Untitled record

Full description

Background of the invention

The present disclosure relates to wellbore operations and, more specifically, to fluid extraction and separation system.

In oil and gas, many different types of fluids are circulated in a wellbore and then returned

5 That to the surface. These fluids, commonly referred to as “fluid returns,” can include, but are not limited to, drilling fluid, completion fluids, fracturing fluids, stimulations fluids, spotting fluids, Wellbore treatment fluids, and so on. Fluid returns are typically analyzed by well operators to determine several downhole variables

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

For example, during well drilling, many measurements of fluid returns can be obtained from the drilling fluid. For example, these measurements provide a running log of the drilling process, allowing the well operator to analyze the ground formations that are progressively penetrated by the drill bit. It can be an operating log that is obtained from the measurements

<p dir="rtl">15 It is particularly important because it allows the well operator to confirm the presence of oil, gas, and/or other formation fluids in the formations being penetrated. For example, by comparing the proportions of methane to each of several other hydrocarbon gases present in the fluid returns, such as ethane, propane, butane, and pentane, it is possible to estimate whether a well is productive and, if so, to estimate whether</p>

<p dir="rtl">20 The well will produce oil, gas or water. In addition, the usefulness of the operating history can be demonstrated by</p>

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Providing ratios of total gas content to oil content, water content, location in relation to the formation, sedimentary environment, and also helps improve drilling.

In order to measure the type and quantity of fluid present in a specific formation being drilled, samples can be taken continuously or separately from the drilling fluid returning to the surface and introduced into a fluid separation facility that extracts the gases.

<p dir="rtl">5 Trapped in drilling fluid. The extracted gases can then be transferred to a gas analysis facility to determine the chemical composition. In some cases, the chemical composition of the separated liquids can also be analysed. US order 6402799 relates to a gas-liquid separator for separating gas and liquid in a two-phase gas-liquid fluid, i.e. gas with a liquid suspended in it, generated in an air conditioner, clothes dryer, internal combustion engine, or the like, especially Related to gas vapor vortex separator</p>

<p dir="rtl">10 Fluid to separate air and water in the circulating fluid of a clothes dryer by passing a circular steam vortex in the fluid passage inside the drying chamber of the clothes dryer.</p>

General description of the inventor

One embodiment of the present invention relates to a fluid extraction system, including:

A fluid circuit coupled through a fluid to a fluid source to receive a fluid sample

<p dir="rtl">15 sample from source; The fluid separator is placed in the fluid circuit and includes:</p>

An object defining at least one fluid inlet; A specific flow chamber in the body to receive the fluid sample from at least one fluid inlet, where the fluid sample flows and a vortex is formed inside the fluid sample and the gases are separated

<p dir="rtl">20 trapped in the fluid sample and moved towards the center of the vortex; The outlet is specified in the flow chamber and provides a gas outlet that traps and removes gases, and a liquid outlet that receives and removes the remaining portion of the fluid sample.</p>

According to another embodiment of the present invention relates to a method, including:

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Obtaining a fluid sample from a fluid source; Transferring the fluid sample to a fluid circuit of a fluid extraction system, where the fluid extraction system includes a fluid separator placed in the fluid circuit and having a body defining at least one fluid inlet, a flow chamber,

5 and an outlet, where the outlet provides a gas outlet and a liquid outlet; Receiving the fluid sample into the flow chamber tangential to the body through at least one inlet; Push the fluid sample onto the rotor inside the flow chamber so that the fluid sample flows and forms a vortex at the outlet; Separating gas from the fluid sample in the vortex and trapping the gas in the gas outlet. And

<p dir="rtl">10 Receiving a remaining portion of the fluid sample into the liquid outlet.</p>

Brief explanation of the drawings

The following figures are included to illustrate certain aspects of the present disclosure, and are not to be viewed as exclusive embodiments. Numerous modifications, variations, combinations and equivalents in form and function can be introduced to the disclosed artistic subject matter, without departing from the scope of this disclosure.

<p dir="rtl">15 Figure 1 shows an illustrative drilling system that may utilize the principles of the present disclosure.</p>

Figure 2 is a schematic diagram of an illustrative fluid extraction system, according to one or more embodiments of the present disclosure.

Figure 3a is a top view of an illustrative fluid separation medium, according to one or more embodiments of the present disclosure.

<p dir="rtl">20 Figure 3b is a side cross-sectional view of the fluid separation medium in Figure 3a.</p>

Figure 4 is a side cross-sectional projection of another illustrative fluid separation medium, according to one or more embodiments.

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Figure 5 is a side cross-sectional projection of another illustrative fluid separation medium, according to one or more embodiments.

Detailed description:

The present disclosure relates to wellbore operations and, more specifically, to fluid extraction

5 extraction and separation system.

Various embodiments of the fluid extraction system disclosed herein can be used to extract and analyze gases trapped in fluid returns or sample fluids at the drilling rig site, but they can equally well be used to extract and analyze gases trapped in sample fluids from which On it from the subsurface. Sample fluid 10 may be associated with any operation performed at the drilling equipment site which includes, but is not limited to,

Drilling, turning, completion, cementing, stimulation and/or fracture formation. Distinctively, the fluid separation methods described herein in a fluid extraction system are configured to extract fluids from a fluid sample on the basis of at least one fluid property. One property of a fluid can be its density, and currently described fluid separation methods can extract fluids from a fluid sample on the basis of the density difference between different fluid components. Another property could be:

A fluid is characterized by its viscosity, and currently described fluid separation methods can also extract fluids from a fluid sample on the basis of the viscosity difference between different fluid components.

Currently described fluid separation methods also have a compact design adapted to induce higher fluid velocities that improve fluid separation based on density and/or viscosity differences. The fluid extraction system 20 may further include one or more energy input devices configured to enhance gas separation. In some embodiments,

For example, a thermal energy device can be used to maintain a fluid sample at a predetermined fluid extraction temperature. In other embodiments, or in addition to them, one or more acoustic wave processing methods may be used to induce the formation of cavities in the sample fluid, which also improves the gas separation process.

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Referring to Figure 1, an illustrative embodiment of a drilling system that can use the principles of the present disclosure is shown. As shown, the drilling system can include 100 rigs

traveling block derrick 104 supports a drilling platform 102 jack

106 To raise and lower the drill pipe string108 drill string. It can include drill pipe string

5 108, but not limited to, drill pipe and coiled pipe, as are generally known to owners of

Skill in the field. The drill stem 110 kelly holds the drill pipe string 108 when it is removed through the rotary table 112. A drill bit 114 is attached to the distal end of the drill pipe string 108 and is driven either by a downhole motor and/or via the drill pipe string rotors 108 from the surface of the well. When the bit 114 rotates, it creates a wellbore 116 that penetrates several

10 Subterranean formations 118 subterranean formations.

It should be recognized that while Figure 1 generally depicts a land-based drilling assembly, those skilled in the art will readily recognize that the concepts described here can be applied equally to seabed drilling operations using floating or offshore platforms and drilling rigs, without deviating from Detection field. The principles can also be applied to other engraving images

<p dir="rtl">15 It includes, but is not limited to, double grade drilling, controlled pressure drilling, and sub-level drilling.</p>

A pump 120 (e.g., a mud pump) circulates fluid 122 through a feed pipe 124 and into the interior of a drill pipe string 108. In some embodiments, fluid 122 can be a drilling fluid used in the drilling system

<p dir="rtl">20 100 described here. However, it should be noted that the principles of the present disclosure are applicable</p>

Equally applicable to any type of return fluid or sample fluid derived from a wellbore. Accordingly, the use of “fluid 122” means to include, but is not limited to, any other fluid type that can be circulated through a wellbore, produced at the surface or near the platform 102, or sampled downhole and subsequently sent to a recovery system. Fluid142 fluid extraction system. on

<p dir="rtl">25 For example, “fluid 122” may apply equally to reservoir fluids, gases, oils,</p>

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Water and any other fluid that can be produced from a wellbore. Furthermore, the drilling system 100 can be replaced or otherwise equivalent to the use of any fluid recovery system, such as a wellhead facility used to produce fluids at surface.

In the drilling system 100, the fluid 122 can be conveyed through the drill pipe string 108 to the drill bit.

5 114 and outside at least one hole in the drill bit 114. The fluid 122 is then circulated

and returned to the surface via an annular space 126 defined between the string of drill pipes 108 and found in the well drilling 116. At the surface, the recirculated or spent fluid 122 emerges from the annulus 126 and can be transferred to one or more fluid processing unit(s) 128 Through the fluid return line 130. After passing through the unit

<p dir="rtl">10 Fluid processing units (units) 128, a “clean” fluid 122 is deposited in a nearby retention pit 132 (i.e., a mud pit). One or more chemicals, fluids, or additives may be added to the fluid 122 via a mixing hopper 134 hopper coupled in connection with or in fluid contact with the detention pit 132.</p>

The drilling system 100 also includes a bottom hole assembly (BHA) 136

<p dir="rtl">15 Disposed in a drill pipe string 108 at or near the drill bit 114. The BHA 136 may include any number of sensor modules 138 (one is shown), which may include formation assessment sensors and directional sensors, such as measuring instruments during drilling and/or recording performance during drilling These sensors are well known in the art and are therefore not described in detail. 136 BHA may also contain a fluid pulse generator system</p>

<p dir="rtl">20 140 pulser system which induces pressure variations in fluid flow. Data is encrypted</p>

They are obtained from downhole sensor modules 138 and sent to the surface via a pulse generating system 140 whose pressure fluctuations, or “pulses,” propagate to the surface through a fluid flow column located in the drill pipe string 108. At the surface the pulses are detected by One or more sensors

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Surface (not shown), such as a pressure transducer, a flow transducer, or a combination of a pressure transducer and a flow transducer.

During the drilling process, a discrete or continuous sample of fluid 122 returning to the surface (i.e., fluid returns) may be obtained or transferred to a fluid extraction system 142 located at or near

<p dir="rtl">5 Drilling platform 102. The sample may be transferred to the fluid extraction system 142 via a suction pipe 143 that is fluidly coupled to the fluid source 122 returning to the surface. In some embodiments, for example, the suction tube 143 through the fluid may be coupled to the fluid return line 130. In other embodiments, however, the suction tube 143 may be coupled directly to the annular space 126 so that a sample of fluid 122 can be obtained directly from The well is at or near the surface of the well. on</p>

<p dir="rtl">10 For example, the fluid extraction system 142 can alternatively be located in the fluid return line 130 return line prior to the fluid handling unit(s) 128. In these embodiments, the suction pipe 143 may be dispensed with. In still other embodiments, the suction pipe may be coupled 143 Flow receiving tank at the slurry tanks or overhead bin connected to the fluid handling unit(s) 128, without departing from the detection range.</p>

<p dir="rtl">15 As described in detail below, the fluid extraction system 142 can include a fluid separation device configured to extract gases from a sample of fluid 122 and analyze the chemical composition of the extracted gases. The fluid separation medium can be configured to use the flow energy of the inlet sample fluid to generate increased fluid velocities that help improve the separation process. When in operation, the fluid separation device can be configured to extract gases from the sample fluid on the basis of the density and/or viscosity difference between</p>

<p dir="rtl">20 The different fluid components of the sample fluid. Once the gas has been extracted from the sample fluid, the chemical composition of the fluid can then be determined using an accompanying analytical facility or a gas performance recording unit positioned at or near the drilling rig 102. In some embodiments, however, the separated fluids can be stored in a container and transported off-site and analyzed Later under laboratory conditions, without departing from the field of detection.</p>

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Once the chemical composition of the fluid has been determined, the data may be transmitted (either wired or wired) to one or more terminals 144, either near or far from the site, to any interested party for consideration, for example, at a control hub remote from the site The well from which the fluid was collected as it will be understood, knowledge of the chemical composition of the gases extracted from it can be used

5 Fluid 122 by the analyst, mud logging analyst, geochemist, geologist, petrophysicist, or other well operator with knowledge of formation fluid analysis to identify zones containing hydrocarbons. Additionally, in applications where the fluid 122 is a drilling fluid, it can be used to change the drilling parameters or drilling fluid composition. As will be explained, the aforementioned knowledge can be of the chemical composition of gases

<p dir="rtl">10 The fluid extracted from fluid 122 is equally useful to well operators in drilling other types of wells including, but not limited to, helium, nitrogen, or geothermal wells.</p>

144 Peripheral devices may include, but are not limited to, a display (e.g., displays, GUIs, and so on), a printer, an alarm, additional storage memory,

<p dir="rtl">15 And so on. In some embodiments, the screen or printing machine can be configured to provide the well operator with a graphical output corresponding to a specific extracted gas parameter. In other embodiments, an alarm can be configured (either audible or visual) to notify the well operator that a specific gas, concentration of gas, or ratio of gases has been detected, such as elevated levels of CO2 or H2S. If the levels or ratios of these gases exceed Above a predetermined limit, the well operator may wish to stop the wellbore operation</p>

<p dir="rtl">20 specified (e.g., drilling, completion, crushing, turning, and so on) or otherwise other than one or more operating variables.</p>

Referring now to Figure 2, and continuing to refer to Figure 1, a schematic diagram of an illustrative embodiment of a fluid extraction system 142 is shown, according to one or more embodiments of the present disclosure. The fluid extraction system 142 (hereinafter referred to as “System 142”) can be configured to receive a fluid sample

<p dir="rtl">25 202 Extracted from a wellbore fluid source, as generally described above. In some</p>

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Embodiments, for example, the fluid sample 202 can be a sample of the fluid 122 (Figure 1) when it is recycled back to the surface. In other embodiments, however, the fluid sample 202 can be any type of hole fluid Well, which includes, but is not limited to, completion fluid, fracturing fluid, wellbore treatment fluid, storage fluid, gas, oil, water, and any combination thereof

5 Further embodiments, the fluid sample 202 may be derived from production fluids drawn from the wellbore, without departing from the detection range.

A sample of the fluid sample 202 may be taken continuously or separately via the suction tube 143, which can introduce the fluid sample 202 into a fluid circuit specified by the system 142.

As indicated above, the fluid-through suction tube 143 may be coupled to a sample source

<p dir="rtl">10 The fluid 202, such as the fluid return line 130 (Figure 1), the annular space 126 (Figure 1), or any other source of fluid returning to the surface. In some embodiments, as also mentioned above, the fluid sample 202 can be a It is obtained at the bottom of the well and is accessible by the suction pipe 143 so that it can be introduced into the fluid circuit.</p>

In some embodiments, the suction tube 143 can be configured to clean or otherwise assist in

<p dir="rtl">15 Eliminate blockages that could prevent or hinder the introduction of fluid sample 202 into system 142.</p>

In one embodiment, for example, compressed gas 204 may be injected into the suction pipe 143 in order to clear any blockages or build-ups that may have developed within the suction pipe 143 or also prior to the fluid return line 130 (Figure 1) or the space Annular 126 (Figure 1). In another embodiment, the suction tube 143 may vibrate and otherwise may be shaken at a high frequency to

<p dir="rtl">20 Similarly, eliminate any blockages or obstructions that may have formed that could interfere with the introduction of the fluid sample 202 into the system 142.</p>

In some embodiments, the system 142 may include a pump 206 that receives a fluid sample 202 from a suction pipe 143. The pump 206 may be any device or mechanism configured to pressurize and otherwise maintain a predetermined pressure on the fluid sample 202 as it circulates through a circuit

<p dir="rtl">25 system fluid 142. In some embodiments, pump 206 can be configured to maintain</p>

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Apparent velocity, volumetric flow rate, or constant mass flow rate of a fluid sample 202 within a fluid circuit. Pump 206 can be a positive displacement pump, such as an advance gap pump or a peristaltic pump. In other embodiments, however, the pump 206 can be or can otherwise be replaced by a fluid column configured to maintain an arc pressure on the fluid sample 202 at

5 Its rotation through the fluid circle. In still other embodiments, the pump 206 can be configured to inject a pressurized fluid, such as nitrogen or air, into the fluid sample 202 to pressure and otherwise push the fluid sample 202 through the fluid circuit of the system 142.

System 142 may also include a pulse dampener 208 and a flow meter (or mass meter 210) placed in the fluid circuit. maybe

10 Configure the pulsation damper 208 to eliminate pulsating fluid flow through the fluid circuit that could be generated by the pump 206. The flow meter 210 can be any device configured to measure the mass flow rate of a fluid sample 202 as it circulates through the fluid circuit, and can also be configured to measure and record the density of a fluid sample 202. In at least one embodiment, for example, the flow meter can be The 210 is a Coriolis flow meter, which is a flow meter

15 Block me.

The fluid sample 202 can then be transferred to and otherwise received by a fluid separation device

212 fluid separator. The fluid separation device 212 can be configured to extract fluids from the fluid sample 202. As described in detail below, the fluid separation device 212 can be configured to separate or extract gases from the fluid sample 202 on the basis of at least one density or viscosity.

20 The various components of the fluid sample 202. The extracted fluids can then be directed out of the fluid separation medium 212 and into the unit 214 via a fluid flow line 216. As shown, the fluid flow line 216 couples the fluid separation medium 212 and the unit 214 through the fluid.

In some embodiments, unit 214 can be a gas performance recording unit configured to analyze gases extracted from the fluid sample 202 for a chemical composition. Includes gas performance recording units

25 Illustrative of, but not limited to, total hydrocarbon analysis methods, gas chromatography methods, and standards

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Fourier transform infrared (FTIR) spectroscopies, infrared spectrometers, mass spectrometers, mass spectrometry/mass spectrometry (MS/MS) instrumentation, selected ion recording media Gas chromatography, gas chromatography-mass spectrometry devices

5 (gas chromatography–mass spectrometry (GC-MS), Arman spectrometer, reagents

Solid-state, liquid-state detectors, and time-of-flight analysis methods for laser desorption/ionization

matrix-assisted laser desorption/ionization time of flight

devices (MALDI-ToF). Combinations of the foregoing may also be used. The unit 214 may include a computer or signal processor configured to provide an output signal 218 corresponding to a specified resulting chemical composition 10 or otherwise detected in the extracted gas. In some embodiments, the This transmits the output signal 218 to the peripheral means 144 described above for consideration by interested parties (i.e., well operator, drillers, and so on).

After analysis in unit 214, extracted gas 214 can exit via a gas conduit 220 and can be used or disposed of in several different ways. In some embodiments, for example 15, the gas stream 220 can ignite the extracted gases or transfer the gases to

Near-site equipment connected to the platform 102 (Figure 1) to supply power to said equipment. In other embodiments, the gas duct 220 can transport the extracted gas to consumers for consumption or sale. In still other embodiments, the gas duct 220 can transport the extracted gas once Another downhole to be re-injected into a wellbore.

20 After gas extraction, the remaining fluid sample 202 can exit the fluid separation device 212 via a fluid stream 222 and can be transported back to the sample fluid source 202. In some embodiments, when the fluid sample 202 is a drilling fluid, a sample can be reintroduced Fluid 202 into the fluid return line 130 (Figure 1) to be replenished using the remaining fluid 122 (Figure 1). As will be understood, the fluid sample 202 can be reintroduced into the return fluid 122 or

25 At any other suitable point for the well operator, without straying from the detection range.

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Before returning to the sample fluid source 202, however, the remaining fluid sample 202 may pass through one or both of a liquid holding device 224 and a second pump 226 placed in the fluid circuit of the system 142. The liquid holding device 224 can be, for example, An expansion vessel used to contain excess fluids generated by the fluid separating device 212. In case 5 where there is a pressure imbalance in the fluid circuit, the liquid separating device 224 may be installed

They are useful in that they contain an excess amount of fluid generated by the fluid separation device 212 and otherwise prevent that excess fluid from flooding any of the dimensional components of the system 142. The pump 226 may be similar to the pump 206, and may be otherwise configured to ensure that a sample can be returned The remaining fluid 202 is appropriately transferred to the fluid sample source 202 for replenishment.

10 A carrier fluid 228 may be injected into the fluid circuit of the system 142 to assist in carrying or transporting gases extracted from the fluid sample 202 in the fluid separation device 212 to the unit 214. The carrier fluid 228 may be an inert gas including, but not limited to, nitrogen , helium, neon or argon. In some embodiments, the carrier fluid 228 can be an atmospheric gas. In other embodiments, the carrier fluid 228 can be any fluid other than

15 Atmospheric gas or gas with a high oxygen content, therefore allowing high sensitivity and low contamination with helium, water, silver species and any other component generally found in high concentrations in the atmosphere.

In some embodiments, as shown, the carrier fluid 228 may be injected into the fluid circuit at a point prior to the fluid separation means 212. Injecting the carrier fluid 228 into the fluid circuit prior to the fluid separation means 212 can facilitate gas extraction by increasing the gaseous surface area 20 through the fluid separation method 212. The injected carrier fluid 228 may also prove useful in

Ensuring that a two-phase flow is always introduced into the fluid separation medium 212. In other embodiments, the injected carrier fluid 228 can prove useful in ensuring that a multi-phase flow is introduced into the fluid separation medium 212.

In other embodiments, however, the carrier fluid 228 (i.e., injected or drawn) may be transported in

25 Fluid circuit after the fluid separation device 212, such as within the fluid flow line 216 (as shown

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Injection of the carrier fluid 228 into the fluid flow line 216 may prove useful in assisting in withdrawing the extracted gas(es) more effectively than the means of separating the fluid 212 and carrying the extracted gas to the unit 214.

System 142 may further include one or more power input means, shown in FIG

5 Thermal energy device 230 thermal energy device and/or at least one sonicator 232. The energy input means may be configured to introduce energy into the fluid sample 202. Whereas the energy input means are shown in Figure 2 as the thermal energy device 230 and the sound wave treatment method 232, it will be realized that other types and/or forms of energy input means can equally be used in the system 142, without departing from the field of

<p dir="rtl">10 Reveal. For example, herein illustrated are embodiments that use energy input means configured to transfer mechanical or electromagnetic energy to the fluid sample 202.</p>

In some embodiments, as shown, the energy input means(s) (i.e., thermal energy means 230 and acoustic treatment means 232) may be located in the system 142 at a point in the fluid circuit prior to the fluid separation means 212. In other embodiments, as Shown with lines

<p dir="rtl">15 Intermittently, the energy input means(s) may be located on or otherwise directly connected to the fluid separation means 212. As will be understood, integrating the energy input means(s) with the fluid separation means 212 can prove beneficial in reducing the overall size of the system 142 and provide a wider range of flexibility in system installation and design 142.</p>

Thermal energy device 230 can be configured to transfer a known amount of thermal energy (i.e., heat) to

<p dir="rtl">20 Fluid sample 202. In some embodiments, the thermal energy means 230 is a heater, such as a heater with a resistance coil or heat exchanger, configured to increase the temperature of the fluid sample 202 to a predetermined gas extraction temperature. In other embodiments, the thermal energy medium 230 can be a cooling medium, such as a heat exchanger, evaporator or freezing unit. A cooling medium may be required, for example, in applications where fluid is returned</p>

<p dir="rtl">25 122 (Figure 1) to the surface at high temperatures, such as more than 100°C.</p>

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As needed, the cooling device may also be configured to hold the fluid sample 202 at a predetermined gas extraction temperature.

The predetermined gas extraction temperature may be, for example, any temperature that does not exceed the limit value of the critical temperature in the fluid sample 202, beyond the point at which

5 In which the fluid sample 202 begins to break down and begins to form scales or remove water from the bentonite. In some fluid samples 202, for example, the critical temperature limit value may be at or about 90°C. In at least one embodiment, the thermal energy device 230 can be configured to maintain the fluid sample 202 at a predetermined gas extraction temperature using, for example, a proportional integral derivative cyclic control device

<p dir="rtl">10 (PID) or similar. Alternatively, or in addition to directly heating the fluid sample 202 using the thermoelectric method 230, the carrier fluid 228 may also be heated using the thermoelectric method 230 or another means. As a result, immediately upon mixing with the fluid sample 202, the carrier fluid 228 can heat the fluid sample 202 to the predetermined gas extraction temperature.</p>

<p dir="rtl">15 The acoustic treatment method(s) 232 may be configured to introduce a known amount of acoustic vibration (i.e., sound energy) into the fluid sample 202 and thus induce the formation of cavities. As will be understood, the acoustic vibration causes a molecular vibration that can It leads to the formation of bubbles in the fluid sample 202 which can subsequently collapse, and energy is thus transferred within the system and results in the formation of cavities in the fluid sample 202. The method(s) of ultrasound treatment can be</p>

<p dir="rtl">20 232 are wide or variable frequency devices capable of working with a variety of values</p>

Densities and compositions of the fluid sample 202. In some embodiments, the acoustic processing means(s) 232 can be selectively adjusted at a predetermined frequency or amplitude corresponding to the type of fluid sample 202 to be analysed. In other embodiments, the acoustic processing means(s) 232 can be configured To introduce pre-conditioned shocks of high, low, or other frequency sound energy into a sample

<p dir="rtl">25 Fluid 202 to cause additional formation of cavities. In at least one embodiment, a means can be operated</p>

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(Methods) Acoustic wave therapy 232 pneumatically or hydraulically. As will be understood, this could prove useful if the system 142 is used in an explosive area.

In some embodiments, one or more fluid restraint devices 234 may be located in one or both of the fluid flow line 216 and the fluid stream 222 . Fluid restraint means 234 may be configured to regulate

5 Fluid flow generated by the fluid separation device 212 and may be, but not limited to, throttle valves or operable valves. The fluid restriction device 234 located in the fluid flow line 216 may, for example, prove useful in that it ensures that an appropriate amount of gas is extracted from the fluid sample 202 in the fluid separation device 212. As can be understood, the use of valves can be demonstrated to Operable as fluid restraint devices 234 it

10 Useful for accurately adjusting the pressure balance in the fluid circuit of the system 142.

Referring now to Figures 3a and 3b, and continuing to refer to Figure 2, a top and side cross-sectional view of an illustrative fluid separation medium 300 is shown, according to one or more embodiments of the disclosure. The fluid separation device 300 may replace the fluid separation device 212 of Figure 2 described above or may otherwise be the same device. As shown, 15 the fluid separation device 300 may include a body 302 defining a flow chamber 304 configured to receive the fluid sample.

202. One or more inlets 306 (one is shown) may be specified or otherwise provided in the body 302 to receive the fluid sample 202 from the fluid circuit of the system 142 (Figure 2) and transfer the inlet fluid sample 202 to the flow chamber 304. While the inlet is shown If there is only one 306 in Figure 3a, it will be realized that more than one input 306 can be used, without departing from the scope of detection 20.

The fluid sample 202 enters the flow chamber 304 through the inlet 306 in a generally tangential direction to the body 302. As depicted, the body 302 can be circular or disk-like in shape, and the inlet 306 can be aligned tangentially to the circumference of the body 302. As a result, once inserted In the flow chamber 304, the fluid sample 202 will begin to spiral or swirl around the flow chamber 304, 25 as indicated by the multiple arrows. Fluid sample 202 flows in a circular motion through a chamber

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flow 304, and eventually spiral inward toward a centrally located outlet 312 in the body 302 where they are ultimately discharged as liquid and gaseous components.

As used herein, the term “spin” refers to the rotating flow of a fluid (e.g., fluid sample 202) within the flow chamber 304. During the rotating flow in the flow chamber

5 304 chamber, the fluid components of the fluid sample 202 that have density will be pushed out

higher or higher viscosity further toward the outside (i.e., periphery) of flow chamber 304 compared to fluid components of lower density or lower viscosity. This is due, in part, to the increased effect of attractive and reactive centrifugal forces on the greater mass or viscosity of fluid components of greater density/ Higher viscosity Accordingly, the phase(s) of the fluid sample 202 that have a higher density or viscosity flow

<p dir="rtl">10 rotationally higher closer to the outside of the flow chamber 304 and the fluid sample phase(s) 202 that have a lower density or lower viscosity flow rotationally closer to the center of the flow chamber 304. As a result, the fluid components with higher density will flow farther toward the outside the flow chamber 304, and fluid components with lower density will flow closer to the center of the flow chamber 304.</p>

<p dir="rtl">15 One or more of the structures 308 may be placed in or otherwise identified by the flow chamber 304. The structures 308 may be configured to assist in flow of the fluid sample 202 and otherwise circumvent the exit 312 until it exits the fluid separation device 300. In some embodiments, the structures may be distinguished 308 As a single structure with one or more gaps or apertures 310 defined within it, or as multiple structures separated by gaps or apertures 310.</p>

<p dir="rtl">20 In other embodiments, the structures 308 may be in the form of one or more circumferentially extending blades having one or more slots 310 defined between the vane(s). Alternatively, or additionally, the structures 308 may be in the form of a single or more cavities extending circumferentially into one or more flow chamber walls 304. For example, structures 308 may protrude inward and/or outward relative to one or more flow chamber walls 308.</p>

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Flow 304. Furthermore, structures 308 may be spaced evenly or unevenly, depending on the operating parameters of the fluid separation medium 300 required.

In an illustrative operation, the fluid sample 202 enters the flow chamber 304 tangentially through the inlet(s) 306 and begins to rotate or twist. The velocity or angular torque of the fluid sample 202 increases

5 Gradually when it is near the 312 outlet, the values of gravitational acceleration are obtained

A higher ground affects the fluid sample 202. The increased G-G values assumed by the fluid sample 202 cause less dense gaseous components to be trapped in the fluid sample 202 to separate them from the denser liquid/solid components. As best illustrated in Figure 3b, the values of the Earth's acceleration due to gravity on the fluid sample 202 can result in the formation of a vortex 314 at

10 Exit 312.

As shown in Figure 3b, outlet 312 may include or otherwise provide a gas outlet 316 extending beyond the upper portion 314a of the fluid separation medium 300 and a liquid outlet 318 extending beyond the lower portion 317b of the fluid separation medium 300. Within the vortex 314 vortex, the fluid components of the sample circulate Fluid 202 which is denser (e.g., liquids and solids)

<p dir="rtl">15 around components of the fluid that are less dense (e.g., gases). As a result, gases 320 may migrate or flow toward the center of the flow chamber 304 and thus be separated from the liquid and solid components of the fluid sample 202. Alternatively, The vortex 314 separates the denser liquid components of the production fluid sample (for example, water) from the less dense liquid components of the production fluid sample (for example, oil).</p>

<p dir="rtl">20 As shown, vortex 314 can extend partially into the fluid outlet 318 while the kinematics and/or dynamics of gas separation 320 from fluid sample 202 via vortex 314 can require additional surface area and time. In at least one embodiment, the circumference or edge of the fluid outlet 318 at the bottom 317b of the fluid separation means 300 can be hollow, angled, or beveled (as shown in Figure 5) to promote vortex extension 314 at the fluid outlet.</p>

<p dir="rtl">25 312, the angular torque of the coiled fluid sample 202 is converted to a linear torque. This results in an angular torque</p>

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A large gravitational force acts radially on a fluid. As a result, gases 320 can be transported into or otherwise trapped in the gas outlet 316, while the liquid and solid components of the fluid sample 202 can enter the liquid outlet 318.

The gas outlet 316 through the fluid may be coupled to the fluid flow line 216 (Figure 2), and

5 The fluid outlet 318 is through the fluid into the fluid stream 222 (Figure 2). Accordingly, it can then

The gas 320 is transported to the unit 214 (Figure 2) for analysis, while the remaining liquid and solid components of the fluid sample 202 may be transported back to the fluid sample source 202, for example being reintroduced into the fluid return line 130 (Figure 1) to be replenished with the remaining fluid 122.

In some embodiments, the fluid separation device 300 may further include a toroidal flow diverter 322

10 Disposed or otherwise defined on the inner surface of the upper portion 317a of the body 302. The flow diverter 322 may form or otherwise define a concentric ring at an angle of 360° around or within the outlet 312. The annular flow diverter 322 may be positioned at an angle or A cavity to direct or divert the rotating fluid sample 202 into the vortex 314 and thus prevent the fluid sample 202 from entering the gas outlet 320 before separation. To implement this, it can be extended

15 The flow diverter 322 is axially a short distance (i.e., height) from the gas outlet 316 and the liquid outlet

318. The toroidal flow diverter 322 may also be configured to at least partially retain the gases 320 separated from the fluid sample 202 when the gases 320 are trapped or otherwise drawn into the gas outlet 316.

Significantly, the gases 320 (i.e., fluids of low density and/or viscosity) and the liquid 20 and solid components of the fluid sample 202 (i.e., fluids of high density and/or viscosity) exit at the center of the medium.

Fluid Separation 300. This configuration is different from conventional fluid separation methods, which typically extract low- and high-density fluids at different points or locations within the fluid separation medium. Furthermore, in contrast to the majority of fluid separation means, which are long cylindrical assemblies, the fluid separation means 300 currently disclosed uses a more compact “flat” design 25 that can be much smaller than conventional fluid separation means. maybe

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This compact design is particularly useful in off-site environments or applications where space is often limited.

Furthermore, while conventional fluid separation methods require paddles or impellers that help induce fluid movement and separation, the flow of the fluid sample 202 itself provides the fluid energy required to initiate

5 Separation process. More specifically, the circular shape and lower profile of the fluid separation medium 300 induce higher fluid velocities in the fluid sample 202, which characteristically leads to improved liquid/gas separation. As will be noted, generating higher fluid velocities amplifies the attractive forces of the rotating fluid, which also translates into shorter residence times in the fluid separation medium 300. Accordingly, the fluid separation medium 300 may be able to process a sample

10 fluid 202 more quickly than conventional fluid separation methods.

Referring now to Figure 4, and continuing to refer to Figures 3a and 3b, a side cross-sectional view of another illustrative fluid separation medium 400 is shown, according to one or more embodiments.

The fluid separation device 400 may be similar in some respects to the fluid separation device 300 of Figures 3a and 3b and thus may be better understood when referred to, as the figures

15 Similar represent similar items that will not be described in detail again. Furthermore, similarly to the fluid separation means 300 of Figures 3a-3b, the fluid separation means 400 may replace the fluid separation means 212 of Figure 2 described above or may otherwise be the same means.

As shown, the fluid separation means 400 can include a body 302 that defines a flow chamber 20 304 to receive the fluid sample 202 from the fluid circuit of the system 142 (Figure 2). Again, the fluid sample 202 can enter the flow chamber 304 of the separation means The fluid 400 passes through the inlet 306 (not shown) in a direction generally tangential to the body 302 where the fluid sample 202 is forced to rotate around the flow chamber 304, eventually turning inward toward the outlet 312. One or more structures 308 may also be placed in or otherwise Defined by

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The flow chamber 304 is configured to assist the fluid sample 202 to flow circularly and otherwise circumvent the outlet 312.

Similarly to the fluid separation means 300, the fluid separation means 400 can include a gas outlet 316 and a liquid outlet 318. In contrast to the fluid separation means 300, however, it can

5 The gas outlet 316 in the fluid separation device 400 provides a tube that is positioned concentrically in the liquid outlet 318. As a result, gases 320 (i.e., low-density fluids) and the liquid and solid components of the fluid sample 202 (i.e., high-density fluids) exit. From the fluid separation means 400 through the lower portion 317b of the fluid separation means 400 and otherwise in the same linear direction Alternatively, although not shown, a second gas outlet may also be specified in the portion

<p dir="rtl">10 The upper 317a of the body 302 is identical to the gas outlet 316 of the fluid separation device 300. In this</p>

In embodiments, gases 320 can be extracted through both the upper portion 317a and the lower portion 317b of the body 302, without straying from the detection field.

In an illustrative process, the fluid sample 202 enters the flow chamber 304 tangentially and begins to circulate.

The velocity of the fluid sample 202 increases as it approaches the outlet 312, and accordingly acceleration values are obtained

<p dir="rtl">15 Higher Earth's gravity affects the fluid sample 202 which causes the lower density gases 320 trapped in the fluid sample 202 to separate from the denser liquid/solid components. The vortex 314 may form again around the outlet 312 in response to gravitational acceleration values affecting the fluid sample 202. The vortex 314 allows the gases 320 to move or flow toward the center of the flow chamber 304, whereby they are separated from the liquid and solid components of the fluid sample 202.</p>

<p dir="rtl">20 Outlet 312, the angular torque of the swirled fluid sample 202 is converted into a linear torque, thus allowing the separated gases 320 to be transported or otherwise trapped in the gas outlet 316, while the liquid and solid components of the fluid sample 202 enter the liquid outlet 318 located around the gas outlet. 316.</p>

The toroidal flow diverter 322 may also be included in the fluid separation device 400 to direct the rotating fluid sample 25 202 into the vortex 314. The toroidal flow diverter 322 can also assist in maintaining

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The gases 320 separate from the remaining fluid sample parts 202 when the gases 320 are trapped in the gas outlet 316 located below.

The gas outlet 316 through the fluid may be coupled to the fluid flow line 216, as indicated above. Furthermore, as discussed above, in some embodiments a restraining device may be provided

5 Fluid 234 in the fluid flow line 216 to regulate the flow of gases 320 exiting the fluid separating means 400. In at least one embodiment, the fluid restricting device 234 of the fluid separating means 400 can be an operable valve that can be adjusted to accommodate the gas flow 320 With the amount of gas retained in the inlet fluid sample 202.

It will be recognized that the characteristics and previous novelty points of the fluid separation medium 300 are as follows:

<p dir="rtl">10 As noted above, they are equally applicable to the fluid separation media 400. For example, in contrast to the design of conventional fluid separation media, both the gases 320 (i.e., low-density fluids) and the liquid and solid components of the fluid sample 202 (i.e., high density fluids) from the center of the fluid separation medium 400. Furthermore, the compact design and circular shape of the fluid separation medium 400 results in higher fluid velocities in the fluid sample 202, which results in</p>

<p dir="rtl">15 Distinctively improves liquid/gas separation. Accordingly, the fluid separation method 400 may be able to process the fluid sample 202 more quickly than conventional fluid separation methods.</p>

Referring now to Figure 5, and continuing to refer to Figures 3a-3b and 4, a side cross-sectional view of another illustrative fluid separation medium 500 is shown, according to one or more embodiments. The fluid separation means 500 may be similar in some respects to fluid separation means

<p dir="rtl">20 300 and 400 shown in Figures 3a-3b and 4 and thus can be better understood when referred to</p>

to it, as similar numbers again represent similar items that will never be described in detail again. Furthermore, similarly to the fluid separation means 300 and 400 of Figures 3a-3b and 4, the fluid separation means 500 can replace the fluid separation means 212 of Figure 2 described above or otherwise be the same means.

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As shown, the fluid separation method 500 can include a first separation stage 502a and a second separation stage 502b. The first and second separation stages 502a, b may be coupled through fluid through a first liquid outlet 318a defined by the first separation stage 502a. The first separation stage 502a may be similar to the fluid separation method 300 of Figures 3a-3b and thus includes

5 The body 302 defines the flow chamber 304 to receive the fluid sample 202. Again, the fluid sample 202 may enter the flow chamber 304 of the fluid separation device 500 via the inlet 306 (not shown) in a direction generally tangential to the body 302 as the fluid sample is induced 202 on turns inside the flow chamber 304, and finally turning inward toward the exit 312. One or more structures 308 may also be placed in or otherwise identified by the flow chamber 304

<p dir="rtl">10 They are configured to assist the fluid sample 202 in flowing circularly and otherwise circumventing the outlet 312.</p>

At the outlet 312, the vortex 314 forms again and the increased angular torque of the fluid sample 202 allows the low-density gases 320 trapped within to separate from the denser liquid/solid components. Any gases 320 that migrate or flow toward the center of the flow chamber 304 can then be separated and transported

<p dir="rtl">15 Or otherwise trapped in the gas outlet 316 defined through the upper portion 317a of the body 302.</p>

The liquid and solid components of the fluid sample 202 can then exit the first separation stage 502a via the first liquid outlet 318a located at the bottom 317b of the body 302.

The fluid sample 202 may then enter a second separation stage 502b, which may be identical in some respects to the first separation stage 502a. For example, it could include a stage

<p dir="rtl">20 Second separation 502b also includes a body 504 which is circular or disk-shaped such that any fluid sample 202 resulting from the first separation stage 502a can also be induced to rotate or wrap around the center of the fluid separation medium 500. As a result, the vortex 314 formed within the fluid separation medium can extend Separating the fluid 500 downwards and in the second separation stage 502b.</p>

One or more structures 308 may be placed in the second expansion phase 502b and also assist

<p dir="rtl">25 On the surface of the fluid sample 202, cancel the gas separation ground. In the vortex 314 that extends within a phase</p>

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For the second expansion 502b, the low-density gases 320 trapped in the fluid sample 202 can again be separated from the denser liquid/solid components and move toward the center to be transported or otherwise trapped in the gas outlet 316. Any remaining liquid or solid components can emerge in particular With the fluid sample 202 resulting from the second separation stage 502b from the body 504 through an outlet

5 A second fluid 318b is located at the bottom of the body 504. The second fluid outlet 318b through the fluid can be coupled to the fluid stream 222 (Figure 2) and configured to reintroduce the remaining fluid sample 202 into the fluid sample source 202, for example in the fluid return line 130 (Figure 1 (To renew it using the remaining fluid 122.

Noticeably, in the second expansion phase 502b, some of the fluid sample 202 can expand within 10 of the body 504, and thus a lower angular velocity or torque is allowed for the fluid sample 202 without losing its energy.

Rotation derived from convolution within the first phase 502a. Using a lower speed, some of the liquid 506 in the fluid sample 202 can be separated and/or extracted from the fluid sample 202 and exit the body 504 through a third fluid outlet 318c identified or otherwise provided in the side wall of the body 504. As shown, The third fluid outlet 318C can be compared to...

15 Through the fluid stream 508 feeds the fluid 506 into the fluid stream 222 (Figure 2) and is otherwise reconnected with the remaining fluid sample 202 resulting from the second separation stage 502b via the second fluid outlet 318b.

20

While the two separation stages 502a and b are depicted in Figure 5, it will be recognized that more than two separation stages can be used, without falling outside the scope of detection. Furthermore, any combinations described for the fluid separation media 300 and 400 in Figures 3a-3b and 4, respectively, may be applied equally to the fluid separation media 500, complying with the principles of the present disclosure. Furthermore, it will once again be recognized that the above features and novelties of the fluid separation method 300 compared to conventional fluid separation methods, as noted above, are equally applicable to the fluid separation method 500 and will therefore not be described further.

25 Embodiments disclosed herein include:

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a. A fluid extraction system including a fluid circuit coupled through the fluid to a fluid source to receive a fluid sample from the source, a fluid separation means placed in the fluid circuit and including a body defining at least one fluid inlet, a specific flow chamber in the body to receive the fluid sample from at least one fluid inlet, wherein The fluid sample flows and forms a vortex inside the flow chamber and the trapped gases are separated

<p dir="rtl">5 The fluid sample moves toward the center of the vortex, and a specific outlet in the flow chamber provides a gas outlet that traps and removes the gases and a liquid outlet that receives and removes the remaining portion of the fluid sample.</p>

B. A method that includes obtaining a fluid sample from a fluid source, transferring the fluid sample to a fluid circuit of a fluid extraction system, wherein the fluid extraction system includes a fluid separation device placed in the fluid circuit and having a body that defines at least one fluid inlet, a flow chamber, and an outlet, which provides

<p dir="rtl">10 The outlet is a gas outlet and a liquid outlet, receiving the fluid sample into the flow chamber tangential to the body through at least one inlet, pushing the fluid sample onto the rotors inside the flow chamber so that the fluid sample flows and forms a vortex at the outlet, separating gas from the fluid sample in the vortex and trapping the gas It evaporates at the gas outlet, and a remaining portion of the fluid sample is received at the liquid outlet.</p>

Each of the embodiments (a) and (b) may include one or more additional elements

<p dir="rtl">15 The following in any combination: Element 1: Further comprising at least one unit disposed in the fluid circuit to receive and analyze the gases produced by the gas outlet, and a carrier fluid is injected into the fluid circuit to assist in transferring the sample fluid to the unit. Element 2: Further includes one or more energy input means placed in the fluid circuit to introduce energy into the fluid sample to aid in the extraction of gases from the fluid sample. Element 3: Where the energy input means include one or more means</p>

<p dir="rtl">20 Thermal energy provides thermal energy to the fluid sample. Element 4: Wherein the one or more energy input means include at least one acoustic wave treatment device that delivers acoustic vibration to the fluid sample to induce cavity formation. Element 5: Where one or more energy input means are placed at a point in the fluid circuit before the fluid separation means. Element 6: Where at least one or more power input devices are placed on the fluid separation device. Element 7: Where you enter</p>

<p dir="rtl">25 The fluid sample in the flow chamber is tangential to the body through at least one inlet. Item 8:</p>

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It also includes one or more structures disposed in the flow chamber that cause the fluid sample to rotate within the flow chamber and around the outlet. Element 9: Where the body has an upper part and a lower part, the gas outlet is specified in the upper part and the liquid outlet is specified in the lower part. Element 10: Where the body contains an upper part and a lower part, and includes a means

5 The fluid is further separated on a toroidal flow diverter placed on an inner surface of the upper part. Element 11: Wherein the body has an upper portion and a lower portion, the liquid outlet is identified at the lower portion and the gas outlet includes a tube disposed concentrically at the liquid outlet. Element 12: It also includes a unit placed in the fluid circuit to receive and analyze the gases resulting from the gas outlet, where the gas outlet is coupled through the fluid to a fluid flow line extending to the unit, and a means

10 A fluid restriction placed in a fluid flow line to regulate the flow of gases produced by a fluid separation device. Element 13: Wherein the fluid separation means further includes a first separation stage, wherein the body, flow chamber, and fluid outlet represent a first body, first flow chamber, and first fluid outlet, respectively, and each is associated with a first separation stage, wherein the first body includes a part An upper part defines the gas outlet and a lower part defines the first fluid outlet, a second separation stage with a second body and a second coupled flow chamber.

15 Through the fluid in the first flow chamber through the first liquid outlet to receive the remaining part of the fluid sample, where the vortex extends into the second separation stage and additional gases trapped in the remaining part of the fluid sample separate and move towards the center of the vortex to be transported inside the gas outlet, and a second liquid outlet specified in A lower part of the second body, where the remaining part of the fluid sample exits the second separation stage through the second fluid outlet. Element 14: Further including a third liquid outlet specified in

20 A side wall of the second body, where the remaining part of the fluid sample expands in the second separation stage and the liquid is separated into the second separation stage and exits the second body through the third liquid outlet. Element 15: Where the sample fluid is a fluid selected from the group consisting of drilling fluid, completion fluid, fracturing fluid, wellbore treatment fluid, production fluid, storage fluid, gas, oil, water, and any combination thereof.

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Element 16: It also includes injecting a carrier fluid into the fluid circuit, transferring gases to a unit placed in the fluid circuit using the carrier fluid, and receiving and analyzing the gases resulting from the gas outlet using the unit. Element 17: Further including introducing energy into the fluid sample using one or more energy input means placed in the fluid circuit. Element 18: Where it includes means

5 Introducing one or more energy by means of thermal energy, where the method also includes transferring thermal energy to the fluid sample using a means of thermal energy. Element 19: It also includes maintaining the temperature of the fluid sample at a predetermined gas extraction temperature using a thermal energy method. Element 20: Wherein the one or more energy input means include at least one sound wave treatment means, wherein the method also includes introducing sound vibration into

<p dir="rtl">10 The fluid sample using at least one ultrasonic treatment method, and the formation of cavities in the fluid sample using acoustic vibration. Element 21: Wherein the body has an upper portion and a lower portion, wherein the method further comprises diverting the fluid sample within the vortex using a toroidal flow diverter positioned on an internal surface of the upper portion. Element 22: Where the body contains an upper part and a lower part, the gas outlet is specified in the upper part and the liquid outlet is specified</p>

<p dir="rtl">15 In the lower part, where the method also includes extracting the gases resulting from the fluid separation method through the upper part of the body, and extracting the remaining part of the fluid sample through the lower part of the body. Element 23: Where the body contains an upper part and a lower part and the liquid outlet is located in the lower part, and wherein trapping gases in the gas outlet includes trapping the gases in a tube placed concentrically in the liquid outlet such that the gases and the remaining part of a sample emerge</p>

<p dir="rtl">20 The fluid from the fluid separation medium in the same linear direction. Element 24: Where the gas outlet is coupled through the fluid to a fluid flow line extending towards a unit placed in the fluid circuit, where the method also includes regulating the flow of gases resulting from the fluid separation means using a fluid restriction means placed in the fluid flow line. Element 25: where body, flow chamber, and fluid outlet represent a first body, first flow chamber, and first fluid outlet, respectively, each associated with a separation stage</p>

<p dir="rtl">25 A first for a fluid extraction system, where the first body includes an upper part that determines the gas outlet and a lower part that determines the first fluid outlet, where the method also includes receiving the remaining part of a sample</p>

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The fluid is in a second separation stage of the fluid extraction system, wherein the second separation stage contains a second body and a second flow chamber coupled through the fluid to the first flow chamber via the first liquid outlet, where the vortex extends within the second separation stage via the first liquid outlet, allowing additional gases trapped in The remaining portion of the fluid sample separates and moves toward the center of the second flow chamber,

5 Detaining the additional gases in the gas outlet, and extracting the remaining part of the fluid sample from the second separation stage through a second liquid outlet specified in a lower part of the second body. Element 26: It also includes expanding the remaining portion of the fluid sample in the second separation stage, separating the liquid from the remaining portion of the fluid sample present in the second separation stage, and extracting the liquid from the second body through a third liquid outlet specified in a side wall of the second body.

<p dir="rtl">10 Thus, the systems and methods disclosed are well adapted to obtain the stated objectives and advantages as well as those inherent in them. The 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, there are no restrictions imposed on the details of construction or design herein, otherwise stated</p>

<p dir="rtl">15 Described in the safeguards below. Therefore, it will be shown that specific illustrative embodiments disclosed above can be varied, combined, or modified, and all such variations are within the scope of the present disclosure. The systems and methods illustratively disclosed herein may be adequately implemented in the absence of any item not specifically disclosed herein and/or any optional item disclosed herein. While the compositions and methods are described in terms of “comprising,” “containing.”</p>

<p dir="rtl">20 Compositions and methods may also "consist primarily" or "comprise" a plurality of components or steps. All of the figures and ranges disclosed above can vary by some amount. Wherever a numeric range with a minimum and an upper limit is disclosed, any number and any contained range that falls within the range are specifically disclosed, you should be aware that each range of values (in the form of "from about A to about B", or... In a way</p>

<p dir="rtl">25 Equivalently, "from about A to B", or equivalently, "from about A to B" (which is disclosed herein)</p>

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Shows which number and range are included in the broader range of values. Also, the terms contained in the protective elements have their plain and simple meaning unless the opposite is clearly and publicly specified by the patentee. Furthermore, indefinite articles, as used in protective items, are defined here as meaning one or more of the items they refer to. In case there is any conflict in

<p dir="rtl">5 For uses of a word or term in this standard and one or more patents or other documents that may be incorporated herein by reference, definitions consistent with this standard should be used.</p>

As used here, the phrase “at least one of” preceding a series of items, together with the terms “and” or “or” to separate any of the items, modifies the list as a whole, rather than each member of the list (i.e. each item). “At least one of” means including at least one of any of the 10 elements, and/or at least one of any combination of the elements, and/or at least one of each of

Elements. For example, each of the phrases “at least one of A, B, and C” or “at least one of A, B, or C” refers to only A, only B, or only C; Any combination of A, B and C; and/or at least one each of A, B and C.

Bookmark drawings

<p dir="rtl">15 Figure 2</p>

A to the fluid return line (Figure 1)

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