• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    analysis and generation of small core in drill as lwd tool. the present description concerns an apparatus for taking a sample from a well during drilling operations. the apparatus may include a drill bit configured to form a core and at least one retractable cutter internal to the drill bit for drawing the sample from the core. the apparatus may also include equipment for sample analysis, extracting fluid from the sample, testing fluid from the sample, encapsulating the sample, and / or marking the sample. the present description also relates to a method for taking a core sample without interrupting drilling operations. the method includes taking a core sample using a drill bit configured to take a core sample using internal cutters. The method may also include analyzing the sample, extracting fluid from the sample, analyzing sample fluid, encapsulating the sample and / or marking the sample.
    公开号:BR112013001309B1
    申请号:R112013001309-5
    申请日:2011-04-29
    公开日:2020-05-26
    发明作者:Sunil Kumar
    申请人:Baker Hughes Incorporated；
    IPC主号:
    专利说明:

    APPARATUS TO FORM A TESTIMONY SAMPLE IN A WELL AND METHOD OF OBTAINING THE SAMPLE
    FIELD OF DISSEMINATION
    [001] This disclosure generally refers to the testing and sampling of underground formations or reservoirs. More specifically, this disclosure relates to the preparation of a core sample without interrupting drilling operations, and, in particular, processing of the core sample for fluid analysis using extraction and / or encapsulation methods and apparatus.
    BACKGROUND OF THE DISCLOSURE
    [002] Hydrocarbons, such as oil and gas, often reside in porous underground geological formations. Often, it can be advantageous to use a ginning tool to obtain representative rock samples taken from the well hole wall intersecting a formation of interest. Rock samples obtained through vertical and lateral wall ginning are generally referred to as core samples. Analysis and study of core samples allow engineers and geologists to evaluate important formation parameters such as the storage capacity of the reservoir (porosity), the flow potential (permeability) of the rock that constitutes the formation, the composition of recoverable or mineral hydrocarbons that reside in the formation, and the irreducible water saturation level of the rock. These estimates are crucial for the subsequent design and implementation of the well finishing program that allows for the production of selected formations and zones that are determined to be economically attractive based on the data obtained from
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    2/22 of the core sample
    [003] Ginning typically requires drilling to be stopped after a core sample is formed, so that the core sample can be brought to the surface. Core samples are generally tested after being brought to the surface, however, moving to the surface can cause contamination or damage to the core samples as they travel to the surface. Drilling stoppage takes time and effort that could be reduced if drilling could continue while core samples were being taken. It would be advantageous to perform continuous drilling while ginning. It would also be advantageous to carry out tests on core samples in situ without the need to move to the surface or to protect core samples from encountering harmful objects and contaminating fluids while traveling to the surface. The present disclosure provides apparatus and methods for preparing core samples for in situ analysis and / or protecting core samples for displacement to the surface while drilling continues without interruption.
    SUMMARY OF THE DISCLOSURE
    [004] In aspects, this description generally refers to the testing and sampling of underground formations or reservoirs. More specifically, this disclosure refers to the preparation of a core sample without interrupting drilling operations, and, in particular, processing the core sample for fluid analysis using extraction and / or extraction methods and apparatus.
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    3/22 encapsulation.
    [005] An embodiment according to the present description can include an apparatus for forming a sample in a well hole, comprising: a drill bit configured to form a core and at least one retractable cutter internal to the drill bit, configured to cut the sample from the core.
    [006] Another embodiment according to the present description may include an apparatus for encapsulating a sample in a well bore, comprising: a drill bit configured to form a core, a chamber configured to receive the sample from the core, and an encapsulator operatively coupled to the chamber and configured to at least partially encapsulate at least part of the sample in an encapsulating material.
    [007] Another embodiment according to the present description can include a method of obtaining a sample in a well hole, comprising: using a drill bit transported to the well to form a core, and using at least one cutter retractable internal to the drill bit to cut the sample from the core.
    [008] Another embodiment according to the present description may include a method for encapsulating a sample in a well hole, comprising: using a drill in the well hole to form a core, using a retractable cutter internal to the drill bit. perforation to cut a sample from the core and transport the sample to a receiving chamber, and use of an encapsulator operatively coupled to the receiving chamber
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    4/22 to at least partially encapsulate at least part of the sample in an encapsulating material.
    [009] Examples of the most important characteristics of the disclosure have been summarized rather than widely so that the detailed description of them that follows can be better understood and so that the contributions they represent to the art can be appreciated.
    BRIEF DESCRIPTION OF THE DRAWINGS
    [010] For a detailed understanding of this disclosure, reference should be made to the following detailed description of the modalities, taken in conjunction with the attached drawings, in which similar elements have been presented similar numbers, in which:
    [011] Figure 1 shows a schematic diagram of a drill bit implanted in a drill hole along one according to one embodiment of the present description;
    [012] Figure 2 shows a schematic diagram of a drill bit configured to test core sample fluids according to an embodiment of the present description;
    [013] Figure 3 shows a schematic diagram of another drill bit configured to test core sample fluids according to an embodiment of the present description;
    [014] Figure 4 shows a schematic diagram of a drill bit configured to test a core sample according to an embodiment of the present description;
    [015] Figure 5 shows a schematic diagram of a
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    5/22 drill bit configured to protect a core sample according to an embodiment of the present description;
    [016] Figure 6 shows a schematic diagram of a drill bit configured to protect and store a core sample according to an embodiment of the present description;
    [017] Figure 7A shows a schematic diagram of a drill bit configured to cut a core sample according to an embodiment of the present description;
    [018] Figure 7B shows a schematic diagram of a drill bit configured to cut multiple core samples according to an embodiment of the present description;
    [019] Figure 8 shows a flowchart of a method for analyzing a fluid from an in situ core sample according to an embodiment of the present description;
    [020] Figure 9 shows a flow chart of a method for protecting a core sample for transport in accordance with an embodiment of the present description; and
    [021] Figure 10 shows a schematic diagram of a drill bit configured to pressurize a core sample according to an embodiment of the present description.
    DETAILED DESCRIPTION
    [022] This disclosure generally refers to the testing and sampling of underground formations or reservoirs. In one aspect, this disclosure relates to the preparation of a testimony sample without interrupting
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    6/22 drilling, and, in another aspect, for processing the core sample for fluid analysis using extraction or encapsulation methods and apparatus. The present description is susceptible to modalities in different ways. Specific modalities of this disclosure are shown in the drawings, and will be described in detail here with the understanding that the present disclosure should be considered an example of the disclosure principles, and is not intended to limit the disclosure to that illustrated and described here. In fact, as will become evident, the teachings of the present disclosure can be used by a variety of tools and thus in all phases of construction and production of the well. Therefore, the modalities discussed below are merely illustrative of the applications of the present invention.
    [023] Figure 1 shows a schematic diagram of an exemplary drilling system 10 with a drilling column 20 carrying a drilling set 90 (also referred to as the downhole assembly, or BHA) transported in a well or borehole. well 26 for drilling the well hole. The drill string 20 can include one or more of the following: hinged tube and coiled tubing. The drilling system 10 includes a conventional drilling tower 11 mounted on a floor 12 which supports a rotary table 14 which is rotated by a main motor such as an electric motor (not shown) at a desired speed of rotation. Drill column 20 includes tubing such as drill tube 22 or coiled tubing extending downwardly from the surface to well hole 26. Drill column 20 is pushed inward
    Petition 870200035086, of 3/16/2020, p. 19/36
    7/22 of well bore 26 when a drill pipe 22 is used as the pipe. For coiled pipe applications, a pipe injector, such as an injector (not shown), however, is used to move the pipe from its source, such as a coil (not shown), to the bore hole. well 26. The drill bit set 50 attached to the end of the drill string breaks geological formations when it is rotated to drill well hole 26. If a drill tube 22 is used, the drill string 20 is coupled to a winch 30 via a Kelly joint 21, swivel joint 28, and line 29 through a pulley 23. During drilling operations, winch 30 is operated to control the weight of the drill, which is an important parameter that affects the penetration rate . The operation of the winch is well known in the art and is therefore not described in detail here.
    [024] During drilling operations, a suitable drilling fluid 31 from a mud tank (source) 32 circulates under pressure through a channel in the drilling chain 20 through a mud pump 34. The drilling fluid passes from the mud pump 34 to the drilling column 20 through a pressure surge absorber (not shown), fluid line 38 and kelly joint 21. The drilling fluid 31 is discharged at the bottom of the well 51 through an opening in the drill bit assembly 50. The drilling fluid 31 circulates up well through the annular space 27 between the drill column 20 and the well hole 26 and returns to the mud tank 32 via a return line 35 The drilling fluid acts to lubricate the drill bit assembly
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    8/22 drilling 50 and for loading well hole cuttings or chips away from drilling bit assembly 50. An S1 sensor placed on line 38 can provide information on the fluid flow rate. The surface torque sensor S2 and sensor S3 associated with the drill string 20, respectively, provide information about the torque and rotation speed of the drill string. In addition, a sensor (not shown) associated with line 29 is used to provide the hook load of the drill string 20.
    [025] In one disclosure modality, the drill bit set 50 is rotated by just turning the drill pipe 22. In another disclosure modality, a downhole engine 55 (mud engine) is arranged in a set of drilling 90 to rotate the drill bit assembly 50 and the drill pipe 22 is generally rotated to supplement the rotational force, if necessary, and to effect changes in the direction of the drilling.
    [026] In an embodiment of Figure 1, the mud motor 55 is coupled to the drill bit set 50 through a drive shaft (not shown) disposed in a bearing set 57. The mud motor rotates the set of drill bit 50 when the drilling fluid 31 passes through the mud motor 55 under pressure. Bearing assembly 57 supports the radial and axial forces of the drill bit assembly. A stabilizer 58 coupled to the bearing assembly 57 acts as a centralizer for the lower portion of the mud motor assembly.
    [027] In a disclosure mode, a perforation sensor module 59 is placed close to the drill assembly
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    Drill 9/22 50. Drill bit set 50 may include one or more of: (i) a drill bit, (ii) a drill bit box, (iii) a drill collar, and (iv) an underwater storage. The drilling sensor module can contain sensors, circuits and processing software and algorithms related to dynamic drilling parameters. Such parameters may include drill swing, drill set stick slip, backward rotation, torque, shocks, well and ring bore pressure, acceleration measures and other measures of drill bit set condition. Proper telemetry or underwater communication 77 using, for example, two-way telemetry, is also provided as illustrated in drilling set 90. The drill sensor module processes the sensor information and transmits it to surface control unit 40 via submarine communication 77.
    [028] Submarine communication 77, a power unit 78 and a MWD 79 tool are all connected together with drilling column 20. Flex submarines, for example, are used in connection with the MWD 79 tool in drilling set 90. These submarines and tools can form the downhole drill set 90 between the drill column 20 and the drill bit set 50. The drill set 90 can take various measurements including pulsed nuclear magnetic resonance measurements while drilling the hole well 26 is being drilled. Underwater communication 77 obtains the signals and measurements and transfers the signals, through two-way telemetry, for example, to be processed on the surface.
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    10/22
    Alternatively, the signals can be processed through a downhole processor at a suitable location (not shown) in the drilling set 90.
    [029] The surface control unit or processor 40 can also receive one or more signals from other sensors and downhole devices and signals from sensors S1-S3 and other sensors used in system 10 and process such signals according to programmed instructions provided for surface control unit 40. Surface control unit 40 can display desired drilling parameters and other information on a screen / monitor 44 used by an operator to control drilling operations. The surface control unit 40 can include a computer or microprocessor based processing system, memory to store programs or models and data, a recorder to record data, and other peripherals. The control unit 40 can be adapted to activate alarms 42 when certain unsafe or undesirable operating conditions occur.
    [030] The apparatus for use with the present description may include one or more downhole processors that can be positioned in any suitable location within or near the downhole assembly. The processor (s) may include a microprocessor that uses a computer program implemented in a suitable computer-readable medium that allows the processor to perform control and processing. The computer-readable medium can include ROMs, EPROMs, EEPROMs, EAROMs, flash memories, RAM, hard drives and / or optical disks. Other equipment, such as power and data buses, power supplies,
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    11/22 and the like, will be apparent to one skilled in the art.
    [031] Figure 2 shows an exemplary embodiment of the drill bit set 50 configured to generate a core sample that can be tested in situ. The drill bit set 50 may include a core 210 configured to receive a core sample 220 of material from the bottom 51. Core sample 220 may be formed by the teeth 230 of the drill bit set 50 Drill bit set 50 may include a recessed section or chamber
    215 configured to store core sample 220. Inside chamber 215, drill bit assembly 50 may include retractable cutters 280 to separate core sample 220 from formation 51. One or more seals 240 may be configured to contain core sample 220 and can isolate core sample 220 inside chamber 215. A probe 250 can be used to extract fluid 255 from core sample 220. The extracted fluid 255 can be transported to a fluid analysis module 260 via a tube 265. The extracted fluid 255 can be forced into tube 265 by pressurized fluid 275 being applied to core sample 220 by means of a pressurized tube 270 that can be configured to apply pressure to core sample 220. The use of pressurized fluid to extract fluid from the core sample is exemplary and illustrative only, as other devices can be used to extract fluids, includes nd, but not limited to, one or more of: (i) an acoustic actuator (an ultrasound actuator is a type of acoustic actuator) and (ii) a mechanical grinder. In some
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    12/22 modalities, a filter can be incorporated into the drill bit set 50 so that the core sample
    220 can be crushed, crushed, and / or sprayed, and then debris can be filtered to extract fluids 255. Fluid 255 can be a fluid including, but not limited to, one or more of: (i) drilling fluid, (ii) production fluid, and (iii) formation fluid. Fluid Analysis Module 260 may include sensors and test equipment configured to estimate physical, chemical, electrical and / or nuclear properties of the extracted fluid 255, including, but not limited to, one or more of the following: (i) pH, ( ii) H2S, (iii) density, (iv) viscosity, (v) temperature, (vi) rheological properties, (vii) thermal conductivity, (viii) electrical resistivity, (ix) chemical composition, (x) reactivity, ( xi) radio frequency properties, (xii) surface tension, (xiii) infrared absorption, (xiv) ultraviolet absorption, refractive index (xv), (xvi) magnetic properties, and (xvii) nuclear spin. In some embodiments, the drill bit set 50 can use the apparatus used to apply pressure to core sample 220 or an additional mechanism (not shown) applying pressure to core sample 220 in such a way that mechanical rock tests can be carried out on core sample 220 in situ. Mechanical rock tests may include, but are not limited to, one or more of the following: (i) a compression test, (ii) a stress test, and (iii) a fracture test. In addition, in some modalities, test data obtained through mechanical rock tests can be used to modify and / or optimize parameters of
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    13/22 drilling. Modification and / or optimization of drilling parameters, (such as, but not limited to, drill weight, rotation speed of the drill bit, drilling fluid flow rate, and geo-orientation parameters) can be determined in the background well or surface, and modification of drilling parameters can be done in real time.
    [032] Figure 3 shows another exemplary embodiment of the drill bit set 50 configured to use a gas chromatograph 300. Core sample 220 can be heated by heater 310 to the desired temperature to cause gases 320 to be generated.
    Heater 310 may heat core sample 220 using, but not limited to, one or more of: (i) electrical induction, (ii) radiation heating, and (iii) electrical resistance heating. Heater 310 can be controlled to operate at different temperatures to provide a variety of gas samples 320 to the gas chromatograph
    300. Gases 320 can be directed from chamber 215 in a gas chromatograph 300 via a connecting tube 330. Heating of core sample 220 may also result in the release of fluids 340 from core sample 220. These 340 liquids can flow along bottom 350 of chamber 215 in a heavy fluid analysis module 360. Bottom 350 can be formed by the top of seals 240 or a separate insulation barrier (not shown). Heavy Fluid Analysis Module 360 may include sensors or test equipment configured to estimate physical, chemical and / or nuclear properties of fluids 340, including, but not limited to, one or more of the following: (i) pH, (ii)
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    14/22
    H2S, (iii) density, (iv) viscosity, (v) temperature, (vi) rheological properties, (vii) thermal conductivity, (viii) electrical resistivity, (ix) chemical composition, (x) reactivity, (xi) properties radiofrequency, (xii) surface tension, (xiii) infrared absorption, (xiv) ultraviolet absorption, (xv) refractive index, (xvi) magnetic properties, and (xvii) nuclear spin.
    [033] Figure 4 shows another exemplary embodiment of the drill bit set 50 configured to expose core sample 220 inside chamber 215 to a strong magnetic field of a nuclear magnetic resonance (NMR) module 400. The module NMR 400 can be equipped to generate a strong magnetic field and detect a response from core sample 220 to the strong magnetic field. The NMR module 400 can be controlled to regulate the power of the magnetic field to be applied to a core sample 220. In some embodiments, the drill bit set 50 can be equipped with a radio frequency generator and / or receiver configured to apply a radio signal to the test sample 220 and detect a radio frequency response caused by the interaction of the radio signal with the test sample 220.
    [034] Figure 5 shows another exemplary embodiment of the drill bit set 50 configured to at least partially encapsulate a core sample 220 in a chamber 215 with an encapsulation material 500. Chamber 215 may include one or more retractable cutters 280 configured to separate core sample 220 from the borehole 51.
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    15/22
    Within the drill bit assembly 50 there may be a reservoir 510 for storing the encapsulation material 500. Since a core sample 220 is inside chamber 215 and isolated from the well hole bottom 51, the encapsulation material 500 can be applied to core sample 220. A tube 530 can allow encapsulation material 500 to flow from reservoir 510 and into chamber 215. Once in contact with core sample 220 the encapsulation material 500 forms a encapsulation liner 540 that at least partially surrounds core sample 220. Drill bit set 50 may also include a marking device 550 with access to chamber 215. Marking device 550 can be configured to insert or implant a marker 560 ( such as a radio frequency identification device (RFID) chip within the 540 encapsulation liner so that a identified. In some embodiments, the marking apparatus 550 may be configured to cauterize or mark an identifier on the core sample 220 or on the casing coating 540. The marking apparatus may include, but is not limited to, one of: (i ) a laser marker, (ii) an ultrasonic blasting tool, (iii) a powder blasting tool, (iv) radioactive tracers, (v) magnetic particles, and (vi) a chip inserter. The encapsulation material 500 may include, but is not limited to, one or more of the following: (i) a polymer, (ii) a gel, (iii) a metallic coating, and (iv) a clay.
    [035] Figure 6 shows another modality
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    Example 16/22 of drill bit set 50 configured with a storage module 600 to store one or more core samples 220. The storage module 600 may include a storage chamber 610 that is configured to receive a core sample 220 from chamber 215. The storage module may also include a carrier 620 located within storage chamber 610 configured to grasp or hold core sample 220 for transport into and / or inside storage chamber 610. The carrier 620 may include a series of teeth 630 configured to grasp or hold core sample 220 so that it can be moved further into storage chamber 610. Storage module 600 may also include bellows or bladders 640 configured to contain samples core 220 firmly within the deepest recesses of the storage chamber 610, which can allow allow multiple core samples 220 to be stored inside storage chamber 610. Bellows 640 and / or teeth 630 can be configured to minimize the possibility of encapsulation liner 540 being damaged by transport or storage of core sample 220. In some embodiments (not shown) the storage module can be located behind the drill bit assembly on the drill rod or a submarine. While a conveyor 620 is shown with mechanical teeth 630, this is illustrative and exemplary only, as conveyor 620 can use any apparatus known to those skilled in the art to move core sample 220 into chamber 215, 610, inclusive, but not
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    17/22 limiting to, (i) gears, (ii) a helical unit, (iii) a spiral unit, (iv) a piston, and (v) a robotic arm.
    [036] Figure 7A shows an exemplary drill bit set 50 equipped with core cutters 700 in addition to drill bits 230. Core cutters can be located adjacent to core 210. Core cutters 700 may include, but are not limited to, one of: (i) elongated cutting blades, (ii) ultrasonic cutters, (iii) acoustic ablators, (iv) fluid disintegrators, (v) dust disintegrators, and (vi) laser cutters.
    [037] Figure 7B shows an exemplary drill bit set 50 configured to cut multiple core samples 220. The face of drill bit assembly 220 may include core bits 210 that open into multiple sample chambers 215. One or more of the core bits 210 may have core cutters 700 mounted adjacent to core core 210 in drill bit set 50. In operation, single or multiple core samples 220 can be received by core core 215 by controlling which core bits core 700 are in operation.
    [038] While Figures 2-7B show various modalities according to the present description with individual characteristics, some or all of these can be combined to form a drill bit set configured to perform one or more tests and to encapsulate a core sample 220. Some modalities can be configured to allow the taking of samples from
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    18/22 multiple cores where some core samples have fluid extraction, others have extracted and tested fluids, and still others are encapsulated with or without previous tests.
    Although several modalities are presented to form a core sample in front of the drill set, this is illustrative and exemplary only; as embodiments of the present description include apparatus for collecting lateral core samples as well.
    [039] Figure 8 shows an exemplary method 800 according to an embodiment of the present description for testing the core sample or fluids derived from the core sample. In method 800, drill bit set can be positioned against the well hole bottom 51 inside the well hole 26 in step 810. In step 820, at least one core sample 220 can be cut from the bottom of the well. well hole 51 using drill bit 230 or specialized core cutters 700 and received inside chamber 215 through core 210. In some embodiments, multiple core samples 220 can be cut at the same time during step 820 In step 830, a stimulus can be applied to a core sample 220. The stimulus applied to core sample 220 may include, but is not limited to, one or more of the following: (i) pressure, (ii) heat, (iii) acoustic energy, (iv) magnetic field, and (v) electromagnetic radiation. In step 840, gaseous or liquid fluids 255, 320, 340 from core sample 220 can be tested to estimate at least one chemical, physical, electrical, and / or nuclear property, including, but not limited to, one or more of the following: (i) pH, (ii) H2S, (iii)
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    19/22 density, (iv) viscosity, (v) temperature, (vi) rheological properties, (vii) thermal conductivity, (viii) electrical resistivity, (ix) chemical composition, (x) reactivity, (xi) radio frequency properties , (xii) surface tension, (xiii) infrared absorption, (xiv) ultraviolet absorption, (xv) refractive index, (xvi) magnetic properties, and (xvii) nuclear spin. In step 845, core sample 220 can be tested for its response to exposure to one or more of: (i) a magnetic field, (ii) radio frequency energy, (iii) electromagnetic radiation, (iv) a electric field, (v) temperature, (vi) density, (vii) resistivity properties, (viii) acoustic radiation, and (ix) pressure. Step 840, step 845, or both, can be performed in different modalities of method 800. In step 850, that of at least one property estimated in one or both steps 840 and step 845, can be used to estimate a parameter of interest of the well-bottom formation 51. In some embodiments, step 855 can be performed in such a way that the stimulus response obtained in step 845 can be used to modify at least one drilling parameter. Step 855 can be performed in real time.
    [040] Figure 9 shows an exemplary method 900 according to an embodiment of the present description for encapsulating the core sample. In method 900, drill bit set 50 can be positioned against the bottom of well hole 51 inside well hole 26 in step 910. In step
    920, at least one core sample 220 can be cut from the borehole bottom 51 using drill bit teeth 230 or core cutters
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    Specialized 20/22 700 and received inside chamber 215 via core 210. In some embodiments, multiple core samples 220 may be cut at the same time during step 920. In step 930, core sample 220 may be compressed out or separated from the formation of retractable cutters 280. In step 940, core sample 220 can be at least partially encapsulated by an encapsulating liner 540 provided from a reservoir 510 of an encapsulating material 500. The process of Encapsulation may include, but is not limited to, one of: (i) spraying, (ii) partial immersion, (iii) complete immersion, (iv) pouring, (v) conditioning, and (vi) thermal evaporation coating. In step 950, core sample 220 can be moved from chamber 215 to a storage chamber 610 by carrier 620. In step 960, drill bit set 50 can be transported to the surface for recovery of core samples 220 In some embodiments, step 950 may be optional. In some embodiments, before, during, or immediately after encapsulation, a marking apparatus may attach an identification marker to core sample 220. In other embodiments, the marking apparatus may cauterize or mark the sample or encapsulation liner with an identifier. The marking apparatus may include, but is not limited to, one of: (i) a laser marker, (ii) an ultrasonic blasting tool, (iii) a powder blasting tool, (iv) radioactive tracers, ( v) magnetic particles, and (vi) a chip inserter.
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    21/22
    [041] While Figure 8 describes an embodiment of a method according to the present description for the extraction and testing of a fluid or a core sample, and Figure 9 describes an embodiment of a method according to the present description for encapsulation from a core sample, in some embodiments, the method may include extracting a fluid, testing the fluid or core sample, and encapsulating the core sample.
    [042] Figure 10 shows another exemplary embodiment of the drill bit set 50 configured to at least partially encapsulate a core sample 220 in a chamber 215 with an encapsulating material 500 while chamber 215 is pressurized. A second set of seals 1010 can be located at the top of chamber 215 so that when seals 1010 and seals 240 are closed, a section of chamber 215 of holding core sample 220 is isolated from storage chamber 610 (Figure 6). While core sample 220 is isolated, any fluid 1050 in chamber 215 can be pressurized by a pressure applicator 1000. In this example, pressure applicator 1000 can include a force applicator 1030 piston 1020, and cylinder 1040 where the applicator of pressure force 1030 is configured to move piston 1020 to reduce the combined volume of chamber 215 and cylinder 1040 resulting in increased pressure within chamber 215. Increasing the pressure on the core sample 220 can intensify the pore pressure inside the core sample 220. Pressure can be reduced or returned to ambient pressure by moving piston 1020 to increase the combined volume of chamber 215 and piston cylinder 1040. After
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    22/22 pressure has been reduced, core sample 220 can be encapsulated as shown above. In some embodiments, encapsulation material 500 may be applied to core sample 220 when the pressure in chamber 215 is above ambient pressure. Encapsulation material 500 can be stored in reservoir 510 at a pressure sufficient to allow encapsulation material 500 to enter chamber 215, or a mechanism (not shown), such as a pump, can be used to increase the pressure of encapsulation material 500 such that it can flow out of tube 530 against pressure in chamber 215. The use of a piston and cylinder to modify pressure in chamber 215 is exemplary and illustrative only, like other mechanisms, such as, but not limited to a: a drilling fluid pressure, adjustable bladders, pumps and displacement devices can be used to modify the pressure in chamber 215.
    [043] While the foregoing description is directed to a mode of disclosure modalities, several changes will be evident to those skilled in the art. It is intended that all variations are embraced by the previous description.
    权利要求:
    Claims (4)
    [1]
    1. Apparatus for forming a core sample (220) in a well (26) comprising:
    a drill bit (50) configured to form a core, and at least one retractable cutter (280) internal to the drill bit (50) configured to cut the sample (220) from the core;
    featured due to the drill bit (50)
    further understand:
    a chamber (215) configured to receive the sample (220); and one or more seals (240) configured to isolate the sample (220) inside the chamber (215).
    2. Apparatus, according to claim 1, characterized by fact of still understanding an extractor
    (250) placed adjacent to the chamber (215) and configured to extract the sample fluid (220).
    3. Appliance, according to claim 2, characterized by fact that it further comprises: at least an analysis module (260,360)
    operatively coupled to the extractor (250) and configured to analyze the extracted fluid.
    4. Apparatus, according to claim 3, characterized by fact that at least one module of analysis (260,360) includes at least one of: (i) one
    gas chromatograph and (ii) a fluid analyzer.
    5. Appliance, according to claim 2, characterized by fact that the extractor (250) comprises
    at least one of: (i) a heater (310), (ii) a
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    [2]
    2/4 mechanical sprayer, (iii) an acoustic controller, and (iv) a filter.
    6. Apparatus, according to claim 2, characterized by the fact that the extractor is configured to perform at least one of: (i) a compression test, (ii) a deformation test, and ( iii) a fracture test.
    7. Apparatus, according to claim 1, characterized by the fact that it also comprises:
    an analysis module (260,360) positioned adjacent to the chamber (215) and configured to apply a stimulus to the sample (220), where optionally the stimulus is at least one of: (i) pressure, (ii) heat, (iii ) acoustic energy, (iv) a magnetic field, (v) electromagnetic radiation, and (vi) force.
    8. Apparatus, according to claim 7, characterized by the fact that it also comprises:
    a processor configured to modify at least one drilling parameter using data acquired by the analysis module (260,360).
    9. Apparatus, according to claim 1, characterized by the fact that it also comprises:
    an encapsulator (530) operatively coupled to the chamber (215) and configured to at least partially encapsulate at least part of the sample (220) in an encapsulating material (500), where optionally the
    encapsulation (500) is at least one in: (i) one polymer, (ii) a gel, iii) one coating metallic, and (iv) an clay. 10. Device, in a deal with The claim 9,
    Petition 870200035086, of 3/16/2020, p. 11/36
    [3]
    3/4 characterized by the fact that the encapsulation material (500) is easily distinguishable from drilling fluids (31) and non-encapsulated materials from the well (26).
    11. Apparatus, according to claim 1, characterized by the fact that it also comprises:
    a marking device (550) adjacent to the chamber (215) and configured to mark the sample (220); where the marking device is optionally configured to mark the sample using at least one of: (i) a laser marker, (ii) an ultrasonic blasting tool, (iii) a powder blasting tool, (iv) tracers radioactive, (v) magnetic particles, and (vi) a chip inserter.
    12. Apparatus, according to claim 1, characterized by the fact that it also comprises:
    a pressure applicator (1000) disposed adjacent to the chamber (215) and configured to modify the pressure of the chamber (215).
    13. Apparatus according to claim 1, characterized by the fact that the sample (220) is at least one of: (i) a core sample (220) and (ii) a cut.
    14. Method of obtaining a core sample from a well comprising:
    use a drill bit (50) transported to the well (26) to form a core, and use at least one retractable cutter (280) internal to the drill bit (50) to cut the sample (220) from the core;
    characterized by the fact that the method also includes:
    Petition 870200035086, of 3/16/2020, p. 12/36
    [4]
    4/4 receiving the sample (220) in a chamber (215) of the drill bit, and isolating the sample (220) inside the chamber (215) using one or more seals (240).
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    法律状态:
    2018-12-26| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2019-07-02| B06T| Formal requirements before examination [chapter 6.20 patent gazette]|
    2019-12-17| B06A| Notification to applicant to reply to the report for non-patentability or inadequacy of the application [chapter 6.1 patent gazette]|
    2020-03-24| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|
    2020-05-26| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 29/04/2011, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US36566510P| true| 2010-07-19|2010-07-19|
    US61/365,665|2010-07-19|
    US13/096,452|US8739899B2|2010-07-19|2011-04-28|Small core generation and analysis at-bit as LWD tool|
    US13/096,452|2011-04-28|
    US13/096,484|2011-04-28|
    US13/096,484|US8499856B2|2010-07-19|2011-04-28|Small core generation and analysis at-bit as LWD tool|
    PCT/US2011/034534|WO2012012006A1|2010-07-19|2011-04-29|Small core generation and analysis at-bit as lwd tool|
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