MXPA99007196A - Measuring the pressure of formation during drilling using a non-rotate shirt - Google Patents

Abstract

The present invention relates to a tool inside the well and a method for collecting data from an underground formation during drilling operations. The tool includes a tubular mandrel adapted for axial connection in a drilling string positioned in a borehole penetrating the underground formation and a jacket or stabilizing element positioned around the tubular mandrel for relative rotation between the stabilizing element and the mandrel and mandrel tubular. A plurality of elongated ribs connected to the stabilizing element. A means connected to the stabilizing element for frictional contact with a wall of the borehole, to prevent the stabilizing element from rotating in relation to the wall of the borehole. The stabilizing element at least partially conveys the drive system and one of the elongated ribs carries a probe, the drive system adapts the probe to move between a retracted position inside the rib and an extended position making contact with the wall of the borehole so that the probe can gather training data. The method includes placing a non-rotating element of a tool positioned in a drill string in contact with a borehole wall, so that the non-rotating element does not move relative to the borehole wall. A probe transported by the non-rotating element moves to make sealed contact with the borehole wall and establish fluid communication between the formation and the non-rotating element, thus allowing to detect one or more properties of the formation fluid.

Description

MEASURING THE PRESSURE OF TRAINING DURING DRILLING USING A NON-ROTATING SHIRT RECIPROCAL REFERENCE TO RELATED APPLICATIONS This application claims priority to the U.S. Patent Applications Nos. 60 / 097,226 filed on August 20, 1998 and 60 / 095,252 filed on August 4, 1998.

BACKGROUND OF THE INVENTION FIELD OF THE INVENTION This invention is generally related to the determination of several parameters in an underground formation penetrated by a borehole while drilling it. More particularly, this invention relates to the determination of the parameters of the formation as the formation pressure, by the use of a non-rotating stabilizer of the drill string.

Description of the associated technology The operation and production of the current oil wells involve the continuous observation of several parameters of the underground formation. One aspect of the standard evaluation of the formation refers to reservoir pressure parameters and the permeability of the formation of the productive stratum. Continuous observation of parameters such as reservoir pressure and permeability indicates the change in formation pressure over a period of time and is essential to forecast the production capacity and life span of an underground formation. Current operations typically obtain these parameters through wired logs steel using a "training test" tool. This type of measurement requires an additional "trip"; In other words, remove the drill string from the well W probe, introduce a training test tool into the borehole to acquire the formation data and, after recovering the tool, reinsert the drill string into the well to continue drilling. So, it's typical that The parameters of the formation, including the pressure, are observed with steel cord forming test tools, such as those tools described in the patents numbers 3,934,468; 4,860,581; 4,893,505; 4,936,139 and 5,622,223 from the United States. Therefore, each of the aforementioned patents is limited by the fact that the training test tools described here can only acquire training data while they are in the borehole and in physical contact with the area of interest of the training. Because "inbound and outbound trips" to use such training test tools consume significant amounts of expensive drilling equipment time, typically it is done under circumstances when it is absolutely necessary to obtain the data from the formation or when the drill string has been removed from the well to change an auger or for some other reason. The availability of data from reservoir formations in "real time" during well drilling activities is of great value. The pressure of the real-time training obtained while drilling will be useful for a drilling engineer or driller to make decisions regarding changes in the weight and composition of the drilling mud and also the penetration parameters with more anticipation, thus promoting the aspects of drilling safety It is also convenient to have the formation data of the deposit in real time to allow to control with precision the weight of the drill bit in relation to the changes of pressure and changes of permeability of the formation, so that the drilling operation can performed with maximum efficiency. Therefore, it is convenient to provide a method and apparatus for drilling the well that allows the acquisition of various formation data from an underground area of interest while the drill string with its lastrabarrenas, drilling bit and other drilling components are present within the borehole, thus eliminating or minimizing the need to introduce and remove drilling equipment for the sole purpose of introducing well formation test tools and identifying these parameters Of the information. To consider these disadvantages, the main purpose of this invention is to use at least one of the components of the drill string to obtain said formation parameter data. More particularly, one purpose of this invention is to use a non-rotating stabilizing tool on the drill string to make contact with the formation and gather information about it.

COMPENDIUM OF THE INVENTION.

The purposes described above, in addition to several additional purposes and advantages, are achieved with the tool inside the well to collect data from an underground formation, including a tubular mandrel adapted for axial connection in a drill string located in a well sound penetrating the underground formation and a stabilizing element positioned around the tubular mandrel so that there is a relative rotation between the stabilizing element and the tubular mandrel. A plurality of elongated ribs are connected to the stabilizing element. A means is connected to the stabilizing element to make fi ctional contact with the wall of the borehole and to prevent the stabilizing element from rotating in relation to the wall of the borehole. He The stabilizer element at least partially conveys the actuator system and at least one of the elongated ribs carries a probe; the drive system adapts the probe to move between a retracted position within the rib and an extended position making contact with the wall of the borehole so that the probe 15 can collect data from the formation. The elongated ribs are preferably spaced radially and oriented either axially or helically along the stabilizing element. The frictional contacting means may be provided in the form of several structures, including the plurality of elongated ribs, a plurality of stabilizing vanes or some combination of both. When the stabilizing blades are selected to make fi ctional contact with the probing well, it is preferred that each of the blades be positioned between two of the elongated ribs. The frictional contact means may also include a spring system for urging the fixture contact means to make contact with the wall of the borehole and to prevent rotation of the frictional contact means relative to the well wall. It is preferred that the spring system includes a plurality of arched spring vanes, each having an inherent spring stiffness. The probe includes in a preferred embodiment a flexible obturator positioned in a substantially cylindrical opening in one of the ribs of the stabilizing element. The shutter has a central opening there. A conduit with an open end is positioned to communicate the fluid with the central opening in the obturator. A filter valve is installed in the central opening of the shutter around the open end of the duct and the filter valve can be moved between a first position closing the open end of the duct and a second position allowing the flow of filtered fluid from the formation between the training and the conduit. The drive system includes in a preferred embodiment a hydraulic fluid system and a means for selectively pressurizing the hydraulic fluid in the hydraulic fluid system. An expandable container is installed so that it communicates with the hydraulic fluid system and the container expands with the pressure increase in the hydraulic fluid and contracts with the pressure drop in the hydraulic fluid. Preferably, the container is a bellows connected to the probe plug, so that the expansion of the bellows as the pressure in the hydraulic fluid increases moves the plug to make sealed contact with the wall of the borehole. In addition, the drive system includes in a preferred embodiment a sequence valve that operates upon detecting a predetermined pressure in the hydraulic fluid produced by the maximum expansion of the container, to move the filter valve of the probe to the second position where the fluid in the formation it can flow to the open end of the duct. It is also preferred that the tool inside the well of this invention includes a sensor placed in fluid communication with the probe conduit to measure a property of the formation fluid. In a preferred representation, the sensor is a pressure sensor adapted to detect the fluid pressure of the formation. This invention includes, in another aspect, a method for measuring a property of the fluid present in an underground formation. The method includes the positioning of a drill string in a borehole that penetrates the underground formation. A non-rotating element of a tool positioned in the drill string is placed in contact with a wall of the borehole, so that the non-rotating element does not move relative to the well wall. A probe conveyed by the non-rotating element moves and makes sealed contact with the well wall to establish fluid communication between the formation and the non-rotating element.

In a preferred embodiment, formation fluid is introduced to a sensor, such as a pressure sensor, carried by the tool inside the well to detect a property of the formation. Said fluid movement is achieved by means of the probe, which is adapted to move by a drive system between a retracted position within the non-rotating element and an extended position making contact with the well wall, so that the probe gathers data from the well. the formation.

BRIEF DESCRIPTION OF (OF THE) DRAWING (S) In order that the manner in which the features, advantages and purposes of this invention may be understood in detail, a more particular description of the invention, briefly summarized above, may be obtained by reference to the preferred representations thereof which are illustrated in the attached drawings. However, it should be noted that the accompanying drawings only illustrate typical representations of this invention and that therefore they should not be considered as limiting their scope, since the invention can be applied to other equally effective representations. In the drawings: Figure 1 is an elevational view, partly in section and partly in block diagram, of a drilling rig and drill string using this invention; Figure 2 is a sectional view of a non-rotating stabilizer, according to a representation of this invention, equipped with elongated ribs with sets of probes therein; Figure 3 is a perspective view of a non-rotating jacket of a stabilizer, according to another embodiment of this invention, equipped with elongated ribs and stabilizing vanes; Figure 4 is a plan view, taken in section, of the non-rotating stabilizer of Figure 2; Figure 5 is a perspective view, partly in section, of one of the elongated ribs of Figure 4; illustrating in particular the use of multiple probes on the elongated rib; Figure 6 is a schematic fluid flow diagram illustrating the movement of fluid from the formation through the non-rotating stabilizer to detect one or more properties of the fluid, such as pressure; Figure 7 is a sectional view of one of the probes in a retracted position within an elongated rib of the non-rotating stabilizer; Figure 8 is a sectional view of the probe of Figure 6 in extended position and making contact with the wall of the borehole; and Figure 9 is a schematic diagram of the non-rotating stabilizer with block representations for the power generation and data communication components.

DESCRIPTION OF THE PREFERRED REPRESENTATIONS Figure 1 illustrates a conventional drilling rig and drill string that can take advantage of the use of this invention. The platform assembly and ground tower 10 is placed over the borehole 11 and penetrates the underground formation F. In the illustrated representation, the borehole 11 is drilled by rotary drilling in a known manner. However, those of ordinary skill in the industry, given the benefit of this disclosure, will recognize that this invention also has application in directional drilling in addition to rotary drilling and that it is not limited to ground drilling equipment. The drill string 12 is suspended within the borehole li and includes the drill bit 15 at its lower end. The rotary table 16, driven by a means not shown, rotates the drill string 12 which contacts the kelly gasket 17 at the upper end of the drill string. The drill string 12 is suspended from the hook 18, connected to a traveling block (which is also not shown), by means of the kelly seal 17 and the rotating coupler 19 that allows the rotation of the drill string in relation to the hook. Drilling fluid or mud 26 is stored in pit 27 formed at the well site. The pump 29 delivers fluid 26 to the interior of the drill string 12 through a hole in the coupler 19, inducing the flow of the drilling fluid down the drill string 12, as indicated by the directional arrow 9. The drilling fluid exits the drill string 12 through the holes in the auger 15 and then flows upwards through the region between the outside of the drill string and the wall of the well, called the annular space, as indicated by the directional arrows 32. In this way, the drilling fluid lubricates the auger 15 and carries the shavings to the surface when it returns to pit 27 for recirculation.

In addition, the drill string 12 includes a downhole assembly that is designated 100, near the drill bit 15 (in other words, at a distance of several lengths from the bit's drill bit). The bottom of the well includes the ability to measure, process and store information, in addition to communicating with the surface. Therefore, the bottom of the well 100 assembly includes, inter alia, a local measurement and communication apparatus 200 for determining and communicating the resistivity of the formation F surrounding the borehole 11. The communications apparatus 200, inclusive the transmitting antenna 205 and the receiving antenna 207, is described in detail in Patent No. 5,339,037 of the United States, commonly assigned to the assigned of this application, the total content of which is incorporated by reference to this document. In addition, the assembly 100 includes the lasbar 130 for performing various other measurement functions and the subset of communications with the surface / locations 150. The subset 150 includes the toroidal antenna 250 used for local communications with the apparatus 200 and a known type of system of acoustic communication that communicates with a similar system (not shown) on the earth's surface by means of signals transported in the fluid or drilling mud. Thus, the communication system with the surface in the subassembly 150 includes an acoustic transmitter that produces an acoustic signal in the drilling fluid that is representative of the parameters measured inside the well. A suitable type of acoustic transmitter employs a device known as a "mud siren" that includes a slotted stator and a slotted rotor that repeatedly rotate and interrupt the flow of drilling fluid to establish a desired sound wave signal in the drilling fluid. The excitation electronics in the subcoole 150 could include a suitable modulator, such as a phase shift manipulation modulator (PSK), which conventionally produces excitation signals for application to the mud transmitter. Those excitation signals can be used to apply the appropriate modulation to the mud siren. The transducers on the surface represented by the reference number 31 receive the generated acoustic wave. Transducers, for example piezoelectric transducers, convert the received acoustic signals to electronic signals. The output of the transducers 31 is coupled to the uphole receiving subsystem 90, which demodulates the transmitted signals. Then, the output of the receiver system 90 is coupled to the processor 85 and the recorder 45. W A well up transmission system 95 is also provided and operates to control the interruption of the operation of the pump 29 in a detectable manner by the transducers 99 in the subset 150. In this way, there is communication bidirectional between the subco? Together 150 and the team well up. The subset 150 is described in greater detail in Patent No. 5,235,285 from the United States, whose full content is incorporated by reference to this document. Those with experience in the industry will recognize that the acoustic alternative, in addition to other techniques, can be used for communication with the surface. Furthermore, in the representation of Figure 1 the drill string 12 is equipped with a stabilizer collar 300. Said stabilizing collars are used to correct the tendency of the drill string to "wobble" and to decenter when it rotates inside the well. probing, producing deviations in the predicted direction of the borehole (for example, a vertical straight line). This deviation can produce excessive lateral forces on the sections of the drill string and the drill bit, producing accelerated wear. This can be corrected by providing a means to centralize the bit and, to some extent, the drill string, into the well. Examples of centering tools known in the industry include tube guards and other tools. In addition to the stabilizers. Now I know will describe a particular representation of this invention as a function of a non-rotary drill string stabilizer.

In addition to Figure 1, Figures 2 and 4 illustrate a preferred representation of a tool for the interior of the well in accordance with this invention for gathering data from an underground formation. The tool for the interior of the well is provided as a non-rotating stabilizer 300 with a tubular mandrel 302 adapted for axial connection to the drill string 12. Thus, the mandrel 302 could be equipped with male and female ends 304, 306 for connecting it in conventional way inside the drill string. As shown in Figure 2, the ends 304, 306 can be specially designed collars that are connected to the central elongated portion of the mandrel 302, in a conventional manner, such as a threaded connection and / or welding. In addition, the stabilizer 300 includes a non-rotating stabilizing element or sleeve 308 positioned around the tubular mandrel 302 between the ends 304 and 306 in such a manner as to allow relative rotation between the stabilizing element and the tubular mandrel. The thrust bearings 310, 312 are provided to reduce the frictional forces and support the axial loads developed at the axial interface between the sleeve 308 and the ends 304 and 306 of the mandrel. Rotary seals are also provided 348 and the radial bearings 346 at the radial interface between the mandrel 302 and the sleeve 308.

A plurality of elongated ribs 314 are connected by welding or bolting to the outer surface of the stabilizer jacket 308. Preferably, the elongated ribs are radially spaced and oriented in either the axial direction, as indicated in Figs. 1, 2 and 4, or helical (not shown) along the non-rotating stabilizing jacket. It is currently preferred that the non-rotating jacket include three of said ribs 314 spaced 120 ° around the circumference of the sleeve, as indicated in Figure 4. However, this invention is not limited to a representation of three ribs and can advantageously used with other arrangements of the elongated ribs. The purpose of the multiple ribs is to increase the possibility of obtaining an appropriate seal with the borehole wall, as will be explained below. A means is connected to the stabilizer jacket 308 for frictional contact with a wall of the borehole 11, to prevent the stabilizer jacket from rotating in relation to the wall of the borehole. The frictional contacting means may be provided in the form of several structures, including the plurality of elongated ribs 314 or as a plurality of stabilizing vanes 316. Figure 3 illustrates an alternate representation including both elongated ribs 314 and stabilizing vanes 316, with the pallets providing at least a substantial part of the frictional contact required ^ fc to prevent the stabilizing element or the sleeve 308 from rotating in relation to the wall of the well. If the stabilizer blades are selected, it is preferred that each of the blades 316 is positioned between two of the elongate ribs 314, as seen in Figure 3. Further, the frictional contacting means could include a spring system for urging the frictional contacting means to make contact with the borehole wall and create a greater force of f iction to resist the rotation of the sleeve 308 in relation to the wall of the well. In the representation of Figure 3, said spring system is provided by selecting a plurality of arched spring vanes 316, each f having an inherent spring stiffness. However, those with experience in the industry, given the benefit of this disclosure, will recognize that a spring system could be provided by the elongate ribs 314, as in FIG.

It is further recognized that various other means for inducing fi nal contact between the stabilizer jacket 308 and the borehole 11, including, for example, hydraulic actuating assemblies for moving, can be used. the elongated ribs / vanes and / or several stabilizer piston assemblies (not shown) or radially outwardly so as to induce firm contact with the borehole wall and prevent rotation between the element 308 and the borehole wall . A probe drive system, generally designated 318, is at least partially conveyed by a non-rotating stabilizer jacket 308 and is shown in Figures 2 and 6. In a currently preferred embodiment, each of The elongated ribs 314 carries three probes 320 and the drive system 318 adapts them to move between a retracted position within the rib, as shown in Figure 7, and an extended position making contact with the wall of the well. so that the probe gathers information from the formation, as shown in Figures 2 and 8. In a preferred embodiment, each probe includes a flexible annular obturator. 322 positioned in a substantially cylindrical cavity or opening 324 extending through one of the elongated ribs 314, as indicated in Figure 2. Each plug 322 is recessed, in the retracted position of the probe, within an opening or recess 324 in the rib 314, as shown in Figure 7, so that the plug (typically made of a flexible material such as vulcanized rubber) is not damaged by the abrasive forces applied to the stabilizer 300 during the drilling operations. . The conduit 326 with an open end or nozzle 328 is connected to a central opening in the plug to allow fluid communication. The filter valve 330 is also positioned in the central opening of the shutter 322 near the open end 328 of the conduit 326. The valve moves between a first position that closes the open end of the duct, as shown in Figure 7, and a second position that allows the flow of filtered fluid from the formation between the? formation and the conduit, as shown in Figures 2 and 8. Referring again to Figures 2 and 6, the drive system 318 also includes a hydraulic fluid system containing a fluid reservoir hydraulic, 332 a hydraulic fluid pump 334 and a hydraulic fluid flow line 336 to selectively pressurize the hydraulic fluid in the hydraulic fluid system. An expandable container, more particularly a flexible metal bellows 340, within each cylindrical opening 324, is connected to the hydraulic fluid system by the flow line 338 (see Figure 2) which is derived from the flow line 336 »20 to allow fluid communication. It is preferred that each of the probes 320 located on an individual elongated rib 314 is connected to a common reservoir 332. In a particular embodiment, each of the probes located on all the ribs 314 are connected in common form to the same fluid reservoir hydraulic. The bellows 340 expands in a conventional manner with the increase in pressure in the hydraulic fluid and contracts in a similar way with the decrease in pressure in the hydraulic fluid. The bellows 340 is connected to the plug 322, so that expansion of the bellows with the increase in pressure in the hydraulic fluid moves the plug to make sealed contact with the wall of the borehole, as indicated in FIG. 8. A comparison of Figures 7 and 8 indicates that each probe 320 has a stroke of short piston produced by the expansion / contraction of the bellows 340. The transfer of electrical energy to a non-rotating stabilizer 300 can be achieved in various ways. One option (not shown) involves embedding permanent magnets into a cylindrical arrangement within the mandrel around its circumference and embedding an annular conduction coil into the non-rotating sleeve around the magnets. Thus, the rotation of the mandrel in relation to the The non-rotating jacket will produce an alternating current within the coil that can be converted to direct current to be used appropriately in the stabilizer 300. Another option for transmitting energy to the non-rotating stabilizer 300 is presented schematically in Figure 9 where a part of the fluid or drilling mud deviates from the center of the mandrel 302 in a detour loop 350 equipped with rotary seals 352. The drilling mud in the deflection loop is conducted through a small turbine 354 located in the non-rotating jacket 308. The activation pump 334 initiates a sequence of "adjustment" of the probes with the energy produced by the turbine 354 to increase the pressure of the hydraulic fluid in the tank 332. A conventional control system (not shown) that regulates either electric power or direct torsion applied to the pump, selectively activates the pump 334. The pressure increase in the tank 332 increases the fluid pressure in the flow line 336 and forces each probe 320 connected to the flow line causing it to come out of its opening or cavity 324. Because the elongate ribs 314 are typically making contact with the wall of the borehole during standard drilling operations, a very small stroke of the piston is required to establish a seal between the bores. shutters 322 of the probes 320 and the wall of the borehole 12. The bellows 340 is also designed to allow sufficient freedom and articulation of movement to accommodate the settings of the obturator 322 to the local irregularities of the borehole 25 In a preferred embodiment , the drive system 318 further includes a sequence valve 342 for each probe 320. The sequence valve is co nectad to the flow line 338, as shown in Figure 2, and operates upon detecting a predetermined pressure in the hydraulic fluid produced by the maximum expansion of each of the bellows 340. Upon detecting said predetermined pressure, each sequence valve 342 is opened, releasing hydraulic fluid to pressurize the region of the cylindrical opening 324 under the filter valve 330 and bounded by the bellows 340 to move the filter valve to the second (upper) position so that the fluid in the formation can flow towards the open end 32§ of the duct 326. As a result, a small extraction of fluid from the formation in each probe is initiated. The sensor 344 is connected to the probe conduit to communicate the fluid and measure a property of the formation fluid passing through the conduit 326. In a preferred embodiment, the sensor 344 is a pressure sensor adapted to detect fluid pressure. of the formation, such as a strain gauge, Meters meter, or crystal gauge. The sensor 344 allows the ability to detect and record pressure data and transmit signals representative of said pressure data via an electronic packet 356 to the receiver circuit within a data receiver, such as within the subset 150 described above, to continue the transmission by drill string 12 in a manner known in the industry. Thus, bidirectional communication can be ensured by a known electromagnetic transceiver system, as described in Patent No. 5,235,285 from the United States. In this regard it will be recognized that the sensor electronics 356 can be designed to communicate with a transceiver within the mandrel 302 in addition to a transceiver above or below a non-rotating stabilizer 300. Although the sensor 344 is described here for use with pressure data only , the present invention also contemplates the use of sensors and related electronics that are adapted to detect, record and transmit data representative of other parameters of the formation, such as temperature and fluid composition. These sensors only need to contact the formation fluid at some point in the fluid flow line 326, such as in a measurement junction that allows the sensor to acquire the desired parameter data of the formation. The hydrostatic pressure of the annular space of the borehole is measured (with other known means) and compared to the respective pressure values obtained from the various probes 320 and sensors 344. Despite the extraction, a probe with a defective seal will continue observing the hydrostatic pressure in the annular space of the borehole. Therefore, the pressure measurement of said probe would not be taken into consideration. Then the weighted average of all "correct" pressures is calculated as the pressure of the formation in the vicinity of the stabilizer 300. Upon completion of the pressure test (or test of another parameter), a "refolding" cycle is initiated by pumping hydraulic fluid back to tank 332 with pump 334. This reduces the pressure in the flow line 336 and the probes 320 retract back into the openings or cavities 324 of their respective ribs. The sequence ends when the sequence valves 342 close and relative movement between the filter valve 330 and the nozzle of the conduit 328 pushes the formation fluid remaining in the flow line back to the borehole.

One of the advantages offered by this invention is the result of the fact that during In a drilling operation, the orientation of a particular elongate rib 314 with respect to the borehole at any given time is not known, nor can f be adjusted to satisfactory accuracy. Therefore, the resulting position of a single seal and probe could be at an angle unfavorable to the borehole wall, preventing an appropriate seal from being obtained and reducing the possibility of performing a successful pressure test or other type of data acquisition. The placement of a plurality of probes on a non-rotating stabilizing rib and the use of a plurality of said non-rotating ribs, ensures a redundancy and increases the possibility that at least one of the probes is correctly sealed and allows a test of successful pressure (or allow acquisition of other training data). Using two, three or even four probes adjacent one to another by elongated rib 314, the coverage of the wall surface of the investigated wellbore expands. Thus, the possibility of obtaining a good contact is further increased. Individuals who have the benefit of having this disclosure will recognize that this invention offers a new option for acquiring training data during drilling operations. As part of the measurement system during drilling / recording during drilling (MWD / LWD), this invention can be used with various types of tools and nuclear, resistivity and acoustic measurements, among others. A current preferred embodiment, as described above, can be used to advantage in drilling forming pressure applications (FPWD). Compared to the known MWD / LWD tools, a non-rotating stabilizer according to this invention offers a relatively impact and vibration free environment for detecting parameters of a formation. Whichever is the total drilling operation, said non-rotating stabilizer will typically experience mainly lateral sliding movements along its longitudinal axis. This fact is favorable for several measurements that depend on fragile components or that require no rotation during data acquisition. This invention can also be adapted to obtain fluid samples from the formation when it is connected to sample chambers such as those described in patents N °. 4,860,581 and 4,936,139. Said sample chambers could be positioned within the non-rotating sleeve 308 and connected to the flow line 326 by the isolation valve 360, the bus of the flow line 364 and the main isolation valve 362, as shown in FIG. Figure 6. Because said non-rotating jacket will withstand minor abrasive forces during drilling operations, only a little additional protection would be required for said sample chambers. In view of the foregoing, it is evident that this invention is well adapted to meet all the objects, advantages and characteristics set forth above, together with other objectives, advantages and features that are inherent in the apparatus disclosed herein. As will be immediately apparent to those with experience in the industry, this invention can easily be produced in other specific ways without deviating from its spirit or essential characteristics. Therefore, the representations herein disclosed should be considered merely as illustrative and not restrictive. The scope of the invention is indicated in the claims presented below, rather than in the foregoing description, and, therefore, all the changes included in the meaning and equivalence margin of the claims are supposed to be considered in the same.

Claims (23)

1. CLAIMS: 1. A tool inside the well to collect data from an underground formation, which consists of: a tubular mandrel adapted for an axial connection in a drilling string positioned in a borehole that penetrates the underground formation; a stabilizing element positioned around the tubular mandrel for relative rotation between the stabilizing element and the tubular mandrel; a plurality of elongated ribs connected to the stabilizing element; a means connected to the stabilizing element for fi ctional contact with a wall of the borehole, where said frictional contact prevents the stabilizing element from rotating in relation to the wall of the borehole; a drive system at least partially transported by the stabilizing element; and a probe carried by one of the elongated ribs and which the drive system adapts to move between a retracted position within the rib and an extended position making contact with the wall of the borehole so that the probe gathers data from the training. The tool inside the well of claim 1, wherein the elongated ribs are spaced radially and axially oriented along the stabilizing element. 3. The tool inside the well of claim 1, wherein the elongated ribs are spaced radially and oriented in a helical direction along the stabilizing element. 4. The tool inside the well of claim 1, wherein the frictional contact means includes the plurality of elongated ribs. 5. The tool inside the well of claim 1, wherein the frictional contacting means includes a plurality of stabilizing blades, each of which is positioned between two of the elongate ribs. 6. The tool inside the well of claim 1, wherein the fi xional contact means includes a spring system which urges the frictional contact means to make contact with the borehole wall to prevent rotation of the contact means. frictional in relation to the wall of the well. 7. The tool inside the well of claim 6, wherein the spring system includes a plurality of arched spring vanes, each with an inherent spring stiffness. 8. The tool inside the well of claim 1, wherein the probe includes a flexible obturator positioned in a substantially cylindrical opening in one of the ribs of the stabilizing element and having a central opening in said position; a conduit with an open end positioned to communicate the fluid with the central opening in the obturator; and a filter valve installed in the central opening of the shutter around the open end of the duct, where the filter valve can be moved between a first position closing the open end of the duct and a second position allowing the flow of filtered fluid from the duct. the training between the training and the conduit. 9. The tool inside the well of claim 1, wherein the drive system includes a hydraulic fluid system; ~ 20 means for selectively pressurizing the hydraulic fluid in the hydraulic fluid system; An expandable container that is installed so as to communicate with the hydraulic fluid system, where said container expands with the increase in pressure in the hydraulic fluid and contracts with the decrease in pressure in the hydraulic fluid. 10. The tool inside the well of claim 8, wherein the drive system includes a hydraulic fluid system; 30 a means for selectively pressurizing the hydraulic fluid in the hydraulic fluid system; an expandable bellows connected to the hydraulic fluid system to communicate the fluid and connected to the shutter, where the bellows expands with the pressure increase in the hydraulic fluid to move the obturator so that it makes sealed contact with the borehole wall . 11. The tool inside the well of claim 10, wherein further, the drive system includes a sequence valve that operates upon detecting a predetermined pressure in the hydraulic fluid produced by the maximum expansion of the bellows to move the filter valve to the second one. position where the fluid in the formation can flow to the open end of the conduit. 12. The tool inside the well of claim 8, further comprising a sensor connected to the conduit for communicating with the fluid and measuring a property of the formation fluid. 13. The tool inside the well of claim 12, wherein the sensor is a pressure sensor adapted to detect the fluid pressure of the formation. 14. The tool inside the well of claim 1, wherein said tool is a non-rotating stabilizer. 15. A tool inside the well to collect data from an underground formation, which consists of: a tubular mandrel adapted for an axial connection in a drilling string positioned in a borehole that penetrates an underground formation; a stabilizing element positioned around the tubular mandrel for relative rotation between the stabilizing element and the tubular mandrel; a plurality of elongated ribs connected to the stabilizing element for frictional contact with a wall of the borehole, where said frictional contact prevents the stabilizing element from rotating in relation to the wall of the borehole; a drive system at least partially transported by the stabilizing element; and a probe carried by one of the elongated ribs and which the drive system adapts to move between a retracted position within the rib and an extended position making contact with the wall of the borehole so that the probe gathers data from the training. 16. A tool inside the well to collect data from an underground formation, which consists of: a tubular mandrel adapted for an axial connection in a drilling string positioned in a borehole that penetrates an underground formation; a stabilizing element positioned around the tubular mandrel for relative rotation between the stabilizing element and the tubular mandrel; a plurality of elongate ribs connected to the stabilizing element, with the ribs spaced radially from one another; a plurality of stabilizing vanes connected to the stabilizing element for frictional contact with a wall of the borehole, where said fi ctional contact prevents the stabilizing element from rotating in relation to the wall of the borehole; a drive system at least partially transported by the stabilizing element; and a probe carried by one of the elongated ribs and which the drive system adapts to move between a retracted position within the rib and an extended position making contact with the wall of the borehole so that the probe gathers data from the training. 17. The tool inside the well of claim 16, wherein each of the stabilizing vanes is positioned between two of the elongate ribs. 18. The tool inside the well of claim 16, wherein each of the stabilizing vanes includes an arcuate spring having an inherent spring stiffness for urging the stabilizing vane to make frictional contact with the borehole wall. 19. A method to measure a property of the fluid present in an underground formation, which consists of: positioning a drilling string in a borehole that penetrates the underground formation; placing a non-rotating element of a tool positioned in the drill string in contact with a wall of the borehole, so that the non-rotating element does not move relative to the wall of the well; and moving a probe carried by the non-rotating element to make sealed contact with the well wall to establish fluid communication between the formation and the non-rotating element. 20. The method of claim 19, which further introduces formation fluid to a sensor carried by the tool inside the well to detect a property of the formation. 21. The method of claim 20, wherein the sensor is a pressure sensor adapted to detect the fluid pressure of the formation. 22. The method of claim 21, wherein the probe is adapted to move through a drive system between a retracted position within the non-rotating element and an extended position making contact with the well wall, so that the probe gathers data from the formation . 23. The method of claim 22, wherein the probe includes a flexible obturator positioned in a substantially cylindrical opening in the non-rotating element, wherein the obturator has a central opening in said position; a duct with an open end positioned to communicate the fluid with the central opening in the obturator; and a filter valve installed in the central opening of the shutter around the open end of the duct, where the filter valve can move between a first position closing the open end of the duct and a second position allowing the flow of filtered fluid from the duct. training between the training and the conduit.