drilling and/or sensors 235, show that drilling the reservoir containing the fluid of interest, and reservoir properties are suitable for sampling, as determined or predicted by setprocessor 240 simulation.

If block 250 data processing (figure 2) and/or the processor 316 (3) determine that the project sampling point is reached, the probe 205 (2) of the tool 200 logging while drilling can be installed at this location on stage 512 and manage to enter in contact with the wall 220 of the wellbore to obtain samples from the formation F at stage 514. During the initial operation of sampling (for example, preliminary tests) at stage 514 measurements are performed to obtain actual measurements of the formation and/or formation fluid unit 230 measurements of fluid and/or sensor 235. Some of the actual measurements can be associated with measurements of the reaction layer on the drilling operations. In particular, some of the actual measurements, together with other data logging while drilling and/or data of the drilling fluid, can be used to update and/or Refine a model of the filtration cake of the drilling fluid and/or establishment and/or modi the project for the reservoir model. In General, the operations performed on stages 508 to 514 include the collection of data during the execution of the plan of drilling and, thus, correspond, in General, stage 404 4.

Upon completion of the initial sampling process (for example, preliminary tests) actual measurements, performed on stage 508 and 514, can be treated with setprocessor 240 simulation to update the planned operation of the sampling on the basis of the actual measurements at the stage 516. In particular, the simulator 302 of the hydraulic system of the wellbore simulator 304 of the filtration cake of the drilling fluid, the simulator 306 reservoir flow and simulator 308 response tool can be used to re-evaluate the various possible scenarios, plans or methods, using actual measurements together with, for example, processing parameters, drilling parameters, parameters, sampling, reservoir parameters and/or parameters of the drilling fluid. Scripts can be associated with the operating parameters, such as the circulation rate of the drilling fluid during sampling and/or in the period of time after drilling. During the processing of actual measurements at the stage 516 probe 205 may maintain contact with the wall 220 of the wellbore or out of contact. Operation (operation)performed on stage 516, correspond, in BSAM, stage 406 figure 4.

After updating the initial sampling plan to stage 516 in method 500 trigger the execution of the updated sampling plan at stage 518. More specifically, the initiating device 312 (Fig 3) may start and/or perform the operation of sampling on the basis of systematic predictions associated with different scenarios, plans or processes. In particular, the operation of sampling can be performed on the basis of the sampling parameters associated with the task of improving sampling, such as improving the quality of the fluid sample, the duration of the sampling process and/or reducing the cost of sampling, etc. If the probe 205 (2) is removed from contact with the wall 220 of the wellbore during the actual measurement at the stage 516, the probe 205 (2) of the tool 200 logging while drilling is in contact with the wall 220 of the wellbore to obtain samples of the formation F. In any case, the block 230 measurement of fluid and/or sensors 235 get actual measurements of samples of the reservoir fluid. Some of the actual measurements may include pressure and/or temperature response of the formation F and/or physical properties of the sample fluid, such as composition, pressure, saturation, density, viscosity, relative resistance and/or conductivity, of erenia nuclear magnetic resonance and/or optical spectral properties.

After starting the operation of the sampling stage 518 of method 500 can measure the response of the reservoir and/or properties of the fluid at stage 520, to interpret the response of the reservoir and/or properties of the fluid at the stage 522, and to control the sampling operation based on the interpreted response of the reservoir and/or properties of the fluid at the stage 524. In the example process 500 then determines whether completed sampling at the stage 526, and if the sampling is not completed, then in the example process 500 updates the operation of the sampling stage 528 and return control to stage 520 to continue the sampling process. Thus, operations in stages 520-528, in General, correspond to the stage of 408 figure 4. Also, in General, operations in stages 520-528 provide the sampling process with a dynamic or real-time control and the repetition of one or more sampling and/or measurement of drilling parameters to improve or optimize the operation of sampling. In this way one or more of the sampling parameters can be adjusted dynamically and/or one or more drilling parameters (for example, the flow rate of the drilling fluid) can be adjusted dynamically to improve the efficiency and/or performance of the transaction (transactions) sampling.

Consider the detail stage 520-528, measuring the response of the reservoir and/or measuring the properties of the fluid at the stage 520 can be performed using block 230 measurement of the fluid (figure 2) and/or sensors 235 (figure 2). For example, the block 230 measurements of fluid and/or the sensors 235 can measure pressure, temperature, flow rate of the fluid selected samples, the composition of the fluid sample and/or properties of the fluid sample. Block 230 measurements of fluid and/or the sensors 235 may also, for example, be used to determine the degree of infiltration of the drilling fluid into the formation F (Fig 2).

Interpretation of the response of the reservoir and/or properties of the fluid, measured at stage 520, can be performed using one or more simulators 302-308 of setprocessor 240 modeling and/or with the use of block 250 data processing. For example, setprocessor 240 modeling and/or block 240, the data processing can process data parameters of the filtration cake of the drilling fluid, reservoir parameters, the parameters of the response of the instrument and/or data associated with the model of the hydraulic system of the wellbore to generate output data of the simulation. Setprocessor 240 modeling and/or block 240, the data processing can process data from actual measurements (for example, parameters and/or filter cake of the drilling RA the creators) together with the sampling parameters for the calculation, determination and/or prediction of theoretical response to the sampling process. Actual measurements may include the length of the zone of penetration into the formation F of the drilling fluid, the radial profile of saturation, the composition of the fluid sample, the permeability of the filtration cake of the drilling fluid, the permeability of the formation, the relative mobility of the fluid mud filtrate, the relative mobility of the fluid of the initial reservoir fluid, the operating parameters of the instrument and/or the sampling parameters. Comparing the device 310 (Fig 3) may then compare the actual response of the reservoir, identified by block 230 measurements of fluid and/or sensors 235, with theoretical response of the reservoir defined by setprocessor 240 simulation (figure 2) and/or block 240 data processing (figure 2). On the basis of the comparison unit 240 data may identify and/or determine which parameter (s) drilling and/or sampling can be changed for better process control sampling to meet planned or required operation of sampling or design values of the processing parameters. For example, properties of the formation, the properties of the drilling fluid and/or temperature and/or pressure in the barrel 11 wells can be identified for a security check is th adjustment. This comparison can also be used for diagnosis and/or problem identification tool operation and/or malfunction. Additionally or alternatively, the axial load on the bit, the flow rate of the drilling fluid, the speed of rotation of the layout 100 of the bottom of the drill string and/or properties of the mud can be identified for possible adjustments. Adjustment of the composition of the drilling fluid may, for example, include the introduction (at a later stage of drilling operations) additives to drilling mud.

The information created by the interpretation of the data response of the formation and properties of the fluid at the stage 522, then used to control the sampling operation at the stage 524 in real-time. For example, the management of real-time operations of sampling can be obtained by controlling the pump sampling, estimating the magnitude of contamination, assessing the amount of pumping to achieve the design level of contamination and/or adjusting the transmission time of the sample in the chamber and/or container for samples. In a more General sense, the sampling operation can be controlled based on the specified properties of the reservoir and/or altered properties of the drilling fluid to improve the sampling process. The improvement of the process of sampling involves improving the quality of the sample and/or decrease in the cost, the cat is who can be associated with the operations of sampling and/or drilling. Specifically, the flow rate of the drilling fluid can be reduced by detecting excessive erosion crusts of mud. Alternatively, the flow rate of the drilling fluid can be increased if the quality of the cake of the drilling fluid is defined as acceptable. In addition, the flow rate of the drilling fluid can be increased if the flow around the drill string 12 (Fig 1) is defined as acceptable.

Update operations sampling is performed at the stage 528, may be based, at least in part, on the updated properties of the reservoir fluid. Alternative and/or additional, the actual measurement can be used to update the parameters used by setprocessor 240 simulation (figure 2). The forecasts generated by setprocessor 240 modeling, can be associated with statistics contamination of the pumped fluid as a function of time and/or volume of the fluid pumped from the reservoir. In other examples, the predictions generated by setprocessor 240 modeling can be statistics of the composition of the pumped fluid as a function of the volume of the fluid pumped from the reservoir, and/or time. Additionally or alternatively, the forecasts generated by setprocessor 240 modeling, can be associated with the prediction of the expected response of PL is a hundred, for example, for a particular sampling operation. Forecasts and/or output data generated by setprocessor 240 simulation can be compared with the actual measurements obtained by block 230 measurements of fluid and/or sensors 235 for identification and/or diagnosis of malfunctions of the instrument and/or determine whether to modify one or more parameters in one or more models used in the simulation.

If at the stage 526, the method 500 determines that the sampling is finished or completed dynamically updated according to the sampling plan, the method 500 determines whether the operation of the drilling or work completed or finished on stage 530. If the drilling operation is completed at stage 530, the control can be passed to the step 534 in which after completion of work, the interpretation of the data response of the formation and properties of fluid. Otherwise, control can be passed to the step 532, in which resume drilling and/or tripping operations, and control goes to the step 508. Similarly, if the method 500 is determined at stage 510, the sampling should not be performed, control passes to the step 530.

Graphics figure 6-13 show the output of the simulation and/or projections generated by the simulator 302 of the hydraulic system of the wellbore imitate the om 304 of the filtration cake of the drilling fluid, the simulator 306 reservoir flow and simulator 308 response of the instrument. In General, 6, 8 and 10 correspond to the predictions associated with the first scenario, the plan or method of sampling, and 7, 9 and 11 correspond to the predictions associated with the second scenario, the plan or method of sampling. The first scenario sampling can be associated with the operation of the sampling location in the barrel 11 wells after a considerable time from the first passage of the drill bit 105. For example, the drill string 12 can be lifted from the wellbore or may be removed from the barrel 11 wells and again lowered into the barrel 11 of the well or may be replaced by another sampling device, such as a sampler on wireline. By contrast, the second scenario sampling can be associated with the sampling operation at the same location as in the first scenario, sampling, but immediately after reaching the designated sampling sampler (for example, the tool 200 logging while drilling) for the first time.

Setprocessor 240 simulations are used to determine which of the two scenarios, plans or ways of sampling is preferred to obtain a sample having a smaller magnitude of contamination after a fixed time of sampling. As discussed below, the first scenario selection clause is about has some advantages and some disadvantages. For example, in the first scenario sampling filtration cork mud is successfully formed in the shaft 11 wells. However, the depth of penetration of the drilling fluid may be relatively high. Similarly, the second scenario sampling has some advantages and some disadvantages. For example, in the second scenario, the sampling depth of penetration of the drilling fluid may be relatively small. However, filtration cork mud is not successfully formed (for example, is unsteady on the wall 220 of the wellbore.

Shown in Fig.6 and 7 graphs 600 and 700 are the speed of circulation of the drilling fluid as a function of time. In each of the graphs 600 and 700, the time at which the sampling point for the first time reached the drill bit 105, represented by t0. The x-axis 602 and 702 of each of the graphs 600 and 700 correspond to the axes of time, and the y-axis 604 and 704 of each of the graphs 600 and 700 correspond to the axes speed (for example, the speed of circulation of the mud) mud in the barrel 11 wells on the site of sampling. Intervals 606 on 6 or 7 show a decrease in the speed of circulation of the drilling fluid (e.g., speed of drilling mud in the annular space), when, for example, additional sections of drill pipe added to drill string 12. The period of time t1 to provide the ing time in which the stabilizer (for example, the blade 215 centralizer tool 200 logging while drilling) passes the sampling point.

As shown in Fig.6, the period of time between t1 and t2 represents the time at which heavy-weight drill pipe is set close to the sampling point. The period of time t2 represents the time at which the drill pipe is close to the sampling point. The position of the drill pipe relative to the location of the sampling indicates that the drill bit 105 continues drilling of the reservoir F even after reaching the place of sampling. In this particular example, the desired depth of the wellbore to be drilling during this particular operation drilling reached at the end of time period t2, and the sample is subject to sampling at the selected sampling location during removal of the drill string 12 of the barrel 11 wells. After deleting or removing the drill string 12 of the barrel 11 well, the circulation of the drilling fluid is usually stopped, which is represented by the time period t3. Although the circulation of drilling fluid is stopped in a given period of time, the drilling fluid may have a small speed due to at least partial action of the drill string on the fluid in the wellbore. This action of the drill string is usually referred to as swabbing. The probe 205 sampling (figure 2) reaches a depth of OTB is RA samples at the beginning of the time period, presents t4, in which the circulation of the drilling fluid starts again to power on the layout 100 of the bottom of the drill string (figure 1) and/or tool 200 logging while drilling (figure 2), when the sampling operation takes place. After the operation is completed sampling at the end of t4 resumed lifting the drill string from the wellbore.

7 shows that the drilling operation (e.g., drilling) continues until the probe 205 (2) place of sampling, which run the sampling operation. During the operation of sampling, represented by the period of time t4', the circulation rate of the drilling fluid can be reduced. After the operation is complete sampling drilling in the barrel 11 wells resumes. By contrast, figure 6 shows that the drill bit 105 continues drilling of the reservoir F over a period of time after reaching the place of sampling and the sampling operation performed during the operation of the lifting of the stem 11 of the well.

On Fig and 9 shows graphs 800 and 900, representing the filtration rate of the drilling fluid in the reservoir at the sampling point as a function of time. The x-axis 802 and 902 of each of the graphs 800 and 900 correspond to the axes of time, and the y-axis 804 and 904 each of the graphs 800 and 900 correspond to the axes of the filtration rate of the drilling fluid per unit area of the barrel 11 wells. The area under the clubs the mi 806 and 906 curves, shown by shading represents the total volume of drilling fluid that has penetrated into the formation F before starting the operation of sampling. As shown in Fig, the amount of penetration of the drilling fluid is relatively high before starting the operation of sampling (for example, time t4). In contrast, as shown in Fig.9, the amount of penetration of the drilling fluid is relatively small before starting the operation of sampling (for example, the time period t4'). In each of the graphs 800 and 900 time during which drilling fluid initially enters (e.g., immediately) into the formation F with sinking drill bit 105 of the reservoir F, represented by a time t0. As shown by sections 808 and 908 curves, after the sinking of the reservoir (e.g., rocks) drill bit 105 (1) filtration cork mud begins to form on the wall 220 of the wellbore, which reduces the filtration rate (e.g. the rate at which the mud filtrate penetrates into the reservoir).

As shown in the beginning on Fig, the first speed 810 dynamic filtering is achieved, at least partially, on the basis of the position of the heavy-weight drill pipe in the bore 11 of the borehole cross-section heavy-weight drill pipe and the velocity of circulation of drilling mud and drilling fluid properties. When the drillstring 12 becomes close to the place of selection is as samples or passes it receive a second speed 812 dynamic filtering based at least in part, on the position of the drill string 12 in the barrel 11 wells, the section of drill string 12, the speed of circulation of the drilling fluid and the drilling fluid properties. Then, when the drill string 12 is removed from the barrel 11 wells, filtration rate is reduced, essentially, to speed the static state, represented by section 814 of the curve. However, the speed of 815 filter increases with the speed of circulation of the drilling fluid to supply energy to the layout 100 of the bottom of the drill string and/or the tool 200 logging while drilling, when the sampling operation takes place.

As shown in Fig.9, the filtration rate of the second scenario sampling is similar to the first scenario of sampling to the time period t2, in which, in the first scenario sampling drill bit 105 continues drilling of the reservoir F even after reaching the place of sampling. By contrast, in the second scenario, sampling, achieved when the sampling start the sampling operation. As a result, the first speed 910 dynamic filtering, essentially, is supported during the operation of sampling. Start sampling after reaching the designated sampling results in a relatively high speed 910 dynamic Phi is Tracie, but the total volume of drilling fluid that has penetrated into the formation, is relatively low.

Figure 10 and 11 shows graphs 1000 and 1100 that represents the point in time (e.g., snapshot) saturation of the fluid medium in the reservoir F before the sampling operation. The x-axis 1002 and 1102 of each of the graphs 1000 and 1100 correspond to the distance from the wall 220 of the wellbore and the y-axis 1004 and 1104 of each of the graphs 1000 and 1100 correspond to the saturation level of the mud filtrate, shown in figure 10 and 11 for the drilling fluid is water-based. In addition, the first section 1006 and 1106 curves represent the zone of penetration of mud filtrate into the formation and second sections 1008 and 1108 of the curves represent the area of the reservoir with a pristine fluid medium (e.g., relict of the reservoir fluid medium). Additionally, the dotted lines 1010 and 1110 represent the saturation level of the reservoir relict water.

Figure 10 shows the first scenario sampling in which the sampling operation is started later than in the second scenario sampling. As a result, the depth of penetration of the drilling fluid in the reservoir is relatively high. However, in the developed (i.e. good) cake of the drilling fluid, the intensity of the filtration of the drilling fluid is relatively low.

Figure 11 shows the second scenario sampling, in which operas is tion sampling starts before than in the first scenario sampling. As a result, the depth of penetration of the drilling fluid into the formation is relatively low. However, in the undeveloped cake of the drilling fluid (e.g., not fully formed), the intensity of the filtration of the drilling fluid is relatively high.

On Fig and 13 shows graphs 1200 and 1300, representing an example of the relationship between the level of contamination of the fluid sample and the volume of fluid withdrawn samples pumped from the reservoir, which can generate simulator 306 reservoir flow. The parameters of the sampling used to obtain the results associated with both charts 1200 and 1300, similar or identical. However, the time at which occurs the sampling operation after drilling is different. The x-axis 1202, and 1302 of each of the graphs 1200 and 1300 correspond to the pumped volume of the reservoir fluid and the y-axis 1204 and 1304 of each of the graphs 1200 and 1300 correspond to the level of contamination of mud filtrate samples of fluid. The pumped volume of the reservoir fluid depends on the time and intensity of pumping.

First, depending on the specific properties of the reservoir and reservoir fluid selected sample volume of mud filtrate can be pumped (e.g., the amount of breakdown) before entering the reservoir fluid is th environment (for example, oil) in the sampler (for example, the tool 200 logging while drilling). Volume breakdown, in General, presents brackets 1206 and 1306. As shown in Fig, the amount of breakdown is relatively large. In contrast, as shown in Fig, the amount of breakdown is relatively small. Section 1208 and 1308 of the curve represent the dynamics of the development of clean, appropriate to improve the quality of the fluid contained in the sampler. On Fig presents the situation where the dynamics of the development of cleaning is determined taking into account the fact that the sampling operation is performed through a significant amount of time after drilling to a depth of sampling. As a consequence, advanced filtration cork mud creates an effective barrier filter mud filtrate during pumping operations. Although the cleaning speed is low, in the end, it is possible to achieve a low level of contamination after pumping a sufficient volume. On Fig presents the situation where the sampling operation is performed through a relatively short time after drilling to a depth of sampling. In this embodiment, the filtration cork mud is not an effective barrier to the infiltration of mud filtrate through the wall of the wellbore. Although the initial dynamics of purification is relatively high, the minimum the level of contamination of the fluid sample reaches at the desired intensity pumping.

On Fig shows a graph 1400, representing the ratio between the differential pressure and intensity pumping. Differential pressure response of the reservoir determined by measuring the pressure in the flow line of the sample on the probe (for example, the probe 205) and determining the difference between the dimension with the reservoir pressure. The pressure difference of importance for the pump is the pressure difference measured at the probe (e.g. a probe 205) and at the discharge point of the sampling line on the output hole pump (not shown). The x-axis of the graph 1402 1400 corresponds to the intensity of pumping, and the y-axis 1404 graph 1400 corresponds to a pressure drop.

As discussed above, the pressure in the reservoir can be estimated by performing the operation of pre-test before starting the operation of sampling. Alternatively, the pressure in the reservoir can be estimated by evaluating survey data collector (e.g., seismic and/or acoustic research), or by measurements made in nearby wells.

Graph 1400 includes a set of curves 1406 and 1408 and straight lines 1410, 1412 and 1414, forming the working modes for downloading, each of which may define the simulator 308 response of the instrument. Line 1410 represents the limit of pressure that can build components layout 100 of the bottom of the drill string and/or tools is ment 200 logging while drilling (for example, hardware pumping). Pressure limitation may be a function of pressure in the barrel 11 wells in the extreme version, if the reservoir is depleted or has a very low mobility of the fluid. Alternatively, line 1410 may be pressure limitation related to the properties of the fluid, such as saturation pressure, the excess of which can lead to breakthrough the fluid and result in unusable sample. Line 1412 and 1414 are the minimum intensity of the pumping and the maximum intensity of the pumping, respectively. Minimum and/or maximum intensity of pumping can be determined on the basis of the minimum and/or maximum speed of the motor, which can run the appropriate pump. Curves 1406 and 1408 are curves of power and can be derived from the power available on the layout 100 of the bottom of the drill string and/or the tool 200 logging while drilling. Curve 1406 corresponds to the first speed of circulation of the drilling fluid, and the curve 1408 corresponds to the second speed of circulation of the drilling fluid. In the operation of the power turbine generates, outside the influence of the drilling fluid circulating in the bore 11 of the well.

Curve 1416 shows the limitation of power on the basis of penetration of the drilling fluid into the formation. Crooked is 1416 may be displayed according to the simulator 302 of the hydraulic system of the wellbore, simulator 304 of the filtration cake of the drilling fluid and/or simulator 306 reservoir flow. In the simulator 302 of the hydraulic system of the wellbore simulator 304 of the filtration cake of the drilling fluid and/or simulator 306 reservoir flow can be used to determine the effect of circulation rate of the drilling fluid in the wellbore 11 wells penetration of drilling mud into the formation. For example, if the circulation rate of the drilling fluid is relatively high, filtration cork mud usually grows relatively slowly or is being eroded relatively quickly and, thus, the filtering may be higher. Thus, the simulator 302 of the hydraulic system of the wellbore simulator 304 of the filtration cake of the drilling fluid and/or simulator 306 reservoir flow can be used to identify the optimum performance of the pump, limiting infiltration rate to obtain high-quality fluid samples at a particular time. The graph 1400 optimum performance 1418 swapping presents, in this example, the intersection curve 1416 (e.g., power, limited filtering and curve 1420 (e.g., curve response of the reservoir), described below.

Curve 1420 curve is the response of the reservoir, depending on the mobility of the fluid cf the water reservoir, the ratio of the mobility of the fluid mud filtrate and a variety of fluid in the reservoir (e.g., water, oil, gas etc) and/or non-linear steps, at least partially, viscosity, density of the fluid and the velocity of the reservoir fluid sampling. Curve 1416 can generate simulator 308 response of the instrument. The mobility of the fluid reservoir can be defined, for example, during preliminary testing, during the sampling process, log charts uncased wellbore (for example, logging diagram of nuclear magnetic resonance) or according to the data collected in the neighboring wells.

On Fig shows a diagram of the platform R processor that can be used and/or programmed to implement the computer 160 logging and control unit 250 data processor 316 and/or setprocessor 240 modeling. For example, the platform R processor is implemented with one or more General-purpose processors, processor cores, microcontrollers, etc.

Platform R processor example Fig includes at least one programmable processor P105 General purpose. The processor P105 executes coded instructions P110 and/or P112 present in the primary storage device of the processor P105 (for example, the operator is main memory P115 and/or permanent storage device P120). The processor P105 may be any type of processor unit, such as processor core, the processor and/or microcontroller. The processor P105 may execute, among other things, is an example of how to manage the device described in this document.

The processor P105 associated with the primary storage device includes a persistent storage device P120 and/or random access memory P115) via the bus P125 business data. Random access memory P115 can be implemented as a dynamic random access memory (DRAM), synchronous dynamic random access memory (SDRAM), and/or as a dynamic random access memory device of any other type, and a persistent storage device can be implemented as a flash memory card and/or any other type of storage device. Access to storage devices P115 and P120 may be controlled by the mass storage controller (not shown).

Platform R processor also includes a circuit P130 interface. Circuit P130 interface can be implemented as any type of interface standard, such as an interface to an external storage device, serial port, input/output General purpose, etc. of One or more input devices P135 and one or more o the-breaking devices P140 connected in circuit P130 interface.

As described above and shown in the figures, it should be clear that the present description is a method of scheduling execution of sampling for underground reservoir, which may include identifying multiple processes and related parameters, where the processes include the drilling and sampling process and related parameters include parameters of drilling and sampling. The method may also include processing parameters for each of the processes on setprocessor simulation to generate predictions associated with the sampling of the reservoir, where setprocessor modeling may include at least one of the following: simulator hydraulic system of the wellbore simulator filtration cake of the drilling fluid, the reservoir simulator or simulator response of the instrument. The method may further include mapping projections associated with the sampling of the reservoir on the basis of at least one of the following: quality of the fluid sample, the duration of the sampling process, the performance of the method of selection or the cost of sampling and planning the operation of sampling on the basis of systematic predictions.

The present description also provides a method of managing operation selection of the samples from an underground formation, which may include the formation testing, scheduled for sampling, measuring a response of the reservoir to the test, determination of the parameters of the filtration cake of the drilling fluid and formation based on the response of the reservoir, the processing parameters of the filtration cake of the drilling fluid and formation on setprocessor simulation to generate output data of the simulation, the parameters of the sampling on the basis of output data of the simulation and control of the operation of sampling from an underground formation on the basis of the sampling parameters.

The present description also provides a method of managing operation of drilling, which may include the process of sampling from an underground formation, measuring the actual response of the reservoir to the sampling process, the calculation on setprocessor theoretical modeling of the reaction layer on the sampling process, comparing the actual response with theoretical response, clarification, at least one of the reservoir properties, or properties of the drilling fluid based on the comparison and control the drilling operation based on the at least one specified reservoir properties or adjusted properties of the drilling fluid to improve the sampling process.

The present description also pre what is the way to control sampling during drilling operations, which may include measurement of parameters of drilling and sampling in the operation of sampling during drilling operations, the data processing of the measured parameters of drilling and sampling using the simulator to update the output of the simulator and control operation of the sampling while drilling in real time based on the updated output of the simulator.

The present description also provides a method of operation of the sampling while drilling, which may include the planning of the sampling while drilling through the simulator, this plan contains the definition of the parameters of drilling and sampling on the basis of the output of the simulator obtained before the operation start sampling while drilling. The method may also include the management of real-time process sampling operation of the sampling while drilling through the simulator to update the input data of the simulator on the basis of data obtained during at least one of the sampling process or a drilling process that occurs during the operation of the sampling while drilling. Optionally, the method may include the management of real-time during drilling simulator to improve the sampling process with updating the receiving input of the simulator on the basis of data obtained during the sampling process or a drilling process.

Although some are examples of the methods, devices, and products described in this document, the scope of protection of the present invention specified is not limited. On the contrary, the invention comprises methods, devices, and products included in the scope of the attached claims, both literally and under the doctrine of equivalents.

1. The method of operation planning of sampling from an underground formation containing the following stages:
identification of multiple processes and related parameters, and processes include the processes of drilling and sampling, and their parameters include parameters of drilling and sampling;
the processing parameter data for each of the processes using setprocessor modeling for predictions associated with sampling in the reservoir that includes at least one of the simulator of the hydraulic system of the wellbore simulator filtration cake of the drilling fluid, the reservoir simulator thread or the simulator response tools;
systematization of forecasts associated with sampling in the reservoir, based on at least one of the quality of the fluid sample, the duration of the sampling process, the performance of the sampling process or the cost of sampling;
PL the plan of operation of the sampling on the basis of systematic predictions.

2. The method according to claim 1, wherein the specified parameters include at least one of the properties of the mud, statistics flow rate of the drilling fluid, the configuration of the BHA, the properties of the fluid samples, the properties of the formation, duration of operation, sampling, statistics flow rate of the fluid sample, a specified time of sampling, process parameters or parameters of the header.

3. The method according to claim 1, in which the systematization of projections contains the definition of the influence of each of these parameters on at least one of the quality of the fluid sample, the duration of the sampling process, the performance of the sampling process or the cost of sampling.

4. The method according to claim 1, additionally containing an operation of sampling on the basis of systematic predictions.

5. The method according to claim 1, additionally containing a measurement while drilling to upgrade the drilling operations in real time.

6. The method according to claim 1, additionally containing obtaining the actual dimensions associated with sampling in the reservoir, and the operation test for the actual measurements in the underground reservoir.

7. The method according to claim 6, which additionally contains an update operation sampling on the basis of the actual measurements.

8. SPO is about 6, additionally contain a comparison of actual measurements with predictions to identify failure of instruments, comparing actual measurements with predictions to update the specified parameters and update of these parameters on the basis of the actual measurements to improve the performance of the operation of sampling.

9. The method according to claim 6, which additionally contains the actual data processing of measurements using setprocessor modeling to create a model to predict at least one property of the formation, the properties of the filtration cake of the drilling fluid or properties of the fluid sample, and an update of drilling operations on the basis of at least one property of the formation, the properties of the filtration cake of the drilling fluid or properties of the fluid samples were taken.

10. The method according to claim 1, wherein a set of processes that include at least the first script and the second script.

11. The method according to claim 10, in which the first script associated with at least one of the simulation the first performance of the first process sampling at the location of the sampler relatively close to the drilling bit, with the first configuration of the stabilizer, or after drilling, and a second script associated with at least one of the second simulation performance, the second is the process of sampling at the location of the sampler relatively far from the drill bit, with the second configuration of the stabilizer, after drilling or during lifting of the BHA from the wellbore.

12. The method according to claim 10, in which the first script associated with at least one of the simulation the first performance of the first sampling process using the first drilling fluid during drilling, with the use of statistics first flow rate of the drilling fluid or by using statistics of the flow rate of the fluid of the first sample, and a second script associated with at least one of the second simulation the performance of the second sampling process using the second mud, using the tool on wireline using statistics flow rate of the second mud or using statistics flow rate of a fluid environment second sample.

13. The method of controlling the sampling operation in the subterranean formation containing the following stages:
the formation testing intended for sampling;
measurement of the response of the reservoir to the test;
determination of parameters of the filtration cake of the drilling fluid and formation based on the response of the reservoir;
the processing parameters of the filtration cake of the drilling fluid and formation using spectrace the Sora simulation to generate output simulation;
the definition of the sampling parameters based on the output of the simulation; and
control the sampling operation in the underground formation on the basis of the sampling parameters.

14. The method according to item 13, containing the control sampling operation in the subterranean formation based on at least one of the parameters of the reservoir, at least one parameter of the pump and model of the instrument.

15. The method according to item 13, which additionally contains the definition of the degree of infiltration of mud filtrate into the formation, intended for sampling, and changing at least one of the flow rate of the drilling fluid or flow rate of the fluid sample based on the measured response of the reservoir.

16. The method according to item 13, in which the sampling parameters associated at least one of the quality of the fluid sample, the duration of the process of sampling, the performance of sampling or the cost of sampling, while the output of the simulation associated with at least one of the statistics filtration rate or volume of leachate on the surface of the wellbore.

17. The method according to item 13, which additionally contains the identification of the parameters associated with loose crust of mud with setprocessor simulation, and the parameters of the filtration cake of the drilling fluid connections is Ana, at least one of the weight of the cake of the drilling fluid, compression of the crust of mud, model sediments crust of mud, model erosion crust of mud, model the permeability of the cake of the drilling fluid or model desorption crust of mud.

18. The method according to item 13, which additionally contains the identification of the parameters associated with at least one of the downhole pressure, the degree of penetration of the mud filtrate or model instantaneous penetration, while the parameters are processed with the parameters of the filtration cake of the drilling fluid through setprocessor simulation to generate output data of the simulation.

19. The method according to item 13, additionally containing identification model of the hydraulic system of the wellbore that is designed to predict at least one of the velocity of the drilling fluid or pressure in the annular space, and the data associated with the model of the hydraulic system of the wellbore can be processed together with the parameters of the filtration cake of the drilling fluid through setprocessor simulation to generate output data of the simulation.

20. The method of controlling the operation of drilling a subterranean formation that contains the following stages:
the process of sampling from an underground formation;
change is giving the actual response of the reservoir to the sampling process;
calculation using setprocessor theoretical modeling of the reaction layer on the sampling process;
comparing the actual response with theoretical response;
adjusting at least one of the properties of the reservoir or the properties of the drilling fluid based on the comparison; and
management of the drilling operation based on at least one of corrected reservoir properties or adjusted properties of the drilling fluid to improve the sampling process.

21. The method according to claim 20, in which the control operation of the drilling contains control in real time at least one of the flow rate of the drilling fluid or movement of the BHA, and the management of drilling operations to improve the sampling process contains at least one of increasing the quality of the sample, reducing the time of sampling, performance sampling or decrease the value.

22. The method according to claim 20, additionally contains an update of setprocessor modeling on the basis of at least one of corrected reservoir properties or adjusted properties of the mud.

23. The method according to claim 20, in which the calculation of theoretical response of the reservoir contains the use, at least on the tion of the parameter of the reservoir, parameter sampling or drilling parameter.

24. The method of operation of the sampling while drilling, containing the following stages:
the planning of the sampling while drilling using a simulator that contains the definition of the parameters of drilling and sampling on the basis of the output of the simulator obtained before the operation of the sampling while drilling;
control in real time during the sampling operation of the sampling while drilling with the simulator by updating the input data of the simulator on the basis of data obtained during at least one of the sampling process or a drilling process that is performed during the operation of the sampling while drilling; and
management of real-time drilling process using a simulator to improve the sampling process by updating the input data of the simulator on the basis of data obtained during the sampling process or a drilling process.

25. The method according to paragraph 24, in which the management of real-time drilling process includes adjusting at least one of the speed of the drilling mud or the intensity of the pumping of the drilling fluid.



 

Same patents:

FIELD: machine building.

SUBSTANCE: device includes sampling tube mounted in pipeline perpendicular to flow movement and provided with slot-like inlet from side of flow movement. Slots in inlet are made horizontally along the height of pipeline and are directed toward liquid flow. Depth of slots changes from small near pipeline walls to largest near pipeline axis. Opposite to inlet in sampling tube there made is a vertical slot.

EFFECT: increasing sample uniformity and improving accuracy of sample composition determination.

4 dwg

FIELD: oil and gas industry.

SUBSTANCE: in addition, analysis of isotopic composition of carbon of sum of hydrocarbons C2-C6 is performed and limits of values of isotopic composition of carbon, methane and isotopic composition of carbon of sum of hydrocarbons C2-C6 for reference horizons are determined. Tables and/or graphs represent ranges of values of isotopic composition of gases from reference horizons and gases are represented from inter-string space of wells or drilling fluid; as per the degree of similarity or coincidence of the above ranges of those values (or individual points) there evaluated is nature of investigated inter-string gas shows.

EFFECT: improving reliability in determination of nature of inter-string gas shows.

1 ex, 2 tbl, 1 dwg

FIELD: oil and gas industry.

SUBSTANCE: method for assessing a gas-recovery ratio for the volume drained by at least one productive gas well comprises: calibration of the changes of an isotopic composition of at least one component of the natural gas recovered from the gas well with the gas-recovery ratio gain. Sampling of the natural gas recovered from the production well, and analysis of the sample for preparing the isotopic composition of the component of the natural gas. Use of the previous calibration and the specific isotopic composition for assessing the gas-recovery ratio for the volume drained by the gas well. Use of the assessed gas-recovery ratio and total volume of the natural gas produced from the gas well to determine the volume drained by the gas well.

EFFECT: amended assessment of the gas-recovery ratio which is based on the calibrated relation of the changes in the isotopic composition of one or more components of the produced gas and the gas-recovery ratio for the volume drained by the productive gas well.

3 dwg, 9 cl

FIELD: oil and gas industry.

SUBSTANCE: in process of sampling, values of specific electric conductivity are measured on liquid arriving into a sampling chamber. At the same time measured values of specific electric conductivity and readings of pressure and temperature sensors are recorded with a surface receiving-processing station, and to form a channel of communication with it and to provide for sampler lowering and lifting, an armoured geophysical cable is used, which is withdrawn from a drilling string via a sealing device. Besides, before opening of a potentially producing bed, the sampler at the vibration and impact safe distance from a bit is fixed on the cable in the above-packer space of the above-bit packering unit, providing for direct circulation of the mud. And after opening the sampling operation is carried out by means of multiple sampling and remote express-analysis of fluid composition in every sample according to specific electric conductivity, for this purpose the chamber by means of piston displacement is released from the first sample with fluid discharge into the above-packer space. Then it is put into the initial working condition, and similarly to the first sample taking, further sampling is carried out, until extremum of specific electric conductivity values is achieved, and on the basis of this parameter, a decision is made to lift the last sample from the well or to continue drilling process, and bed parameters are identified on the basis of pressure, temperature sensor readings, and by the value and speed of increments of specific electric conductivity.

EFFECT: increased efficiency of sampling of oil reservoirs opened with drilling, also in abnormal boreholes.

8 cl, 6 dwg

FIELD: oil and gas industry.

SUBSTANCE: method includes taking of a downhole sample by a sampler and its transportation to the surface. At that at the surface the sealed sampled chamber is set in different positions under vertical angles less than 180 degrees and measurements of the fluid are made by primary detectors installed inside the chamber on the surface of a dividing piston; then content of the downhole sample is analysed and calculated.

EFFECT: checkout of parameters for the total downhole sample, acquisition of reliable data on the fluid, creation of cost-effective control method.

7 dwg

FIELD: oil and gas industry.

SUBSTANCE: method and tool that implements the method involving the measurement of viscosities and flow rates of fluid media of the formation and obtainment of the ratio of relative permeabilities of formation fluid media and formation wetting ability using those viscosities and flow rates of the formation fluid media.

EFFECT: testing of bottom-hole formation for determination of relative permeability under bottom-hole conditions.

18 cl, 5 dwg

FIELD: oil and gas industry.

SUBSTANCE: invention relates to the method and system for obtaining characteristics of the composition gradients and fluid medium properties of the involved header, and analysis of the header properties based on such gradients.

EFFECT: improvement of the device.

20 cl, 3 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: invention relates to sampling of deep wells. Proposed device comprises suction-type sample intake chamber with separation piston, check valve and check valve seat, ballast chamber with pressure regulator, sample pressurisation mechanism with compressed gas chamber, pressurisation fluid chamber and pressurisation piston, control and data exchange module, sample input channel and valve. Said sample pressurisation mechanism is arranged between sample intake chamber and ballast chamber, and equipped with uncoupler with piston and holder. Note here that sample intake chamber is provided with extra moving piston with check valve.

EFFECT: simplified sample pressurisation mechanism.

6 dwg

Bed fluid sampler // 2465457

FIELD: oil and gas production.

SUBSTANCE: proposed sampler consists of fluid sampling system. Said system includes fluid sample taking and keeping valve, logical hydroelectric system for sampler locking and unlocking in well. Said system comprises motor connected to pump coupled with first distributor via first check valve, filter, safety valve and second distributor connected to tank, fluid sample taking and keeping valve, first, second and third pressure transducers. Note also that first distributor is connected to head ends of first, second and third hydraulic cylinders. Rod end of the latter are connected to third distributor connected with throttle and accumulator with fifth pressure transducer. In compliance with this invention, added fluid sampling rate control system comprises storage chamber connected with sixth check valve, fourth hydraulic cylinder via seventh check valve and proportional fluid flow rate regulator while sampling valve is connected with second, third, fourth, fifth and sixth check valves. Note also that fourth hydraulic cylinder, proportional flow rate regulator, fourth and fifth check valves are connected with the tank.

EFFECT: controlled fluid sampling rate, higher efficiency and quality.

1 dwg

FIELD: oil and gas industry.

SUBSTANCE: there created is a device and method of measuring the parameters characterising the rock bed in oil well with device for probe field generation in the rock bed zone and device that generates the flow through the zone in presence of probe field additionally including sensors sensitive to changes in the zone, note that sensor response indicates the values of fluid quantity and changes in hydrocarbons phases in the bed. The changes can be performed before the flow influences the measurement zone and after the flow appearance through the measurement zone.

EFFECT: advancement and improvement of devices and methods of defining the bed characteristics with the use of the flow created in the bed.

25 cl, 5 dwg

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: 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: oil industry.

SUBSTANCE: hollow body of device is actually a fragment of force pipeline at mostly vertical portion of mouth armature. Organ for controlling flow of multi-component gas-liquid substance is made in form of valve mounted on shaft having lesser size, than inner diameter of hollow body. Sample chamber is in form of ring-shaped hollow on hollow body, positioned at same level with valve. Ring-shaped hollow is connected at input to flow of multi-component gas-liquid substance through intake channels, positioned symmetrically to valve rotation axis, and at output - with locking organ. Driving screw mounted on body of locking organ is connected to sample-taking valve with possible mutual rotation and combined axial displacement. Sample-taking valve and shaft with valve are mated with possible synchronous rotation around common axis and relative axial displacement. Working organs of device are positioned immediately near main flow of substance taken as sample to provide for lesser dimensions of device and prevented freezing in winter season.

EFFECT: simplified construction, simplified maintenance.

7 dwg

FIELD: oil production industry, particularly methods or devices for cementing, for plugging holes, crevices, or the like.

SUBSTANCE: device comprises inflatable packers to be lowered into well along with flow string. One flow string end is closed to provide simultaneous well bore packing, another end is connected to production equipment. Flow string is provided with centralizers located near inflatable packers. Formed in flow string are additional holes located opposite to packers. Well pump is installed inside flow string. High-pressure water conduit having low diameter is connected to above holes. Flow string has perforated orifices created between inflatable packers.

EFFECT: extended operational capabilities.

1 dwg

Sampler // 2257471

FIELD: oil-field equipment, particularly for obtaining fluid samples or testing fluids in boreholes or wells and may be used for integrated obtaining sample of multicomponent liquid-gas systems transported through pipelines.

SUBSTANCE: sampler comprises hollow body installed in high-pressure pipeline of wellhead fittings and extraction chamber with discharge channels. Rotary tool adapted for multicomponent liquid-gas medium flow regulation is installed inside the body. Sampler also has shutoff member with actuated sample extracting valve, handle and guiding tube. Sampler comprises hollow body made as a part of high-pressure pipeline and tool adapted for multicomponent liquid-gas medium flow regulation arranged in hollow body. The tool consists of flap installed on a shaft and having diameter corresponding to inner hollow body diameter, extraction chamber used to extract and mix multicomponent liquid-gas medium flow formed as annular cavity around hollow body. The cavity is divided into inlet and outlet parts by partition arranged at flap level. Inlet and outlet parts communicate with common multicomponent liquid-gas medium flow correspondingly through inlet and outlet channels on hollow body and through opening formed in the partition at sample extracting valve inlet. Drive screw installed in shutoff member body is connected with sample extracting valve so that drive screw and sample extracting valve may perform mutual rotation and move in axial direction. Sample extracting valve and shaft with flap mate each other so that they may perform synchronous limited rotation about common axis and mutual axial movement.

EFFECT: increased simplicity, provision of high-quality mixing of sample product and increased sample reliability.

3 dwg

Sampling device // 2258807

FIELD: oil field equipment, particularly for take samples from wellhead, namely for integrated sampling multi-component gas-liquid medium transported through pipelines.

SUBSTANCE: device has hollow body built in pressure pipeline and formed as a part of the pipeline located on vertical part of wellhead fittings. Multi-component gas-liquid medium flow control unit is made as a gate connected to rotary support shaft. Sampling chamber is created as annular cavity arranged on hollow body at gate level. Sampling chamber inlet is communicated with multi-component gas-liquid medium flow through intake manifolds formed on hollow body. Intake manifolds are side slots arranged symmetrically about gate axis of rotation. Sampling chamber outlet is communicated with shutoff member installed on rotary gate support shaft extension. Shutoff member includes seat, hold-down screw and ball contacting with the seat and embedded in pressure screw end.

EFFECT: simplified structure and increased sampling quality.

2 dwg

FIELD: mining industry, particularly to take subsurface oil samples in running and exploratory wells working in flow mode.

SUBSTANCE: sampling device has tubular body with lock mechanism arranged inside the body and connected to controlling valve assembly from the first side and controllable valve assembly from the second side thereof. Joint relay is screwed on the controlling valve assembly. The controlling assembly is retained in its opened position by joint relay including body with orifices for pin receiving, pusher acting upon the controlling valve assembly and bush with fluid circulation orifices. Valve assemblies include all-rubber valves having 30° cone angles. The relay has barbs to engage with production string connector. When sampling device moves downwards the barbs are brought into folded state.

EFFECT: increased operational reliability and prevention of oil sample degassing due to improved air-tightness of sampling device interior.

2 cl, 1 dwg

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