Untitled record

Full description

Sister Ar'a's background

The present disclosure relates generally to downhole operations, and more specifically to positive indication of suitable operation of a downhole tool.

U.S. Application No. 2013020088 relates to downhole injection and flow control means

<p dir="rtl">5 Downhole flow control and injection devices. More specifically, this patent specification relates to selective control of flow control and injection means installed in a wellbore using targeted chemistry.</p>

US Application No. 2009151939 relates generally to the field of subsurface surveillance and communications technologies. More specifically, the invention relates to the use of tracers or marker materials

<p dir="rtl">10 materials in combination with wired tubulars for subsurface measurements. Said document discloses a downhole system that includes at least one tag designed to capture a recognizable specific agent, an assembly for selective release of a subsurface location, and at least one sensor positioned in a downhole to detect at least one tag at a subsurface location. At least one sensor may be designed to transmit a signal</p>

<p dir="rtl">15 Associated with at least one detected mark of a surface.</p>

U.S. Application No. 2010245096 relates to optical analysis systems for analyzing fluids, for example, crude petroleum, i.e., flowing in a pipe, into a crude petroleum well, or extracted from, from, or out of a well. Weigh, specifically, with optical analysis systems for these fluids.

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International Application No. 0173423 relates to equipment and methods used in drilling and completing wells, such as oil wells and gas wells, and in producing fluids from these wells, as the aforementioned documents reveal a device that can be used in the method described above. This device is described in more detail below.

<p dir="rtl">5 U.S. Application No. 2008223586 relates to downhole tools and, specifically, a ball actuator downhole release tool.</p>

General description of the invention

Hydrocarbon-producing wells are often stimulated by hydraulic fracturing processes to improve the production of hydrocarbons found in subterranean formations. During a typical fracturing process, service fluid may be injected

(i.e., a fracturing fluid or perforating fluid) in a subterranean formation penetrated by a wellbore at hydraulic pressure sufficient to create or enhance fractures within the subterranean formation. The resulting fractures increase the conductivity potential to extract hydrocarbons from the subterranean formation.

<p dir="rtl">15 In some wellborings, several fractures may preferably be produced strategically along the wellbore at predetermined distances from each other, creating numerous “sink zones” in the subterranean formation. Some yielding zones can extend a significant distance along the axial length of the wellbore. To sufficiently fracture the subterranean formation containing these subducted zones, it may be preferable to introduce a stimulating fluid through several stimulating assemblies placed within the wellbore at locations spaced apart from</p>

<p dir="rtl">20 each other on a series of running tubes extending within it. Each stimulation assembly, generally referred to as sliding sleeve assemblies, may include, for example, a sliding sleeve configured to open and/or close to regulate fluid communication between the interior of the drive pipe string and the surrounding subterranean formation.</p>

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In some uses, the sleeve can be opened or actuated by inserting a wellbore projectile, such as a ball or dart into a string of operating tubing. The wellbore shell is transported to the bushing location which engages an internal baffle or seat marked on the inner surface of the drive tubing string. Once the wellbore shell is adequately seated in its corresponding internal diaphragm, it is pressurized

<p dir="rtl">5 Operating tube series up to a predetermined pressure. The increased pressure drives the bushing through a combination of mechanical or hydraulic means. As measured on the surface, the predetermined increased pressure acts as an indicator that the sleeve will open or move as planned.</p>

In some cases, however, the increased pressure in the drive tube string does not actually cause the 10 bushing to move. Alternatively, excessive pressure can sometimes force the wellbore shell to extrude past the barrier without

Actually causing the bushing to turn on. However, in these cases, the excess pressure is measured on the surface and the operator is mistakenly informed that the bushing has moved when in fact the bushing remains stationary throughout the pressure conditioning process. As a result, subsequent wellbore operations that require sleeve movement as planned will be inefficient and result in lost time and costs.

15 Brief explanation of the drawings

The following figures are included to illustrate certain aspects of the present disclosure, and should not be considered as exclusive embodiments. Modifications, changes, combinations thereof, and equivalents in form and function can be introduced to the artistic subject matter that has been disclosed, as will become clear to those skilled in the field once they benefit from this disclosure.

<p dir="rtl">20 Figure 1 is a schematic diagram of an illustrative well system that can embody or utilize one or more of the principles of the present disclosure, according to one or more embodiments.</p>

Figures 2a and 2b are enlarged cross-sectional views of an illustrative downhole tool, according to one or more embodiments.

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Figure 3 is an illustrative combined account element, according to one or more embodiments.

Figure 4 is a schematic diagram of an illustrative optional computing device, according to one or more embodiments.

Detailed description:

<p dir="rtl">5 The present disclosure relates generally to downhole operations and, more specifically, to the positive indication of proper operation of a downhole tool.</p>

The systems and methods disclosed provide a positive indication for a well operator to operate a downhole tool, such as a sliding sleeve assembly. The downhole instrument may include an indicator chamber containing or retaining a supernatant that can be detected at the surface using one or more optical computational means.

<p dir="rtl">10 When a downhole tool is operated, for example when a sliding sleeve moves from its closed to its open configuration, the indicator chamber can become exposed and the supernatant can be released into the drive string. As long as the material is buoyant compared to the fluid actually placed inside the drive tube string, it tends to float toward the surface. Once the material is detected by the optical computer method, a signal can be sent that provides the well operator with positive indication that the sliding sleeve has moved.</p>

<p dir="rtl">15 Already to the open body. At this point, the well operator can confidently conduct or perform subsequent well operations that require the slip sleeve in the open configuration.</p>

Referring to Figure 1, an illustrative well system 100 is illustrated that can embody or utilize one or more of the principles of the present disclosure, according to one or more embodiments. As shown, the well system 100 can include an oil and gas rig 102 placed on

<p dir="rtl">20 The surface of the Earth 104 and a wellbore 106 extending from it and penetrating a subterranean earth formation 108. It should be understood that although Figure 1 depicts an oil and gas drilling rig located on land 102, it will be understood that embodiments of the present disclosure are similarly suitable for use on other types of drilling rigs, such as offshore platforms, or drilling rigs used at any offshore site. last.</p>

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The rig 102 may include a jack 110 derrick and a rig floor 112, and the jack 110 may hold or assist in the pivot position of a string of drive tubing 114 extending into the wellbore 106 from the rig floor 112. As used herein, the term “ “running pipe string” to one or more types of continuous lengths of tubular components 5 as known in the art, which may include, but are not limited to, drill pipe, drill pipe string, ground pipe string, production tubing, casing, liners, and combinations thereof. , or something like that. In other embodiments, the work string 114 may represent any other downhole conveyance known to those skilled in the art such as, but not limited to, coiled tubing, wireline, slickline, and the like, without departing from

<p dir="rtl">10 About the field of detection. The drive tube string 114 may be connected to the surface 104 and in at least one embodiment, may include an open-hole section between the drive tube string 114 and the surface 104 (e.g. as at the side when there is often an open-hole section at the connection). In an illustrative process, The operating tubing series 114 may be used for drilling, stimulating, completing, or servicing the wellbore 106, or many combinations thereof.</p>

<p dir="rtl">15 As shown, the wellbore 106 can extend substantially arcuate away from surface 104 over an arcuate wellbore portion. In other embodiments, the wellbore 106 can be deflected at any angle from the surface 104 on a skewed or horizontal wellbore portion. In other uses, parts of or substantially all of the wellbore 106 may be arcuate, oblique, horizontal, and/or curved. Furthermore, directional terms such as up, down, up, down, up, down, top 20 well, downhole, and the like are used for the illustrative embodiments as shown in the figures, the up direction being towards the top of the corresponding figure and the direction being Down towards the bottom of the corresponding figure, the direction at the top of the well is towards the surface of the well and the direction at the bottom of the well is towards the bottom or bottom of the well.</p>

In one embodiment, the wellbore 106 can be at least partially encased with casing tubing string 116 25 or can remain at least partially uncased. The casing tube series can be installed 116 in

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Place it within the wellbore 106 using, for example, cement 118. In other embodiments, the casing tubing string 116 may be only partially cemented within the wellbore 106 or, alternatively, the casing tubing string 116 may not be completely cemented. A lower portion of the operating pipe string 114 may extend within a sub or side portion 120 of a pit

<p dir="rtl">5 Well 106. As shown, the side section 120 can be an uncased or “open-hole” section of wellbore 106. It is noteworthy that although Figure 1 depicts both horizontal and vertical sections of wellbore 106, instrumentation principles can be applied , systems, and methods similarly disclosed or suitable for use in fully horizontal or vertical wellbore configurations. Subsequently, the horizontal or horizontal nature of wellbore 106 should not be construed as restricting the present disclosure in any way.</p>

<p dir="rtl">10 Wellbore 106 identified.</p>

The drive tubing string 114 may be placed or anchored within the side portion 120 of the wellbore 106 using one or more packers 122 or other wellbore isolation means known to those skilled in the art. Gaskets 122 may be configured to prevent leakage from a seal off annular space 124 an annulus defined between the series of operating tubes 114 and the walls of the 15 106 wellbore. As a result, the 108 subterranean formation can be divided

effectively into a plurality of separations or “pay zones” which can be independently stimulated and/or produced across isolated portions of toroidal space 124 defined between adjacent pairs of pay zones 122. While only three pay zones are shown in Figure 1, owners will realize Skill in the field Easily the possibility of using any number of boiling areas in the 100 well system, without 20 moving away from the detection field.

The well system 100 may also include one or more downhole tools 126 (shown in Figs. 126a, 126b, and 126c) disposed in, coupled to, or forming an integrated part of the drive tubing string 114. As shown, a tool may be located down at least one well 126 in the operating pipeline series 114 in each closed area, except that those skilled in

<p dir="rtl">25 The field will easily realize the possibility of placing more than one tool down one well 126 in it, without moving away from</p>

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Detection field. The downhole tool 126 may include a set of tools, methods, or machines known to those skilled in the art that can be used in preparing, stimulating, and producing subterranean formation 108. In at least one embodiment, the downhole tool 126 may include in each yield zone. Or it can be a sliding bushing assembly that can be machined to provide

<p dir="rtl">5 A fluid connection between the annular space 124 and the interior of the operating tubing string 114. In other embodiments, the downhole tool 126 can be a fluid collection device such as a fluid sampling device or a fluid restriction device such as a valve, a flow control device, an independent flow control device , adjustable flow control device, or similar. In still other embodiments, downhole instrument 126 may include two or more of the means specified above, without departing from the detection field.</p>

<p dir="rtl">10 Referring to Figures 2a and 2b, and continuing to refer to Figure 1, enlarged cross-section views of an illustrative downhole tool, such as one of the downhole tools 126 of Figure 1, are shown in accordance with one or more embodiments. In the shown embodiment, the downhole tool 126 can be a sliding sleeve assembly that includes an elongate body 202 that is threaded or coupled to the drive tubing string 114 at their opposing ends. The body 202 can define a central corridor in</p>

<p dir="rtl">15 Its internal portion 206 is such that a flow path 204 is provided that connects via fluid the drive tubing string 114 to the downhole tool 126. The flow path 204 can be configured to extend along the entire length of the drive tubing string 114.</p>

The body 202 may also specify one or more flow ports 208 configured to provide a fluid connection between the annular space 124 annulus and the interior 206 of a running pipe string 20 114. In some embodiments, the flow ports 208 may be equipped with one or more means

Flow control (e.g., nozzles, erodible nozzles, inflow control devices, flow restrictors, and so on). In other embodiments, flow ports 208 may be equipped with one or more plugs , screens, covers, or protectors, shields

<p dir="rtl">25 For example, to prevent debris from entering the interior 206 of the drive tube string 114.</p>

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Sleeve 210 can be movably positioned or slidable within the inner portion 206 between the open and closed bodies. For example, the sleeve 210 in FIG. 2A is depicted in a closed configuration where the sleeve 210 generally blocks the flow ports 208 preventing fluid contact between the annular space 124 and the interior 206 of the drive tube string 114. Figure 2B, however, 5 depicts the sleeve 210 in an open configuration where the sleeve 210 is moved axially within the inner portion 206 such that the flow ports 208 are exposed and thus fluid contact between the annular space 124 and the inner portion 206 occurs or is facilitated by it. With the sleeve 210 in the open configuration, a plurality of fracturing or stimulating fluids can be drained from the driver tubing string 114 or downhole tool 126 through the flow ports 208 to stimulate the surrounding formation 108. Alternatively, with the sleeve 210 in the open configuration 10, fluids derived from the configuration 108 and annular space 124 can be drawn into a series of tubes

Operating 114 through flow ports 208 and outputting to the surface 104 (Figure 1) for processing.

In one or more embodiments, the bushing 210 can be retained in the closed form using at least one suitable retention mechanism, such as one or more frangible members 212. The frangible member 212 can be, for example, a shear pin, a shear ring , or 15 the like, and can be placed in corresponding holes in both the body 202 and the sleeve 210 . Once subjected to or exceeding a predetermined shear limit, the brittle member(s) 212 can be conditioned to shear thus allowing the sleeve 210 to slide axially in the inner portion 206 into its open conformation, as shown in Figure 2b.

In the open configuration, in at least one embodiment, the sleeve 210 can be configured to rest on a trunnion or shoulder bracket 20 (not shown) provided or specified in the body 202 to prevent the sleeve 210 from advancing further down the well (e.g., on the right in Figures 2a and 2b). (.In other embodiments, the sleeve 210 may be retained in the open form using a suitable retention mechanism, such as a snap ring 214 or the like. The snap ring 214 can be received and/or carried in a defined groove in the sleeve 210 and prepared for expansion once a specific complementary groove 216 25 has been located in the body 202. As depicted in Fig. 2b, the snap ring 214 is successfully positioned.

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In the groove 216 located in the body 202 and then causes the axial movement of the sleeve 210 to stop in the downhole direction.

In one or more embodiments, the bushing 210 can be moved from its closed configuration (Figure 2a) to its open configuration (Figure 2b) using one or more wellbore 5 projectiles (not shown) inserted into the drive tubing string 114 from surface and transported to Downhole tool 126. Illustrative wellbore shells include, but are not limited to, card, stock, and plugs, as generally known in the art. Bushing 210 may include or define a seat or guard 218 configured to receive, engage, and/ Or detention of a wellbore shell to a specific size and/or shape. As shown, the barrier 218 can exhibit a reduced train compared to the diameter of the flow path 204 and thus 10 can be configured to engage and generally prevent the wellbore shell from advancing further down the well past the barrier.

<p dir="rtl">218. Once the wellbore shell is suitably engaged on or with the barrier 218, fluid contact is substantially prevented past the barrier 218 in the downhole direction, allowing flow path pressure 204 to be hydraulically adapted from the surface. Once the flow path pressure 204 is conditioned, the predetermined shear limit of the brittle members 212 can be reached to shear the members 212 and allow movement</p>

15 The sleeve 210 is pivoted down the well to its open shape.

In other embodiments, the sleeve 210 may be displaced and moved using a displacement tool (not shown), such as a mechanical shifter. In this embodiment, the sleeve 210 may include one or more lugs, catches, keys, grippers, and/or structures Complementary to one or more lugs, catches, keys, grippers, and/or corresponding structures of an illustrative displacement tool. Once the displacement tool 20 is properly coupled to the sleeve, a force can be applied from the surface and transmitted to the sleeve 210 via the displacement tool. Disclosed

Suitable offset devices are provided in U.S. patent applications serial numbers 12/538079 and 12/566467, each of which is incorporated herein by reference in their entirety.

In still other embodiments, the downhole tool 126 can also include at least one actuation means 220 that is effectively coupled to or forming an accessory part of the downhole tool 126. 25 The actuation means 220 can be configured to move the sleeve 210 axially within the inner portion 206 of the body 202 between

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Open and closed bodies. Actuation device 220 can include, but is not limited to, an electromechanical actuation device such as an electromechanical actuator, mechanical actuator, hydraulic actuator, pneumatic actuator

<p dir="rtl">5 pneumatic actuator, piezoelectric actuator, solenoid, combinations thereof, and the like. In other embodiments, the actuating device 220 may be equipped with electric motor power, hydraulic fluid pressure, pneumatic pressure, combinations thereof, and the like. Thus, in at least one embodiment, the sleeve 210 can be moved back and forth between the open and closed bodies.</p>

<p dir="rtl">10 In one or more embodiments, the body 202 may also specify or provide an indicator chamber 222. In some embodiments, the indicator chamber 222 can be a notch or recess extending in the diameter direction identified in the inner surface of the inner part 206. In other embodiments, however, the indicator chamber 222 can be any specified appropriate recess, depression, notch or block. On the inner surface of the inner portion 206. The volume of the indicator chamber 222 can be determined</p>

<p dir="rtl">15 In general, forming or preparing it to receive and detain Article 224 when a commotion occurs 210 in the body.</p>

Closed. Once the sleeve 210 moves from the closed to the open configuration, however, the indicator chamber 222 becomes exposed to the inner portion 206 of the driver tube series 114 and would otherwise be able to release material 224 into the inner portion 206 and flow path 204.

As will be described in greater detail below, the material 224 can be or include a floating fluid or material 20 as opposed to the fluid actually placed in the flow path 204. As a result, once it is released from the indicator chamber

222, the material 224 can be configured to float toward the surface 104 (Figure 1) within the flow path 204.

Once at the surface 104, the material 224 can be exposed to provide a positive open indication to a well operator that the bushing 210 has moved from the closed to the open position. As will be realized, knowing that the sleeve 210 has successfully moved from the closed to the open position may allow

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The well operator can reliably perform subsequent well operations, which require the bushing 210 to be in the open form.

Referring back to Figure 1, and continuing to refer to Figures 2a and 2b, the well system 100 may also include at least one optical computing device

<p dir="rtl">5 128 is positioned within the flow path 204 or is in optical contact with the flow path 204.</p>

While only one optical computational method 128 has been described, it will be recognized that any number of optical computational methods 128 can be used, without departing from the scope of the disclosure. In some embodiments, the optical computing facility 128 may be located within the wellbore 106 near the surface 104, as shown. In other embodiments, however, the optical computing medium 128 may be placed on the surface

<p dir="rtl">10 104, such as on the drilling rig 102. In still other embodiments, the computing facility may be located</p>

The optical sensor 128 is at any intermediate location within the well system 100 (e.g., between the surface 104 and the downhole tools 126a-c) as long as it remains in optical contact with the flow path 204, without moving out of the detection field.

As shown, the optical computing device 128 can be effectively coupled to a computer system 130

<p dir="rtl">15 or the like placed on the surface 104 over one or more communication lines 132. The communication line(s) 132 may be any wired or wireless means of remote communication between two locations and may include, but is not limited to, electrical lines, fiber lines Optical, radio frequency transmission, electromagnetic telemetry, acoustic telemetry, or any other type of telecommunications means known to those skilled in the art. In at least one embodiment, it can</p>

20 The optical computing medium 128 forms an integrated part of the computer system 130.

In an illustration, the indicator chamber 222 can be configured to hold a predetermined concentration or amount of substance 224 and the optical computing device 128 can be configured to continuously monitor the flow path 204 to detect substance 224 when it floats toward the surface 104 upon its release from the indicator chamber 222. Optical computing method 128 for matter 224 (or a specific characteristic thereof),

<p dir="rtl">25 It may deliver a signal indicating this to the computer system 130 via communication lines</p>

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<p dir="rtl">132. The well operator may be able to consult the computer system 130, such as one or more peripheral means associated with it (e.g., a monitor, a printed form from a printer, an audible or visual alarm, and so on), and thus become aware, at the time Actual, at the time when the optical computing device 128 definitely detects the substance 224 (or a specific property thereof).</p>

<p dir="rtl">5 Therefore, the well operator can be provided in real time with a positive indication that the bushing 210 has successfully moved from the closed to the open position.</p>

A description of the illustrative optical computing device 128 and its illustrative operation will now be presented. As used herein, the term “optical computing device” means an optical measuring device configured to receive input electromagnetic radiation associated with a material (i.e., material 224) and produce an output radiation

<p dir="rtl">10 Electromagnetic radiation from a processing element housed within or forming an integral part of an optical computing medium. The processing element could be, for example, an integrated ICE (computational element). The electromagnetic radiation that optically interacts with the processing element is changed to be readable by the detector, so that the detector's output can be linked to a substance or a specific property of it. It can reflect radiation output</p>

<p dir="rtl">15 Electromagnetic radiation from the processing element, transmitted electromagnetic radiation, and/or scattered electromagnetic radiation. In addition, the transmission and/or scattering of a fluid or phase thereof can also be monitored, for example via fluorescence, luminescence, Mie, Raman, and/or Raleigh scattering, by optical computational means.</p>

As used herein, the term “substance,” or variants thereof, refers to a floating substance or object

<p dir="rtl">20 An interest that will be tested or evaluated using a visual computational method, as described here. In agreement with Archimedes' principle, matter is considered "buoyant" in that it generally floats with a force equal to the weight of the surrounding fluid being displaced by the matter. In the present disclosure, the ambient fluid includes the fluid placed within the drive tube string 114 or flow path 204. The material may include a property of interest, as defined below, and may be any fluid or any solid material that is buoyant and thus configured</p>

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To float in the direction of the optical computing device 128 of Figure 1 once it is released from its indicator chamber 222 (Figures 2a-2b).

In one or more embodiments, the material may be trapped in the fluid placed within the drive pipe string 114 and/or flow path 204. For example, when the material is trapped in the fluid, it causes

<p dir="rtl">5 Hydraulic forces that affect the material in moving the material with the fluid flow. The readiness of a substance to be trapped in a fluid depends on the shape of the substance (or the particles that make up the substance), the viscosity of the fluid, the relative density between the fluid and the substance, and the probability of the substance being dissolved in or by the fluid. In some embodiments, the substance can be trapped in the fluid without being buoyant at all. is larger than the fluid. In other words, matter can be transported or flowed to the surface 104 by being trapped in</p>

<p dir="rtl">10 fluid or its buoyancy relative to the fluid, or a combination of the two.</p>

As used herein, the term "fluid" refers to any substance capable of flow, including particulate solids, liquids, gases, slurries, emulsions, powders, clays, glasses, mixtures, Combinations thereof, and the like.

<p dir="rtl">15 The fluid can be a single-phase or multi-phase fluid. In some embodiments, the fluid can be an aqueous fluid, including water, b-arene solutions, or the like. In other embodiments, the fluid can be a non-aqueous fluid, including organic compounds, more specifically, hydrocarbons, petroleum, a refined component of petroleum, petrochemical products, and the like. In some embodiments, the fluid can be a process fluid, a fracturing fluid, or a formation fluid as found in</p>

<p dir="rtl">20 Oil and gas industry. The fluid may include alcohols, esters, sugars, coatings, waxes, combinations thereof, and the like. The fluid may also include one or more solids or particulate solids trapped in it. For example, fluids can include many flowable mixtures of solids, liquids and/or gases. Illustrative gases that may be considered fluids according to the present embodiments include, for example, air, nitrogen,</p>

<p dir="rtl">25 Carbon dioxide, argon, helium, methane</p>

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methane, ethane, butane, other hydrocarbon gases, combinations thereof, and/or the like.

As used herein, the term “property” refers to a chemical, mechanical, or physical property of a substance (i.e., substance 224), such as a floating fluid or a solid. Property can also refer to the property

<p dir="rtl">5 Chemical, mechanical, or physical phase of matter. Illustrative properties of a substance that can be detected or monitored by optical computational means disclosed herein may include, for example, chemical composition (e.g., identity and concentration of the total or individual components), presence of phase, impurity content, pH , viscosity, density, ionic strength, total dissolved solids, salt content, porosity,</p>

<p dir="rtl">10 Opacity, bacterial content, concentration, combinations thereof, color, state of matter (e.g., solid, liquid, gaseous, emulsion, mixtures, and so on), and the like. Other illustrative characteristics may include volumetric flow rate or mass flow rate flow rate.</p>

As used herein, the term “flow path” refers to a path along which a material can be transported between two points. In some cases, the flow path need not be continuous or touching between the two points.

<p dir="rtl">15 Illustrative flow paths include, but are not limited to, a flow line, a pipeline, a production pipe or tubing, a run of pipe, a defined annular space between a wellbore and a pipeline, a hose, a processing facility, a storage vessel, an oil tanker, a rail tank car Railroad, transport ship or vessel, subterranean formation, combinations thereof, or the like. In cases where the flow path is a pipeline, or similar, the pipeline can be a pre-commissioned pipeline or an active pipeline.</p>

<p dir="rtl">20 In other cases, the flow path can be created or produced by moving an optical computational device through a fluid (for example, an open air sensor). In still other cases, the flow path need not necessarily be contained within any solid structure, but rather refers to the path that passes In which the fluid flows between the two points, such as when the fluid flows from one location to another without including it, itself. It is worth noting that the term “flow path” does not necessarily imply the flow of the fluid in it, but rather that it can be transferred</p>

<p dir="rtl">25 The fluid or its flow through it.</p>

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As used herein, the term “electromagnetic radiation” refers to radio waves, microwave radiation, infrared and near-infrared radiation, visible light, infrared radiation ultraviolet light,

<p dir="rtl">5 X-ray radiation and gamma ray radiation</p>

As used herein, the term “photoreactive” or its variants refers to the reflection, transmission, scattering, diffraction, or absorption of electromagnetic radiation either onto, through, or from one or more processing elements (i.e., embedded computational elements), or Substance. Thus, photoactive light refers to the reflection, transmission, scattering, diffraction, or absorption of electromagnetic radiation, or

<p dir="rtl">10 Re-irradiation, for example, using a built-in computational component, but it can also apply to interaction with a substance.</p>

As noted above, the processing element used in the optical computing demonstration device 128 may be an integrated computational element (ICE). When operational, the ICE component is capable of recognizing electromagnetic radiation related to a material or a property of it

<p dir="rtl">15 From electromagnetic radiation related to other components or decomposition products of the substance. Referring to Figure 3, an illustrative ICE 300 is illustrated, according to one or more embodiments. As shown, ICE 300 can include a plurality of alternating layers 302 and 304, such as silicon (Si) and silicon dioxide (quartz), respectively. In general, these layers 302, 304 are composed of materials that are Their reflectivity index is high and low, respectively</p>

<p dir="rtl">20 Other examples of niobium materials include niobia, niobium, germanium, germanium, SiO, MgF, germania, and other high- and low-index materials known in the art. Layers 302, 304 can be strategically placed on an optical substrate 306. In some embodiments, the optical substrate 306 is a 7-BK optical glass. In other embodiments, the optical substrate 306 can be another type of optical substrate, such as quartz,</p>

<p dir="rtl">25 sapphire, silicon, germanium, zinc selenide</p>

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selenide, zinc sulfide, or many plastics such as polycarbonate, polymethylmethacrylate (PMMA), polyvinylchloride (PVC), diamond, ceramics, combinations thereof, and the like.

<p dir="rtl">5 At the opposite end (e.g., the corresponding optical substrate 306 in Figure 3), the ICE 300 may include a layer 308 that is generally exposed to the environment of the facility or facility and is capable of optical interaction with electromagnetic radiation or matter 224 (Figures 2a-2b). Determine the number of layers 302, 304 and the thickness of each layer 302, 304 from spectral features obtained from spectrophotometric analysis of a property of the material being analyzed using a conventional spectrophotometric instrument.</p>

<p dir="rtl">10 It should be understood that the illustrative ICE 300 in Figure 3 does not actually represent any specific property of a material, but is provided for illustrative purposes only. Thereafter, there are a number of layers 302, 304 and their relative thicknesses, as shown in Figure 3, not related to any specific property. Furthermore, those skilled in the art will already recognize that the materials comprising each layer 302, 304 (i.e., silicon and silicon dioxide) may vary, depending on the application, cost of materials, and/or</p>

<p dir="rtl">15 Usability of the material with the material being analyzed.</p>

In some embodiments, the material of each layer 302 , 304 can be doped or two or more materials can be combined in a manner that allows the preferred optical property to be achieved. In addition to solids, the demonstration ICE 300 can also contain liquids and/or gases, optionally in combination with solids, to produce a preferred optical characteristic. In the case of gases and liquids, the ICE 20 300 may include a corresponding receptacle (not shown), which contains the gases or liquids. It may include

Various illustrative images of the ICE 300 also include holographic, grating, piezoelectric, light tube, and/or photoacoustic elements, for example, which can create the transmission, reflection, and/or absorption properties of interest.

The several layers 302, 304 show different reflectivity indices. And by choosing layer materials

<p dir="rtl">25 302, 304 and their relative thickness and spacing, 300 ICE can be configured to pass/reverse/break</p>

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A pre-determined portion of electromagnetic radiation selectively at different wavelengths. Each wavelength is given a pre-defined weighting or load factor. The thickness and spacing of layers 302, 304 can be determined using a variety of approximation methods from the property spectrum or analysis product of interest. These methods may include the inverse Fourier transform

<p dir="rtl">5 (IFT) of the optical transmission spectrum and the structure of the 300 ICE as a physical representation of the IFT. Approximations transform the IFT into a structure based on materials with known fixed refractive indices. More information on the structures and design of ICEs can be found in Applied</p>

,Vol. 29, pp. 2876-2893 (1990) and Optics, Vol. 35, pp. 5484-5492 (1996)

Which are included herein are referred to in their entirety.

<p dir="rtl">10 The values ​​applied by the ICE layers 302, 304 300 at each wavelength are adjusted to the return values ​​described in relation to a known equation, data, or spectral signature. When electromagnetic radiation interacts with a substance, individual physical and chemical information about the substance can be encoded in the electromagnetic radiation that is reflected from, transmitted through, or radiated from the substance. This information is often referred to as the spectral "trace" of the material. 300 ICE can be configured</p>

<p dir="rtl">15 To perform the dot product of the electromagnetic radiation received by the ICE 300 function</p>

Wavelength dependent transmission of the ICE 300. The wavelength-dependent transmission function of the ICE depends on the refractive index of the layer material, the number of layers 302, 304 and the layer thickness rates. The 300 ICE transmission function is then fit to a preferred regressor vector derived from the solution of the linear multivariate problem targeting a specific component of the sample material being analysed. As a result,

<p dir="rtl">20 The resulting light intensity of ICE 300 is related to the property or degradation product of interest.</p>

Optical computational methods using these ICEs may be able to infer information about the spectral effect of various properties or degradation products within a material and convert that information into detectable output regarding the overall properties of the material. This means that with appropriate bodies of optical computational means, the electromagnetic radiation associated with the properties can be separated

<p dir="rtl">25 Or the decomposition products of interest in a substance resulting from electromagnetic radiation associated with all components</p>

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Other methods of the material to estimate the properties of the material in real time or near real time. Further details regarding how the ICE Illustration 300 recognizes and processes electromagnetic radiation associated with the property or degradation product of interest are described in U.S. Patent Nos. 6,198,531, 6,529,276, and 7,920,258, which are incorporated herein by reference.

<p dir="rtl">5 Referring now to Figure 4, and with reference to Figures 1, 2a and 2b, a schematic projection of the illustrative optical computing device, such as the optical computing device 128 of Figure 1, according to one or more embodiments is shown. Those skilled in the art will readily realize that it is not necessary to apply a drawing scale to the optical computing device 128, and its components described below, or more sharply, not necessarily depict it in an optically correct image as those of</p>

<p dir="rtl">10 Skill in optics. Instead, Figure 4 is only illustrative in nature and is used generally herein to complete an understanding of the description of the several illustrative embodiments. However, while Figure 4 may be photoaccurate, the conceptual explanations depicted therein accurately reflect the illustrative nature of many of the embodiments disclosed.</p>

As briefly described above, the optical computing device 128 can be positioned or configured to monitor

<p dir="rtl">15 The flow path 204 of the drive tube string 114 (Figures 2a and 2b) and reveals a substance 224 or a specific property thereof. As discussed above, the substance 224 can be a floater or an object capable of floating toward the surface 104 (Figure 1) after being released from a chamber. Their corresponding indicator 222 in the downhole tool 126 (Figures 2a and 2b). In some embodiments, the material 224 can be a fluid, but in other embodiments, the material 224 can be particulate matter</p>

20 A solid trapped in a fluid.

As shown, the optical computing device 128 may be housed in an enclosure or housing 402 configured to protect the internal components of the optical computing device 128 from damage or contamination from material 224 or any other material in the flow path 204. In some embodiments, the housing 402 can be operated to couple the device Optical computing 128 mechanically connected to a series of drive tubes 114 such that it is capable of

<p dir="rtl">25 Monitoring or optical interaction with the flow path 204. The housing 402 may be coupled to a series of tubes.</p>

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Operation 114 using, for example, mechanical fasteners, brazing or welding techniques, adhesives, magnets, combinations thereof, or the like.

Housing 402 can be designed to withstand pressure rates to which it may be exposed downhole and thus 5 provide a fluid seal against external contamination.

The optical computing device 128 can include an electromagnetic radiation source 404 configured to emit or generate electromagnetic radiation 406. The electromagnetic radiation source 404 can be any device capable of emitting or generating electromagnetic radiation, as defined herein. For example, it could be a radiation source

<p dir="rtl">10 Electromagnetic 404 Light bulb, light emitting diode, laser, blackbody, photonic crystal, X-ray source, combinations thereof, or the like.</p>

In some embodiments, lens 408 can be configured to collect or receive electromagnetic radiation 406 and direct a beam 410 of electromagnetic radiation 406 to a location for sampling or monitoring.

<p dir="rtl">15 Flow path 204 and material 224. The lens 408 may be any type of optical means adapted to transmit electromagnetic radiation 406 as desired and may include, for example, a normal lens, a Fresnel lens, a diffractive optical element, a holographic graphical element, mirror (e.g., focusing mirror), ray guide type</p>

<p dir="rtl">20 collimator, or any other means of transmitting electromagnetic radiation known to those skilled in the art. In other embodiments, the lens 408 can be dispensed with in the optical computing device 128 and the electromagnetic radiation 406 can instead be directed toward the material 224 directly from the electromagnetic radiation source 404. In still other embodiments, an optical light tube (e.g., cable or line) may be used Fiber optic cable or line (for transfer</p>

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Electromagnetic radiation 406. As will be understood, the use of optical light tubes may allow the optical computing device 128 to be placed in the configuration 108.

In one or more embodiments, the optical computing device 128 may further include a sampling window 412 positioned adjacent to or in contact with the flow path 204 on one side

<p dir="rtl">5 Lag land of discovery. The sampling window 412 can be made of a variety of transparent, solid materials</p>

or semi-rigid that is configured to allow electromagnetic radiation 406 to be transmitted through it. For example, sampling window 412 may be made, but is not limited to, of glass, plastics, semiconductors, crystalline materials, polycrystalline materials, hot or cold pressed powders, combinations thereof, or

<p dir="rtl">10 Similar.</p>

After passing through the sampling window 412, the electromagnetic radiation 406 impinges on and photo-interacts with the material 224 in the flow path 204. As a result, photo-interacting radiation 414 is generated by and reflected from the material 224. However, those skilled in the art will readily recognize that various images An alternative to optical computing method 128 may allow the generation of photoactive radiation 414

<p dir="rtl">15 By transmitting it through, scattering, or diffusing it by, absorbing it, emitting it from, or re-irradiating it with and/or from Article 224, without moving beyond the detection field.</p>

Photoreactive radiation 414 generated by interaction with matter 224 may be directed to or received by ICE 416 placed within the optical computing medium 128. ICE 416 may have a spectral component substantially similar to the ICE 300 described above with reference to FIG.

<p dir="rtl">20 3. Therefore, upon operation the ICE 416 can be configured to receive photoreactive radiation 414 and produce</p>

Modified electromagnetic radiation 418 corresponding to a specific property of matter 224. Specifically, the modified electromagnetic radiation 418 is electromagnetic radiation that optically interacted with 416 ICE, resulting in an approximate simulation of the recoil vector corresponding to the property of interest.

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It is noteworthy that, while Figure 4 depicts the ICE 416 receiving reflected electromagnetic radiation from the material 224, the ICE 416 can be positioned at any point along the optical chain of the optical computing device 128, without straying from the detection field. For example, in one or more embodiments, the ICE416 (as shown by the dashed line) can be placed within the optical chain 5 prior to the sampling window 412 and substantially the same results are achieved. In other embodiments, the sampling window 412 can serve the dual purpose of being a transmission window and 416 an ICE (i.e., a spectral component). In still other embodiments, the ICE 416 can produce modulated electromagnetic radiation 418 by reflection, rather than by transmission.

Furthermore, while only one ICE 416 is shown in the optical computing device 128, 10 embodiments are shown herein involving the use of two or more ICE components in the optical computing device 128 that monitor not more than one property of the material 224 in any given period of time. In these embodiments, a plurality of configurations may be used for a plurality of ICE components, where each ICE component is configured to detect a specific and/or distinctive property of interest. In some embodiments, the feature may be analyzed sequentially using a plurality of ICE components that are provided with a single beam of electromagnetic radiation 15 that is reflected from or transmitted through the material 224. In some embodiments, a plurality of ICE components may be placed on a rotating disk where the individual ICE components are exposed Only into the electromagnetic radiation beam for a short period of time. Advantages of this method may include the ability to analyze multiple properties of the material 224 using a single optical computational method and the opportunity to test additional properties simply by adding additional ICE components to the rotating disc 20. These are described as optional embodiments that use two or more components

ICE publishes pending US patent applications for the same serial numbers 13/546264, 13/456405, 13/456302, 13/456302, and 13/456327, the contents of which are incorporated herein by reference in their entirety.

In other embodiments, a plurality of optical computing devices 128 may be used at a single location 25 (or at least in close proximity) along the flow path 204, where each optical computing device includes

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Optical 128 on a unique ICE component that is configured to detect a specific property of interest. Each optical computing device 128 may be coupled to a corresponding detector or array of detectors configured to detect and analyze the electromagnetic radiation output from the respective optical computing device 128. Parallel bodies of optical computing device 128 may be particularly useful for applications requiring low power output rates and/ Or you don't need any moving parts.

The modified electromagnetic radiation 418 generated by the ICE 416 can then be transmitted to a detector

420 To determine the signal quantity. Detector 420 can be any device capable of detecting electromagnetic radiation, generally recognizable as an optical transducer. In some embodiments, detector 420 can be, but is not limited to, a thermal detector such as a thermal or sonic column detector

<p dir="rtl">10 Optical, semiconductor detector, piezoelectric detector, rotating charge-coupled device detector</p>

disc (CCD), visual detector or array, split detector, photon detector (such as a photomultiplier tube), photodiodes, combinations thereof, or the like, or other detectors known to those skilled in the art .

<p dir="rtl">15 In some embodiments, the detector 420 can be configured to produce an output signal 422 in real time or near real time in the form of a voltage (or current) corresponding to the specified property of interest in material 224. The return voltage from the detector 420 is essentially the dot product of the photoreaction of the radiation The photoreactivity 414 with the ICE of interest 416 as a function of the concentration of the property of interest of the substance 224. Thus, the output signal 422 generated by the detector 420 can be correlated</p>

<p dir="rtl">20 The concentration of the characteristic of interest in Article 224, for example, is directly proportional. In other embodiments, however, the relationship may be analogous to a polynomial function, an exponential function, a logarithmic function, and/or a combination thereof.</p>

In some embodiments, the optical computing method 128 may include a second detector 424, which

It may be similar to the first detector 420 in that it may be any device capable of detecting radiation

<p dir="rtl">25 Electromagnetic. The second detector 424 can be used to detect resulting radiation aberrations</p>

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From the source of electromagnetic radiation 404. Unfavorable radiation deviations in the intensity of electromagnetic radiation 406 can occur due to a wide range of causes and are likely to cause negative effects on the optical computing device 128. These negative effects can be detrimental to the measurements being taken Over a period of time. In some embodiments, it can occur

<p dir="rtl">5 Aberrations in radiation resulting from the accumulation of a film or material on the sampling window 412 which has</p>

The effect is to reduce the quantity and quality of light that ultimately reaches the first detector 420. Without appropriate compensation, these aberrations in radiation can lead to false readings and the output signal 422 photodiodes will not be initially or accurately related to the property of interest.

To compensate for these types of unfavorable effects, the second detector 424 can be configured to produce a 10 compensating signal 426 that generally indicates aberrations in the radiation of the radiation source

The electromagnetic field 404 then normalizes the output signal 422 generated by the first detector 420. As shown, the second detector 424 can be configured to receive a portion of the photoactive radiation 414 through the beam splitter 428 to detect aberrations in the radiation. In other embodiments, however, the second detector 424 may be positioned to receive electromagnetic radiation from any part

<p dir="rtl">15 Of the optical chain in optical computing method 128 to detect aberrations in radiation, without moving away from the detection field.</p>

In some uses, the output signal 422 and the compensating signal 426 can be transmitted to or received by a signal processor 430 that is connected in series with both detectors 420, 424. The signal processor 430 can be a computer that includes a non-temporary machine-readable medium, which can be configured or 20 Programmed to mathematically combine the compensating signal 426 with the output signal 422 to equalize the output signal.

422 In view of any radiation deviations detected by the second detector 424. In some embodiments, arithmetic summation of the output and compensation signals 422, 426 may result in the ratio of the two signals 422, 426 being calculated.

In real time or near real time, the signal processor 430 can be configured to determine or calculate 25 the concentration or amplitude of the property of interest in the substance 224. In some embodiments, the signal processor 430 can be programmed to

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Signals 430 to understand whether the detected concentration of substance 224 or a property thereof is

Within or without a pre-defined or pre-programmed range for its intended purpose as used with

Downhole tool 126. For example, the signal processor 430 can be programmed such that when the concentration or property of the substance 224 remains below a predetermined minimum, the signal processor 430 does not operate.

5 In contrast, when the concentration or property of the substance 224 reaches or exceeds a minimum

Predetermined, the signal processor 430 can be configured to send a signal 432 to the computer system 130 (Figure 1) to inform the well operator that the sleeve 210 has been effectively opened. As briefly described above, the signal 432 can be transmitted to the computer system 130 via the communication line 132 .

Those skilled in the field will realize that there are many advantages that systems can provide

<p dir="rtl">10 And the methods that were revealed. For example, referring back to Figures 1, 2A and 2B, and continuing to refer to Figure 4, in at least one embodiment, a predetermined amount or concentration of supernatant 224 or a predetermined concentration of a substance property 224 may be held in the indicator chamber 222 when The sleeve 210 is located in a closed configuration. In some embodiments, the supernatant 224 can be a fluid, such as non-aqueous fluids, hydrocarbons, oil, refined component of oil, products</p>

<p dir="rtl">15 Petrochemicals, organic compounds, alcohols, esters, sugars, coatings, types of waxes, toluids, and the like. In other embodiments, the material 224 can be a gaseous fluid such as, but not limited to, air, nitrogen, carbon dioxide, argon, helium, methane, ethane, butane, and other hydrocarbon gases. In still other embodiments, the material 224 can be a solid material such as, but not limited to, plastics, elastomers, joint foams, metals</p>

<p dir="rtl">20 Gas-filled, gas-filled ceramic materials, gas-filled glass types, composites and/or structures, thermoplastic materials, thermosetting materials, combinations thereof and the like. As noted, "gas-filled" solids can be filled with any gas, such as, but not limited to, air, nitrogen, carbon dioxide, argon, helium, methane, ethane, butane, gas Hydrocarbon gases</p>

<p dir="rtl">25 Others, combinations thereof and the like.</p>

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Once the sleeve 210 moves to the open conformation, generally as described above, the supernatant 224 can exit the indicator chamber 222 and move into the flow path 204 and continue to float toward the surface 104. At or near the surface 104, the material 224 can be detected. or a property thereof) by the optical computing facility 128. When the predetermined minimum 5 of the material 224 is met or exceeded, the optical computing facility 128 can be configured to send the signal 432 to the computer system 130 and thus provide a positive indication of the sleeve 210 moving in the open configuration. Once it is determined that sleeve 210 is indeed in the open configuration, the well operator can confidently continue subsequent well operations that require sleeve 210 in that position.

Referring specifically to Figure 1, in some embodiments, each instrument may be trapped down a well 126a-10c or include unique material 224 held in a corresponding indicator chamber 222. In these embodiments, the optical computing facility 128, or a combination of optical computing facilities, may be configured 128, to detect each unique substance 224 and send corresponding signals 432 to the computer system 130. For example, when material 224 corresponding to the first downhole tool 126a is detected, signal 432 could be an indication that the sleeve 210 associated with the first downhole tool 126a has moved to

<p dir="rtl">15 Its open form. Likewise, when material 224 corresponding to the second downhole tool 126b is detected, signal 432 can be indicative of the sleeve 210 associated with the second downhole tool 126b moving to its open conformation. Finally, when the material 224 corresponding to the third downhole tool 126c is detected, the signal 432 could be an indication that the sleeve 210 associated with the third downhole tool 126c has moved to its open conformation.</p>

<p dir="rtl">20 Those skilled in the art will already be aware of the advantages that can be provided, particularly as used in performing wellbore servicing operations. For example, a positive indication that a sleeve 210 has been opened for a specific downhole tool 126a-c can allow the well operator to confirm the appearance of those downhole tools 126a-c while the specific downhole tool 126a-c remains downhole. Also, the operator can be certain that a particular service fluid will be delivered to a submerged area within the subterranean formation</p>

<p dir="rtl">25 108. Furthermore, such certainties can allow the operator to avoid errors in</p>

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Performing various service operations, for example, delivering a fluid to the wrong boiler area. In addition, the operator can perform service operations with confidence that the operation has, in fact, reached the desired target area.

In some embodiments, the optical computing device 128 may include more than one ICE 5 416 configured to monitor or detect more than one corresponding substance 224. For example,

In at least one embodiment, a first ICE can be configured to detect substance 224 while a second ICE can be configured to detect a fluid (e.g., water, production fluid, hydrocarbon, and so on) that is trapping substance 224. In these embodiments, the signal processor can be configured 430 to calculate a ratio between two detected substances to determine when the detected concentration of the substance 224 or its 10 property falls within or outside a predetermined or preprogrammed range to achieve its desired purpose as used with downhole instrument 126. As will be noted, the ratio between the two detected substances can help control optical intensity and detect occlusion of the sampling window412.

In other embodiments, two or more different materials 224 may be released from a single location within

15 The operating tubing string 114 and the ratio between the two asymmetric materials 224, as measured by the optical computing method 128, can be an indicator or can determine the original location of the material 224. As a result, the operator can be informed in real time that a downhole tool 126 is then operated site effectively.

In some embodiments, downhole tool 126 can be a sampling device

<p dir="rtl">20 fluid or the like and the embodiments discussed herein can be distinctive in determining whether the medium has been operated effectively or whether a sample has actually been obtained. One problem is sampling the fluid at the exact sampling time. Positive verification of sampling can be valuable in demonstrating the performance of the sampled fluid at surface 104. For example, it can extend the difference between the downhole sampled fluid (which is maintained at pressure) and the downhole fluid</p>

<p dir="rtl">25 The product is on the surface 104 (and not maintained under pressure) The operator uses several special tools</p>

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Sample fluid. It can also help in understanding and interpolating between the properties as measured at the surface 104 and the actual downhole properties of the sampling fluid.

In other embodiments, the downhole device 126 can be a valve (i.e., any flow restricting means such as flow control means, independent flow control means, throttle valves, and the like).

<p dir="rtl">5 Placed within the operating tubing string 114 or within the wellbore 106 and embodiments can be distinguished</p>

discussed here by determining or sensing the valve position. For example, when the valve is actuated or moved between the open and closed positions, material 224 can be released into the flow path 204 and detected by the optical computing method 128 at or near the surface 104. Verifying the valve's displacement or movement to its desired position can be Distinctive as long as, just as

<p dir="rtl">10 As those skilled in the art will know, it is often difficult to know whether downhole valves or restraints have actually been moved or not.</p>

In still other embodiments, the downhole tool 126 can be a multi-displacement tool, such as a tool equipped with a j-slot mechanism, the embodiments discussed herein having the advantage of determining or sensing the position of the tool. For example, the tool can be configured to edit material 224 in the flow path

<p dir="rtl">15 204 once it moves into a specific body. In at least one embodiment, the disclosure can result in or</p>

Sensing the material 224 at or near the surface 104 using optical computational means 128 informs the operator that the tool is ready for work, for example by releasing a valve or opening a plug.

In other embodiments, material 224 may be trapped in an injection fluid or the like during a catalytic process

<p dir="rtl">20 Formation, such as hydraulic fracturing and gravel grouting process. Thus, once the formation stimulation process is complete, material 224 will be effectively injected into or embedded in the formation 108. During production operations, material 224 can be produced by normal flow of fluids, such as hydrocarbons and water, and subsequently detected at or near the surface 104 using optical computational means. 128. As a result, the operator can be informed in real time that the selected operating area is productive. In one embodiment</p>

<p dir="rtl">25 At a minimum, dissimilar materials 224 or materials 224 that exhibit a different property can be detained</p>

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Within injection fluids are directed to different yielding zones within the formation 108. Once these dissimilar materials 224 are detected on the surface 104 using optical computing facility 128, the operator can be informed in real time of any yielding zone produced.

in one or more embodiments, rather than being released into the flow path 204 formed in a series

<p dir="rtl">5 Operating tubing 114, material 224 may be released or moved into the annular space 124 (Figure 1) during an injection operation to detect the operation or operation of a downhole tool 126. As will be realized, releasing material 224 into the annular space 124 can remove forces Trapping that can affect the material 224, allowing the buoyancy of the material 224 to control the movement of the material 224 toward the optical computing device 128 at or near the surface 104. Once the material 224 is detected by the device</p>

<p dir="rtl">10 Optical computing 128 , the operator can be informed in real time of the successful operation or operation of the downhole tool 126 .</p>

It will be understood that many embodiments contained herein relating to computer control and/or artificial neural networks, including various blocks, modules, elements, components, methods, and algorithms, can be implemented using physical computer components, programs, and combinations. Of which, and what

<p dir="rtl">15 Similar. To illustrate the interchangeability between hardware and software, several illustrative blocks, modules, elements, components, methods and algorithms are generally described in terms of their function. The determination of whether this functionality is implemented as a hardware component or software will depend on the specific application and any design constraints imposed. For this reason at least, it will be recognized that those of ordinary skill in the art can perform the described function in a variety of ways for a specific application. Furthermore it,</p>

<p dir="rtl">20 Various components and blocks may be arranged in a different order or divided differently, for example, without departing from the scope of the embodiments explicitly described.</p>

Computer hardware used to implement many of the blocks, modules, elements, components, methods, and illustrative algorithms described herein may include a processor configured to execute one or more sequences of instructions, programming situations, or code stored on a non-temporary medium.

<p dir="rtl">25 Computer readable. The processor could be, for example, a multimicroprocessor</p>

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Uses: A microcontroller, a digital signal processor, an application-specific integrated circuit, a field-programmable gate array, a programmable logic device, a control device, a state machine, a gate logic, distinct hardware components, an artificial neural network, or any similar suitable object that can To perform calculations or other uses of data. In some embodiments, it can include a component

<p dir="rtl">5 Computer Material Elements such as, for example, memory (for example, Random Access Memory), flash memory, Read Only Memory (ROM), programmable read-only memory</p>

Electrical EPROM(Programmable Read Only Memory(), registers, disks

<p dir="rtl">10 Hard disks, removable disks, Compact Disc CD-ROMS read-only-memory, Digital Versatile Disk</p>

DVDs (Versatile Disc), or any other suitable storage medium.

The executable sequences described herein may be executed by one or more code sequences contained in memory. In some embodiments, this code can be read into memory from another readable medium

<p dir="rtl">15 By machine. Executing sequences of instructions contained in memory can cause the processor to perform the process steps described here. One or more processors may also be used in a multi-threaded arrangement to execute sequences of instructions in memory. Additionally, a wired circuit may be used instead of or in combination with software instructions to implement several embodiments described herein. Thus, the present embodiments are not limited to any specific combination of hardware and/or software components.</p>

<p dir="rtl">20 As used herein, machine-readable medium will refer to any non-temporary medium that directly or indirectly provides instructions for a processor to execute. Machine-readable media can take many forms, including, for example, fixed media, volatile media, and transmission media. Static media can include, for example, optical and magnetic disks. Volatile media can include, for example, dynamic memory. And it can</p>

<p dir="rtl">25 The transmission media includes, for example, coaxial cable, wire, optical fiber,</p>

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And wires form a conductor. Common forms of machine-readable media may include, for example, soft disks, floppy disks, hard disks, magnetic tapes, or other similar magnetic media, DVDs, CD-ROMs, or similar optical media, cards. Perforations, paper strips and similar physical media such as perforations, EPROM, PROM, ROM, RAM

<p dir="rtl">5 And EPROM is flash.</p>

The embodiments disclosed herein include Embodiment A, Embodiment B, Embodiment C, and Embodiment D.

Embodiment A: A well system comprising: a series of operating pipes providing a flow path within; A downhole tool coupled to a series of drive tubing and having a body fluidly coupled to the flow path; An indicator chamber defined in the body and adapted to hold material within it until the tool is run downhole, thus becoming a chamber

<p dir="rtl">10 The cursor is exposed and the material is released into the flow path; and an optical computing device in optical communication with the flow path and configured to detect a material property in the flow path and to communicate a signal when the property is detected, the signal indicating that the tool has been operated downhole.</p>

Embodiment A may include one or more of the following additional elements in any combination:

Element A1: The well system wherein the optical computing facility includes: at least one integrated computing element 15 configured to interact optically with the material and thereby produce photoreactive light; The at least one detector is configured to receive the photoactive light and produce an output signal corresponding to the material property.

Element A2: Well system in which the material is buoyant compared to the fluids placed in the flow path.

Element A3: Well system where material is trapped in fluids placed in the flow path.

Element A4: Well system wherein the optical computing medium is positioned at or near the surface of well 20 and the material is prepared to float toward the optical computing medium within the flow path after it is released from the indicator chamber.

Element A5: Well system where the material is a fluid selected from the group consisting of hydrocarbons, oil, refined component of oil, petrochemical products, organic compounds, air, nitrate

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Nitrogen, carbon dioxide, argon, helium, methane, ethane, butane, hydrocarbon gases, alcohols, esters, sugars, paints, types of waxes and combinations thereof.

<p dir="rtl">5 Element A6: Well system where the material is a fluid selected from the group consisting of hydrocarbons, oil, refined component of petroleum, petrochemical products, organic compounds, air, nitrogen, carbon dioxide, argon, helium, methane, ethane, butane, Hydrocarbon gases, alcohols, esters, sugars, coatings, waxes and combinations thereof, where the characteristic is a predetermined concentration of the fluid.</p>

<p dir="rtl">10 Element A7: Well system where the material is a solid material selected from the group consisting of plastics, elastomeric materials, joint foams, gas-filled metals, gas-filled ceramic materials, gas-filled glass types, composite materials and/or structures, refractory materials Plasticizing, thermosetting materials, and combinations thereof.</p>

Element A8: Well system where the material property is at least one of chemical composition, 15 phase, impurity content, pH level, viscosity, density, total dissolved solids concentration, salt content, porosity, opacity, bacteria content, color, and state of the material. .

As a non-restrictive example, illustrative combinations applicable to Embodiment A include: Embodiment A with elements A1 and A2; Embodiment A with elements A1, A5, and A7; Embodiment A with elements A1, A3, A4, and A8; And so on.

<p dir="rtl">20 Embodiment B: A method comprising: trapping a material in a specified indicator chamber in a downhole tool body, the downhole tool being coupled to a series of operating tubing which provides a flow path within it, the body being in fluid contact with the flow path; operating a downhole tool which exposes the indicator chamber and releases material into the flow path; Monitoring the flow path using a computer-adapted optical method</p>

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To detect the property of material in the flow path; A signal is communicated using an optical computer method when a material property is detected, and the signal indicates that the tool has been operated downhole.

Embodiment B may include one or more of the following additional elements in any combination:

Element B1: The method where monitoring the flow path by optical computer means includes: the reaction

<p dir="rtl">5 Photosynthesis of at least one computing element integrated with the material to produce photoreactive light; Receiving photoactive light using at least one detector; and producing an output signal using at least one detector corresponding to the material property.</p>

Element B2: The method whereby communicating a signal by an optical computer means includes communicating the signal to a computer system placed on the surface of a well.

<p dir="rtl">10 Element B3: The method wherein the material is buoyant relative to fluids placed in the flow path and the optical computing medium is placed at or near the surface of a well, wherein the method further includes the material floating toward the optical computing medium within the flow path after it is released from the indicator chamber.</p>

Element B4: Where the material is buoyant compared to the fluids placed in the flow path and the optical computing method is placed at or near the surface of a well, wherein the method also includes buoyancy

<p dir="rtl">15 The substance towards the optical computing medium within the flow path after its release from the indicator chamber and method wherein the substance is a fluid selected from the group consisting of hydrocarbons, petroleum, refined component of petroleum, petrochemical products, organic compounds, air, nitrogen, carbon dioxide, argon. Helium, methane, ethane, butane, hydrocarbon gases, alcohols, esters, sugars, coatings, types of wax, and combinations thereof.</p>

<p dir="rtl">20 Element B5: The method further comprises: trapping the material in a fluid within the flow path; m Monitoring the flow path by optical computer means to detect the fluid; Calculating the ratio between the fluid and the substance using the optical computer method.</p>

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As a non-restrictive example, illustrative combinations applicable to Embodiment B include: Embodiment B with elements B1 and B2; Embodiment B with elements B1, B2 and B3; Embodiment B with elements B2 and B4; And so on.

Embodiment C: A well system comprising: a string of operating pipes providing a flow path within it; Bushing assembly

<p dir="rtl">5 a slide coupled to the drive tube string and having a body in which the sleeve is movably disposed between a closed body, wherein fluid contact is prevented between the inner portion of the body and the outer portion of the drive pipe string, and an open body, wherein fluid contact is permitted between the inner portion of the body and the outer portion of the drive pipe string; An indicator chamber defined in the body and configured to trap material within it when the sleeve is in the closed configuration and to release material into the flow path when the sleeve is in the open configuration;</p>

<p dir="rtl">10 An optical computing device in optical communication with the flow path and configured to detect a property of the material in the flow path and to communicate a signal when the property is detected, the signal indicating the presence of the sleeve in the open form.</p>

Embodiment C may include one or more of the following additional elements in any combination:

Element C1: The well system, wherein the optical computing facility includes: an integrated computing element

15 At least one is configured to photochemically interact with the material and thus produce photoactive light; The at least one detector is positioned to receive the photoactive light and produces an output signal corresponding to a material property.

Element C2: The well system in which the material is buoyant compared to the fluids placed in the flow path.

20

Element C3: Well system where the material is buoyant relative to fluids placed in the flow path and where the optical computing medium is positioned at or near the surface of a well and the material is prepared to float toward the optical computing medium within the flow path after being released from the indicator chamber.

Element C4: Well system where the material is a fluid selected from the group consisting of hydrocarbons, oil, refined component of petroleum, petrochemical products, organic compounds, air, nitrogen, carbon dioxide, argon, helium, methane, ethane, butane, Hydrocarbon gases, alcohols, esters, sugars, coatings, waxes, and combinations thereof.

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Element C5: Well system where the material is a fluid selected from the group consisting of hydrocarbons, oil, refined component of petroleum, petrochemical products, organic compounds, air, nitrogen, carbon dioxide, argon, helium, methane, ethane, butane, Hydrocarbon gases, alcohols, esters, sugars, coatings, waxes, and combinations thereof, where the property is

<p dir="rtl">5 Preset concentration of fluid.</p>

Element C6: Well system where the material is a solid material selected from the group consisting of plastics, elastomeric materials, joint foams, gas-filled metals, gas-filled ceramic materials, gas-filled glass types, composite materials and/or structures, refractory materials Plasticizing, thermosetting materials, and combinations thereof.

<p dir="rtl">10 As a non-limiting example, illustrative combinations applicable to Embodiment C include: Embodiment C with elements C1 and C2; Embodiment C with elements C1, C2, and C4; Embodiment C with elements C1, C3, and C5; And so on.</p>

Embodiment D: A method comprising: trapping a material in a specified indicator chamber in the body of a sliding sleeve assembly, the sliding sleeve assembly being coupled to a series of operating tubes which provide a flow path within it,

<p dir="rtl">15 The body is in fluid contact with the flow path; Moving a sleeve disposed within the body of a closed configuration, wherein the indicator chamber is blocked and fluid contact is prevented between the inner portion of the body and the outer portion of the drive tube string, and an open configuration, wherein the indicator chamber is exposed and fluid contact is permitted between the inner portion of the body and the outer portion of the drive tube string; releasing material into the flow path from the indicator chamber; Monitoring the flow path using a computer-adapted optical method</p>

<p dir="rtl">20 To detect the property of material in the flow path; A signal is delivered using an optical computational method when a material property is detected, and the signal indicates the presence of the sleeve in the open form.</p>

Embodiment D may include one or more of the following additional elements in any combination:

Element D1: The method wherein monitoring the flow path by optical computing means includes: photointeracting at least one integrated computing element with the material to produce photoreactive light; Recepion

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photoreactive light using at least one detector; and producing an output signal using at least one detector corresponding to the material property.

Element D2: The method wherein the material is buoyant relative to fluids placed in the flow path and the optical computing medium is placed at or near the surface of a well, wherein the method further includes 5 floating the material toward the optical computing medium within the flow path after it is released from the indicator chamber.

Element D3: The method wherein the material is buoyant relative to fluids placed in the flow path and the optical computing medium is placed at or near the surface of a well, wherein the method further includes the material floating toward the optical computing medium within the flow path after it is released from the indicator chamber and where the material is A fluid selected from the group consisting of hydrocarbons, oil,

<p dir="rtl">10 Refined component of petroleum, petrochemical products, organic compounds, air, nitrogen, carbon dioxide, argon, helium, methane</p>

methane, ethane, butane, and hydrocarbon gas

Gases, alcohols, esters, sugars, paints, types of waxes, and combinations thereof.

<p dir="rtl">15 Element D4: The method where the material is buoyant compared to the fluids placed in the flow path and the optical computing medium is placed at or near the surface of a well, where the method also includes the material floating toward the optical computing medium within the flow path after it is released from the indicator chamber and where the material is a solid. Selected from the group consisting of plastics, elastomers, joint foams, gas-filled metals , gas-filled ceramics, gas-filled glass types,</p>

<p dir="rtl">20 Composites and/or structures, thermosetting materials, thermosetting materials, and combinations thereof.</p>

Element D5: The method further comprising: trapping the material in a fluid within the flow path; m Monitoring the flow path by optical computer means to detect the fluid; Calculating the ratio between the fluid and the substance using the optical computer method.

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As a non-restrictive example, illustrative combinations applicable to Embodiment D include: Embodiment D with elements D1 and D2; Embodiment D with elements D1, D3, and D5; Embodiment D with elements D1, D4, and D5; And so on.

Therefore, the systems and methods disclosed are well-equipped to achieve the stated objectives and features

<p dir="rtl">5 And also those that are inherent here. The specific embodiments disclosed above are illustrative only, and the information contained in the present disclosure may be modified and implemented in different but equivalent ways that are evident to those skilled in the art upon making use of the information contained herein. Furthermore, no limitations are intended to be imposed on the construction or design details described herein, other than as described in the safeguards below. Thus, the specific illustrative embodiments disclosed will be demonstrated</p>

<p dir="rtl">10 The above may be changed, combined, or modified, and all of these various images fall within the scope and content of the present disclosure. The systems and methods illustratively disclosed herein may be conveniently implemented in the absence of any item not specifically disclosed herein and/or any optional item disclosed herein. While compositions and methods are described in terms of “comprising,” “containing,” or “involving” multiple components or steps, compositions and methods may “consist primarily</p>

<p dir="rtl">15 Of or consisting of numerous components and steps. All numbers and ranges disclosed above can vary by some amount. Where a lower and upper limit numeric range is disclosed, any number and any contained range that falls within the range are specifically disclosed. Specifically, each range of values ​​(as, “from about A to about B,” or, equivalently, “from about A to B,” or, equivalently, “from about A to B”) must be interpreted as disclosed It is mentioned here as it defines every number and range that falls within</p>

<p dir="rtl">20 Wider range of values. Likewise, the terms mentioned in the protective elements have their normal and clear meaning unless the opposite is clearly and publicly stated by the patentee. Furthermore, indefinite articles, as used in protective elements, are defined here as meaning one or more of the elements they refer to.</p>

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