MX2013015266A

MX2013015266A - Downhole sample module with an accessible captured volume adjacent a sample bottle.

Info

Publication number: MX2013015266A
Application number: MX2013015266A
Authority: MX
Inventors: Anthony Herman Van Zuilekom; Jim Randall Wilson
Original assignee: Halliburton Energy Serv Inc
Priority date: 2011-06-30
Filing date: 2011-06-30
Publication date: 2014-02-27
Also published as: CA2840355A1; EP2726710A1; BR112013033521A2; US20140345860A1; EP2726710A4; WO2013002803A1; AU2011371869A1

Abstract

Systems and methods for accessing a second or additional volume of sampled formation fluids identical to a first volume of formation fluids collected in a primary sample bottle during the downhole sampling process. The second volume can be accessed, extracted and analyzed without having to interfere with the first volume or the integrity of the primary sample. The second volume may be captured in a flowline coupled to the primary sample bottle and accessed using a secondary or mini-sample bottle.

Description

SAMPLE MODULE INSIDE WELLS WITH A VOLUME CAPTURED ACCESSIBLE ADJACENT TO A BOTTLE OF SAMPLES FIELD OF THE INVENTION The present invention relates to the field of well drilling, and more particularly it relates to systems and methods for accessing a second volume of sampled fluids of the formation identical to a first volume of fluids of the formation.

BACKGROUND OF THE INVENTION During the drilling and completion of oil and gas wells, it may be necessary to enter auxiliary operations, such as evaluating the production capacities of the formations intersected by the well. For example, after a well or well interval has been drilled, the areas of interest are often tested or sampled to determine different properties of the formation such as permeability, fluid type, fluid quality, formation temperature, formation pressure, bubble point and pressure gradient of the formation. When a formation is sampled, a fluid from the formation or other material is extracted into the tester of the formation and captured for further analysis. These tests are carried out in order to determine if the commercial exploitation of skiable intersected formations and how to optimize production. The acquisition of accurate well data is critical for the optimization of hydrocarbon wells. These well data can be used to determine the location and quality of hydrocarbon reserves, whether the reserves can be produced through the well, and for well control during drilling operations.

The sampling of fluid inside the well is conducted to obtain representative samples of fluid and gas in sample chambers of the test tool of the formation inside the well. Afterwards, the samples can be removed to the surface and analyzed in Pressure-Volume-Temperature (PVT) laboratories to carry out chemical and gas composition analysis. It is important that samples of the formation fluid are stored in containers and maintained under conditions that retain the composition of the original sample over time. However, the time it takes to obtain a sample captured in a sample bottle chamber to the laboratory under the conditions in which the sample was taken is undesirably long. Therefore, a need remains for a sample module that includes a readily available volume of samples for efficient and flexible testing.

The principles of the present disclosure overcome the limitations of current art.

BRIEF DESCRIPTION OF THE DRAWINGS For a detailed description of the exemplary embodiments of the invention, reference will now be made to the accompanying drawings, in which: Figure 1 is a schematic view, partly in cross section, of a drilling apparatus with a formation tester.

Figure 2 is a schematic view, partly in cross section, of a formation tester transported by wire line.

Figure 3 is a schematic view, partially in cross section, of a formation tester placed in a drill pipe connected to a telemetry network.

Figure 4 is a cross-sectional view of a section of wired piercing tube that includes a wired tool.

Figure 5 is a side view, partly in cross section, of a drill collar including a probe assembly of the array.

Figure 6 is a schematic view of a fluid sampling assembly of the formation in accordance with the principles that are disclosed in this document.

Figure 7 is a schematic view of a fluid sampling assembly of the formation with a captured volume of the sample fluid according to the principles disclosed herein.

Figure 8 is a schematic view of a sample volume captured adjacent to a sample bottle in a first position in accordance with the principles disclosed herein.

Figure 9 is a schematic view of a sample volume captured adjacent to a sample bottle in a second position in accordance with the principles disclosed herein.

Figure 10 is a flow diagram of a method for analyzing a fluid sample from the formation that includes directing a portion of the formation fluid flow into a removable secondary sample bottle from the flow line separately from a bottle of primary samples.

Figure 11 is a flowchart of another method for analyzing a fluid sample from the formation that includes directing a portion of the formation fluid flow into a secondary sample bottle for independent analysis of a bottle fluid analysis of samples primary.

Figure 12 is a flow chart of additional methods for capturing a volume of secondary formation fluid that will be tested and analyzed separately from a primary volume of formation fluid.

DETAILED DESCRIPTION OF THE INVENTION In the drawings and the description that follows, similar parts are typically marked throughout the specification and drawings with the same reference numbers. The drawings of the figures are not necessarily the scale. Certain features of the disclosure may be exaggerated in scale or in some schematic form and some details of the conventional elements may not be shown in the interest of clarity and conciseness. The present disclosure is susceptible to modalities in different ways. The specific modalities are described in detail and are shown in the drawings, with the understanding that the present disclosure should be considered as an exemplification of the principles of disclosure, and is not intended to limit disclosure to what is illustrated and described in this document. It must be fully recognized that the different teachings of the modalities discussed below can be employed separately or in any suitable combination to produce the desired results.

In the following discussion and the claims, the terms "including" and "comprising" are used in an open form, and therefore should be interpreted to mean "including, but not limited to, unless specified otherwise, any use of the terms "connect", "coupled", "join", or any other term that describes an interaction between elements is not intended to limit the interaction to the direct interaction between the elements and may also Include the indirect interaction between the described elements The above or below reference will be made for description purposes with "above", "superior", "upwards", or "upstream" meaning towards the surface of the well and with "below" "," bottom "," down ", or" downstream "meaning towards the terminal end of the well, regardless of the orientation of the well.In addition, in the discussion and claims that follow, can be set in goose sions that certain components or elements are in fluid communication. By this it is intended that the components be interpreted as interrelated in such a way that a fluid could be communicated between them, such as by means of a passage, tube, or conduit. Also, the Designation of "MWD" or "LWD" are used to refer to all measuring devices and systems during drilling or registration during drilling. The various features mentioned above, as well as other features described in greater detail below, will be readily apparent to those experienced in the art upon reading the following detailed description of the embodiments, and by referring to the accompanying drawings.

Referring initially to Figure 1, a drilling apparatus including a formation tester is shown. A tester of the formation 10 is shown enlarged and schematically as part of an assembly of the interior of the well 6 that includes a submersible 13 and a drill bit 7 at its distal end. The assembly of the interior of the well 6 is lowered from a drilling platform 2, such as a ship or other conventional earth platform, by means of a drill string 5. The drill string 5 is placed through a riser 3 and a well head 4. Conventional drilling equipment (not shown) is supported within a drilling tower 1 and rotates the drill string 5 and drill bit 7, causing drill 7 to form a well 8 through of the training material 9. The drill bit Drilling 7 can also be rotated using other means, such as an engine inside the well. Well 8 penetrates underground areas or deposits, such as tank 11, which is believed to contain hydrocarbons in a commercially viable amount. A ring 15 is formed therethrough. In addition to the formation tester 10, the assembly of the interior of the well 6 contains different conventional apparatus and systems, such as an in-hole drilling motor, a steerable rotary tool, a mud pulse telemetry system, sensors and control systems. MWD or LWD, and others known in the field.

In some embodiments, and with reference to Figure 2, a training test tool 60 is placed in a tool chain 50 which is transported into the well 8 by means of a cable 52 and a winch 54. The tool of Tests include a body 62, a sampling assembly 64, a backup assembly 66, analysis modules 68, 84 that include electronic devices, a flow line 82, a material module 65, and an electronics module 67. The tester of the formation 60 is coupled to a surface unit 70 which may include an electrical control system 72 having an electronic storage means 74 and a control processor 76. In other embodiments, the tool 60 may alternatively include or additionally an electrical control system, an electronic storage medium and a processor.

Referring to Figure 3, a telemetry network 100 is shown. A formation tester 120 is coupled to a drill string 101 which is formed by a series of wired drill pipes 103 connected for communication through joints using communication elements. It will be appreciated that the work chain 101 may be another form of transport, such as flexible wireline. The drilling and control operations inside the well interface with the rest of the world in the network 100 by means of a repeater unit 102 outside the well, a kelly 104 or motor in the top (or, submersible of transition with the elements of communication ), a computer 106 in the control center of the drilling rig, and an uplink 108. The computer 106 can act as a server, controlling access to the transmissions of the network 100, sending control and command signals to the interior of the well, and receive and process information sent to the outside of the well. The software running the server can control access to the network 100 and can communicate this information through dedicated terrestrial lines, satellite uplink 108, the Internet, or other means to a central server accessible from anywhere in the world. The tester of the formation 120 is shown bonded on network 100. Above drill bit 110 for communication along its conductive path and along wired perforation string 101.

The formation tester 120 may include a plurality of transducers 115 deposited in the formation tester 120 to relieve information from the interior of the well to the operator on the surface or to a remote site. The transducers 115 can include any conventional source / sensor (e.g., pressure, temperature, gravity, etc.) to provide the operator with information and / or parameters inside the well, as well as diagnostics or position indication in relation to the tool. The telemetry network 100 can combine multiple signal transport formats (e.g., mud pulse, optical fiber, acoustic, EM jumps, etc.). It will also be appreciated that software / firmware can be configured in the training tester 120 and / or the network 100 (eg, on the surface, in the well, in combination, and / or remotely through linked wire links). to network) .

Referring briefly to Figure 4, the sections of the wired piercing tube 103 are enlarged for clarity. Wired drilling tube 103 includes conductors 150 running the entire length of the sections of the tube. The communication elements 155 allow the transfer of energy and / or data between the sections of the tube 103. A data / energy signal can be transmitted along a section of tube of the wired perforation string, such as the section of tube with the formation tester 120 (Figure 3), from one end through the conductor (s) 150 to the other end through the communication elements 155. In some embodiments, the conductor (s) is ) 150 comprises (s) coaxial cables, copper wires, fiber optic cable, triaxial cables, and twisted pairs of wire. The conductor (s) 150 may be placed through a hole formed in the walls of the outer tubular members of the tubes 103. The communication elements 155 may comprise inductive couplers, contacts direct electric, optical couplers, and combinations thereof. The portions of the wired drill pipes 103 can be submersible or other connection means. The ends of the submersibles or connection means of the wired submersibles 103 are configured to communicate within the telemetry network within the well 100.

Referring now to Figure 5, a modality of a probe collar section 200 is shown in detail. of the WD formation, which can be used as the tool 10 in Figure 1 or the tool 120 in Figure 3. A drill collar 202 houses the tester of the probe assembly 210. The probe assembly 210 includes different components for the operation of the probe assembly 210 for receiving and analyzing formation fluids from the ground formation 9 and the reservoir 11. An expandable probe member 220 is placed in an aperture 222 in the drill collar 202 and is it can extend beyond the outer surface of the piercing collar 202, as shown. The probe member 220 is reprehensible to a recessed position below the outer surface of the piercing collar 202. The probe assembly 210 may include a recessed outer portion 203 of the outer surface of the piercing collar 202 adjacent the probe member 220 The probe assembly 210 includes a depression or piston accumulator assembly 208, a sensor 206, a valve assembly 212 having a flow line shutoff valve 214 and a relief valve 216, and a fluid flow hole perforation 204. At one end of the probe collar 200, generally the lower end when the tool 10 is placed in the well 8, is an optional stabilizer 230, and the other end is an assembly 240 that includes a hydraulic system 242 and a collector 244.

The piston assembly 208 includes a piston chamber 252 that contains piston 254 and a manifold 256 that includes different fluid and electrical conduits and control devices. The piston assembly 208, the probe 220, the sensor 206 (eg, a pressure gauge) and the valve assembly 212 communicate with each other and with other components of the probe collar 200, such as the connector 244 and the hydraulic system 242, as well as the tool 10 by means of the conduits 224a, 224b, 224c and 224d. The conduits 244a, 224b, 224c and 224d include different fluid flow lines and electrical conduits for the operation of the probe assembly 210 and the probe collar 200.

The ling of fluid from the formation within the well allows the representative les of fluid and gas to move to the surface in the le chambers, in such a way that they are available for analysis in PVT laboratories separated from the well site. The PVT laboratory can carry out chemical analysis and gas composition, among other tests. Depending on how critical the fluid information is inside the well for well operation, the fluid le can be rushed to the laboratory or opened at the well site to make basic measurements. These actions generally require that les be taken additional, multiple, or redundant. The fluid samples should be substantially free of contamination for accurate analysis in the PVT laboratory. Contamination can include fluid introduced by the drilling process. As the perforation logo invades the formation, it becomes a contaminant of the original fluids of the formation and is commonly called filtering. Once the sample bottle is removed from the surface, the analysis requires that it be opened in such a way that the contained fluid can be tested. If the sample is tested in an off-site PVT laboratory, the time needed to transport the sample bottle and sample fluids to the PVT laboratory generally exceeds what is considered a reasonable time to wait at the well site (due to the high cost of well time and drilling equipment). In addition, the ability to generate a high-quality laboratory measurement requires that the sample bottle be heated and shaken for long periods of time to ensure that the fluid sample is in the chemical composition of the sample as it was captured within the well. .

Referring now to Figure 6, a mode of a training tester tool chain 300 is shown which includes certain principles disclosed in this document. The tester tool chain of the formation 300 comprises a series of submersibles or physically coupled modules fluidly interconnected as will be described. A submersible upper connector 302 provides a module for supporting the formation tester and binding to a transport above the formation tester. A sampling module 304 including multiple probes 338 for receiving formation fluids and a primary flow line 305 for conveying the formation fluids through the module is coupled below the submersible connector 302. The sampling module also includes a piston 306 for drawing fluids from the formation into the probes 238. Below the sample module 304 is coupled a first sensor module 310 which includes a primary flow line 315 coupled to the flow 305, and a fluid sensor 312. Below the first sensor module 310 is coupled a second sensor module 320 which includes a primary flow line 325 coupled to the flow line 315, and a pressure sensor 322. under the second sensor module 320 is coupled a pump module 330 which includes a pump 334, such as a dual-acting pump, and a primary flow line 335 having a check valve 332. The primary flow line 335 is coupled between the flow line 325 and a primary flow line 345 of a third sensor module 340 that includes another fluid or pressure sensor 342. Below the third sensor module 340 is coupled a sample bottle module 350 that includes a primary flow line 355 and multiple removable sample bottles 360.

When the tester of the formation 300 is coupled and the tests have started, the formation fluid enters the formation tester in the probes 338 and passes through the fluid sensors 312, 322 within the pump module 330. The Flow path from the probes 338 to the input of the pump module 330 is at or below the formation pressure if communication is established with the surrounding formation. The pump module 330 operates to draw fluid into the pump module, further reducing the pressure and then expelling the fluid into the flow lines 335, 345 at the outlet of the pump module. The fluid travels to the sensor 342 and is expelled through a purge valve in the sample bottle module 350. The formation fluids are generally pumped from the formation until the minimum desired contamination is reached, at which time the fluids of the formation can be redirected to the sample bottles 360 in the sample bottle module 350.

Referring now to Figure 7, an enlarged representation of the sample bottle 350, to illustrate various embodiments in accordance with the inventive principles disclosed in this document. The primary flow line 355 extends from an upper portion 355a to a lower portion 355b in the module. The flow line portion 355a may be coupled to the outlet of the pump module 330, and in some embodiments measurements of fluid properties may be made as the fluid enters or exits in an upstream pump configuration where the fluid enters the fluid. 355b and leaves at 355a. In other embodiments, measurements of fluid properties can be made in a downstream pump configuration where the fluid enters 355a and exits at 355b. A flow line 357 directs the fluids between the primary flow line 355 and the sample bottle portion of the module 350. The flow line 357 includes a purge valve 368 and a 370 check valve. the formation is required by the sample bottle module 350, the purge valve 368 is opened in a process start step to allow the fluid to be expelled out of the verification valve 370 into the surrounding wellbore ring 15.

Module 350 includes multiple bottles of removable samples. In some embodiments, three bottles of removable samples 360a, 360b, 360c, are mounted in the module of sample bottle 350. Each sample bottle includes a manual transport valve 361a, 361b, 361c at the inlet of each perspective bottle. The transport valves 361a, 361b, 361c are used to isolate the bottle chambers such that the bottles can be removed from the sample bottle module 350 and transported safely to the PV laboratory. The transport valves 361a, 361b, 361c are opened during the sampling process inside the well. A series of feeder flow lines 362a, 362b, 362c are coupled to the sample bottles 360a, 360b, 360c in the flow line 357, and are equipped with drain ports or adapters 364a, 364b, 364c.

In the initial stages of the sampling process, the pump module 330 will pass fluid through the flow lines 355, 357 to the purge valve 368, which is open, and out of the check valve 370 to the well ring 15. If the fluid samples are ready to be taken, and the operator decides that a sample will be acquired, one or more sample valves 366a, 366b, 366c are opened. Once opened, the sample valves 366a, 366b, 366c allow the flow of the formation fluid to enter the sample bottles 360a, 360b, 360c along the flow paths through the flow lines 362a, 362b, 362c. For example, if the target bottle is the bottle of samples 360a, the sample valve 366a is opened and the purge valve 368 is closed allowing substantially all of the fluid pumped from the pump module 330 to enter the sample bottle 360a through the flow line 362a and through the transport valve 361a open. After the sample bottle 360a is full, the system is overpressed causing the sample valve 366a to close and capture the fluid sample in the sample bottle 360a and the flow line 362a. In different modalities, the sampling operation will result in fluids captured from a single depth in the well or various depths, depending on the sampling work requirements. The training test tool is brought to the surface with the first and primary volumes of samples captured and isolated in the sample bottles 360a, 360b, 360c by means of the sample valves 361a, 361b, 361c, with the second volumes of additional fluid sample also captured in the above flow lines 362a, 362b, 362c and leading to the interior of the sample bottles. Sample bottles 360a, 360b, 360c include basic, generic fluid chambers, but additional embodiments are also contemplated as will be described below, including sample chambers that can be referenced to pressure hydrostatic using a flotation piston or a nitrogen buffer.

Referring now to Figure 8, there is shown an enlarged schematic representation of a single sample bottle 380a removable and associated flow line 362a. The sample bottle 380a is slightly different from the sample bottle 360a, as will be described. For reference purposes, the sample bottle 380a is shown in the condition in which it would be after sampling and recovery of the well. During the sampling process, the sample bottle 380a is filled and the formation fluid is captured in a chamber 378a. The fluid sample is isolated in chamber 378a and flow line 362a by means of sample valve 366a. The sample bottle 380a also includes a nitrogen buffer having a piston 372a, 374a and a nitrogen filled chamber 376a. The nitrogen buffer 376a maintains the sample pressure in the chamber 378a and the flow line 362a in the pressure within the existing well during sampling. The nitrogen load reacts to the pressure and temperature of the sampling process to maintain that pressure during recovery to the surface. When the sample module 350 is recovered from the well to the surface, the operator isolates the sample bottle chamber when closing a manual transport valve 381a for ensure the integrity of the fluid sample of the formation. The fluid sample from the formation is thus sealed in the sample chamber 378a. If desired, the sample bottle 380a can then be safely removed from the sample module 350.

Upon closing the transport valve 381a to seal the primary sample of the formation fluid in the sample chamber 378a, an additional or secondary volume of formation fluid remains trapped or captured in the flow line 362a at the pressure at which the transport valve 381a closes. The secondary volume of the formation fluid is captured upstream of the transport valve 381a and the sample bottle 380a, or between the transport valve 381a and the sample valve 366a. Such volume of captured fluid sample has test value. The adapter 364a (and the adapters 364b, 364c of Figure 7) coupled in the flow line 362a can be used to access the fluid volume of the captured formation sealed in the flow line 362a. A secondary or smaller sample bottle 390, also referred to as a mini-sample bottle, may be coupled attached to the drain adapter 364a to provide a fluidic coupling with the flow line 362a. This fluidic coupling can be used to extract fluid and gas from the 362a flow line for storage in mini-sample bottle 390a. As shown in Figure 8, the fluidic coupling between the mini-sample bottle 390a and the flow line 332a is separate and apart from the fluidic coupling between the primary sample bottle 380a and the flow line 362a. In some embodiments, the mini-sample bottle 390a includes a vacuum chamber that allows fluid and gas to enter the chamber. In some embodiments, the mini-sample bottle 390a is a zero volume cylinder, a vacuum piston retracted to allow fluid and gas to enter the cylinder.

The drain adapter 364a may include manual or mechanical valves that will maintain pressure in the flow line 362a while also allowing the mini-sample bottle 390a to be connected thereto for the recovery of gases and liquids from the flow line 362a. Once the sample is recovered or the bottle has been properly filled, the mini-sample bottle 390a can be removed from the flow line 362a, independently of the primary sample bottle 380a, so that the formation fluids in it they can be tested and analyzed. In addition, the flow line 362a is reduced to atmospheric pressure such that the first or primary sample bottle 380a can be safely removed at any time later and provide for PVT analysis.

In another embodiment, and still with reference to Figure 8, the sample bottle assembly is recovered to the well surface. The first or primary fluid sample volume of the formation is captured in the sample chamber 378a. Now, pressure can be applied by means of an external pump to a port 385a to pressurize the piston 374a, which will then pressurize the nitrogen in the chamber 376a. The pressurized nitrogen acts against the piston 372a to increase the pressure of formation fluids in the sample chamber 378a and the flow line 362a. Then, the sample chamber 378a is isolated by closing the manual transport valve 381a, thereby sealing the first or primary volume of fluid sample from the formation. The fluid of the pressurized formation in the flow line 362a is a second sample volume that the formation fluid that is captured upstream of the transport valve 381a and the sample bottle 380a and downstream of the sample valve 366a . The second fluid sample from the captured formation can be accessed separately or can be ventilated by connecting the mini-sample bottle 390a through the adapter 364a at a location separate from the fluidic coupling of the sample bottle primary 380a, as previously described. The mini-sample bottle 390a can then be removed from the flow line 362a independently of the primary sample bottle 380a for testing and analysis.

Referring now to Figure 9, a schematic representation of another embodiment of a sample bottle assembly is shown. A first or primary sample bottle 460 is configured as being recovered from the well, including a full sample chamber 478, standard having a single piston 472 and an isolation transport valve 461. The sample bottle 460 also includes a port 485. When the sample module 350 is recovered from the well to the surface, the fluid pressure of the formation in the sample chamber 478 depends on the thermal coefficient of expansion of the fluid as well as the compressibility and the pressure that was applied to fluid before the sample valve 366a was enclosed. The fluid pressure in bed 478 is generally much lower than the pressure at the sampling time of the formation. Accordingly, an external pump can be coupled to port 485 and used to apply pressure to piston 472, which will then pressurize the formation fluids in sample chamber 478 and flow line 362a. The sample chamber 478 is then isolated when the valve is closed 461 manual transport to seal the sample chamber 478 and ensure the integrity of the first or primary volume of samples in preparation for the removal of the sample bottle 460 from the sample module 350. Prior to removal of the sample bottle 460, can access the second fluid volume of the formation captured in the flow line 362a between the valves 366a and 461 and upstream of the sample bottle 460, currently at the pressure applied by the pressure pump connected to port 485, or it can be ventilated using the mini-sample bottle 390a and the adapter 364a, as previously described. The mini-sample bottle 390a is then removable for testing and analysis.

Even with reference to Figure 9, certain components can be added to the sample bottle assembly to evaluate or monitor the integrity of the transfer or venting of the fluid to the mini-sample bottle 390a. For example, a sensor 491 is coupled to the mini-sample bottle 390a. In other embodiments, an additional or alternative sensor 493 is coupled to the drain adapter 364a. The sensors 491, 493, alternatively or in combination, are used to analyze the purity of the fluid transfer to the mini-sample bottle 390a such as by detecting any pressure loss or other exposure to environmental conditions during the transfer.

As will now be described, the different modalities described above can be used in different processes to enable the sampled formation fluids to be identical to those captured in the primary sample bottle during the sampling process inside the well that will be extracted and analyzed without have to interfere with the integrity of the primary sample. In addition, the modalities enable the analysis of the formation fluid in vivo or in real time at the well site without having to disturb the integrity of the primary sample in the primary sample bottles. Alternatively, the modalities allow the easy and safe transportation to a laboratory of a second volume of the sample fluid from the formation, using a separate sample container from the primary sample bottle. These and other processes and methods are now fully detailed below.

Referring now to Figure 10, a method 500 for accessing and analyzing a sample of formation fluid is more fully detailed. Initially, the method 500 includes extracting a fluid from the formation within a sample module and through a flow line, at 502, and flowing the formation fluid towards the module of the sample bottle, at 504. Then, method 500 includes capturing a first volume of formation fluid in a first sample bottle, at 506, and capturing a second volume of formation fluid in the flow line, at 508. The method 500 then includes coupling a second sample bottle in the flow line to access the second volume of formation fluid, at 510. The method 500 may also include redirecting at least a portion of the second volume of formation fluid. into the second sample bottle, at 512. In some embodiments, the redirected portion of the second fluid volume of the formation is maintained in a single phase. The method 500 may further include removing the second sample bottle from the flow line independently of the first sample bottle, at 514. The method 500 may also include testing the second volume of formation fluid in the second sample bottle independently of the first fluid sample of the formation in the first bottle samples, in 516. In some modalities, testing the second volume of fluid formation can include at least one of carrying out chemical composition analysis, carrying out an analysis of gas composition, acquire a gas / oil ratio (GOR, Gas / Oil Ratio), or acquire a live oil company. The 500 method can also include removing the second bottle of samples from the flow line and transporting the second sample bottle from a well site, at 518. In some embodiments, method 500 may include collecting gas released from the second volume of formation fluid into the second bottle of samples The method 500 may also include accessing the second sample bottle before accessing the first sample bottle at 520.

In other embodiments, a method 600 (Figure 11) for accessing and analyzing a fluid sample from the formation includes extracting fluid from the formation into a sample module and through a flow line at 602, flowing the fluid from the sample. training towards a sample bottle module at 604, capturing a first volume of formation fluid in a first sample bottle at 606, and capturing a second volume of formation fluid at the flow line at 608. The method 600 also includes recovering the sample module and sample bottle module to the surface of a well at 610, applying pressure from an external source to the first sample bottle to increase the formation fluid pressure in the first bottle of samples and the flow line in 612, close a valve in the first sample bottle in 614, capture the second volume of fluid from the formation in the Flow line at the increased pressure at 616, and attach a second sample bottle on the flow line to access the second volume of formation fluid at 618. The method 600 can also include maintaining the increased fluid pressure of the formation in the flow line using a drain adapter, then attach the second sample bottle to the drain adapter to access and recover the increased fluid pressure from the formation of the flow line at 620.

In different modalities described in this document, a fluid sampling process of the formation includes capturing fluids in a sampling tool flow line and then accessing those fluids, independently of the primary sample fluid, while maintaining the fluids in a single phase. The fluids can then be transported and analyzed. In some embodiments, the fluids are contained and transported in a secondary sample bottle relative to the primary sample bottle. In some embodiments, the secondary sample bottle is smaller than the primary sample bottle, and can therefore be referred to as a mini-sample or miniature bottle. The secondary fluid sample from the formation can then be tested or analyzed, regardless of the primary fluid sample of the formation, to obtain characteristics of the formation fluid such as the chemical or gas composition, the gas / oil ratio (GOR), live oil signatures, and others. In some embodiments, the secondary sample of the formation fluid in the mini-sample bottle can be analyzed for argon, ¾S, CO2, paraffins, and other substances.

In certain modalities, the mini-bottle or secondary provides efficient and flexible access to the training fluids for testing and analysis separately from the training fluids captured by the primary sample bottles. Now with reference to Figure 12, a method 700 includes capturing a second volume of formation fluid in a flow line coupled to a bottle of primary samples with a primary fluid volume of the formation at 702, and accessing and receiving the second volume of formation fluid with a second fluid bottle of the formation coupled within the flow line at 704. In some embodiments, the method includes analyzing the second volume of formation fluid at the well site or site of the drilling equipment, in 706. In other modalities, the method includes analyzing the second volume of formation fluid in 708, and determining a quality of the primary fluid volume of the formation based on the analysis of the second fluid volume of the formation in 710. Therefore, using the different modalities described in this document, the preliminary analysis can be done in the secondary samples of the formation fluid in such a way that control of the quality of the primary samples.

Even with reference to Figure 12, further embodiments of the method include analyzing a plurality of second fluid volumes of the corresponding formation each with a different primary sample bottle at 712, removing or replacing one or more of the primary sample bottles with Based on the analyzes of the second fluid volumes of the formation in 714, and return one or more bottles of primary samples to the well based on the analyzes of the second fluid volumes of the formation in 716. Therefore, they can be expand the preliminary analysis and the quality control aspects of the tests of the captured secondary fluid samples of the formation. For example, additional secondary samples collected in the secondary mini-bottles can be pre-tested to determine if expensive primary bottle testing is necessary for any given primary sample bottle. If a sample module includes the primary sample bottles 1-5, and the pre-tests of the corresponding secondary mini-bottles indicate that the primary sample bottle 3 contains the best sample of the fluid for full tests, then the primary sample bottle 3 can be chosen for complete tests while the primary sample bottles 1, 2, 4, and 5 can be eliminated for testing thereby reducing costs. In addition, after analyzing the secondary samples, one or more primary bottles of interest can be chosen for tests for removal and / or replacement with empty primary bottles before returning the system to the interior of the well. In some embodiments, one or more of the primary bottles can simply be left attached within the sample module before the system is returned to the well. In still further embodiments, all bottles of primary samples are removed and / or replaced after the secondary samples are removed and / or analyzed. In some modalities, the pre-tests of the secondary mini-bottles allow the analysis to be obtained more quickly, so that efficient decisions can be made about whether the drilling should continue or whether a section of the deposit should be produced.

The disclosure in this document includes embodiments of an apparatus for accessing a fluid sample of the formation including a sample bottle module of the The interior of the well includes a fluid flow line of the formation coupled to a bottle of primary samples, an adapter coupled within the fluid flow line of the formation, and a second sample bottle to be attached to the adapter and communicate with the fluid flow line of the formation. In some embodiments, the coupling between the primary sample bottle and the flow line is separated and part of the coupling in the adapter between the second sample bottle and the flow line. In some embodiments, the adapter seals the fluid flow line of the formation, and a transport valve seals the bottle of primary samples such that the bottle of secondary samples can be connected to and removed from the flow line independently of the bottle of primary samples. In some embodiments, the fluid flow is established between the second sample bottle and the flow line while a primary fluid sample from the formation is contained in the primary sample bottle. The apparatus may include a transport valve for sealing the primary sample bottle of the fluid flow line of the formation, and wherein the adapter is coupled within the fluid flow line of the formation upstream of the valve. transport. The apparatus may include a sample valve upstream of the adapter to capture a second volume of fluid from the separate formation of the primary sample bottle by the transport valve.

In some embodiments, the apparatus may include a first fluid transfer sensor coupled to the second sample bottle, a second fluid transfer sensor coupled to the adapter, or a combination thereof. The apparatus may include a sample module that includes a formation probe to receive fluids from the formation and direct fluids from the formation to the flow line.

In some embodiments, a method of accessing a fluid sample from the formation includes, through a fluid of the formation within a sample module and through a flow line, to flow the formation fluid towards a module. sample bottle and within a first bottle of samples to capture a first volume of formation fluid, capture a second volume of formation fluid in the flow line, and attach a second sample bottle within the line of flow to access the second fluid volume of the formation. The method can include redirecting at least a portion of the second volume of formation fluid to the interior of the second sample bottle. The method can including keeping the redirected portion of the second volume of fluid from the formation in a single phase. The method may include removing the second bottle of samples from the flow line independently of the first bottle of samples. The method may include testing the second fluid of the formation in the second sample bottle independently of the first fluid sample from the formation in the first sample bottle. The method may include removing the second sample bottle from the flow line and transporting the second sample bottle from a well site. The method may include collecting the gas evolved from the second formation fluid in the second sample bottle. The method may include accessing the second sample bottle before accessing the first sample bottle. The method may include, before coupling the second sample bottle within the flow line, recovering the sample module and the sample bottle module to the surface of a well, applying pressure from an external source to the first bottle of sample. samples to increase the formation fluid pressure in the first sample bottle and the flow line, close a valve in the first sample bottle, and capture the second volume of formation fluid in the flow line in the pressure increased. The method may include maintaining the increased pressure of the formation fluid in the flow line using a drain adapter, then coupled the second sample bottle to the drain adapter to access and recover the increased pressure of the formation fluid from the flow line.

In some embodiments, a method for accessing a fluid sample from the formation includes capturing a second volume of fluid from the formation in a flow line coupled to a primary sample bottle with a primary fluid volume of the formation, accessing the second volume of formation fluid with a second sample bottle coupled within the flow line, and recovering the second formation fluid with the second sample bottle. In some embodiments, the capture of the second volume of fluid from the formation in the flow line also includes drawing a fluid from the formation into a sampling tool and through the flow line, flowing the formation fluid to the inside the bottle of primary samples, and close a primary sample bottle valve to capture the primary volume of the formation fluid and isolate the second volume of fluid from the formation in the flow line. The method may include closing a sample valve upstream of the primary sample bottle valve for capture the second volume of fluid from the formation in the flow line upstream of the primary sample bottle. The method may include analyzing the second fluid of the formation at a well site. The method may include analyzing the second fluid in the formation, and determining a quality of the primary fluid in the formation based on the analysis of the second formation fluid. The method may include analyzing a plurality of second fluid volumes of the corresponding formation each with a different primary sample bottle, and removing or replacing one or more of the primary sample bottles based on analyzes of the second formation fluid. . The method can include analyzing a plurality of second fluid volumes of the corresponding formation each with a different primary sample bottle, and returning one or more of the primary sample bottles to the well based on analyzes of the second formation fluid. .

The modalities set out in this document are only illustrative and do not limit the scope of the disclosure to the details in them. It will be appreciated that many other modifications and improvements may be made to the disclosure of this document without departing from the scope of the disclosure or the inventive concepts disclosed in this document. For example, secondary bottles or The mini-samples described in this document for accessing and receiving the secondary volume of fluid from the captured formation can be from other types of fluid containers and vehicles for receiving and / or transporting the fluids from the formation of the volume section captured from the fluid flow line of the formation that leads to the bottle of primary samples. Because many variable and different modalities can be made within the scope of the inventive concept taught in this document, including equivalent structures or materials that are considered in the following, and because many modifications can be made in the detailed modalities in this document in accordance with the descriptive requirements of the law, it must be understood that the details of this document should be interpreted as illustrative and not in a limiting sense.

Claims

NOVELTY OF THE INVENTION Having described the present invention as above, it is considered as a novelty and, therefore, the content of the following is claimed as property: CLAIMS

1. An apparatus for accessing a fluid sample of the formation, comprising: a sample bottle module inside the well that includes a fluid flow line of the formation coupled to a bottle of primary samples; an adapter coupled within the fluid flow line of the formation; Y a second bottle of samples to attach to the adapter and communicate with the fluid flow line of the formation.

2. The apparatus according to claim 1, characterized in that the coupling between the primary sample bottle and the flow line is separated and the coupling part in the adapter between the second sample bottle and the flow line.

3. The apparatus according to claim 1, characterized in that the adapter seals the flow line of fluid from the formation, and a transport valve seals the primary sample bottle such that the second sample bottle can be connected to and removed from the flow line independently of the primary sample bottle.

4. The apparatus according to claim 1, characterized in that the fluid flow is established between the second sample bottle and the flow line while a primary fluid sample of the formation is contained in the bottle of primary samples.

5. The apparatus according to claim 1 further comprises a transport valve for sealing the bottle of primary samples from the formation fluid flow line, and wherein the adapter is coupled within the fluid flow line of the formation. formation upstream of the transport valve.

6. The apparatus according to claim 5 further comprises a sample valve upstream of the adapter for capturing a second volume of fluid from the separate formation of the primary sample bottle by the transport valve.

7. The apparatus according to claim 1, further includes a first fluid transfer sensor coupled to the second sample bottle, a second sensor of fluid transfer coupled to the adapter, or a combination thereof.

8. The apparatus according to claim 1, further includes a sample module including a formation probe to receive fluids from the formation and direct the fluids from the formation to the flow line.

9. A method to access a fluid sample of the formation, comprising: attract a formation fluid into a sample module and through a flow line; flowing the formation fluid to a sample bottle module and into a first sample bottle to capture a first volume of formation fluid; capture a second volume of fluid from the formation in the flow line; Y attach a second bottle of samples within the flow line to access the second volume of fluid in the formation.

10. The method according to claim 9 further comprises redirecting at least a portion of the second volume of formation fluid to the interior of the second sample bottle.

11. The method according to claim 10, further comprises maintaining the redirected portion of the second volume of formation fluid in a single phase.

12. The method according to claim 9 further comprises removing the second sample bottle from the flow line independently of the first sample bottle.

13. The method according to claim 10, further comprises testing the second fluid of the formation in the second sample bottle independently of the first fluid sample of the formation in the first sample bottle.

14. The method according to claim 9 further comprises removing the second sample bottle from the flow line and transporting the second sample bottle from a well site.

15. The method according to claim 10, further comprises collecting gas released from the second formation fluid in the second sample bottle.

16. The method according to claim 9, further comprises accessing the second sample bottle before accessing the first sample bottle.

17. The method according to claim 9, further comprises, before coupling the second bottle of Samples within the flow line: recover the sample module and the sample bottle module to the surface of a well; apply pressure from an external source to the first sample bottle to increase the formation fluid pressure in the first sample bottle and the flow line; close a valve in the first bottle of samples; and capture the second volume of formation fluid in the flow line at the increased pressure.

18. The method according to claim 17 further comprises maintaining the increased pressure of the formation fluid in the flow line using a drain adapter, then coupling the second sample bottle to the drain adapter to access and recover the increased pressure of the flow of the formation from the flow line.

19. A method to access a fluid sample of the formation, comprising: capturing a second volume of formation fluid in a flow line coupled to a bottle of primary samples with a primary volume of formation fluid; to the second volume of fluid of the formation with a second sample bottle coupled within the flow line; Y receive the second fluid from the formation, the second sample bottle.

20. The method according to claim 19, characterized in that capturing the second volume of formation fluid in the flow line further comprises: attract a formation fluid into a sampling tool and through the flow line; flowing the formation fluid into the bottle of primary samples; Y Close a valve in the primary sample bottle to capture the primary volume of the formation fluid and isolate the second volume of fluid from the formation in the flow line.

21. The method according to claim 20 further comprises closing a sample valve upstream of the primary sample bottle valve to capture the second volume of formation fluid in the flow line upstream of the primary sample bottle .

22. The method according to claim 19, further comprises analyzing the second formation fluid at a well site.

23. The method according to claim 19, further comprises analyzing the second fluid of the formation, and determining a fluid quality of the primary formation based on the analysis of the second formation fluid.

24. The method according to claim 19, further comprises: analyzing a plurality of second volumes of fluid of the corresponding each formation with a different primary sample bottle; Y remove or replace one or more of the primary sample bottles based on analyzes of the second formation fluid.

25. The method according to claim 19, further comprises: analyzing a plurality of second volumes of fluid of the corresponding each formation with a different primary sample bottle; Y return one or more of the primary sample bottles to the well based on analyzes of the second formation fluid.